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Hamilton Spectator
01-08-2025
- Business
- Hamilton Spectator
TransAlta Reports Strong Second Quarter 2025 Results, Advancement of Strategic Priorities and Reaffirms Guidance
CALGARY, Alberta, Aug. 01, 2025 (GLOBE NEWSWIRE) — TransAlta Corporation (TransAlta or the Company) (TSX: TA) (NYSE: TAC) today reported its financial results for the second quarter ended June 30, 2025. 'Our strong second quarter results illustrate the value of our diversified fleet and exceptional operational performance. Our Alberta portfolio's hedging strategy and active asset optimization continued to generate realized prices well above spot prices while environmental credits generated by our hydro and wind assets significantly offset our gas fleet's carbon price compliance obligation. While we continue to navigate a challenging Alberta price environment, our assets continue to perform well, and we remain confident in achieving our 2025 Outlook,' said John Kousinioris, President and Chief Executive Officer. 'Our team remains focused on advancing our strategic priorities. We are pleased with the progress on our Alberta data centre strategy and the associated negotiations, which now reflect the Alberta Electric System Operator's (AESO) approach to large load integration. The AESO currently expects Demand Transmission Service contracts to be executed in mid-September, which will secure each proponent's access to system capacity. We continue to work closely with our counterparties and are progressing towards the execution of a data centre memorandum of understanding in relation to our system capacity allocation,' added Mr. Kousinioris. 'Finally, we continue to progress negotiations on conversion opportunities at Centralia and are working towards executing a definitive agreement later this year with our customer for the full capacity of Centralia Unit 2.' Second Quarter 2025 Highlights Second Quarter 2025 Operational and Financial Highlights Segmented Financial Performance Key Business Developments Credit Facility Extension On July 16, 2025, the Company executed agreements to extend committed credit facilities totalling $2.1 billion with a syndicate of lenders. The revised agreements extend the maturity dates of the syndicated credit facility from June 30, 2028 to June 30, 2029 and the bilateral credit facilities from June 30, 2026 to June 30, 2027. Divestiture of Poplar Hill During the second quarter of 2025, the Company signed an agreement for the divestiture of the 48 MW Poplar Hill asset, as required by the consent agreement with the federal Competition Bureau and pursuant to the terms of the acquisition of Heartland Generation. Energy Capital Partners will be entitled to receive the proceeds from the sale of Poplar Hill, net of certain adjustments, following completion of the divestiture. Recontracting of Ontario Wind Facilities During the second quarter of 2025, the Company successfully recontracted its Melancthon 1, Melancthon 2 and Wolfe Island wind facilities through the Ontario Independent Electricity System Operator Five-Year Medium-Term 2 Energy Contract (MT2e). MT2e will replace current energy contracts for the three wind facilities when they expire, extending the contract dates until April 30, 2031, for Melancthon 1 and April 30, 2034, for Melancthon 2 and Wolfe Island. Normal Course Issuer Bid (NCIB) On May 27, 2025, the Company announced that it had received approval from the Toronto Stock Exchange to repurchase up to a maximum of 14 million common shares during the 12-month period that commenced May 31, 2025 and will terminate on May 30, 2026. On Feb. 19, 2025, the Company announced it was allocating up to $100 million to be returned to shareholders in the form of share repurchases. During the six months ended June 30, 2025, the Company purchased and cancelled a total of 1,932,800 common shares at an average price of $12.42 per common share, for a total cost of $24 million, including taxes. Conference call and webcast TransAlta will host a conference call and webcast at 9:00 a.m. MST (11:00 a.m. EST) today, August 1, 2025, to discuss our second quarter 2025 results. The call will begin with comments from John Kousinioris, President and Chief Executive Officer, and Joel Hunter, EVP Finance and Chief Financial Officer, followed by a question-and-answer period. Second Quarter 2025 Conference Call Webcast link: To access the conference call via telephone, please register ahead of time using the call link here: . Once registered, participants will have the option of 1) dialing into the call from their phone (via a personalized PIN); or 2) clicking the 'Call Me' option to receive an automated call directly to their phone. If you are unable to participate in the call, the replay will be accessible at . A transcript of the broadcast will be posted on TransAlta's website once it becomes available. Related Materials Related materials, including the consolidated financial statements and Management's Discussion and Analysis (MD&A) will be available on the Investor Centre section of TransAlta's website at and and have been filed under TransAlta Corporation's profile on SEDAR+ at and with the U.S. Securities and Exchange Commission on EDGAR at . Notes 1. These items (Adjusted EBITDA, adjusted earnings (loss) before income taxes, adjusted net earnings (loss) after income taxes attributable to common shareholders, funds from operations, free cash flow, adjusted net earnings attributable to common shareholders per share, funds from operations (FFO) per share and free cash flow (FCF) per share) are non-IFRS measures, which are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Presenting these items from period to period provides management and investors with the ability to evaluate earnings (loss) trends more readily in comparison with prior periods' results. Please refer to the Non-IFRS financial measures section of this earnings release for further discussion of these items, including, where applicable, reconciliations to measures calculated in accordance with IFRS. 2. During the first quarter of 2025, our Adjusted EBITDA composition was amended to exclude the impact of realized gain (loss) on closed exchange positions and Australian interest income. Therefore, the Company has applied this composition to all previously reported periods. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. Non-IFRS financial measures We use a number of financial measures to evaluate our performance and the performance of our business segments, including measures and ratios that are presented on a non-IFRS basis, as described below. Unless otherwise indicated, all amounts are in Canadian dollars and have been derived from our consolidated financial statements prepared in accordance with IFRS. We believe that these non-IFRS amounts, measures and ratios, read together with our IFRS amounts, provide readers with a better understanding of how management assesses results. Non-IFRS amounts, measures and ratios do not have standardized meanings under IFRS. They are unlikely to be comparable to similar measures presented by other companies and should not be viewed in isolation from, as an alternative to, or more meaningful than, our IFRS results. We calculate adjusted measures by adjusting certain IFRS measures for certain items we believe are not reflective of our ongoing operations in the period. Except as otherwise described, these adjusted measures are calculated on a consistent basis from period to period and are adjusted for specific items in each period, unless stated otherwise. Adjusted EBITDA Each business segment assumes responsibility for its operating results measured by adjusted EBITDA. Adjusted EBITDA is an important metric for management that represents our core operational results. During the first quarter of 2025, our adjusted EBITDA composition was amended to remove the impact of realized gain (loss) on closed exchange positions, which was included in adjusted EBITDA composition until the fourth quarter of 2024. The adjustment was intended to explain a timing difference between our internally and externally reported results and was useful at a time when markets were more volatile. The impact of realized gain (loss) on closed exchange positions was removed to simplify our reporting. Accordingly, the Company has applied this composition to all previously reported periods. During the first quarter of 2025, our adjusted EBITDA composition was amended to remove the impact of Australian interest income, which was included in adjusted EBITDA composition until the fourth quarter of 2024. Initially, on the commissioning of the South Hedland facility in July 2017, we prepaid approximately $74 million of electricity transmission and distribution costs. Interest income, which was recorded on the prepaid funds, was reclassified as a reduction in the transmission and distribution costs expensed each period to reflect the net cost to the business. The impact of Australian interest income was removed to simplify our reporting since the amounts were not material. Accordingly, the Company has applied this composition to all previously reported periods. Interest, taxes, depreciation and amortization are not included, as differences in accounting treatment may distort our core business results. In addition, certain reclassifications and adjustments are made to better assess results, excluding those items that may not be reflective of ongoing business performance. This presentation may facilitate the readers' analysis of trends. The most directly comparable IFRS measure is earnings before income taxes. Adjusted Revenue Adjusted Revenues is Revenues (the most directly comparable IFRS measure) adjusted to exclude: The impact of unrealized mark-to-market gains or losses and unrealized foreign exchange gains or losses on commodity transactions. Certain assets that we own in Canada and Western Australia are fully contracted and recorded as finance leases under IFRS. We believe that it is more appropriate to reflect the payments we receive under the contracts as a capacity payment in our revenues instead of as finance lease income and a decrease in finance lease receivables. Revenues from the Planned Divestitures as they do not reflect ongoing business performance. Adjusted Fuel and Purchased Power Adjusted Fuel and Purchased Power is Fuel and Purchased Power (the most directly comparable IFRS measure) adjusted to exclude fuel and purchased power from the Planned Divestitures as it does not reflect ongoing business performance. Adjusted Gross Margin Adjusted gross margin is calculated as adjusted revenues less adjusted fuel and purchased power and carbon compliance costs, where adjustments to revenue or fuel and purchased power were applied as stated above. The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment. The most directly comparable IFRS measure is gross margin in the consolidated statement of earnings. Adjusted OM&A Adjusted OM&A is OM&A (the most directly comparable IFRS measure) adjusted to exclude: Acquisition-related transaction and restructuring costs, mainly comprised of severance, legal and consultant fees as these do not reflect ongoing business performance. ERP integration costs representing planning, design and integration costs of upgrades to the existing ERP system as they represent project costs that do not occur on a regular basis, and therefore do not reflect ongoing performance. OM&A from the Planned Divestitures as it does not reflect ongoing business performance. Adjusted Net Other Operating Income Adjusted Net Other Operating Income is Net Other Operating Income (the most directly comparable IFRS measure) adjusted to exclude insurance recoveries related to the Kent Hills replacement costs of the tower collapse as these relate to investing activities and are not reflective of ongoing business performance. Adjustments to Earnings (Loss) in Addition to Interest, Taxes, Depreciation and Amortization Adjustments for Equity-Accounted Investments Adjusted Earnings (Loss) before income taxes Adjusted earnings (loss) before income taxes represents segmented earnings (loss) adjusted for certain items that we believe do not reflect ongoing business performance and is an important metric for evaluating performance trends in each segment. For details of the adjustments made to earnings (loss) before income taxes (the most directly comparable IFRS measure) to calculate adjusted earnings (loss) before income taxes, refer to the Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment section of the MD&A. Adjusted Net Earnings (Loss) attributable to common shareholders Adjusted net earnings (loss) attributable to common shareholders represents net earnings (loss) attributable to common shareholders adjusted for specific reclassifications and adjustments and their tax impact, and is an important metric for evaluating performance. For details of the reclassifications and adjustments made to net earnings (loss) attributable to common shareholders (the most directly comparable IFRS measure), please refer to the reconciliation of net earnings (loss) to adjusted net earnings (loss) attributable to common shareholders in the Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment section of the MD&A. Adjusted Net Earnings (Loss) per common share attributable to common shareholders Adjusted net earning (loss) per common share attributable to common shareholders is calculated as adjusted net earnings (loss) attributable to common shareholders divided by a weighted average number of common shares outstanding during the period. The measure is useful in showing the earnings per common share for our core operational results as it excludes the impact of items that do not reflect an ongoing business performance. Adjusted net earnings (loss) attributable per common share is a non-IFRS ratio and the most directly comparable IFRS measure is net income (loss) per common share attributable to common shareholders. Refer to the reconciliation of earnings (loss) before income taxes to adjusted net earnings (loss) attributable to common shareholders in the Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment section of the MD&A. Funds From Operations (FFO) Represents a proxy for cash generated from operating activities before changes in working capital and provides the ability to evaluate cash flow trends in comparison with results from prior periods. FFO is calculated as cash flow from operating activities before changes in working capital and is adjusted for transactions and amounts that the Company believes are not representative of ongoing cash flows from operations. Free Cash Flow (FCF) Represents the amount of cash that is available to invest in growth initiatives, make scheduled principal debt repayments, repay maturing debt, pay common share dividends or repurchase common shares and provides the ability to evaluate cash flow trends in comparison with the results from prior periods. Changes in working capital are excluded so that FFO and FCF are not distorted by changes that we consider temporary in nature, reflecting, among other things, the impact of seasonal factors and timing of receipts and payments. Non-IFRS Ratios FFO per share, FCF per share and adjusted net debt to adjusted EBITDA are non-IFRS ratios that are presented in the MD&A. Refer to the Reconciliation of Cash Flow from Operations to FFO and FCF and Key Non-IFRS Financial Ratios sections of the MD&A for additional information. Net Interest Expense Net interest expense is calculated as total interest expense less total interest income and non-cash items. For detailed calculation refer to the table in the Reconciliation of Adjusted EBITDA to FFO and FCF section of this MD&A. Net Interest expense is a proxy for the actual cash interest paid that approximates the cash outflow in the FFO and FCF calculation. The most directly comparable IFRS measure is total interest expense. FFO per share and FCF per share FFO per share and FCF per share are calculated using the weighted average number of common shares outstanding during the period. FFO per share and FCF per share are non-IFRS ratios. Supplementary financial measures include available liquidity, carbon compliance per MWh, fuel cost per MWh, hedged power price average per MWh, realized foreign exchange loss, sustaining capital expenditures, the Alberta electricity portfolio metrics and unrealized foreign exchange loss (gain). Reconciliation of these non-IFRS financial measures to the most comparable IFRS measure are provided below. Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the three months ended June 30, 2025: The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the three months ended June 30, 2024: The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the six months ended June 30, 2025: The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the six months ended June 30, 2024: Reconciliation of Earnings Before Income Taxes to Adjusted Net Earnings attributable to common shareholders The following table reflects reconciliation of (loss) earnings before income taxes to adjusted net earnings attributable to common shareholders for the three and six months ended June 30, 2025 and June 30, 2024: Reconciliation of cash flow from operations to FFO and FCF The table below reconciles our cash flow from operating activities to our FFO and FCF: The table below provides a reconciliation of our adjusted EBITDA to our FFO and FCF: Net interest expense in the reconciliation of our adjusted EBITDA to our FFO and FCF is calculated as follows: TransAlta is in the process of filing its unaudited interim Consolidated Financial Statements and accompanying notes, as well as the associated Management's Discussion & Analysis (MD&A). These documents will be available today on the Investors section of TransAlta's website at or through SEDAR at . About TransAlta Corporation: TransAlta owns, operates and develops a diverse fleet of electrical power generation assets in Canada, the United States and Australia with a focus on long-term shareholder value. TransAlta provides municipalities, medium and large industries, businesses and utility customers with affordable, energy efficient and reliable power. Today, TransAlta is one of Canada's largest producers of wind power and Alberta's largest producer of thermal generation and hydro-electric power. For over 114 years, TransAlta has been a responsible operator and a proud member of the communities where we operate and where our employees work and live. TransAlta aligns its corporate goals with the UN Sustainable Development Goals and the Future-Fit Business Benchmark, which also defines sustainable goals for businesses. Our reporting on climate change management has been guided by the International Financial Reporting Standards (IFRS) S2 Climate-related Disclosures Standard and the Task Force on Climate-related Financial Disclosures (TCFD) recommendations. TransAlta has achieved a 70 per cent reduction in GHG emissions or 22.7 million tonnes CO2e since 2015 and received an upgraded MSCI ESG rating of AA. For more information about TransAlta, visit our web site at . Cautionary Statement Regarding Forward-Looking Information This news release includes 'forward-looking information,' within the meaning of applicable Canadian securities laws, and 'forward-looking statements,' within the meaning of applicable United States securities laws, including the Private Securities Litigation Reform Act of 1995 (collectively referred to herein as 'forward-looking statements'). Forward-looking statements are not facts, but only predictions and generally can be identified by the use of statements that include phrases such as 'may', 'will', 'can', 'could', 'would', 'shall', 'believe', 'expect', 'estimate', 'anticipate', 'intend', 'plan', 'forecast', 'foresee', 'potential', 'enable', 'continue' or other comparable terminology. These statements are not guarantees of our future performance, events or results and are subject to risks, uncertainties and other important factors that could cause our actual performance, events or results to be materially different from those set out in or implied by the forward-looking statements. In particular, this news release contains forward-looking statements about the following, among other things: the strategic objectives of the Company and that the execution of the Company's strategy will realize value for shareholders; our capital allocation and financing strategy; our sustainability goals and targets, including those in our 2024 Sustainability Report; our 2025 Outlook; our financial and operational performance, including our hedge position; optimizing and diversifying our existing assets; the increasingly contracted nature of our fleet; expectations about strategies for growth and expansion; data centre opportunities, including the AESO's expectation around the timing of execution of Demand Transmission Service contracts and entering into a data centre memorandum of understanding; opportunities for Centralia redevelopment, including the execution of a definitive agreement with our customer for the full capacity of Centralia Unit 2; expectations regarding ongoing and future transactions, including the sale of Poplar Hill; expected costs and schedules for planned projects; expected regulatory processes and outcomes, including in relation to the Alberta restructured energy market; the completion and closing of acquisition and divestiture transactions which are subject to customary closing terms and conditions, the power generation industry and the supply and demand of electricity; the cyclicality of our business; expected outcomes with respect to legal proceedings; the expected impact of future tax and accounting changes; and expected industry, market and economic conditions. The forward-looking statements contained in this news release are based on many assumptions including, but not limited to, the following: no significant changes to applicable laws and regulations; no unexpected delays in obtaining required regulatory approvals; no material adverse impacts to investment and credit markets; no significant changes to power price and hedging assumptions; no significant changes to gas commodity price assumptions and transport costs; no significant changes to interest rates; no significant changes to the demand and growth of renewables generation; no significant changes to the integrity and reliability of our facilities; no significant changes to the Company's debt and credit ratings; no unforeseen changes to economic and market conditions; no significant event occurring outside the ordinary course of business; and realization of expected impacts from ongoing and future transactions. These assumptions are based on information currently available to TransAlta, including information obtained from third-party sources. Actual results may differ materially from those predicted. Factors that may adversely impact what is expressed or implied by forward-looking statements contained in this news release include, but are not limited to: fluctuations in power prices; changes in supply and demand for electricity; our ability to contract our electricity generation for prices that will provide expected returns; our ability to replace contracts as they expire; risks associated with development projects and acquisitions; failure to complete divestitures on the terms and conditions specified or at all; any difficulty raising needed capital in the future on reasonable terms or at all; our ability to achieve our targets relating to ESG; long-term commitments on gas transportation capacity that may not be fully utilized over time; changes to the legislative, regulatory and political environments; environmental requirements and changes in, or liabilities under, these requirements; operational risks involving our facilities, including unplanned outages and equipment failure; disruptions in the transmission and distribution of electricity; reductions in production; impairments and/or writedowns of assets; adverse impacts on our information technology systems and our internal control systems, including increased cybersecurity threats; commodity risk management and energy trading risks; reduced labour availability and ability to continue to staff our operations and facilities; disruptions to our supply chains; climate-change related risks; reductions to our generating units' relative efficiency or capacity factors; general economic risks, including deterioration of equity and debt markets, increasing interest rates or rising inflation; general domestic and international economic and political developments, including potential trade tariffs; industry risk and competition; counterparty credit risk; inadequacy or unavailability of insurance coverage; increases in the Company's income taxes and any risk of reassessments; legal, regulatory and contractual disputes and proceedings involving the Company; reliance on key personnel; and labour relations matters. The foregoing risk factors, among others, are described in further detail under the heading 'Governance and Risk Management' in the MD&A, which section is incorporated by reference herein. Readers are urged to consider these factors carefully when evaluating the forward-looking statements and are cautioned not to place undue reliance on them. The forward-looking statements included in this news release are made only as of the date hereof and we do not undertake to publicly update these forward-looking statements to reflect new information, future events or otherwise, except as required by applicable laws. The purpose of the financial outlooks contained herein is to give the reader information about management's current expectations and plans and readers are cautioned that such information may not be appropriate for other purposes. Note: All financial figures are in Canadian dollars unless otherwise indicated. For more information:
Yahoo
01-08-2025
- Business
- Yahoo
TransAlta Reports Strong Second Quarter 2025 Results, Advancement of Strategic Priorities and Reaffirms Guidance
CALGARY, Alberta, Aug. 01, 2025 (GLOBE NEWSWIRE) -- TransAlta Corporation (TransAlta or the Company) (TSX: TA) (NYSE: TAC) today reported its financial results for the second quarter ended June 30, 2025. 'Our strong second quarter results illustrate the value of our diversified fleet and exceptional operational performance. Our Alberta portfolio's hedging strategy and active asset optimization continued to generate realized prices well above spot prices while environmental credits generated by our hydro and wind assets significantly offset our gas fleet's carbon price compliance obligation. While we continue to navigate a challenging Alberta price environment, our assets continue to perform well, and we remain confident in achieving our 2025 Outlook," said John Kousinioris, President and Chief Executive Officer. "Our team remains focused on advancing our strategic priorities. We are pleased with the progress on our Alberta data centre strategy and the associated negotiations, which now reflect the Alberta Electric System Operator's (AESO) approach to large load integration. The AESO currently expects Demand Transmission Service contracts to be executed in mid-September, which will secure each proponent's access to system capacity. We continue to work closely with our counterparties and are progressing towards the execution of a data centre memorandum of understanding in relation to our system capacity allocation," added Mr. Kousinioris. "Finally, we continue to progress negotiations on conversion opportunities at Centralia and are working towards executing a definitive agreement later this year with our customer for the full capacity of Centralia Unit 2." Second Quarter 2025 Highlights Achieved strong operational availability of 91.6 per cent in 2025, compared to 90.8 per cent in 2024 Adjusted EBITDA(1) of $349 million, compared to $316 million for the same period in 2024 Free Cash Flow (FCF)(1) of $177 million, or $0.60 per share, remained consistent with the same period in 2024 Adjusted earnings before income taxes(1) of $122 million, or $0.41 per share, compared to $112 million, or $0.37 per share, for the same period in 2024 Cash flow from operating activities of $157 million, or $0.53 per share, compared to $108 million, or $0.36 per share, from the same period in 2024 Net loss attributable to common shareholders(1) of $112 million, or $0.38 per share, compared to net earnings attributable to common shareholders of $56 million, or $0.18 per share, for the same period in 2024 Second Quarter 2025 Operational and Financial Highlights $ millions, unless otherwise stated Three Months Ended Six Months Ended June 30,2025 June 30,2024 June 30,2025 June 30,2024 Operational information Availability (%) 91.6 90.8 93.3 91.5 Production (GWh) 4,813 4,781 11,645 10,959 Select financial information Revenues 433 582 1,191 1,529 Adjusted EBITDA(1) 349 316 619 658 Adjusted earnings before income taxes(1) 122 112 150 256 (Loss) earnings before income taxes (95 ) 94 (46 ) 361 Adjusted net earnings after taxes attributable to common shareholders(1) 54 70 84 197 Net (loss) earnings attributable to common shareholders (112 ) 56 (66 ) 278 Cash flows Cash flow from operating activities 157 108 164 352 Funds from operations(1) 252 236 431 490 Free cash flow(1) 177 177 316 398 Per share Adjusted net earnings attributable to common shareholders per share(1) 0.18 0.23 0.28 0.64 Net (loss) earnings per share attributable to common shareholders, basic and diluted (0.38 ) 0.18 (0.22 ) 0.91 Cash flow from operating activities per share 0.53 0.36 0.55 1.15 Funds from operations per share(1) 0.85 0.78 1.45 1.60 FCF per share(1) 0.60 0.58 1.06 1.30 Dividends declared per common share — 0.06 0.07 0.06 Weighted average number of common shares outstanding 297 303 297 306 Segmented Financial Performance $ millions Three Months Ended Six Months Ended June 30,2025 June 30,2024 June 30,2025 June 30,2024 Hydro 126 83 173 170 Wind and Solar 89 88 191 177 Gas 128 142 232 267 Energy Transition 19 2 56 29 Energy Marketing 26 39 47 78 Corporate (39 ) (38 ) (80 ) (63 ) Total adjusted EBITDA(1)(2) 349 316 619 658 Adjusted earnings before income taxes(1) 122 112 150 256 (Loss) earnings before income taxes (95 ) 94 (46 ) 361 Adjusted net earnings attributable to common shareholders(1) 54 70 84 197 Net (loss) earnings attributable to common shareholders (112 ) 56 (66 ) 278 Key Business Developments Credit Facility Extension On July 16, 2025, the Company executed agreements to extend committed credit facilities totalling $2.1 billion with a syndicate of lenders. The revised agreements extend the maturity dates of the syndicated credit facility from June 30, 2028 to June 30, 2029 and the bilateral credit facilities from June 30, 2026 to June 30, 2027. Divestiture of Poplar Hill During the second quarter of 2025, the Company signed an agreement for the divestiture of the 48 MW Poplar Hill asset, as required by the consent agreement with the federal Competition Bureau and pursuant to the terms of the acquisition of Heartland Generation. Energy Capital Partners will be entitled to receive the proceeds from the sale of Poplar Hill, net of certain adjustments, following completion of the divestiture. Recontracting of Ontario Wind Facilities During the second quarter of 2025, the Company successfully recontracted its Melancthon 1, Melancthon 2 and Wolfe Island wind facilities through the Ontario Independent Electricity System Operator Five-Year Medium-Term 2 Energy Contract (MT2e). MT2e will replace current energy contracts for the three wind facilities when they expire, extending the contract dates until April 30, 2031, for Melancthon 1 and April 30, 2034, for Melancthon 2 and Wolfe Island. Normal Course Issuer Bid (NCIB) On May 27, 2025, the Company announced that it had received approval from the Toronto Stock Exchange to repurchase up to a maximum of 14 million common shares during the 12-month period that commenced May 31, 2025 and will terminate on May 30, 2026. On Feb. 19, 2025, the Company announced it was allocating up to $100 million to be returned to shareholders in the form of share repurchases. During the six months ended June 30, 2025, the Company purchased and cancelled a total of 1,932,800 common shares at an average price of $12.42 per common share, for a total cost of $24 million, including taxes. Conference call and webcast TransAlta will host a conference call and webcast at 9:00 a.m. MST (11:00 a.m. EST) today, August 1, 2025, to discuss our second quarter 2025 results. The call will begin with comments from John Kousinioris, President and Chief Executive Officer, and Joel Hunter, EVP Finance and Chief Financial Officer, followed by a question-and-answer period. Second Quarter 2025 Conference Call Webcast link: To access the conference call via telephone, please register ahead of time using the call link here: Once registered, participants will have the option of 1) dialing into the call from their phone (via a personalized PIN); or 2) clicking the 'Call Me' option to receive an automated call directly to their phone. If you are unable to participate in the call, the replay will be accessible at A transcript of the broadcast will be posted on TransAlta's website once it becomes available. Related Materials Related materials, including the consolidated financial statements and Management's Discussion and Analysis (MD&A) will be available on the Investor Centre section of TransAlta's website at and and have been filed under TransAlta Corporation's profile on SEDAR+ at and with the U.S. Securities and Exchange Commission on EDGAR at Notes 1. These items (Adjusted EBITDA, adjusted earnings (loss) before income taxes, adjusted net earnings (loss) after income taxes attributable to common shareholders, funds from operations, free cash flow, adjusted net earnings attributable to common shareholders per share, funds from operations (FFO) per share and free cash flow (FCF) per share) are non-IFRS measures, which are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Presenting these items from period to period provides management and investors with the ability to evaluate earnings (loss) trends more readily in comparison with prior periods' results. Please refer to the Non-IFRS financial measures section of this earnings release for further discussion of these items, including, where applicable, reconciliations to measures calculated in accordance with IFRS.2. During the first quarter of 2025, our Adjusted EBITDA composition was amended to exclude the impact of realized gain (loss) on closed exchange positions and Australian interest income. Therefore, the Company has applied this composition to all previously reported periods. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. Non-IFRS financial measures We use a number of financial measures to evaluate our performance and the performance of our business segments, including measures and ratios that are presented on a non-IFRS basis, as described below. Unless otherwise indicated, all amounts are in Canadian dollars and have been derived from our consolidated financial statements prepared in accordance with IFRS. We believe that these non-IFRS amounts, measures and ratios, read together with our IFRS amounts, provide readers with a better understanding of how management assesses results. Non-IFRS amounts, measures and ratios do not have standardized meanings under IFRS. They are unlikely to be comparable to similar measures presented by other companies and should not be viewed in isolation from, as an alternative to, or more meaningful than, our IFRS results. We calculate adjusted measures by adjusting certain IFRS measures for certain items we believe are not reflective of our ongoing operations in the period. Except as otherwise described, these adjusted measures are calculated on a consistent basis from period to period and are adjusted for specific items in each period, unless stated otherwise. Adjusted EBITDA Each business segment assumes responsibility for its operating results measured by adjusted EBITDA. Adjusted EBITDA is an important metric for management that represents our core operational results. During the first quarter of 2025, our adjusted EBITDA composition was amended to remove the impact of realized gain (loss) on closed exchange positions, which was included in adjusted EBITDA composition until the fourth quarter of 2024. The adjustment was intended to explain a timing difference between our internally and externally reported results and was useful at a time when markets were more volatile. The impact of realized gain (loss) on closed exchange positions was removed to simplify our reporting. Accordingly, the Company has applied this composition to all previously reported periods. During the first quarter of 2025, our adjusted EBITDA composition was amended to remove the impact of Australian interest income, which was included in adjusted EBITDA composition until the fourth quarter of 2024. Initially, on the commissioning of the South Hedland facility in July 2017, we prepaid approximately $74 million of electricity transmission and distribution costs. Interest income, which was recorded on the prepaid funds, was reclassified as a reduction in the transmission and distribution costs expensed each period to reflect the net cost to the business. The impact of Australian interest income was removed to simplify our reporting since the amounts were not material. Accordingly, the Company has applied this composition to all previously reported periods. Interest, taxes, depreciation and amortization are not included, as differences in accounting treatment may distort our core business results. In addition, certain reclassifications and adjustments are made to better assess results, excluding those items that may not be reflective of ongoing business performance. This presentation may facilitate the readers' analysis of trends. The most directly comparable IFRS measure is earnings before income taxes. Adjusted Revenue Adjusted Revenues is Revenues (the most directly comparable IFRS measure) adjusted to exclude: The impact of unrealized mark-to-market gains or losses and unrealized foreign exchange gains or losses on commodity transactions. Certain assets that we own in Canada and Western Australia are fully contracted and recorded as finance leases under IFRS. We believe that it is more appropriate to reflect the payments we receive under the contracts as a capacity payment in our revenues instead of as finance lease income and a decrease in finance lease receivables. Revenues from the Planned Divestitures as they do not reflect ongoing business performance. Adjusted Fuel and Purchased Power Adjusted Fuel and Purchased Power is Fuel and Purchased Power (the most directly comparable IFRS measure) adjusted to exclude fuel and purchased power from the Planned Divestitures as it does not reflect ongoing business performance. Adjusted Gross Margin Adjusted gross margin is calculated as adjusted revenues less adjusted fuel and purchased power and carbon compliance costs, where adjustments to revenue or fuel and purchased power were applied as stated above. The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment. The most directly comparable IFRS measure is gross margin in the consolidated statement of earnings. Adjusted OM&A Adjusted OM&A is OM&A (the most directly comparable IFRS measure) adjusted to exclude: Acquisition-related transaction and restructuring costs, mainly comprised of severance, legal and consultant fees as these do not reflect ongoing business performance. ERP integration costs representing planning, design and integration costs of upgrades to the existing ERP system as they represent project costs that do not occur on a regular basis, and therefore do not reflect ongoing performance. OM&A from the Planned Divestitures as it does not reflect ongoing business performance. Adjusted Net Other Operating Income Adjusted Net Other Operating Income is Net Other Operating Income (the most directly comparable IFRS measure) adjusted to exclude insurance recoveries related to the Kent Hills replacement costs of the tower collapse as these relate to investing activities and are not reflective of ongoing business performance. Adjustments to Earnings (Loss) in Addition to Interest, Taxes, Depreciation and Amortization Fair value change in contingent consideration payable is not included as it is not reflective of ongoing business performance. Asset impairment charges and reversals are not included as these are accounting adjustments that impact depreciation and amortization and do not reflect ongoing business performance. Any gains or losses on asset sales or foreign exchange gains or losses are not included as these are not part of operating income. Adjustments for Equity-Accounted Investments During the fourth quarter of 2020, we acquired a 49 per cent interest in the Skookumchuck wind facility, which is treated as an equity investment under IFRS and our proportionate share of the net earnings is reflected as equity income on the statement of earnings under IFRS. As this investment is part of our regular power-generating operations, we have included our proportionate share of adjusted EBITDA for the Skookumchuck wind facility in our total adjusted EBITDA. In addition, in the Wind and Solar adjusted results, we have included our proportionate share of revenues and expenses to reflect the full operational results of this investment. We have not included adjusted EBITDA of other equity-accounted investments in our total adjusted EBITDA as it does not represent our regular power-generating operations. Adjusted Earnings (Loss) before income taxes Adjusted earnings (loss) before income taxes represents segmented earnings (loss) adjusted for certain items that we believe do not reflect ongoing business performance and is an important metric for evaluating performance trends in each segment. For details of the adjustments made to earnings (loss) before income taxes (the most directly comparable IFRS measure) to calculate adjusted earnings (loss) before income taxes, refer to the Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment section of the MD&A. Adjusted Net Earnings (Loss) attributable to common shareholders Adjusted net earnings (loss) attributable to common shareholders represents net earnings (loss) attributable to common shareholders adjusted for specific reclassifications and adjustments and their tax impact, and is an important metric for evaluating performance. For details of the reclassifications and adjustments made to net earnings (loss) attributable to common shareholders (the most directly comparable IFRS measure), please refer to the reconciliation of net earnings (loss) to adjusted net earnings (loss) attributable to common shareholders in the Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment section of the MD&A. Adjusted Net Earnings (Loss) per common share attributable to common shareholders Adjusted net earning (loss) per common share attributable to common shareholders is calculated as adjusted net earnings (loss) attributable to common shareholders divided by a weighted average number of common shares outstanding during the period. The measure is useful in showing the earnings per common share for our core operational results as it excludes the impact of items that do not reflect an ongoing business performance. Adjusted net earnings (loss) attributable per common share is a non-IFRS ratio and the most directly comparable IFRS measure is net income (loss) per common share attributable to common shareholders. Refer to the reconciliation of earnings (loss) before income taxes to adjusted net earnings (loss) attributable to common shareholders in the Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment section of the MD&A. Funds From Operations (FFO) Represents a proxy for cash generated from operating activities before changes in working capital and provides the ability to evaluate cash flow trends in comparison with results from prior periods. FFO is calculated as cash flow from operating activities before changes in working capital and is adjusted for transactions and amounts that the Company believes are not representative of ongoing cash flows from operations. Free Cash Flow (FCF) Represents the amount of cash that is available to invest in growth initiatives, make scheduled principal debt repayments, repay maturing debt, pay common share dividends or repurchase common shares and provides the ability to evaluate cash flow trends in comparison with the results from prior periods. Changes in working capital are excluded so that FFO and FCF are not distorted by changes that we consider temporary in nature, reflecting, among other things, the impact of seasonal factors and timing of receipts and payments. Non-IFRS Ratios FFO per share, FCF per share and adjusted net debt to adjusted EBITDA are non-IFRS ratios that are presented in the MD&A. Refer to the Reconciliation of Cash Flow from Operations to FFO and FCF and Key Non-IFRS Financial Ratios sections of the MD&A for additional information. Net Interest Expense Net interest expense is calculated as total interest expense less total interest income and non-cash items. For detailed calculation refer to the table in the Reconciliation of Adjusted EBITDA to FFO and FCF section of this MD&A. Net Interest expense is a proxy for the actual cash interest paid that approximates the cash outflow in the FFO and FCF calculation. The most directly comparable IFRS measure is total interest expense. FFO per share and FCF per share FFO per share and FCF per share are calculated using the weighted average number of common shares outstanding during the period. FFO per share and FCF per share are non-IFRS ratios. Supplementary financial measures include available liquidity, carbon compliance per MWh, fuel cost per MWh, hedged power price average per MWh, realized foreign exchange loss, sustaining capital expenditures, the Alberta electricity portfolio metrics and unrealized foreign exchange loss (gain). Reconciliation of these non-IFRS financial measures to the most comparable IFRS measure are provided below. Reconciliation of Non-IFRS Measures on a Consolidated Basis by Segment The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the three months ended June 30, 2025: Hydro Wind &Solar(1) Gas EnergyTransition EnergyMarketing Corporate Total Equity-accounted investments(1) Reclassadjustments IFRSfinancials Revenues 129 59 204 73 38 (67 ) 436 (3 ) — 433 Reclassifications and adjustments: Unrealized mark-to-market (gain) loss 18 68 71 15 (2 ) — 170 — (170 ) — Decrease in finance lease receivable — — 7 — — — 7 — (7 ) — Finance lease income — 2 3 — — — 5 — (5 ) — Revenues from Planned Divestitures — — (3 ) — — — (3 ) — 3 — Unrealized foreign exchange gain on commodity — — — — (2 ) — (2 ) — 2 — Adjusted revenue 147 129 282 88 34 (67 ) 613 (3 ) (177 ) 433 Fuel and purchased power 7 9 106 51 — — 173 — — 173 Reclassifications and adjustments: Fuel and purchased power related to Planned Divestitures — — (1 ) — — — (1 ) — 1 — Adjusted fuel and purchased power 7 9 105 51 — — 172 — 1 173 Carbon compliance costs (recovery) — 1 (8 ) — — (67 ) (74 ) — — (74 ) Adjusted gross margin 140 119 185 37 34 — 515 (3 ) (178 ) 334 OM&A 13 25 65 18 8 45 174 (1 ) — 173 Reclassifications and adjustments: OM&A related to Planned Divestitures — — (1 ) — — — (1 ) — 1 — ERP integration costs — — — — — (6 ) (6 ) — 6 — Acquisition-related transaction and restructuring costs — — — — — (1 ) (1 ) — 1 — Adjusted OM&A 13 25 64 18 8 38 166 (1 ) 8 173 Taxes, other than income taxes 1 5 5 — — 1 12 — — 12 Net other operating income — — (12 ) — — — (12 ) — — (12 ) Adjusted EBITDA(2) 126 89 128 19 26 (39 ) 349 Depreciation and amortization (8 ) (52 ) (74 ) (13 ) — (4 ) (151 ) 1 — (150 ) Equity income — — — — — — — — 1 1 Interest income — — — — — 7 7 (1 ) — 6 Interest expense — — — — — (89 ) (89 ) 1 — (88 ) Realized foreign exchange gain — — — — — 6 6 — — 6 Adjusted earnings (loss) before income taxes(2) 118 37 54 6 26 (119 ) 122 Reclassifications and adjustments above (18 ) (70 ) (80 ) (15 ) 4 (7 ) (186 ) Finance lease income — 2 3 — — — 5 — — 5 Skookumchuk earnings reclass to Equity income(1) — (1 ) — — — 1 — — — — Asset impairment charges — — — (11 ) — (2 ) (13 ) — — (13 ) Unrealized foreign exchange loss — — — — — (23 ) (23 ) — — (23 ) Earnings (loss) before income taxes 100 (32 ) (23 ) (20 ) 30 (150 ) (95 ) — — (95 ) The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment. Adjusted EBITDA, adjusted earnings (loss) before income taxes are non-IFRS measures, are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the three months ended June 30, 2024: Hydro Wind &Solar(1) Gas EnergyTransition EnergyMarketing Corporate Total Equity-accounted investments(1) Reclassadjustments IFRSfinancials Revenues 99 112 284 79 47 (34 ) 587 (5 ) — 582 Reclassifications and adjustments: Unrealized mark-to-market (gain) loss 1 8 10 (14 ) 1 — 6 — (6 ) — Decrease in finance lease receivable — — 5 — — — 5 — (5 ) — Finance lease income — 2 2 — — — 4 — (4 ) — Unrealized foreign exchange gain on commodity — — (1 ) — — — (1 ) — 1 — Adjusted revenue 100 122 300 65 48 (34 ) 601 (5 ) (14 ) 582 Fuel and purchased power 3 8 97 46 — — 154 — — 154 Carbon compliance costs (recovery) — — 26 — — (34 ) (8 ) — — (8 ) Adjusted gross margin 97 114 177 19 48 — 455 (5 ) (14 ) 436 OM&A 13 24 42 15 9 42 145 (1 ) — 144 Reclassifications and adjustments: Acquisition-related transaction and restructuring costs — — — — — (4 ) (4 ) — 4 — Adjusted OM&A 13 24 42 15 9 38 141 (1 ) 4 144 Taxes, other than income taxes 1 4 3 2 — — 10 (1 ) — 9 Net other operating income — (2 ) (10 ) — — — (12 ) — — (12 ) Adjusted EBITDA(2)(3) 83 88 142 2 39 (38 ) 316 — — — Depreciation and amortization (8 ) (47 ) (56 ) (15 ) (1 ) (5 ) (132 ) 1 — (131 ) Equity income — — — — — 1 1 — 2 3 Interest income — — — — — 8 8 — — 8 Interest expense — — — — — (80 ) (80 ) — — (80 ) Realized foreign exchange loss(3) — — — — — (1 ) (1 ) — — (1 ) Adjusted earnings (loss) before income taxes(2) 75 41 86 (13 ) 38 (115 ) 112 — — — Reclassifications and adjustments above (1 ) (10 ) (16 ) 14 (1 ) (4 ) (18 ) — — — Finance lease income — 2 2 — — — 4 — — 4 Skookumchuk earnings reclass to Equity income(1) — (2 ) — — — 2 — — — — Asset impairment (charges) reversals — (1 ) — 1 — (5 ) (5 ) — — (5 ) Gain on sale of assets and other(3) — — — 1 — — 1 — — 1 Unrealized foreign exchange loss(3) — — — — — (1 ) (1 ) — — (1 ) Earnings (loss) before income taxes 74 30 72 3 37 (122 ) 94 — — 94 The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment. Adjusted EBITDA, adjusted earnings (loss) before income taxes are non-IFRS measures, are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. During the first quarter of 2025, our Adjusted EBITDA composition was amended to exclude the impact of realized gain (loss) on closed exchange positions and Australian interest income. Therefore, the Company has applied this composition to all previously reported periods. The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the six months ended June 30, 2025: Hydro Wind &Solar(1) Gas EnergyTransition EnergyMarketing Corporate Total Equity-accountedinvestments(1) Reclassadjustments IFRSfinancials Revenues 215 166 594 227 65 (66 ) 1,201 (10 ) — 1,191 Reclassifications and adjustments: Unrealized mark-to-market (gain) loss (3 ) 104 39 14 (1 ) — 153 — (153 ) — Decrease in finance lease receivable — 1 14 — — — 15 — (15 ) — Finance lease income — 3 8 — — — 11 — (11 ) — Revenues from Planned Divestitures — — (7 ) — — — (7 ) — 7 — Unrealized foreign exchange gain on commodity — — — — (2 ) — (2 ) — 2 — Adjusted revenue 212 274 648 241 62 (66 ) 1,371 (10 ) (170 ) 1,191 Fuel and purchased power 11 19 269 149 — 2 450 — — 450 Reclassifications and adjustments: Fuel and purchased power related to Planned Divestitures — — (3 ) — — — (3 ) — 3 — Adjusted fuel and purchased power 11 19 266 149 — 2 447 — 3 450 Carbon compliance costs (recovery) — 2 41 — — (68 ) (25 ) — — (25 ) Adjusted gross margin 201 253 341 92 62 — 949 (10 ) (173 ) 766 OM&A 26 54 124 35 15 94 348 (2 ) — 346 Reclassifications and adjustments: OM&A related to Planned Divestitures — — (3 ) — — — (3 ) — 3 — ERP integration costs — — — — — (10 ) (10 ) — 10 — Acquisition-related transaction and restructuring costs — — — — — (5 ) (5 ) — 5 — Adjusted OM&A 26 54 121 35 15 79 330 (2 ) 18 346 Taxes, other than income taxes 2 10 10 1 — 1 24 — — 24 Net other operating income — (4 ) (22 ) — — — (26 ) — — (26 ) Reclassifications and adjustments: Insurance recovery — 2 — — — — 2 — (2 ) — Adjusted net other operating income — (2 ) (22 ) — — — (24 ) — (2 ) (26 ) Adjusted EBITDA(2) 173 191 232 56 47 (80 ) 619 Depreciation and amortization (17 ) (105 ) (138 ) (28 ) (2 ) (9 ) (299 ) 3 — (296 ) Equity income — — — — — (1 ) (1 ) — 4 3 Interest income — — — — — 12 12 (1 ) — 11 Interest expense — — — — — (183 ) (183 ) 2 — (181 ) Realized foreign exchange gain — — — — — 2 2 — — 2 Adjusted earnings (loss) before income taxes(2) 156 86 94 28 45 (259 ) 150 Reclassifications and adjustments above 3 (106 ) (60 ) (14 ) 3 (15 ) (189 ) Finance lease income — 3 8 — — — 11 — — 11 Skookumchuk earnings reclass to Equity income(1) — (4 ) — — — 4 — — — — Fair value change in contingent consideration payable — — 34 — — — 34 — — 34 Asset impairment (charges) reversals — — (34 ) 13 — (7 ) (28 ) — — (28 ) Loss on sale of assets and other — — — — — (1 ) (1 ) — — (1 ) Unrealized foreign exchange loss — — — — — (23 ) (23 ) — — (23 ) Earnings (loss) before income taxes 159 (21 ) 42 27 48 (301 ) (46 ) — — (46 ) The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment. Adjusted EBITDA, adjusted earnings (loss) before income taxes are non-IFRS measures, are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. The following table reflects adjusted EBITDA and adjusted earnings (loss) before income taxes by segment and provides reconciliation to earnings (loss) before income taxes for the six months ended June 30, 2024: Hydro Wind &Solar(1) Gas EnergyTransition EnergyMarketing Corporate Total Equity-accounted investments(1) Reclassadjustments IFRSfinancials Revenues 211 251 717 296 99 (34 ) 1,540 (11 ) — 1,529 Reclassifications and adjustments: Unrealized mark-to-market (gain) loss (4 ) (13 ) (81 ) (20 ) (2 ) — (120 ) — 120 — Decrease in finance lease receivable — 1 9 — — — 10 — (10 ) — Finance lease income — 3 3 — — — 6 — (6 ) — Unrealized foreign exchange gain on commodity — — (2 ) — — — (2 ) — 2 — Adjusted revenue 207 242 646 276 97 (34 ) 1,434 (11 ) 106 1,529 Fuel and purchased power 9 17 239 212 — — 477 — — 477 Carbon compliance costs (recovery) — — 66 — — (34 ) 32 — — 32 Adjusted gross margin 198 225 341 64 97 — 925 (11 ) 106 1,020 OM&A 26 44 88 33 19 70 280 (2 ) — 278 Reclassifications and adjustments: Acquisition-related transaction and restructuring costs — — — — — (7 ) (7 ) — 7 — Adjusted OM&A 26 44 88 33 19 63 273 (2 ) 7 278 Taxes, other than income taxes 2 8 6 2 — — 18 (1 ) — 17 Net other operating income — (4 ) (20 ) — — — (24 ) — — (24 ) Adjusted EBITDA(2)(3) 170 177 267 29 78 (63 ) 658 Depreciation and amortization (15 ) (90 ) (111 ) (31 ) (2 ) (9 ) (258 ) 3 — (255 ) Equity income — — — — — (1 ) (1 ) — 5 4 Interest income — — — — — 15 15 — — 15 Interest expense — — — — — (149 ) (149 ) — — (149 ) Realized foreign exchange loss(4) — — — — — (9 ) (9 ) — — (9 ) Adjusted earnings (loss) before income taxes(2) 155 87 156 (2 ) 76 (216 ) 256 Reclassifications and adjustments above 4 9 71 20 2 (7 ) 99 Finance lease income — 3 3 — — — 6 — — 6 Skookumchuk earnings reclass to Equity income(1) — (5 ) — — — 5 — — — — Asset impairment (charges) reversals — (5 ) — 4 — (5 ) (6 ) — — (6 ) Gain on sale of assets and other(4) — — — 1 — 2 3 — — 3 Unrealized foreign exchange gain(4) — — — — — 3 3 — — 3 Earnings (loss) before income taxes 159 89 230 23 78 (218 ) 361 — — 361 The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment. Adjusted EBITDA, adjusted earnings (loss) before income taxes are non-IFRS measures, are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. During the first quarter of 2025, our Adjusted EBITDA composition was amended to exclude the impact of realized gain (loss) on closed exchange positions and Australian interest income. Therefore, the Company has applied this composition to all previously reported periods. Reconciliation of Earnings Before Income Taxes to Adjusted Net Earnings attributable to common shareholders The following table reflects reconciliation of (loss) earnings before income taxes to adjusted net earnings attributable to common shareholders for the three and six months ended June 30, 2025 and June 30, 2024: Three months ended June 30 Six months ended June 30 2025 2024 2025 2024 (Loss) earnings before income taxes (95 ) 94 (46 ) 361 Income tax expense 11 28 18 57 Net (loss) earnings (106 ) 66 (64 ) 304 Net (loss) earnings attributable to non-controlling interests (7 ) (3 ) (11 ) 13 Preferred share dividends 13 13 13 13 Net (loss) earnings attributable to common shareholders (112 ) 56 (66 ) 278 Adjustments and reclassifications (pre-tax): Adjustments and reclassifications to Revenues 177 14 170 (106 ) Adjustments and reclassifications to Fuel and purchased power 1 — 3 — Adjustments and reclassifications to OM&A 8 4 18 7 Adjustments and reclassifications to Net other operating income — — (2 ) — Fair value change in contingent consideration payable (gain) — — (34 ) — Finance lease income (5 ) (4 ) (11 ) (6 ) Asset impairment charges 13 5 28 6 Loss (gain) on sale of assets and other — (1 ) 1 (3 ) Unrealized foreign exchange loss (gain)(1) 23 — 23 (3 ) Calculated tax (expense) recovery on adjustments and reclassifications(2) (51 ) (4 ) (46 ) 24 Adjusted net earnings attributable to common shareholders(3) 54 70 84 197 Weighted average number of common shares outstanding in the period 297 303 297 306 Net (loss) income per common share attributable to common shareholders (0.38 ) 0.18 (0.22 ) 0.91 Adjustments and reclassifications (net of tax) 0.56 0.05 0.50 (0.26 ) Adjusted net earnings per common share attributable to common shareholders(3) 0.18 0.23 0.28 0.64 Unrealized foreign exchange (loss) gain is a supplementary financial measure. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this MD&A for more details. Represents a theoretical tax calculated by applying the Company's consolidated effective tax rate of 23.3 per cent for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 — 23.3 per cent). The amount does not take into account the impact of different tax jurisdictions the Company's operations are domiciled and does not include the impact of deferred taxes. Adjusted net earnings attributable to common shareholders and Adjusted net earnings per common share attributable to common shareholders are non-IFRS measures, are not defined, have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. The most directly comparable IFRS measures are net earnings attributable to common shareholders and net earnings per share attributable to common shareholders, basic and diluted. Refer to the Non-IFRS financial measures section in this earnings release for more details. Reconciliation of cash flow from operations to FFO and FCF The table below reconciles our cash flow from operating activities to our FFO and FCF: Three months ended June 30 Six months ended June 30 2025 2024 2025 2024 Cash flow from operating activities(1) 157 108 164 352 Change in non-cash operating working capital balances 81 114 198 107 Cash flow from operations before changes in working capital 238 222 362 459 Adjustments Share of adjusted FFO from joint venture(1) 1 2 3 4 Decrease in finance lease receivable 7 5 15 10 Clean energy transition provisions and adjustments — 2 — 2 Brazeau penalties payment — — 33 — Acquisition-related transaction and restructuring costs 2 4 8 7 Other(2) 4 1 10 8 FFO(3) 252 236 431 490 Deduct: Sustaining capital expenditures(1) (57 ) (40 ) (80 ) (40 ) Dividends paid on preferred shares (13 ) (13 ) (26 ) (26 ) Distributions paid to subsidiaries' non-controlling interests (2 ) (5 ) (2 ) (24 ) Principal payments on lease liabilities — (1 ) (1 ) (2 ) Other (3 ) — (6 ) — FCF(3) 177 177 316 398 Weighted average number of common shares outstanding in the period 297 303 297 306 Cash flow from operating activities per share 0.53 0.36 0.55 1.15 FFO per share(3) 0.85 0.78 1.45 1.60 FCF per share(3) 0.60 0.58 1.06 1.30 Includes our share of amounts for the Skookumchuck wind facility, an equity-accounted joint venture. Other consists of production tax credits, which is a reduction to tax equity debt, less distributions from an equity-accounted joint venture. These items are not defined and have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. During the first quarter of 2025, our Adjusted EBITDA composition was amended to exclude the impact of realized gain (loss) on closed exchange positions and Australian interest income. Therefore, the Company has applied this composition to all previously reported periods. Refer to the Non-IFRS financial measures and other specified financial measures section in this earnings release. The table below provides a reconciliation of our adjusted EBITDA to our FFO and FCF: Three months ended June 30 Six months endedJune 30 $ millions, unless otherwise stated 2025 2024 2025 2024 Adjusted EBITDA(1)(5) 349 316 619 658 Provisions (2 ) 6 6 6 Net interest expense(2) (66 ) (57 ) (138 ) (105 ) Current income tax expense (46 ) (33 ) (59 ) (60 ) Realized foreign exchange gain (loss)(3) 4 (1 ) 2 (9 ) Decommissioning and restoration costs settled (11 ) (12 ) (20 ) (19 ) Other non-cash items 24 17 21 19 FFO(4)(5) 252 236 431 490 Deduct: Sustaining capital expenditures(3)(5) (57 ) (40 ) (80 ) (40 ) Dividends paid on preferred shares (13 ) (13 ) (26 ) (26 ) Distributions paid to subsidiaries' non-controlling interests (2 ) (5 ) (2 ) (24 ) Principal payments on lease liabilities — (1 ) (1 ) (2 ) Other (3 ) — (6 ) — FCF(4)(5) 177 177 316 398 Adjusted EBITDA is defined in the Additional IFRS Measures and Non-IFRS Measures of this earnings release and reconciled to earnings (loss) before income taxes above. During the first quarter of 2025, our Adjusted EBITDA composition was amended to exclude the impact of realized gain (loss) on closed exchange positions and Australian interest income. Therefore, the Company has applied this composition to all previously reported periods. Net interest expense is a non-IFRS measure, is not defined and has no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. Refer to the table below for detailed calculation. Supplementary financial measure. Refer to the Additional Non-IFRS and Supplementary Financial Measures section of this earnings release. These items are not defined and have no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers. FFO and FCF are defined in the Non-IFRS financial measures and other specified financial measures section in this earnings release and reconciled to cash flow from operating activities above. Includes our share of amounts for Skookumchuck wind facility, an equity-accounted joint venture. Net interest expense in the reconciliation of our adjusted EBITDA to our FFO and FCF is calculated as follows: Three months ended June 30 Six months endedJune 30 2025 2024 2025 2024 Interest expense 88 80 181 149 Less: Interest Income (6 ) (8 ) (11 ) (15 ) Less: non-cash items(1) (16 ) (15 ) (32 ) (29 ) Net Interest Expense 66 57 138 105 Non-cash items include accretion of provisions, financing cost amortization and other non-cash items. TransAlta is in the process of filing its unaudited interim Consolidated Financial Statements and accompanying notes, as well as the associated Management's Discussion & Analysis (MD&A). These documents will be available today on the Investors section of TransAlta's website at or through SEDAR at About TransAlta Corporation: TransAlta owns, operates and develops a diverse fleet of electrical power generation assets in Canada, the United States and Australia with a focus on long-term shareholder value. TransAlta provides municipalities, medium and large industries, businesses and utility customers with affordable, energy efficient and reliable power. Today, TransAlta is one of Canada's largest producers of wind power and Alberta's largest producer of thermal generation and hydro-electric power. For over 114 years, TransAlta has been a responsible operator and a proud member of the communities where we operate and where our employees work and live. TransAlta aligns its corporate goals with the UN Sustainable Development Goals and the Future-Fit Business Benchmark, which also defines sustainable goals for businesses. Our reporting on climate change management has been guided by the International Financial Reporting Standards (IFRS) S2 Climate-related Disclosures Standard and the Task Force on Climate-related Financial Disclosures (TCFD) recommendations. TransAlta has achieved a 70 per cent reduction in GHG emissions or 22.7 million tonnes CO2e since 2015 and received an upgraded MSCI ESG rating of AA. For more information about TransAlta, visit our web site at Cautionary Statement Regarding Forward-Looking Information This news release includes "forward-looking information," within the meaning of applicable Canadian securities laws, and "forward-looking statements," within the meaning of applicable United States securities laws, including the Private Securities Litigation Reform Act of 1995 (collectively referred to herein as "forward-looking statements"). Forward-looking statements are not facts, but only predictions and generally can be identified by the use of statements that include phrases such as "may", "will", "can", "could", "would", "shall", "believe", "expect", "estimate", "anticipate", "intend", "plan", "forecast", "foresee", "potential", "enable", "continue" or other comparable terminology. These statements are not guarantees of our future performance, events or results and are subject to risks, uncertainties and other important factors that could cause our actual performance, events or results to be materially different from those set out in or implied by the forward-looking statements. In particular, this news release contains forward-looking statements about the following, among other things: the strategic objectives of the Company and that the execution of the Company's strategy will realize value for shareholders; our capital allocation and financing strategy; our sustainability goals and targets, including those in our 2024 Sustainability Report; our 2025 Outlook; our financial and operational performance, including our hedge position; optimizing and diversifying our existing assets; the increasingly contracted nature of our fleet; expectations about strategies for growth and expansion; data centre opportunities, including the AESO's expectation around the timing of execution of Demand Transmission Service contracts and entering into a data centre memorandum of understanding; opportunities for Centralia redevelopment, including the execution of a definitive agreement with our customer for the full capacity of Centralia Unit 2; expectations regarding ongoing and future transactions, including the sale of Poplar Hill; expected costs and schedules for planned projects; expected regulatory processes and outcomes, including in relation to the Alberta restructured energy market; the completion and closing of acquisition and divestiture transactions which are subject to customary closing terms and conditions, the power generation industry and the supply and demand of electricity; the cyclicality of our business; expected outcomes with respect to legal proceedings; the expected impact of future tax and accounting changes; and expected industry, market and economic conditions. The forward-looking statements contained in this news release are based on many assumptions including, but not limited to, the following: no significant changes to applicable laws and regulations; no unexpected delays in obtaining required regulatory approvals; no material adverse impacts to investment and credit markets; no significant changes to power price and hedging assumptions; no significant changes to gas commodity price assumptions and transport costs; no significant changes to interest rates; no significant changes to the demand and growth of renewables generation; no significant changes to the integrity and reliability of our facilities; no significant changes to the Company's debt and credit ratings; no unforeseen changes to economic and market conditions; no significant event occurring outside the ordinary course of business; and realization of expected impacts from ongoing and future transactions. These assumptions are based on information currently available to TransAlta, including information obtained from third-party sources. Actual results may differ materially from those predicted. Factors that may adversely impact what is expressed or implied by forward-looking statements contained in this news release include, but are not limited to: fluctuations in power prices; changes in supply and demand for electricity; our ability to contract our electricity generation for prices that will provide expected returns; our ability to replace contracts as they expire; risks associated with development projects and acquisitions; failure to complete divestitures on the terms and conditions specified or at all; any difficulty raising needed capital in the future on reasonable terms or at all; our ability to achieve our targets relating to ESG; long-term commitments on gas transportation capacity that may not be fully utilized over time; changes to the legislative, regulatory and political environments; environmental requirements and changes in, or liabilities under, these requirements; operational risks involving our facilities, including unplanned outages and equipment failure; disruptions in the transmission and distribution of electricity; reductions in production; impairments and/or writedowns of assets; adverse impacts on our information technology systems and our internal control systems, including increased cybersecurity threats; commodity risk management and energy trading risks; reduced labour availability and ability to continue to staff our operations and facilities; disruptions to our supply chains; climate-change related risks; reductions to our generating units' relative efficiency or capacity factors; general economic risks, including deterioration of equity and debt markets, increasing interest rates or rising inflation; general domestic and international economic and political developments, including potential trade tariffs; industry risk and competition; counterparty credit risk; inadequacy or unavailability of insurance coverage; increases in the Company's income taxes and any risk of reassessments; legal, regulatory and contractual disputes and proceedings involving the Company; reliance on key personnel; and labour relations matters. The foregoing risk factors, among others, are described in further detail under the heading "Governance and Risk Management" in the MD&A, which section is incorporated by reference herein. Readers are urged to consider these factors carefully when evaluating the forward-looking statements and are cautioned not to place undue reliance on them. The forward-looking statements included in this news release are made only as of the date hereof and we do not undertake to publicly update these forward-looking statements to reflect new information, future events or otherwise, except as required by applicable laws. The purpose of the financial outlooks contained herein is to give the reader information about management's current expectations and plans and readers are cautioned that such information may not be appropriate for other purposes. Note: All financial figures are in Canadian dollars unless otherwise indicated. For more information: Phone: 1-800-387-3598 in Canada and U.S. Phone: 1-855-255-9184 Email: investor_relations@ Email: ta_media_relations@ in retrieving data Sign in to access your portfolio Error in retrieving data Error in retrieving data Error in retrieving data Error in retrieving data
CBC
31-07-2025
- Business
- CBC
Capital Power still waiting for Alberta data centre powering opportunity at Genesee plant
Capital Power Corp. says it's holding out for an opportunity to power a large-scale data centre at its Genesee Generating Station, but Alberta's grid operator is not currently making enough electrical connection capacity available for the size of project it's chasing. The power plant 80 kilometres southwest of Edmonton now runs entirely on natural gas instead of coal after a $1.6-billion multi-year revamp, allowing it to boost its capacity by around 60 per cent while cutting greenhouse gas emissions by 40 per cent. Capital Power CEO Avik Dey has said it would be the perfect site to exclusively power a data centre. Those are huge facilities housing the computing firepower needed for artificial intelligence and other applications. It can take an enormous amount of power to run and cool them. The Alberta government has set a goal of attracting $100 billion in data centre investments over five years. WATCH | Alberta's plan to build huge data centres for AI could pose a significant emissions challenge: Alberta's plan to build huge data centres for AI could pose a significant emissions challenge 7 months ago The Alberta Electric System Operator (AESO) said last month it has received requests from 29 proposed data centre projects representing more than 16,000 megawatts — more than 11 times the City of Edmonton's load. To accommodate that surge in demand, the AESO has placed a temporary limit on the projects wanting to connect to the grid — 1,200 megawatts between now and 2028 — in order to ensure system reliability. Capital Power was among those raising concerns about the interim limit. Dey told analysts on a conference call Wednesday that it wants to pursue a 1,000-megawatt project, but doesn't see something that big moving forward with a potential partner under the grid operator's current Phase 1 limits. It's taking a pass on pursuing something smaller at Genesee in the meantime. "Our physical site at Genesee is incredibly advantaged for a large hyper data centre," he said, pointing to its access to fibre, transmission and distribution infrastructure. Dey said Capital Power will look at whether it can move a project ahead under future phases of the AESO's allocation plan, and continue to advocate for the current limit to be raised. "I think we all want the same thing here … We have a different view on how that should be allocated, but I think everyone's trying to work to the same endgame here," he said. "And I will concede the AESO and the utilities ministry and the government are balancing multiple needs and considerations." Capital Power shares dropped almost six per cent in afternoon trading on the TSX to $58.55. Earlier Wednesday, the power producer said it swung to a loss in the second quarter compared with a profit last year. It said its net loss attributable to shareholders was $132 million during the quarter ended June 30, or 92 cents per diluted share. That compared with a profit of $75 million, or 51 cents per share in the same quarter last year. The loss came as revenue also dropped to $441 million, down from $774 million last year. In the quarter, the company completed its $3 billion acquisition of two power facilities in the U.S. that it says add to its flexible power generation.
Hamilton Spectator
30-07-2025
- Business
- Hamilton Spectator
Capital Power still waiting for Alberta data centre powering opportunity
Capital Power Corp. says it's holding out for an opportunity to power a large-scale data centre at its Genesee Generating Station, but Alberta's grid operator is not currently making enough electrical connection capacity available for the size of project it's chasing. The power plant southwest of Edmonton now runs entirely on natural gas instead of coal after a $1.6-billion multi-year revamp, allowing it to boost its capacity by around 60 per cent while cutting greenhouse gas emissions by 40 per cent. Capital Power chief executive Avik Dey has said it would be the perfect site to exclusively power a data centre. Those are huge facilities housing the computing firepower needed for artificial intelligence and other applications. It can take an enormous amount of power to run and cool them. The Alberta government has set a goal of attracting $100 billion in data centre investments over five years. The Alberta Electric System Operator said last month it has received requests from 29 proposed data centre projects representing more than 16,000 megawatts — more than 11 times the City of Edmonton's load. To accommodate that surge in demand, the AESO has placed a temporary limit on the projects wanting to connect to the grid — 1,200 megawatts between now and 2028 — in order to ensure system reliability. Capital Power was among those raising concerns about the interim limit. Dey told analysts on a conference call Wednesday that it wants to pursue a 1,000-megawatt project, but doesn't see something that big moving forward with a potential partner under the grid operator's current Phase 1 limits. It's taking a pass on pursuing something smaller at Genesee in the meantime. 'Our physical site at Genesee is incredibly advantaged for a large hyper data centre,' he said, pointing to its access to fibre, transmission and distribution infrastructure. Dey said Capital Power will look at whether it can move a project ahead under future phases of the AESO's allocation plan, and continue to advocate for the current limit to be raised. 'I think we all want the same thing here … We have a different view on how that should be allocated, but I think everyone's trying to work to the same endgame here,' he said. 'And I will concede the AESO and the utilities ministry and the government are balancing multiple needs and considerations.' Capital Power shares dropped almost six per cent in afternoon trading on the TSX to $58.55. Earlier Wednesday, the power producer said it swung to a loss in the second quarter compared with a profit last year. It said its net loss attributable to shareholders was $132 million during the quarter ended June 30, or 92 cents per diluted share. That compared with a profit of $75 million, or 51 cents per share in the same quarter last year. The loss came as revenue also dropped to $441 million, down from $774 million last year. In the quarter, the company completed its $3 billion acquisition of two power facilities in the U.S. that it says add to its flexible power generation. The company also revised its guidance for the year, raising its expected capital expenditures, adjusted earnings before certain deductions and adjusted funds from operations. This report by The Canadian Press was first published July 30, 2025. Companies in this story: (TSX: CPX)
Calgary Herald
08-07-2025
- Climate
- Calgary Herald
City of Calgary warns against excessive outdoor water use amid climbing temperatures
With a high of 31 degrees forecast for Tuesday afternoon, Calgary is facing one of the hottest days of the year so far — which could put a strain on the water system, the city warns. Article content 'We're closely monitoring river and weather conditions and watching the impacts of sustained heat and water demands,' said Nicole Newton, the city's manager of natural environment and adaptation. Article content Article content Article content 'On Calgary's hottest days, every effort to manage outdoor water use when watering lawns and yards helps maintain a reliable water supply for everyone.' Article content Article content No water restrictions are currently in effect, but the city is asking Calgarians to limit outdoor water use by shortening watering times or skipping a watering day, watering during late evening or early morning to limit evaporation, utilizing a rain barrel and keeping grass longer. Article content For those attending the Stampede or partaking in other outdoor activities, the city encourages drinking lots of water and taking breaks in the shade. Article content Currently, a prolonged heat wave is not expected and rain is predicted throughout the week — but forecasts can change, so the city is taking pre-emptive measures. Article content Article content 'We're hopeful that temperatures ease up and a prolonged heat wave doesn't materialize,' Newton said. 'We'll continue to keep Calgarians informed if anything changes.' Article content Earlier this year, Environment Canada predicted a hotter-than-average summer in Alberta, with average temperatures reaching 23.5 C in July and 23.1 C in August. Article content Last year, the Bearspaw south feeder main rupture resulted in months of water restrictions, and the summer of 2023 also saw an extended period of Stage 1 restrictions. Article content Drought-related restrictions may be becoming the norm for Calgarians. Last year, the city considered implementing seasonal restrictions as a pre-emptive measure, but the idea was scrapped this spring. Article content Matthew John, a senior communications strategist at Enmax, said energy usage tends to be high on hot summer days, peaking in the evenings when most people get home from work, but so far consumption levels are 'nothing to be worried about.' Article content 'Enmax works closely with the AESO (Alberta Electric System Operator) to maintain reliability and avoid temporary outages,' John said. 'Power conservation efforts during peak hours of 5 p.m. to 9:30 p.m. can help by reducing demand on the system.' Article content
