Q2 2026 TransAlta Corp Earnings Call

July 31, 2026

Speaker #1: All lines have been placed on mute to prevent any background noise. After the speakers' remarks, there will be a question-and-answer session. If you would like to ask a question during this time, simply press *11 on your telephone keypad.

Speaker #1: If you would like to withdraw your question, please press * followed by 11 again. Thank you. Ms. Paris, you may begin your conference.

Stephanie Paris: Thank you, Michelle. Good morning, everyone. My name is Stephanie Paris, and I am the Vice President of Investor Relations and Corporate Strategy of TransAlta. Welcome to TransAlta's Q2 2026 conference call. With me today are Joel Hunter, President and Chief Executive Officer; Mike Politeski, EVP Finance and Chief Financial Officer, and Chris Fralick, EVP Generation and Chief Operating Officer. Today's call is being webcast, and I invite those listening on the phone lines to view the supporting slides that are posted on our website. A replay of the call will be made available later today, and the transcript will be posted to our website shortly thereafter. All the information provided during this conference call is subject to the forward-looking statement qualification set out here on slide two, detailed further in our MD&A, and incorporated in full for the purposes of today's call.

Speaker #2: Thank you, Michelle. Good morning, everyone. My name is Stephanie Paris, and I am the Vice President of Investor Relations and Corporate Strategy at TransAlta.

Speaker #2: Welcome to TRANSALTA's 2nd Quarter 2026 Conference Call. With me today are Joel Hunter, President and Chief Executive Officer; Mike Politeski, EVP Finance and Chief Financial Officer; and Chris Frelich, EVP Generation and Chief Operating Officer.

Speaker #2: Today's call is being webcast, and I invite those listening on the phone lines to view the supporting slides that are posted on our website.

Speaker #2: A replay of the call will be made available later today, and the transcript will be posted to our website shortly thereafter. All the information provided during this conference call is subject to the forward-looking statement qualification settled here on slide 2, detailed further in our MDNA and incorporated in full for purposes of today's call.

Stephanie Paris: All amounts referenced are in Canadian dollars unless otherwise noted. The non-IFRS terminology used, including adjusted EBITDA and free cash flow, are reconciled in the MD&A for your reference. On today's call, Joel and Mike will provide an overview of TransAlta's quarterly results. After these remarks, we will open the call for questions. With that, I will turn the call over to Joel.

Speaker #2: All amounts referenced are in Canadian dollars unless otherwise noted. The non-IFRS terminology used, including adjusted EBITDA and free cash flow, are reconciled in the MDNA for your reference.

Speaker #2: On today's call, Joel and Mike will provide an overview of TransAlta's quarterly results. After these remarks, we will open the call for questions. With that, I will turn the call over to Joel.

Joel Hunter: Thanks, Stephanie. Good morning, everyone, and thank you for joining our Q2 conference call. TransAlta delivered solid operational financial performance during Q2 2026, demonstrating our fleet's continued resilience during challenging market conditions. During the quarter, we delivered adjusted EBITDA of CAD 291 million, free cash flow of CAD 143 million or CAD 0.47 per share, and average fleet availability of 90.2%. While our Alberta merchant portfolio continues to be impacted by softer prices, our hedging strategy and active asset optimization generated realized prices that were well above spot prices during the quarter, along with our hydro and wind assets providing significant environmental offsets to our gas fleet's 2025 carbon compliance obligation. We remain confident in achieving our 2026 guidance range, which Mike will talk about later. In the quarter, we continued to advance our data center strategy with CPP Investments in Brookfield.

Speaker #3: Thanks, Stephanie. Good morning, everyone, and thank you for joining our 2nd Quarter Conference Call. TRANSALTA delivered solid operational financial performance during the 2nd Quarter 2026, demonstrating our fleet's continued resilience during challenging market conditions.

Speaker #3: During the quarter, we delivered adjusted EBITDA of $291 million, free cash flow of $143 million, or 47 cents per share, and average fleet availability of 90.2%.

Speaker #3: While our Alberta merchant portfolio continues to be impacted by softer prices, our hedging strategy and active asset optimization generated realized prices that were well above spot prices during the quarter.

Speaker #3: Along with our hydro and wind assets providing significant environmental offsets, to our gas fleet's 2025 carbon compliance obligation. We remain confident in our in achieving our 2026 guidance range, which Mike will talk about later.

Speaker #3: In the quarter, we continued to advance our data center strategy with CPP investments in Brookfield. More broadly, in Alberta, positive recent developments reinforced the momentum and collective commitment across government and industry to develop AI infrastructure.

Joel Hunter: More broadly in Alberta, positive recent developments reinforce the momentum and collective commitment across government and industry to develop AI infrastructure. In particular, in June, the Government of Alberta published their Data Centre Regulation, giving authority to the AESO to proceed with the next phase of their Large Load Integration Plan. The regulation includes provisions that permit the AESO to determine underutilized capacity that can be used to serve incremental data centre load. Consistent with our messaging at Investor Day, we believe that our gas-fired steam units constitute underutilized generation that can support both grid reliability and the continued build-out of AI infrastructure in the province. Our gas-fired steam units are designed to operate as base load and can produce at capacity factors greater than 90%. Their recent performance and lower capacity factors, averaging around 20% in 2025, have been driven by economic decisions, not capability.

Speaker #3: In particular, in June, the Government of Alberta published their data center regulations, giving authority to the ASO to proceed with the next phase of their large load integration plan.

Speaker #3: The regulation includes provisions that permit the ASO to determine underutilized capacity that can be used to serve incremental data center load. Consistent with our messaging and investor day, we believe that our gas-fired steam units constitute underutilized generation that can support both grid reliability and the continued build-out of AI infrastructure in the province.

Speaker #3: Our gas-fired steam units are designed to operate as base load and can produce a capacity factors greater than 90%. Their recent performance and lower capacity factors averaging around 20% in 2025 have been driven by economic decisions, not capability.

Joel Hunter: Speed to power is critical. We view the Data Centre Regulation as an important step towards framework clarity. The determination on how underutilized assets will be incorporated into the build-out of AI infrastructure will be made by the AESO, and we remain actively engaged with them. Also in the quarter, we fully integrated the four gas-fired facilities in connection with the acquisition of Far North. In June, the U.S. Department of Energy issued its third temporary order requiring that Centralia Unit 2 remain available for operation if needed for a period of 90 days. TransAlta is adhering to the order, and we plan to submit a request for reimbursement to the FERC for costs related to the second order.

Speaker #3: Speed to power is critical, and we view the data center regulations as an important step towards framework clarity. The determination on how underutilized assets will be incorporated into the build-out of AI infrastructure will be made by the ASO, and we remain actively engaged with them.

Speaker #3: Also, in the quarter, we fully integrated the four gas-fired facilities in connection with the acquisition of FourNorth. And in June, the U.S. Department of Energy issued its third temporary order requiring that Centrale Unit 2 remain available for operation if needed for a period of 90 days.

Speaker #3: TRANSALTA is adhering to the order, and we plan to submit a request for reimbursement to the FERC for costs related to the second order.

Joel Hunter: Progress continues with the conversion of the unit to natural gas. I am pleased to report that our timeline for a final investment decision in Q1 2027 remains on schedule. Last month, we announced that TransAlta has entered into an agreement to acquire two natural gas-fired peaking facilities in Colorado for US$1 billion, paired with a common share offering for CAD 350 million. Both assets are fully contracted to investment-grade counterparties under long-term tolling agreements that include full cost pass-through of all operations and maintenance, fuel, and capital expenses, which meaningfully reduce the risk profile of the acquired assets. The acquisition is expected to deliver CAD 110 million per year in low risk, high-quality adjusted EBITDA to our portfolio and is immediately accretive to free cash flow per share.

Speaker #3: Progress continues with the conversion of the unit to natural gas, and I am pleased to report that our timeline for a final investment decision in the first quarter of 2027 remains on schedule.

Speaker #3: Last month, we announced that TRANSALTA has entered into an agreement to acquire two natural gas-fired peaking facilities in Colorado for U.S. $1 billion. Paired with a common share offering for $350 million.

Speaker #3: Both assets are fully contracted to investment-grade counterparties under long-term tooling agreements that include full-cost pass-through of all operations and maintenance, fuel and capital expenses, which meaningfully reduced the risk profile of the acquired assets.

Speaker #3: The acquisition is expected to deliver $110 million per year in low-risk, high-quality adjusted EBITDA to our portfolio and is immediately accretive to free cash flow per share.

Joel Hunter: We expect closing to occur in Q4, following receipt of all regulatory approvals, as well as Canyon Peak Power achieving commercial operations. Adding stable operating assets like this delivers immediate cash flow that can be redeployed into our most compelling growth initiatives, including the Centralia coal to gas conversion and Alberta data centre projects. Finally, we realigned our executive management team, adding Mike Politeski as our Executive Vice President, Finance and Chief Financial Officer, and Grant Arnold as our Executive Vice President, Growth and Chief Commercial Officer. In addition, Nancy Brennan assumed an expanded role as Chief Legal, People, and Corporate Affairs Officer, and Chris Fralick's new title is Executive Vice President, Generation and Chief Operating Officer. Supported by an exceptional team across the organization, I am confident that we have the right people and structure to execute our strategy and realize long-term value creation for TransAlta.

Speaker #3: We expect closing to occur in the fourth quarter, following receipt of all regulatory approvals, as well as Canning Peak Power achieving commercial operations. Adding stable operating assets like this delivers immediate cash flow that can be redeployed into our most compelling growth initiatives, including the Centrale coal-to-gas conversion and Alberta data center projects.

Speaker #3: And finally, we re re-realigned our executive management team, adding Mike Politeski as our EVP Finance and Chief Financial Officer, and Grant Arnold as our EVP Growth and Chief Commercial Officer.

Speaker #3: In addition, Nancy Brennan assumed an expanded role as Chief Legal, People, and Corporate Affairs Officer, and Chris Frelich's new title is EVP, Generation and Chief Operating Officer.

Speaker #3: Supported by an exceptional team across the organization, I am confident that we have the right people and structure to execute our strategy and realize long-term value creation for TransAlta.

Joel Hunter: I'll now turn the call over to Mike to talk more about our financial performance in the Q2 of 2026.

Speaker #3: I'll now turn the call over to Mike to talk more about our financial performance in the second quarter of 2026.

Mike Politeski: Thanks, Joel. Good morning, everyone. During the quarter, we generated adjusted EBITDA of CAD 291 million, despite challenging market pricing in Alberta. Our hydro segment adjusted EBITDA was CAD 87 million, down CAD 39 million from the same quarter in 2025 due to lower Alberta spot and hedge prices, as well as lower intercompany sales of emissions credits. Our wind and solar segment reported adjusted EBITDA of CAD 90 million. Consistent with the prior year, as higher US wind resource mitigated lower Alberta pricing and reduced wind resource in Eastern Canada. Within our gas segment, adjusted EBITDA was CAD 14 million higher than the prior year due to strong optimization of our Alberta fleet and positive contributions from our Far North acquisition. Consistent with prior years, our Q2 results benefited from the realization of emissions credits against our prior year carbon obligation.

Speaker #4: Thanks, Joel. Good morning, everyone. During the quarter, we generated adjusted EBITDA of $291 million, despite challenging market pricing in Alberta. Our hydro segment adjusted EBITDA was $87 million, down $39 million from the same quarter in 2025 due to lower Alberta spot and hedge prices, as well as lower intercompany sales of emissions credits.

Speaker #4: Our wind and solar segment reported adjusted EBITDA of $90 million, consistent with the prior year, as higher U.S. wind resource mitigated lower Alberta pricing and reduced wind resource in Eastern Canada.

Speaker #4: Within our gas segment, adjusted EBITDA was $14 million higher than the prior year, due to strong optimization of our Alberta fleet and positive contributions from our Far North acquisition.

Speaker #4: Consistent with prior years, our second quarter results benefited from the realization of emissions credits against our prior year carbon obligation. For the balance of 2026, we expect additional contributions to our segments from the realization of carbon credits against in-year carbon compliance costs.

Mike Politeski: For the balance of 2026, we expect additional contributions to our segments from the realization of carbon credits against in-year carbon compliance costs. Our energy marketing adjusted EBITDA decreased by CAD 16 million, primarily due to subdued market volatility in western power markets and lower realized gains within the quarter. We expect to have more gains realized by year-end as favorable trade positions settle. In our corporate segment, costs were 8% lower than the prior year due to initiatives to control spend. Finally, our energy transition segment adjusted EBITDA was lower than the prior year due to the Centralia contract expiry at the end of 2025. We also generated strong free cash flow during the Q2, totaling CAD 143 million. Our sustaining capital expenditures were down CAD 18 million year-over-year.

Speaker #4: Our energy marketing adjusted EBITDA decreased by $16 million, primarily due to subdued market volatility in western power markets and lower realized gains within the quarter. We expect to have more gains realized by year-end as favorable trade positions settle.

Speaker #4: In our Corporate segment, costs were 8% lower than the prior year due to initiatives to control spend. Finally, our Energy Transition segment adjusted EBITDA was lower than the prior year due to the Centrale contract expiry at the end of 2025.

Speaker #4: We also generated strong free cash flow during the second quarter, totaling $143 million. Our sustaining capital expenditures were down $18 million year over year.

Mike Politeski: However, this was primarily timing related, and we continue to expect sustaining capital of CAD 140 to 160 million in 2026. Turning to the Alberta portfolio, spot prices averaged CAD 29 per megawatt hour in the Q2, notably lower than the CAD 40 per megawatt hour in the Q2 of 2025. The decline was primarily due to seasonally lower demand and continued strong supply in the market. Although prices were low, we enhanced our margins by meeting portions of our higher price hedge commitments through power purchases when market prices were below our variable production costs. We benefited from approximately 2,400 GWh of hedges at an average price of CAD 63 per megawatt hour, which was CAD 34 per megawatt higher than the average spot price.

Speaker #4: However, this was primarily timing-related, and we continue to expect sustaining capital of $140 to $160 million in 2026. Turning to the Alberta portfolio, spot prices averaged $29 per megawatt-hour in the second quarter, notably lower than the $40 per megawatt-hour in the second quarter of 2025.

Speaker #4: The decline was primarily due to seasonally lower demand and continued strong supply in the market. Although prices were low, we enhanced our margins by meeting portions of our higher-priced hedge commitments through power purchases when market prices were below our variable production costs.

Speaker #4: We benefited from approximately 2,400 gigawatt-hours of hedges at an average price of $63 per megawatt-hour, which was $34 per megawatt-hour higher than the average spot price.

Mike Politeski: Our gas fleet realized an average price of CAD 68 per megawatt hour, a significant 134% premium to the average spot price, largely due to our dispatch optimization during high price hours, which materially raised our realized price. The hydro fleet also continued to capture merchant upside, delivering an average realized price of CAD 36 per megawatt hour, a 24% premium to the average spot price. Our merchant wind fleet realized an average price of CAD 14 per megawatt hour, which was impacted by increased thermal production and intermittent wind and solar generation. During the quarter, we also delivered approximately 900 GWh of ancillary service volumes at a 14% premium to the average spot price. Through effective fleet optimization and meeting hedge obligations with purchased power, we consistently address the AESO need for reliability products. We continue to have a strong hedge book to support our Alberta cash flows.

Speaker #4: Our gas fleet realized an average price of $68 per megawatt-hour, a significant 134% premium to the average spot price. This was largely due to our dispatch optimization during high-priced hours, which materially raised our realized price.

Speaker #4: The hydro fleet also continued to capture merchant upside, delivering an average realized price of $36 per megawatt-hour at 24% premium to the average spot price.

Speaker #4: Our merchant wind fleet realized an average price of $14 per megawatt-hour, which was impacted by increased thermal production and intermittent wind and solar generation.

Speaker #4: During the quarter, we also delivered approximately 900 gigawatt-hours of ancillary service volumes at a 14% premium to the average spot price. Through effective fleet optimization and meeting hedge obligations with purchased power, we consistently addressed the AESO's need for reliability products.

Speaker #4: We continue to have a strong hedge book to support our Alberta cash flows. For the balance of the year, we have approximately $4,500 gigawatt-hours of our Alberta generation hedged at an average price of $64 per megawatt-hour, well above current forward pricing.

Mike Politeski: For the balance of the year, we have approximately 4,500 GWh of our Alberta generation hedged at an average price of CAD 64 per megawatt hour, well above current forward pricing. For 2027, we have approximately 6,600 GWh hedged at an average price of CAD 64 per megawatt hour, also well above current forward levels. Looking ahead, we continue to expect the Alberta supply and demand imbalance will correct later this decade with anticipated load growth. We believe we are well-positioned to manage through the current pricing environment and to capture growth opportunities to drive long-term value creation for our shareholders. Turning to the balance sheet. In June, Moody's reaffirmed our Ba1 credit rating with a stable outlook. Last week, S&P reaffirmed our BB+ rating while shifting the outlook to negative. We remain committed to strengthening our balance sheet through multiple levers, including asset recycling.

Speaker #4: For 2027, we have approximately $6,600 gigawatt-hours hedged at an average price of $64 per megawatt-hour, also well above current forward levels. Looking ahead, we continue to expect the Alberta supply-demand imbalance will correct later this decade, with anticipated load growth.

Speaker #4: We believe we are well positioned to manage through the current pricing environment and to capture growth opportunities to drive long-term value creation for our shareholders.

Speaker #4: Turning to the balance sheet, in June, Moody's reaffirmed our BA1 credit rating with a stable outlook and last week S&P reaffirmed our BB+ rating while shifting the outlook to negative.

Speaker #4: We remain committed to strengthening our balance sheet through multiple levers, including asset recycling. In addition, the forecast tightening of the Alberta market and recovery of power prices along with expected cash flows from Centrale after conversion will provide cash flow growth to further strengthen our financial position.

Mike Politeski: In addition, the forecast tightening of the Alberta market and recovery of power prices, along with the expected cash flows from Centralia after conversion, will provide cash flow growth to further strengthen our financial position. Overall, we are pleased with our year-to-date operational and financial performance across all our business segments, and we remain confident in our ability to meet our 2026 guidance range. Our contracted fleet, strong hedge position, and consistent optimization provide us with core cash flows even in a low merchant power pricing environment. The Colorado acquisition is not factored into our reaffirmation of guidance, and upon closing, which is expected in Q4 2026, will add to our financial results. I'll now turn the call back over to Joel.

Speaker #4: Overall, we are pleased with our year-to-date operational and financial performance across all our business segments, and we remain confident in our ability to meet our 2026 guidance range.

Speaker #4: Our contracted fleet, strong hedge position, and consistent optimization provide us with core cash flows even in a low merchant power pricing environment. The Colorado acquisition is not factored into our reaffirmation of guidance, and upon closing—which is expected in the fourth quarter of 2026—will add to our financial results.

Speaker #4: I'll now turn the call back over to Joel.

Joel Hunter: Thanks, Mike. This year, we remain focused on the following priorities. Improving our leading and lagging safety performance indicators while achieving strong fleet availability. Delivering adjusted EBITDA and free cash flow within our 2026 guidance ranges. Maximizing the value of our legacy thermal sites by advancing our Alberta data center strategy, as well as advancing our coal to gas conversion at Centralia toward a final investment decision. Pursuing strategic M&A opportunities and enhancing our financial strength and flexibility through disciplined capital allocation and cost control. I believe TransAlta offers a compelling investment opportunity. We have operated a safe and reliable power generation fleet for over 115 years, providing strong and consistent cash flows. This strength is grounded in a diversified portfolio of hydro, wind, solar, storage, and thermal assets across three countries. It is enhanced by our industry-leading asset optimization and energy marketing capabilities.

Speaker #1: Thanks, Mike. This year we remain focused on the following priorities. Improving our leading and lagging safety performance indicators while achieving strong fleet availability. Delivering adjusted EBITDA and free cash flow within our 2026 guidance regions.

Speaker #1: Maximizing the value of our legacy thermal sites by advancing our Alberta data center strategy, as well as advancing our coal-to-gas conversion at Centrale toward a final investment decision.

Speaker #1: Pursuing strategic M&A opportunities and enhancing our financial strength and flexibility through disciplined capital allocation and cost control. I believe TransAlta offers a compelling investment opportunity.

Speaker #1: We have operated a safe and reliable power generation fleet for over 115 years, providing strong and consistent cash flows. This strength is grounded in a diversified portfolio of hydro, wind, solar, storage, and thermal assets across three countries.

Speaker #1: It is enhanced by our industry-leading asset optimization and energy marketing capabilities. Our legacy sites continue to represent considerable and increasing value. We are proactively pursuing repurposing initiatives at these facilities to address the growing demand for reliable power in our operating markets.

Joel Hunter: Our legacy sites continue to represent considerable and increasing value. We are proactively pursuing repurposing initiatives at these facilities to address the growing demand for reliable power in our operating markets. Concurrently, we maintain a leadership position across multiple technologies, consistently prioritizing responsible and reliable generation. We are disciplined in how we grow. Our priority is creating shareholder value as we diversify our portfolio within our core geographies and continue to increase the stability and contracted nature of our cash flows. This strategy is supported by a strong financial foundation. We have a flexible balance sheet and ample liquidity, giving us the ability to pursue and deliver multiple growth opportunities while continuing to return capital to shareholders. Finally, and most importantly, we have our people. Everything we achieve is powered by the dedication and expertise of our employees and contractors.

Speaker #1: Concurrently, we maintain a leadership position across multiple technologies, consistently prioritizing responsible and reliable generation. We are disciplined in how we grow, with our priorities creating shareholder value as we diversify our portfolio within our core geographies and continue to increase the stability and contracted nature of our cash flows.

Speaker #1: This strategy is supported by a strong financial foundation. We have a flexible balance sheet and ample liquidity, giving us the ability to pursue and deliver multiple growth opportunities while continuing to return capital to shareholders.

Speaker #1: And finally, and most importantly, we have our people. Everything we achieve is powered by the dedication and expertise of our employees and contractors. I want to thank them for their commitment and for positioning TRANSALTA for continued success in 2026 and beyond.

Joel Hunter: I want to thank them for their commitment and for positioning TransAlta for continued success in 2026 and beyond. Thank you, I'll now turn the call back over to Stephanie.

Speaker #1: Thank you, and I'll now turn the call back over to Stephanie.

Stephanie Paris: Thank you, Joel. Michelle, would you please open the call for questions from the analysts?

Speaker #2: Thank you, Joel. Michelle, would you please open the call for questions from the analysts?

Operator: Thank you. As a reminder to ask a question, please press star one one on your telephone and wait for your name to be announced. To withdraw your question, please press star one one again. In fairness to all, we ask that you please limit yourself to one question, one follow-up. One moment as we compile our Q&A roster. Our first question is going to come from the line of Mark Jarvi with CIBC. Your line is open. Please go ahead.

Speaker #3: Thank you. As a reminder, to ask a question, please press *11 on your telephone and wait for your name to be announced. To withdraw your question, please press *11 again.

Speaker #3: In fairness to all, we ask that you please limit yourself to one question and one follow-up. One moment as we compile our Q&A roster.

Speaker #3: Our first question is going to come from the line of Mark Jarvie with CIBC. Your line is open. Please go ahead.

Mark Jarvi: Yeah. Good morning, everyone. Just in terms of those discussions with the AESO and the unrealized assets, do you have any sense of when you might have clarity and just how that's impacting anything about getting from the MoU to a definitive agreement with Brookfield and CPP?

Speaker #5: Yeah, good morning, everyone. Just in terms of those discussions with the ASO and the underutilized assets, do you have any sense of when you might have clarity?

Speaker #5: And just how that's impacting anything about getting from the MOU to a definitive agreement with Brookfield and CPP?

Joel Hunter: Yeah. Thanks, Mark, and good morning. It's Joel here. I would say, there's ongoing discussions with the AESO. Again, we are very encouraged, as mentioned in our prepared remarks, by the Data Centre Regulation that really turn over to the AESO to determine what is underutilized capacity here as it relates to our gas-fired steam units. Again, we're working with them very collaboratively here as we move forward. I would say with the MoU and the definitive agreements that we have with CPP Investments and Brookfield, those continue to advance, as we highlighted when we announced the MoU back in February. Again, working alongside those two parties and we continue to remain very confident in our ability to bring forward our data center option here later in the year.

Speaker #1: Yeah, thanks, Mark. And good morning. It's Joel here. I would say, you know, there's ongoing discussions with ASO, and again, we are very encouraged as mentioned in our prepared remarks by the data center regulations that really turn over to the ASO to determine what is underutilized capacity.

Speaker #1: Here, as it relates to our gas-fired steam units—so again, we're working with them very collaboratively here as we move forward. I would say, with the MOU and the definitive agreements that we have with CPP Investments and Brookfield, those continue to advance.

Speaker #1: As we highlighted when we announced the MOU back in February, we're again working alongside those two parties, and we continue to remain very confident in our ability to bring forward our data center option here later in the year.

Mark Jarvi: The expectation is a matter of months? Could it be a couple of quarters before you have clarity on the underutilized assets? Yeah.

Speaker #5: So is the expectation a matter of months? Could it be a couple of quarters before you have clarity on the underutilized assets? Yeah.

Joel Hunter: Hard to say. We can't really speak for the AESO, Mark. We are actively engaged with them. We're hopeful it will be in the next quarter or so. We can't speak on behalf of them as to the timing.

Speaker #1: Hard to say. We can't really speak for the ASO, Mark. But we are actively engaged with them, so we're hopeful it will be in the next quarter or so.

Speaker #1: But we can't speak on on behalf of them as to the timing.

Mark Jarvi: That might influence how you think about scaling beyond the 230 MW. If that drags on a little bit, hopefully it doesn't, would you look at maybe moving to FID on the first phase of the 230 MW from phase 1 allocation and then subsequent scale up after that through a follow-on agreement, or is there a way to sequence sort of, I guess, moving through FID?

Speaker #5: And then, you know, obviously that might influence how you think about scaling beyond the 230 megawatts. So if that drags on a little bit—hopefully it doesn't—would you look at maybe moving to, like, FID on the first phase of the 230 megawatts from phase one allocation, and then subsequent scale-up after that through a follow-on agreement? Or, like, is there a way to sequence, sort of, I guess, moving through FID?

Joel Hunter: I think that's very possible here, Mark, that we would look to that. Again, it's really up to us along with Brookfield and CPPI to determine that. As we said before, 230, we were very pleased with that in the phase 1 allocation. Looking forward to how we can build upon that. I'd say that there's possibility here that that could advance the 230 before the remaining here with the underutilized capacity.

Speaker #1: I think that's very possible here, Mark, that we would look to that. Again, it's it's really up to you know, us along with with Brookfield and CPPI to determine that.

Speaker #1: But as we said before, you know, 230 — we were very pleased with that in the Phase One allocation. And then, looking forward to how we can build upon that.

Speaker #1: So I'd say that there's a possibility here that that could advance the 230 before we, you know, the remaining here with the underutilized capacity.

Mark Jarvi: Okay, I'll leave it there for now.

Speaker #5: Okay, I'll leave it there for now.

Joel Hunter: Thanks, Mark.

Speaker #1: Thanks, Mark.

Operator: Thank you. Our next question is going to come from the line of Maurice Choy with RBC Capital Markets. Your line is open. Please go ahead.

Speaker #3: Thank you. And our next question is going to come from the line of Maurice Choi with RBC Capital Markets. Your line is open—please go ahead.

Maurice Choy: Thank you, good morning, everyone. Just wanted to touch on any updates you have on the asset recycling initiatives that was mentioned earlier to reduce debt. What are some of the things that are influencing the timing, and perhaps selection of some of these assets for sale?

Speaker #5: Thank you, and good morning, everyone. I just wanted to touch on, you know, any updates you have on the asset recycling initiatives that were mentioned earlier to reduce debt.

Speaker #5: What are some of the things that are influencing the timing, and perhaps the selection, of some of these assets for sale?

Joel Hunter: Yeah. Thanks, Maurice. We are very active. We have a few that are well underway. Obviously, we can't give everything away here as we're in processes, if you will. I think what you'll see going forward here, Maurice, just given the amount of opportunities that we see going forward, whether it's a Centralia coal-to-gas conversion, AI data centers, M&A opportunities, further kind of organic growth in our portfolio that we're seeing, that I think portfolio rotation will become more active here. We do have a few processes underway. Can't say anything more, we are certainly very active in that space right now.

Speaker #1: Yeah, thanks, Maurice. You know, we are very active. We have a few that are well underway. Obviously, we can't give everything away here as we're in in in in processes, if you will.

Speaker #1: I think what you'll see going forward here, Maurice, just given the the amount of opportunities that we see going forward, whether it's a Centralia coal to gas conversion, AI data centers, M&A opportunities, and then further kind of organic growth in our portfolio, that we're seeing that in portfolio rotation will become more active.

Speaker #1: We do have a few processes underway. I can't say anything more, but we are certainly very active in that space right now.

Maurice Choy: Looking forward to hearing more of that. If I could just finish off with just a more broad discussion about forward power prices. I think over the last few weeks, since all these announcements were made, we've seen forward prices move up a little bit, particularly for 2029. Yet it still is below the CAD 80 to 120 range that you laid out in Investor Day. You mentioned at the start of the call that you've seen a lot of positive developments in the province thus far. Just curious as to what else you're expecting to hear in the coming months that would prompt the forwards to rise into your projected range.

Speaker #5: Looking forward to hearing more of that. And if I could just finish off with a more broad discussion about forward power prices. I think over the last few weeks, since all these announcements were made, we've seen forward prices move up a little bit, particularly for 2029.

Speaker #5: Yet it still is below the 80 to 120 range that you laid out at Investor Day. You mentioned at the start of the call that you've seen a lot of positive developments in the province thus far.

Speaker #5: I'm just curious as to what else you're expecting to hear in the coming months that would prompt the forwards to rise into your projected range.

Joel Hunter: First of all, Maurice, when you look out further like to Cal 28 and Cal 29, there isn't a lot of liquidity. Generally, when you look at forward pricing, you're out 12 to maybe 18 months at best. When I look at Cal 29 today, I think it's marked around CAD 81. It is actually in the range of that CAD 80 to 120, that we highlighted at Investor Day. Certainly, we've seen an improvement in those forward prices since even the announcement with Meta around their data center project with Kineticor and Pembina. We remain very encouraged by that. I think for the market, as we move forward here, just getting further clarity around the ramping of the load growth will certainly support further the forward pricing.

Speaker #1: You know, first of all, Maurice, when you look out further like to Cal 28 and Cal 29, you know, there isn't a lot of liquidity.

Speaker #1: Generally, when you look at kind of forward pricing, you're up, you know, 12 to maybe 18 months at best. And when I look at Cal '29 today, I think it's marked around $81.

Speaker #1: So, it is actually in the range of that 80 to 120, you know, that we highlighted at Investor Day. And certainly, we've seen an improvement in those forward prices since, you know, even the announcement with Meta around their data center project with Kineticore and Pameta.

Speaker #1: So we remain very encouraged by that. I think for the market, as we move forward here, just getting further kind of clarity around the ramping of the load growth will certainly further support the forward pricing.

Joel Hunter: Again, when I look at where we are today for Cal 29 from where we were back at Investor Day at the end of March, we've certainly seen an improvement there. I would expect that over time, as the market sees or has better visibility behind the load ramp, if you will, that will then further support these forward prices and could even go higher.

Speaker #1: So again, when I look at where we are today, for Cal 29, for from where we were pocket investor day at the end of March, we've certainly seen an improvement there.

Speaker #1: But I would expect that over time, as the market sees or has better visibility behind kind of the load ramp, if you will, that will then further support these forward prices and could even go higher.

Maurice Choy: Maybe on that last note, a quick follow-up here. Obviously, we know where CONE is in the province. Also historically when we had, I think it was 2021 to 2023, when we had triple-digit power prices, that led to the regulator looking more into the industry. In this world of affordability, is there such thing as a balance number where pretty much everyone's happy?

Speaker #5: Maybe on on that last note and a quick follow-up here. Obviously, we know where cone is in the province. But also historically, when we had, you know, I think it was 2020, one to 2023, when we had triple digit power prices.

Speaker #5: That led to the regulator looking more into the industry. In this world of affordability, like is there such thing as a balanced number where you know, pretty much everyone's happy?

Joel Hunter: Yeah. When you look at, again, the CONE or the Cost of New Entry that you referred to, I know that that was something that was highlighted with the recent announcement from Pembina and Kineticor, kind of in the low CAD 100s, if you will, which completely makes sense, right, given the cost of new build that we're seeing today relative to even where we were back in 2021 and 2023, as you referenced, where we saw triple-digit pricing. This I think, is where it's really important to have legacy generation, like we have with our gas-fired steam units to help support the infrastructure build-out that we've talked about. That pricing would be below CONE. Where you're seeing here going forward is the market will continue to tighten.

Speaker #1: You know, yeah, when you look at the the again, the the cone or the cost new entry that you referred to, and I know that that was something that was highlighted with the recent announcement from from Pemada and Kinetic Core, you know, kind of in the in the low 100s, if you will, which completely makes sense, right?

Speaker #1: Given the the cost of new build that we're seeing today, relative to even where we were back in 2021 and 2023, as as you referenced where we saw triple digit pricing, again, this I think is where it's really important to have kind of legacy generation like we have with our gas fired steam units, to help support the infrastructure build-out that we've talked about, that you know, that pricing would be you know, below cone.

Speaker #1: But what you're seeing here, you know, going forward, is the market will continue to tighten. We're not seeing much by way of new supply, but we're obviously seeing load growth coming—whether it's organically in the province, as we highlighted at our Investor Day back in March, along with phase one here.

Joel Hunter: We're not seeing much by way of new supply, but we're obviously seeing load growth coming, whether it's organically in the province, as we highlighted at our Investor Day back in March, along with phase I here. We can't say exactly where that price point would be, but I think when you look at Alberta relative to other jurisdictions in North America, we remain very cheap given the surplus generation that we see here. Again, I think it really supports why legacy generation should be utilized, just given that it is at a price that is below CONE that we're seeing today. Going forward, it'll be what it'll be, if you will, as it relates to if there's new generation required and given the cost of that new generation to ensure that the generation provider is earning a full return on capital.

Speaker #1: So we can't say exactly where that price point would be, but I think, when you look at Alberta relative to other jurisdictions in North America, we remain very cheap given the surplus generation that we see here.

Speaker #1: And again, I think it really supports why legacy generation should be utilized, just given that it is at a price that is below CONE.

Speaker #1: That we're seeing today. But you know, going forward, it'll be what it'll be, if you will, as it relates to if there's new generation required. And given the cost of that new generation, to ensure that the generation provider is earning a full return of and on capital, the price will be what it is. And so again, I can't say exactly where that price point would be, where there is maybe some kind of, I think, concern around, you know, power prices overall for consumers.

Joel Hunter: The price will be what it is. Again, I can't say exactly where that price point would be, where there is maybe some kind of, I think, concern around power prices overall for consumers. The other thing to remind yourself of is that when you look at Alberta, when you look at the average power bill, roughly a third is really the price of the electron, and two-thirds is really through the transmission and distribution costs. To the extent you see additional load come, what you'd hope to see is that the transmission and distribution costs are kind of butter spread more evenly, given the additional load here. That also has to be taken into factor. It's just not the cost of power at the end of the day that impacts consumers. It's all these other costs as well.

Speaker #1: What that should remind you of is that, when you look at Alberta and you look at the average power bill, roughly a third is really the price of the electron, and two thirds is really through the transmission and distribution.

Speaker #1: Costs. So, to the extent you see additional load come, where you'd hope to see that is the transmission and distribution costs are kind of spread more evenly given the additional load here.

Speaker #1: So that helps us and has to be taken into account. It's not just the cost of power at the end of the day that impacts consumers.

Speaker #1: It's all these other costs as well.

Maurice Choy: That's a really good point. Thank you very much for that follow, Joel.

Speaker #5: That's a really good point. Thank you very much for the clarification.

Joel Hunter: Thanks, Maurice.

Speaker #1: Thanks, Maurice.

Operator: Thank you, and one moment for our next question. Our next question is going to come from the line of Robert Hope with Scotiabank. Your line is open. Please go ahead.

Speaker #2: Thank you. One moment for our next question. Our next question will come from the line of Robert Hope, Wisconsin Bank. Your line is open.

Speaker #2: Please go ahead.

Robert Hope: Morning, everyone. Appreciate the commentary on the asset sales potentially strengthening the balance sheet and acknowledge that you may be limited on what you can say. That being said, how do you think about an asset sale program when you have quite a large uncertainty out there regarding the Brookfield Renewable power option and the potential for it to top up and provide what could be a significant amount of capital for TA?

Speaker #6: Morning, everyone. We appreciate the commentary on the asset sales potentially strengthening the balance sheet, with the acknowledgment that you may be limited in what you can say.

Speaker #6: You know, but that being said, how do you think about an asset sale program when you have, you know, quite large uncertainty out there regarding the Brookfield Hydro option and the potential for it to top up and provide, you know, what could be a significant amount of capital for TA?

Joel Hunter: Yeah, Rob, I think it's both. When we look at how we further strengthen the balance sheet here, we certainly factor, at some point in time, we can't predict when, but the option that Brookfield has to convert into the hydro here in Alberta. That's one piece of it, and certainly would not only get the cash infusion that would come in from a potential top up, but also CAD 750 million of debt that would essentially come off the balance sheet as it relates to the rating agencies. That's one important factor or lever, if you will, to strengthen the balance sheet. I think it's all of it. It's also doing additional asset sales. What we're seeing here is just tremendous opportunities for our company. As I mentioned earlier, when you think about the Centralia coal-to-gas conversions being one.

Speaker #1: Yeah, Rob, I think it's both. When we look at how we further strengthen the the balance sheet here, you know, we certainly factor, you know, at some point in time, we can't predict when, but the the option that Brookfield has to convert into to the hydro here in Alberta, that's one piece of it.

Speaker #1: And certainly would, you know, not only get the cash infusion that would come in from a a potential top up, but also 750 million of debt that would essentially come off the balance sheet as it relates to to the radiate seas.

Speaker #1: So that's one important factor, or lever, if you will, to strengthen the balance sheet. But I think it's all of it. It's also doing additional asset sales, because what we're seeing here is just tremendous opportunities for our company. As I mentioned earlier, you know, we think about the Centralia coal-to-gas conversion as being one. The M&A opportunities that we're seeing out there, like we did with the Colorado acquisition here just over a month ago.

Joel Hunter: The M&A opportunities that we're seeing out there, like we did with the Colorado acquisition here just over a month ago, along with just other kind of greenfield opportunities that we're seeing in our portfolio that might be further down in the decade, if you will. That will require capital. Certainly there's no shortage of uses of capital, if you will. As we look at how we can strengthen our balance sheet, provide incremental cash to the balance sheet, it's obviously Brookfield's conversion is factored there on top of asset recycling.

Speaker #1: Along with just other kind of greenfield opportunities that we're seeing in our portfolio that might be further down in the decade, if you will, that will require capital, so certainly there's no shortage of uses of capital, if you will.

Speaker #1: So, as we look at how we can strengthen our balance sheet and provide incremental cash to the balance sheet, obviously the Brookfield conversion is factored in there on top of asset recycling.

Robert Hope: All right. Appreciate that. Maybe just going back to some prior commentary on the BYOG process as well as the commentary on repurposing some assets. When you think about your asset fleet in Alberta, how do you think about the decision tree of using, we'll call it your steam conversions on an interim basis as a bridge to, we'll call it a larger brownfield expansion of your project? How do you work through the uncertainty of you don't quite know what the AESO will ultimately land on?

Speaker #6: All right. Appreciate that. And then maybe just going back to some prior commentary on the BYOG process as well as the commentary on repurposing some assets.

Speaker #6: You know, when you think about your asset fleet in Alberta, you know, how do you think about the decision tree of, you know, using we'll call it your steam conversions on an interim basis as a bridge to we'll call it a larger brownfield expansion of your project?

Speaker #6: And and how do you work through the uncertainty of, you know, you don't quite know what the, you know, what the ASA will ultimately land on?

Joel Hunter: Yeah, I think, part of this is first is really landing on how much capacity, as you said, of the gas-fired steam units that we can use or would constitute underutilized or bring your own generation, if you will. That's the first part here is part of that decision tree. Obviously there can be a wide range there, given that we have a very sizable gas-fired steam fleet here. As I mentioned in my remarks, the capacity factor has been around 20% as relates to 2025. We do see excess capacity there that could be used as bring your own generation.

Speaker #1: Yeah, I think, you know, part of this is, you know, first is really landing on, you know, how much capacity of the, as you said, of the gas-fired steam units that we can use or would constitute underutilized, or 'bring your own generation,' if you will.

Speaker #1: That's the first part here. Then it's part of that decision tree. And so, obviously, there can be a wide range there, given that we have a very sizable gas-fired steam fleet here, and as I mentioned in my remarks, the capacity factor has been around 20% as it relates to 2025.

Speaker #1: So we do see excess capacity there that could be used as bring your own generation. And what I really like about that is, you know, for the data center or AI infrastructure build out is, as you know, like the the cost of new build is is just so expensive today and the supply chain constraints are are so challenging.

Joel Hunter: What I really like about that is for the data center or AI infrastructure build-out is, as you know, the cost of new build is just so expensive today and the supply chain constraints are so challenging that using these units to support the AI infrastructure build-out will then lead to new build sometime next decade, because these units won't run forever. It is, in a way, kind of like a bridge. I don't like to use that term, but that's kind of what this would be, is that you get the AI infrastructure built in the province, supported by our existing gas-fired steam units. At some point in time, we would look to then repower those units so they could run for decades after that.

Speaker #1: That using these units to support the AI infrastructure build out will then lead to new build sometime next decade because these units won't run forever.

Speaker #1: So, it is, in a way, kind of like a bridge. I don't like to use that term, but that's kind of what this would be: you get the AI infrastructure built in the province, supported by our existing gas-fired steam units, and then at some point in time we would look to then repower those units so that they can run for, you know, decades after that.

Joel Hunter: That's, again, I see this is where it's very compelling for Alberta as it relates to the fact that we do have surplus generation. The supply chain constraints that we see that this fits really nicely that we could use. This could be gas-fired steam units. There would be a new build down the road that would be underpinned by long-term contracts with our customers.

Speaker #1: So, that's again—I see this is where it's very compelling for Alberta, as it relates to the fact that we do have surplus generation.

Speaker #1: You know, the the supply chain supply chain constraints that we see that this fits really nicely that we could use this the gas fired steam units and but then there would be new build, you know, down the road that would be underpinned by long-term contracts with our our our customers.

Robert Hope: Thank you.

Speaker #6: Thank you.

Joel Hunter: Thanks, Rob.

Speaker #1: Thanks, Rob.

Operator: Thank you. One moment for our next question. Our next question will come from the line of John Mould with TD Securities. Your line is open please.

Speaker #2: Thank you. One moment for our next question. Our next question will come from the line of John Mold with TD Securities. Your line is open.

Speaker #2: Please.

John Mould: Hi. Morning, everybody. Maybe just to follow on on that last question. On the repowering projects that you have, I guess Flippy as well on the greenfield side. I guess how active are you on those in terms of costing activities, planning, just to be in a position to proceed rapidly with those if there is some kind of meaningful load growth that drives a need for those? Should investors really think of those as more of a longer-dated option into the next decade, depending on how possibly well into the next decade? You flagged the timeline of the coal-to-gas retirements in the past. Just in terms of maybe meeting the province's load growth more on a long-term basis.

Speaker #7: Hi, morning everybody. Maybe just to follow up on that last question. You know, on the repowering projects that you have and, you know, I guess Flippy as well on the greenfield side, I guess, how active are you?

Speaker #7: You know, on those in terms of costing activities, you know, planning, just just to be you know, in a position to proceed rapidly with those if there is, you know, some kind of meaningful low growth that that that drives a need for those.

Speaker #7: Or should investors, you know, really think of those as, you know, more of a longer-dated option into the next decade, you know, possibly well into the next decade depending on how it goes.

Speaker #7: You know, you flagged the timeline of the coal and gas retirements in the past — just in terms of maybe meeting the province's, you know, load growth more on a long-term basis.

Joel Hunter: John, when you reference Flippy and Keephills 1 and Sundance 5, the total is just over 2 gigawatts. I'd say there's still a lot of work going on today. It's still very early days. Again, you can see as part of our path forward here, first step is utilizing the underutilized capacity we have with our gas-fired steam units. That makes the most sense. Then look to potentially build out these sites, if you will, next decade. It's not something that we'd look to be building tomorrow, because we don't need to. The most effective way is to use the gas-fired steam units. They're the most cost-effective, and it's all about speed to power, too, for AI infrastructure. The assets are there, as you know. The gas is there, the transmission's there, the water's there, everything is there.

Speaker #1: Yeah, John, when you look, when you reference, you know, Flippy, and Keephills 1 and Sun 5, there are, you know, the total is just over, you know, 2 gigawatts.

Speaker #1: You know, I'd say there's still a lot of work going on today. It's still very early days. But again, you can see as part of our path forward here, the first step is utilizing the underutilized capacity that we have with our gas-fired steam units.

Speaker #1: That makes the most sense. And then look to potentially build out these these sites, if you will, next decade. So it's not something that we'd look to be building tomorrow.

Speaker #1: So we don't need to. The most effective way is to use the gas-fired steam units. They're the most cost-effective. And it's all about speed to power too, for AI infrastructure.

Speaker #1: The assets are there—as you know, the gas is there, the transmission is there, the water is there. Everything is there. So use those first, but knowing again, as mentioned earlier, they're not going to run forever.

Joel Hunter: Use those first, knowing, again, as mentioned earlier, they're not going to run forever. Then look to these sites, like whether it's Wippee K1 or Sun 5, as you talked about, as to repower down the road. It's a stage process here. It's certainly something we're not looking at doing tomorrow. This would be next decade. The work is underway now because these take a long time. To do all the planning, the stakeholder engagement, all those things that's underway. We do have a bit of time here because we view really repurposing our gas-fired steam units is the way to go.

Speaker #1: And then look to these sites, like whether it's Flapjack K1 or Sun 5, as we talked about, to repower down the road.

Speaker #1: So that's kind of, you know, it's kind of a staged process here. So it's certainly something we're not looking at doing tomorrow. This would be in the next decade.

Speaker #1: But the work is underway now because these take a long time, right? To do all the planning, the stakeholder engagement, all those things—that's underway.

Speaker #1: But we do have a bit of time here, because we view really repurposing our gas-fired steam units as the way to go.

John Mould: Okay, thanks for that. Then maybe just on your hedges, you layered on about, I think 20% or so incrementally just in terms of volume for next year. What kind of appetite are you seeing from customers to contract at more normalized pricing levels versus holding on to something more like the spot exposure today? Just in terms of how that contributes to your ability to add more meaningful length to your hedges between now and the end of the year.

Speaker #7: Okay, thanks for that. And then maybe just on your hedges -- you know, you layered on about, I think, 20% or so incrementally just in terms of volume for next year.

Speaker #7: What kind of appetite are you seeing from customers to contract at, you know, more normalized pricing levels versus holding on to, you know, something more like the spot exposure today and just in terms of how that contributes to your ability to, you know, add more meaningful length to your hedges?

Speaker #7: You know, between now and the end of the year.

Speaker #1: Yeah, you know, we've John, obviously we we always remain very active as it relates to our, you know, managing our hedge portfolio. You know, roughly half of the portfolio is our CNI business, which is, you know, think of those as almost like three-year contracts that continue to roll kind of every year.

Joel Hunter: John, obviously, we always remain very active as it relates to managing our hedge portfolio. Roughly half of the portfolio is our C&I business, which is, think of those as almost like 3-year contracts that continue to roll kind of every year. Those tend to are transacted a bit of a premium over where you would see the forward pricing. The team looks for opportunities here, where there's a nice spread that they see that they go, "We're going to lock in these prices." I'm very encouraged by what the team has done so far. If you look at on one of our slides, when we show that for next year, we have around 6,700 gigawatt hours already hedged at CAD 64. Again, well above where we're at today when we look at kind of spot pricing.

Speaker #1: And those tend to be transacted at a bit of a premium over where you would see, like, the forward pricing. So, you know, the team looks for opportunities here.

Speaker #1: You know, where there's a nice spread that they see that they go, "we're going to lock in these prices." So I'm very encouraged by what the team has done so far.

Speaker #1: If you look at, you know, one of our on one of our slides, we show that for, you know, next year we have around 6700 gigawatt hours already hedged to $64.

Speaker #1: Again, well above where we're at today when we look at kind of spot pricing. And that's due in large part to our our CNI business along with adding financial hedges where we can.

Joel Hunter: That's due in large part to our C&I business, along with adding financial hedges where we can. This is something that it's a real core competency, if you will, of TransAlta, that they look for these opportunities to kind of lock in when they can. I expect they will continue to roll in hedges here going forward. I can't say how much, but they will find opportunities. Again, a large part of that is due to the C&I book that we have.

Speaker #1: So this is something that it's a real core competency, if you will, of of of Transalta. That they they look for these opportunities to kind of lock in when they in hedges here you know, going forward.

Speaker #1: And I can't say how much, but they will find opportunities. And again, a large part of that is due to the CNI book that we have.

John Mould: Okay. I'll get back in the queue. Thank you.

Speaker #7: Okay, I'll get back in the queue. Thank you.

Operator: Thank you. One moment for our next question. Our next question is a follow-up question from the line of Mark Jarvi with CIBC. Your line is open. Please go ahead.

Speaker #2: Thank you. One moment for our next question. Our next question is a follow-up from the line of Mark Jervy with CIBC.

Speaker #2: Your line is open. Please go ahead.

Mark Jarvi: Yeah, thanks. Just following up on the underutilized assets. If you got a meaningful amount granted by the AESO, like a gigawatt or more, would that likely be used to scale up increased opportunities around Keephills? Or are there conversation opportunities to look at another site like Sundance?

Speaker #8: Yeah, thanks. Just following up on the underutilized assets. If you got a meaningful amount granted by the ASO, like a gigawatt or more, would that likely be used to scale up, increase opportunities around Keephills, or are there conversation opportunities to look at another site, like Sundance?

Joel Hunter: Right now, Mark, we are focused around Keephills. That depending on what the ultimate number is, that we certainly have the land there, the gas supply is there, the transmission is there to support additional build-outs. If you talk of up to a gigawatt, or even higher, certainly that could be supported at around the Keephills facility.

Speaker #1: You know, right now, Mark, we're we are focused around around Keep Hills. That you know, depending on what the ultimate number is, that we certainly have the land there, the gas supply is there, the transmission is there, to support, you know, additional build out.

Speaker #1: So if you talk up to a gigawatt, or even higher, certainly that could be supported at around the the Keep Hills facility.

Mark Jarvi: Okay, thanks.

Speaker #8: Okay, thanks.

Operator: Thank you. One moment for our next question. Our next question is going to come from the line of Patrick Kenny with National Bank Capital Markets. Your line is open. Please go ahead.

Speaker #2: Thank you. question. Our next question is going to come from the line of Patrick Kennedy with National Bank Capital Markets. Your line is open.

Speaker #2: Please go ahead.

Patrick Kenny: Yeah, good morning. I know you guys are still working on the Class 3 estimate for the Centralia Unit 2, just wondering if perhaps there's been any progress with potentially tapping into more gas supply and looking at repowering Unit 1. How we should be thinking about the timing of that opportunity, and maybe a comment on how those brownfield returns might stack up to, say, Alberta greenfield or other US M&A opportunities.

Speaker #9: Yeah, good morning. I know you guys are still working on the Class 3 estimate for the Centralia unit, too, but just wondering if perhaps there's been any progress with, you know, potentially tapping into more gas supply and looking at repowering Unit 1.

Speaker #9: How should we be thinking about the timing of that opportunity? And maybe a comment on how those brownfield returns might stack up to, say, Alberta greenfield or other U.S. M&A opportunities.

Joel Hunter: Yeah, Pat. When we look at with Centralia, as you highlighted, we are working toward the Class 3 estimate. Everything is on schedule such that we'll be in a position to have that by the end of the year. It to be then on track to make FID very early in 2027. Again, subject to the permits that are required both for ourselves and obviously with PSE, that they get the WUTC approval. That work is well underway there at the facility. When you look at the returns, hard to beat. As we highlighted when we made the announcement for Centralia, and we said, our estimate is a CAD 600 million capital cost at a 5.5x build multiple. Obviously very attractive. Like any company, I wish we had more of those types of opportunities with those types of multiples.

Speaker #1: Yeah, Pat, you know, when we look at Centralia, as you highlighted, we are working toward the Class 3 estimate. Everything is on schedule such that we'll be in a position to have that by the end of the year.

Speaker #1: We'd then be on track to make the FID very early in 2027. Again, subject to the permits that are required both for ourselves and, obviously, with PSE, that they get the WTC approval.

Speaker #1: So that work is well underway there at the facility. It is, you know, when you look at the returns—I mean, hard to beat.

Speaker #1: You know, as we've highlighted when we made the announcement for Centralia, you know, we said, you know, kind of our estimate is a $600 million capital cost at a 5.5 times build multiple.

Speaker #1: So obviously, very attractive. I wish we had—like any company—I wish we had more of those types of opportunities with those types of multiples.

Joel Hunter: Again, very attractive, and again, just shows the value of having legacy assets where you can either repurpose, maybe extend a contract or what have you, that offer very compelling risk-adjusted returns. When you look at the gas supply, just recall that the gas supply for Unit 2, that's on for PSE as the customer to provide not only the gas, but obviously the transportation of that gas to the facility. There is enough gas supply there. The gas line is around 1,500 feet away from the facility, so it is very close. As it relates to Unit 1, I think this is a longer-term option because we've been having discussions around that, but very early days. That it would be very compelling given where the location, given the transmission's there, the water is there. You are 85 miles south of Seattle.

Speaker #1: So again, very, very attractive. And again, it just shows the value of having legacy assets where you can either repurpose, maybe extend a contract, or what have you, that offer very compelling risk-adjusted returns.

Speaker #1: When you look at the gas supply, you know, just recall that the gas supply for for unit two that's on for PSE as the customer.

Speaker #1: To provide not only the gas, but obviously the the the the transportation of that gas to the facility and there is enough gas supply there.

Speaker #1: The gas line is around 1,500 feet away from the facility, so it is very close. As it relates to Unit One, I think this is a longer-term option because we've been having discussions around that, but it's still very, very early days.

Speaker #1: That it would be very compelling, given the location, given the transmissions there, the water is there. You are 85 miles south of Seattle.

Joel Hunter: There's a lot of reasons why it'd be very good to be able to expand that facility. It comes down to, again, gas supply. It's the Williams Northwest Pipeline that is full today, but certainly something that we're talking to them on. Also, just trying to find, obviously, a customer, like a commercial arrangement. Again, very early days, and this would be next decade. We do see that there could be an option there. I wouldn't put a high probability at this point in time. The focus, again, is on getting Unit 2 to FID early next year and moving that project along to get it in service by Q4 2028.

Speaker #1: So there's a lot of reasons why it would be very good to to be able to expand that facility. It comes down to, again, gas supply.

Speaker #1: It's the northwest Williams northwest pipeline. That you know, is full today, but certainly something that we're talking to them on. And then also, you know, just trying to find, you know, obviously, you know, a customer like a commercial arrangement, but but again, very, very early days and this would be kind of next decade, but you know, we do see that there could be an option there.

Speaker #1: But I wouldn't put a high probability on it at this point in time. And again, the focus is on getting Unit Two to FID early next year and moving that project along to get it in service by the fourth quarter of 2028.

Patrick Kenny: Okay. That's perfect. Thanks for that. Maybe just on the M&A front, obviously, I know you can't comment on specific opportunities, but just curious, after the Colorado transaction closes, how you might describe your wish list in terms of geography, asset type, or technology, fuel supply. Just how you're thinking about maximizing the value of the portfolio going forward through M&A, whether it's capturing synergies across the portfolio or otherwise.

Speaker #9: Okay, that's perfect. Thanks for that. And then maybe just on the M&A front, obviously I know you can't comment on, you know, specific opportunities, but just curious, you know, after the Colorado transaction closes, how you might describe your wish list in terms of geography, asset type or, you know, technology, fuel supply.

Speaker #9: Just how you're thinking about maximizing the value of the portfolio going forward through M&A—whether it's capturing synergies across the portfolio or otherwise.

Joel Hunter: Yeah, Pat, again, we're very pleased with the Colorado acquisition. I think this is an acquisition that will serve our shareholders for decades to come, given the weighted average duration is 27 years. As we've talked about before, the full cost pass-through that we have there. A very low risk investment for us that, again, in a core geography, that now we have a presence in Colorado with these two facilities. We're very happy with that. Going forward, though, the M&A strategy remains the same, focused on our four core geographies. You've seen us transact. The Heartland acquisition was here in Alberta, Hut 8 acquisition was in Ontario, and this most recent one in Colorado. I would say with technology, we remain agnostic. It's all about the highest risk-adjusted returns. That's the key for us.

Speaker #1: Yeah, Pat, you know, again, we're very, very pleased with the Colorado acquisition. I think this is an acquisition that will serve our shareholders for decades to come, given the weighted average duration is 27 years, and as we've talked about before, the full cost pass-through that we have there.

Speaker #1: So a very low risk investment for us that again, in a core geography, that now we have a presence in in Colorado. With these two facilities, so we're very, very happy with that.

Speaker #1: You know, going forward, the M&A strategy remains the same, focused on our forecast geographies. So, you've seen us transact—for example, the Heartland acquisition was here in Alberta.

Speaker #1: HUD 8 acquisition was in Ontario, and then this most recent one, you know, in Colorado. I would say with technology, we remain agnostic; it's all about the highest risk-adjusted returns.

Speaker #1: That's the key for us. And so it just so happens, you know, recently it's been more on the gas part side of things. When you look at, you know, again, Hut 8, you look at Colorado, you look at Heartland.

Joel Hunter: It just so happens, recently it's been more on the gas-fired side of things. When you look at, again, Hut 8, you look at Colorado, you look at Heartland. If there's opportunities in renewables, we're certainly looking at those as well. Again, it comes down to the highest risk-adjusted returns in our four key geographies. We remain very active there. We're also conscious of our balance sheet and what we can do. This is where, again, I think as we talked about earlier, active asset optimization, if you are, portfolio rotation, certainly would support those opportunities going forward. It's really kind of more the same, if you will, as it relates to how we look at M&A.

Speaker #1: But if there's opportunities in the renewables, we're certainly looking at those as well. But again, it comes down to the highest risk adjusted returns.

Speaker #1: In our four key geographies. So we remain very active there. But we're also conscious of our balance sheet and what we can do. And this is where, again, I think as we talked about earlier, active asset optimization, if you are a portfolio rotation, certainly with support, those opportunities going forward.

Speaker #1: So it's really kind of more the same, if you will, as it relates to how we look at M&A.

Patrick Kenny: Okay. That's great. Thanks, Joel.

Speaker #9: Okay, that's great. Thanks, Joel.

Joel Hunter: Thanks, Pat.

Speaker #1: Thanks, Pat.

Operator: One moment for our next question. Our next question will come from the line of Benjamin Pham with BMO. Your line is open. Please go ahead.

Speaker #2: Thank you. In one moment for our next question. Our next question will come from the line of Benjamin Pham with BMO. Your line is open.

Speaker #2: Please go ahead.

Benjamin Pham: Hi. Thank you. Good morning. I want to follow up on our last question around your comments on risk-adjusted returns across the portfolio, including M&A. Can you parse that out a little bit? Because it sounds like if you're going on different risk profiles within energy infrastructure, that return spectrum does change quite a bit, i.e., the Colorado transaction, where it's long-dated cash flows and the return may be a different profile than maybe some of the other assets. Can you maybe put the bookends of the returns and how you adjust for the risk differences?

Speaker #10: All right, thank you. Good morning. I want to follow up on our last question around your comments on risk-adjusted returns across the portfolio, including M&A, and can you parse that a little bit?

Speaker #10: Because it sounds like, if you're going on different risk profiles within energy infrastructure, that return spectrum does change quite a bit—i.e., the Colorado transaction, where it's long-dated cash flows and the return may be a different profile than maybe some of the other assets.

Speaker #10: But can you maybe put the bookends on the returns, and how you adjust for the risk differences?

Joel Hunter: Yeah. I would say, Ben, when we look at the various opportunities, I'll just give you some relevant examples here. You look at the Heartland acquisition, where not fully contracted but substantially contracted. Here in Alberta, older vintage assets, we did that at around a 5.4x multiple. When you look at Hut 8, again, older assets, shorter contracts, but we believe we'll be able to recontract those assets in 5-year increments. Again, we were able to acquire those at a lower multiple. When you look at Colorado, yes, it was a higher multiple, but it makes a lot of sense, right? That this is brand-new generation, 27-year contracts. We have to look at this on a kind of overall portfolio. That you're going to get some at a lower multiple, there's reasons for that.

Speaker #1: Yeah, you know, I would say, you know, Ben, when we look at, you know, the various opportunities—so I'll just give you some relevant examples here.

Speaker #1: You look at the Heartland acquisition, where it's not fully contracted but substantially contracted. Here in Alberta—older vintage assets. And we did that at around a 5.4 times multiple.

Speaker #1: When you look at HUD 8, again, older assets, shorter contracts, but we believe we'll be able to re-contract those assets, you know, for four- or five-year increments.

Speaker #1: Again, we we were able to acquire those at a lower multiple. When you look at Colorado and yes, it was a higher multiple, but it makes a lot of sense, right?

Speaker #1: That this is brand new generation, 27 year contract, so we have to look at this on a kind of overall portfolio. That you know, I you know, you're going to get some at a at a lower multiple and there's reasons for that.

Joel Hunter: There's going to be some, like Colorado, where it's going to be at a higher multiple that is fair value given, again, the vintage of the assets, given the contracts and the nature of those contracts, and the like. When we look at our opportunities here going forward, you have to take that all into consideration. I think what was important for Colorado is I know some folks looked at really the multiple. That's one way to look at it, but probably the best way to look at it is really the free cash flow yield. The free cash flow yield on that acquisition is approximately 13%. Our free cash flow yield on a TA is around 7%, so it's free cash flow accretive at the end of the day. For us, there's a number of ways we look at acquisitions.

Speaker #1: And there's going to be some like Colorado where it's going to be at a higher multiple. That's that is fair value. Given you know, again, the vintage of the of the assets, given the contracts and the nature of those contracts.

Speaker #1: And the like. So you know, when we look at, you know, our opportunities here, you know, going forward, you know, you have to take that all into to consideration.

Speaker #1: I think what was important for Colorado is, I know some folks looked at, you know, really the multiple. That's one way to look at it.

Speaker #1: But probably the best way to look at it is really the free cash flow yield. The free cash flow yield on that acquisition is approximately 13%.

Speaker #1: And our free cash flow yield on a TA is around 7%, so it's free cash flow accretive at the end of the day. So, you know, for us, there's a number of ways we look at acquisitions.

Joel Hunter: Whether it's an EBITDA multiple, it's a free cash flow yield multiple. We also have to look at the leverage that's on the acquired assets, if any. There's kind of a wide range here. You have to compare everything on a per share basis as well, too, right? That we want to be accretive. At the end of the day, we don't want to do anything that is dilutive, and Colorado was accretive, as I mentioned. Everything has to stack up against on a per share metric basis. Hopefully it gives you some context of how we look at things here. It really depends on the nature of the acquisition.

Speaker #1: You know, whether it's an EBITDA multiple, it's a free cash, it's the leverage that's, you know, on the acquired assets, if any. So there's kind of a wide range here.

Speaker #1: But I think, you know, you have to compare everything on a per share basis as well, too, right? So that, you know, we want to be accretive at the end of the day.

Speaker #1: We don't want to do anything that is dilutive. And Colorado was accretive, as I mentioned. So everything has to stack up, you know, against, on a per share metric basis.

Speaker #1: So hopefully that gives you some context on how we look at things. Here, it really depends on the nature of the acquisition.

Benjamin Pham: Okay. Got it. Thanks for the color. Can you comment really just with some of the credit rating updates. Does that constrain your ability at all from your balance sheet to add on more M&A over the next 12 months? If I can just put a timeframe to that.

Speaker #10: Okay, got it. Thanks, Howard. And can you comment, related to that, on some of the credit rating updates? Does that constrain your ability at all, for your balance sheet, to add in more M&A over the next 12 months—so that I can just put a time frame to that?

Mike Politeski: Hey, Ben. It's Mike here. Maybe I'll handle this one. The negative outlook from S&P, we kind of view that as a temporary hurdle for us. When you look at the soft Alberta power pricing market right now, and Centralia being offline here, as we progress that towards FID, our cash flows have come down. We do see a glide path forward with the recovery of the balance sheet. When you look at the Alberta forward pricing market, you're starting to see that uplift in the back half of 2028 into 2029. If you look at the hedge book we've built here, 2027 sets up pretty nice with 6,600 gigawatts hedged at CAD 64, quite a bit higher than the forward market. If you look at our optimization team and what they are able to do in tough markets, they have pretty amazing capabilities.

Speaker #11: Oh, hey, hey Ben, it's Mike here. Maybe I'll handle this one. Yeah, so the negative outlook from S&P—we kind of view that as a temporary hurdle for us.

Speaker #11: When you look at the soft Alberta power pricing market right now, and Centralia being offline here as we progress that towards FID, you know, our cash flows have come down.

Speaker #11: But we do see a glide path forward with recovery of the balance sheet. And when you look at the Alberta forward pricing market, you're starting to see that uplift in the back half of 2028 into 2029.

Speaker #11: If you look at the hedge book we've built here, 2027 sets up pretty nicely with 6,600 gigawatt-hours hedged at $64. That's quite a bit higher than the forward market.

Speaker #11: If you look at our optimization team and what they are able to do in tough markets, they have pretty amazing capabilities. You saw that here in the second quarter with what they were able to do.

Mike Politeski: You saw that here in the Q2 with what they were able to do. If you look at the data center opportunity in Alberta, we are pursuing, and the nature of our assets and the capital-light nature of that opportunity, that's very credit positive for us. Joel's earlier comments on Centralia and progressing that towards FID and that looking like a COD timing back half of 2028. That's a wave of cash flows coming. The final piece is the asset recycling program. Doing that for multiple reasons, but one benefit of that is obviously proceeds in the door, helping the balance sheet. We see a lot of incremental things that will progress the balance sheet to a position where we want it to be in. In the meantime, is it hampering our flexibility? I would say, no, not really.

Speaker #11: If you look at the data center opportunity in Alberta that we are pursuing, and the nature of our assets and the capital-light nature of that opportunity, that's very credit positive for us.

Speaker #11: And Joel's earlier comments on Centralia and progressing that towards FID, and that, you know, looking like a COD timing in the back half of 2028, that's a wave of cash flows coming.

Speaker #11: And then the final piece is the asset recycling program. We're doing that for multiple reasons, but one benefit is, obviously, the proceeds coming in the door, which helps the balance sheet.

Speaker #11: So, we see a lot of incremental things that will progress the balance sheet to a position where we want it to be. In the meantime, is it hampering our flexibility?

Speaker #11: I would say no, not really. The things we're pursuing right now, we have the flexibility to operate within the bounds of our balance sheet.

Mike Politeski: The things we're pursuing right now, we have the flexibility to operate within the bounds of our balance sheet. We are definitely conscious of the leverage levels and how the rating agencies are viewing it. We see that improving here over the next while, it's something we are actively working towards.

Speaker #11: But we are definitely conscious of the leverage levels and how the rating agencies are viewing it. And you know, we see we see that improving here over the next over the next while.

Speaker #11: And it's something we are actively working towards.

Benjamin Pham: Okay. Thanks for that. Maybe a quick one from me, just to squeeze it in, if I may. You mentioned the work on the folks on Keephills with respect to the data center opportunity. Can you remind me, when you went through the multi-phase process with that asset, was there community engagement involved in that? I know it's an industrial site, there's a plant there. Did you do that and work here? Is this the community feedback and support or lack of support for a site?

Speaker #10: Okay, thanks for that quick one. If I may, I'd like to squeeze in another question. You mentioned the work and the focus on key pillars with respect to the data center.

Speaker #10: Opportunity, can you remind me, when you went through the multi-phase process, what that asset was? Was it community engagement involving that? I know it's an industrial site and there's a plant there.

Speaker #10: Did you do that, and work here, just for the community feedback and support—or lack of support—for a site?

Joel Hunter: Yeah, Ben. Whenever we have any investment that we make, we have community engagements or stakeholder engagement very early on, right at the development stage, really through the whole life cycle of the asset. Once the asset is developed and then operating, we stay in the community. We remain very engaged with the community. Again, we're an important part of these communities in which we operate in. When you look at Keephills, we are, again, very actively engaged there within the community. There is certainly a lot of support there at Keephills, just given the infrastructure is there today. It's been there for many decades. We have to remain very active there and really bring our stakeholders along with us on this journey when we develop any project. It's not only here in Alberta, it's anywhere in which we operate.

Speaker #1: Yeah, Ben. You know, whenever we have. Any investment that we make, you know, we we have community engagements or stakeholder engagement very early on early on right at the development stage.

Speaker #1: And really, through the whole life cycle of the asset. So, once the asset is developed and then operating, we stay in the community.

Speaker #1: We remain very engaged with the community, because again, we're an important part of these communities in which we operate. So, when you look at Keephills, we are, again, very actively engaged there.

Speaker #1: Within the community, there is certainly a lot of support there. And at key pillars, just given the infrastructure that is there today, it’s been there for many decades.

Speaker #1: But, you know, we have to remain very active there, and really bring our stakeholders along with us on this journey when we develop any project.

Speaker #1: And it's not only here in Alberta, it's anywhere in which we operate. Stakeholder engagement is just critical, both through development and throughout the operating life of the asset.

Joel Hunter: Stakeholder engagement is just critical. Through, like I said, development and through the operating life of the asset. Again, we are very engaged there. It's really important that we are very transparent with our stakeholders. We have transparent communication. It's really important that we have that because these are our stakeholders. We want to make sure that we are communicating with them, we're listening to them, understanding what their needs and their concerns are. It really is almost like a partnership at the end of the day, when you are putting infrastructure into a community. I would say with Keephills, we're certainly very actively engaged in that right now and have been for decades because we've been operating there for that long.

Speaker #1: So again, we are very engaged there. It's really important that we're very transparent with our stakeholders. We have transparent communication. It's really important that we have that, because these are our stakeholders.

Speaker #1: And so we want to make sure that, you know, we are communicating with them. We're listening to them, understanding what their needs and their concerns are.

Speaker #1: Because it really is almost like a partnership at the end of the day when you are putting infrastructure into a community, and I would say with Keephills, we're certainly very, very actively engaged in that right now.

Speaker #1: And and have been for for for decades because we've been operating there for for for that long.

Benjamin Pham: Okay, got it. Thank you.

Speaker #10: Okay, got it. Thank you.

Operator: Thank you. There are no further questions at this time. I would like to hand the conference back over to Stephanie Paris for closing remarks.

Speaker #12: Thank you. There are no further questions at this time. I would now like to turn the call back over to Stephanie Paris for closing remarks.

Stephanie Paris: Thank you, everyone. That concludes our call for today. If you have any further questions, please contact the TransAlta Investor Relations team.

Speaker #2: Thank you, everyone. That concludes our call for today. If you have any further questions, please reach out to the team.

Operator: This concludes today's conference call. Thank you for participating. You may now disconnect. Everyone, have a great day.

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