Q2 2023TransAlta Corporation TransAlta Renewables Inc Earnings Call

Speaker 1: Good morning, my name is Joelle and I will be your conference...

Good morning, My name is joelle and I will be your conference operator today at this time I would like to welcome everyone to Transalta Corporation's second quarter 2020 triggers off conference call.

Speaker 1: At this time, I would like to welcome everyone to TransAlta Corporation's second quarter 2020 through results conference call. Lines have been placed on mute to prevent any background noise.

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 Star then the number one on your telephone keypad. If you would like to withdraw your question. Please press star two.

Speaker 1: If you would like to ask a question during this time, simply press star then the number one on your telephone keypad. If you would like to withdraw your question, please press star two.

MS. Valentini you may begin your conference.

Speaker 2: Great. Thank you, Michelle. Good morning everyone and welcome to TransAlta second quarter, twenty twenty.

Chiara Valentini: Great. Thank you, Michelle. Good morning, everyone, and welcome to TransAlta's Q2 2023 Conference Call. With me today are John Kousinioris, President and Chief Executive Officer, and Todd Stack, EVP Finance and Chief Financial Officer. Today's call is being webcast, and I invite those listening on phone lines to view the supporting slides that are posted on our website. A replay of the call will be 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 qualifications set out here on slide two. It's detailed further in our MD&A and incorporated in full for the purposes of today's call. All amounts referenced during the call are in Canadian currency, unless otherwise noted.

Great. Thank you Michele good morning, everyone and welcome to Transalta second quarter 2023.

Speaker 2: With me today are John Puzanaris, President and Chief Executive Officer, and Todd Stack, EBP Finance and Chief Financial Officer.

With me today are John <unk>, President and Chief Executive Officer, and Todd Stack, EVP Finance and Chief Financial Officer.

Speaker 2: Today's call is being webcast and I invite those listening on the phone line to view the slides that are posted on our website. A replay of the call will be available later today and the transcript will be posted to our website shortly thereafter.

Today's call is being webcast and I invite those listening online.

These slides that are posted on our website.

A replay of the call will be available later today and the transcript will be posted to our website. Shortly thereafter.

Speaker 2: All the information provided during this conference call is subject to the forward looking statement qualifications set out here on slide 2. It's details further in our and incorporated full.

All of the information provided during this conference call is subject to the forward looking statement qualification that I see on slide two is detailed further in our MD&A and incorporated.

Speaker 2: All amounts referenced during the call are in Canadian currency unless otherwise known.

Oh Oh.

All amounts referenced during the call are in Canadian currency, unless otherwise noted.

Speaker 2: The non-IFRS terminology used, including adjusted EBITDA, funds from operations, and free Tashflow are reconciled in the MD&A for your reference.

Chiara Valentini: The non-IFRS terminology used, including adjusted EBITDA, funds from operations, and free cash flow, are reconciled in the MD&A for your reference. On today's call, John and Todd will provide an overview of the quarter's results. After these remarks, we will open the call for questions. With that, let me turn the call over to John.

And I for us terminology used.

Adjusted EBITDA funds from operations and free cash flow are reconciled in the MD&A for your reference.

Speaker 2: On today's call, John and I will provide an overview of the porter's results. After these remarks, we will open the call for questions. With that, let me turn the call over to John .

On today's call John will provide an overview of the quarter's results. After these remarks, we will open the call for questions.

Let me turn the call over to John .

Speaker 3: Thank you, Kiara. Good morning, everyone, and thank you for joining our second quarter results call for 2020.

John Kousinioris: Thank you, Kiara. Good morning, everyone, and thank you for joining our Q2 results call for 2023. As part of our commitment towards reconciliation, I want to begin by acknowledging that TransAlta's head office, where we are today, is located in the traditional territories of the Niitsitapi, the people of the Treaty 7 region in southern Alberta, which includes the Siksika, the Piikani, the Kainai, the Tsuut'ina, and the Stoney Nakoda First Nations, as well as the home of Métis Nation Region 3. TransAlta had another exceptional quarter. We're proud of the overall performance of our company and our employees. We delivered CAD 387 million of adjusted EBITDA, a 39% increase over our Q2 2022 results, and free cash flow of CAD 278 million, or CAD 1.05 per share, a 94% increase over Q2 2022 results on a per-share basis. Both metrics beat our expectations for the quarter.

Thank you Chiara good morning, everyone and thank you for joining our second quarter results call for 2023.

Speaker 3: As part of our commitment towards reconciliation, I want to begin by acknowledging that TransAlta's head office, where we are today, is located in the traditional territories of the Nisetapi, the people of the Treaty 7 region in southern Alberta, which includes the Siksika, the Pikani, the Kainai, the Tutsina, and the Stoney Nakoda First Nations, as well as the home of Metis in Region 3.

As part of our commitment towards reconciliation I want to begin by acknowledging the trends out of head office, where we are today is located in the traditional territories of the and it's a choppy the people of the Treaty seven region in Southern Alberta, which includes the sika that'd be corny kind of <unk>, the <unk> and the stunning Dakota first nations.

As well as the home of the <unk> nation, reaching three.

Speaker 3: TransAlba had another exceptional quarter. We're proud of the overall performance of our company and our employees.

Transalta had another exceptional quarter, we're proud of the overall performance of our company and our employees we.

Speaker 3: We delivered $387 million of adjusted EBITDA, 39% increase over our Q2 2022 results, and free cash flow of $278 million, or $1.05 per share, a 94% increase over Q2 2022 results on a per share basis. Both metrics feed our expectations.

We delivered 387 million of adjusted EBITDA, 39% increase over our Q2 2022 results and free cash flow of 278 million.

$1 <unk> five per share on 94% increase over Q2 2022 results on a per share basis.

Both metrics beat our expectations for the quarter.

Speaker 3: Our results benefited from continuing strong power prices in Alberta and Mid-Sea, lower natural gas commodity prices, and the success of our asset optimization and hedging strategy.

John Kousinioris: Our results benefited from continuing strong power prices in Alberta and Mid-C, lower natural gas commodity prices, and the success of our asset optimization and hedging strategies. Overall, the Alberta market was impacted by tighter supply conditions resulting from transmission constraints, which limited imports from adjacent markets, supportive power prices in adjacent markets, which also lowered net imports into Alberta and encouraged exports of power from Alberta to the Pacific Northwest, periods of overlapping outages, and lower than normal wind resources, which impacted renewable generation. We also saw significantly lower fuel costs compared to last year, given lower overall commodity prices and the impact of our hedging program. The higher realized prices, coupled with lower realized gas prices, delivered higher gross margins for our portfolio compared to Q2 2022. Our overall availability was 85%.

Our results benefited from continuing strong power prices in Alberta, and mid C lower natural gas commodity prices and the success of our asset optimization and hedging strategies.

Speaker 3: Overall, the Alberta market was impacted by tighter supply conditions resulting from transmission constraints, which limited imports from adjacent markets, supportive power prices in adjacent markets, which also lowered net imports into Alberta and encouraged exports of power from Alberta to the Pacific Northwest.

Overall, the Alberta market was impacted by tighter supply conditions, resulting from transmission constraints, which limited imports from adjacent markets supported power prices in adjacent markets, which also lowered net imports into Alberta, and encouraged exports of power from Alberta to the Pacific Northwest peers.

Speaker 3: periods of overlapping outages, and lower than normal wind resources which impacted renewable generation.

Kids are overlapping outages and lower than normal wind resources, which impacted renewable generation.

Speaker 3: We also saw significantly lower fuel costs compared to last year, given lower overall commodity prices and the impact of our hedging program.

We also saw significantly lower fuel costs compared to last year, given lower overall commodity prices and the impact of our hedging program.

Speaker 3: The higher realized prices, coupled with lower realized gas prices, delivered higher gross margins for our portfolio compared to Q2 2022.

Higher realized prices, coupled with lower realized gas prices delivered higher gross margins for our portfolio compared to Q2 2022.

Our overall availability was 85%.

John Kousinioris: Apart from our ongoing outage at Kent Hills, our performance had weaker availability due to higher plant outages in the hydro and gas segments, which was partially offset by better performance at Centralia compared to last year. During the quarter, we delivered on a number of key priorities, beginning with the announcement of the proposed acquisition of TransAlta Renewables by TransAlta Corporation. This transaction will not only simplify our corporate structure, it will enhance our strategic position and provide alignment within our clean electricity growth plan in a manner that we believe will create value for all our shareholders. The combination will also deliver capital efficiencies and enhance cash flow predictability and diversification for both sets of shareholders while preserving the combined company's ability to realize future growth.

Speaker 3: Apart from our ongoing outage at Kent Hills, our performance had weaker availability due to higher plant outages in the hydro and gas segments, which was partially offset by better performance at Centralia compared to last year.

Apart from our ongoing outage at Kent Hills, our performance had weaker availability due to higher planned outages in the hydro and gas segments, which was partially offset by better performance at centralia compared to last year.

Speaker 3: During the quarter, we delivered on a number of key priorities, beginning with the announcement of the proposed acquisition of TransAlta Renewables by TransAlta Corporation.

During the quarter, we delivered on a number of key priorities beginning with the announcement of the proposed acquisition of Transalta renewables by Transalta Corporation.

Speaker 3: This transaction will not only simplify our corporate structure, it will enhance our strategic position and provide alignment within our clean electricity growth plan in a manner that we believe will create value for all our

This transaction will not only simplify our corporate structure it will enhance our strategic position and provide alignment within our clean electricity growth plan in a manner that we believe will create value for all our share.

Speaker 3: The combination will also deliver capital efficiencies and enhance cash flow predictability and diversification for both sets of shareholders while preserving the combined company's ability to realize future growth.

The combination will also deliver capital efficiencies and enhance cash flow predictability and diversification for both sets of shareholders, while preserving the combined company's ability to realize future growth.

Speaker 3: On the growth side, our development team continues to expand our pipeline, adding another 344 megawatts of growth projects, 300 megawatts of which are renewables projects based in the US and Australia. And 44 megawatts relate to a new peaker initiative that we have here in Alberta and that I'll be speaking about shortly.

John Kousinioris: On the growth side, our development team continues to expand our pipeline, adding another 344 MW of growth projects, 300 MW of which are renewables projects based in the US and Australia, and 44 MW relate to a new peaker initiative that we have here in Alberta and that I'll be speaking about shortly. The rehabilitation of Kent Hills is progressing well, with 27 of 50 turbines fully reassembled. Turbines are being returned to service as commissioning activities are completed, and to date, 10 turbines have been fully placed back into operation and are earning revenues from New Brunswick Power. We are now anticipating that the repair cost will increase to about CAD 140 million as we have opportunistically expanded the scope of work to include certain blade repairs, which will permit us to defer or avoid future maintenance at the site.

On the growth side, our development team continues to expand our pipeline, adding another 344 megawatts of growth projects 300 megawatts of which our renewables projects based in the U S and Australia, and 44 megawatts relate to a new peak or initiatives that we have here in Alberta, and then I'll be speaking about shortly.

Speaker 3: The rehabilitation of Kent Hills is progressing well with 27 of 50 turbines fully reassembled. Turbines are being returned to service as commissioning activities are completed and, to date, 10 turbines have been fully placed back into operation and are earning revenues from New Brunswick Power.

The rehabilitation of Kent Hills is progressing well with 27 or 50 turbines fully reassembled.

Turbines are being returned to service is commissioning activities are completed and to date 10 turbines have been fully placed back into operation and are earning revenues from new Brunswick power we.

Speaker 3: We are now anticipating that the repair costs will increase to about $140 million as we have opportunistically expanded the scope of work to include certain blade repairs which will permit us to defer or avoid future maintenance at the site.

We are now anticipating that the repair costs will increase to about $140 million as we have opportunistically expanded the scope of work to include certain blade repairs, which will permit us to defer or avoid future maintenance at the site.

John Kousinioris: We completed CAD 35 million in share buybacks during Q2, bringing our total capital return to shareholders during H1 of the year to CAD 71 million through the repurchase of 6.1 million common shares at an average purchase price of CAD 11.62. Our current NCIB program was renewed in May, and we see it as a capital allocation alternative that will help us continue to enhance long-term shareholder value. Finally, with another quarter of strong cash flow, our balance sheet position is strong, with excellent liquidity and cash on hand to fund our recently announced transaction with TransAlta Renewables, as well as our growth projects. As you all know, a key priority for the company for 2023 is completing the construction of our contracted renewables projects.

Speaker 3: We completed $35 million in share buybacks during the second quarter, bringing our total capital return to shareholders during the first half of the year to $71 million through the repurchase of 6.1 million common shares at an average purchase price of $11.62.

We completed $35 million in share buybacks during the second quarter, bringing our total capital returned to shareholders. During the first half of the year to $71 million through the repurchase of $6 1 million common shares at an average purchase price of $11 62.

Speaker 3: Our current NCIB program was renewed in May, and we see it as a capital allocation alternative that will help us continue to enhance long-term shareholder value.

Our current and CIB program was renewed in May and we see it as a capital allocation alternative that will help us continue to enhance long term shareholder value.

Speaker 3: And finally, with another quarter of strong cash flow, our balance sheet position is strong with excellent liquidity and cash on hand to fund our recently announced transaction with TransAlta Renewables as well as our growth project.

Finally, with another quarter of strong cash flow our balance sheet position is strong with excellent liquidity and cash on hand to fund, our recently announced transaction with Transalta renewables as well as our growth projects.

Speaker 3: As you all know, a key priority for the company for 2023 is completing the construction of our contracted renewables project.

As you all know a key priority for the company for 2023 is completing the construction of our contracted renewables projects.

John Kousinioris: We currently have 678 MW of projects in the construction phase, representing an investment of CAD 1.4 billion, with approximately CAD 1.1 billion spent to date and CAD 300 million left to go. Our 130 MW Garden Plain Wind Farm here in Alberta is nearing completion. All 26 turbines have been assembled, we're pleased to announce that 23 units are in operation today and available to generate electricity to the grid. We expect to finalize commissioning and declare commercial operations in a week or so following resolution of an outstanding issue with the three remaining turbines. We expect the wind farm to contribute CAD 15 million of contracted EBITDA annually, so far, we're pleased with the performance of the turbines at the site. Our Northern Goldfields solar project in Australia is also reaching its final stages of completion. All major equipment has been installed, construction work is largely complete.

Speaker 3: We currently have 678 megawatts of projects in the construction phase, representing an investment of 1.4 billion with approximately 1.1 billion spent a day and 300 million left to go.

We currently have 678 megawatts of projects in the construction phase representing an investment of $1 4 billion with approximately $1 1 billion spent to date and $300 million left to go.

Speaker 3: Our 130 megawatt Garden Plain wind farm here in Alberta is nearing completion. All 26 turbines have been assembled and we're pleased to announce that 23 units are in operation today and available to generate electricity to the grid.

Our 130 megawatt garden Planed wind farm here in Alberta is nearing completion, all 26 turbines have been assembled and we're pleased to announce the 23 units are in operation today and available to generate electricity to the grid.

Speaker 3: We expect to finalize commissioning and declare commercial operations in a week or so, following resolution of an outstanding issue with the three remaining turbines. We expect the wind farm to contribute 15 million of contracted EBITDA annually and so far we're pleased with the performance of the turbines at the site.

We expect to finalize commissioning and declared commercial operations in a week or so following resolution of an outstanding issue with the three remaining turbines. We expect the wind farm to contribute $15 million of contracted EBITDA annually and so far we're pleased with the performance of the turbines at the site.

Speaker 3: Our Northern Goldfield Solar Project in Australia is also reaching its final stages of completion.

Our northern Goldfield Solar project in Australia is also reaching its final stages of completion of all major equipment has been installed and construction work is largely complete.

Speaker 3: All major equipment has been installed and construction work is largely complete. Energization and testing processes have commenced.

John Kousinioris: Energization and testing processes have commenced. The solar facility is beginning to generate electricity and is expected to achieve full commercial operations in H2 2023. This project will deliver approximately CAD 9 million of adjusted EBITDA annually. Construction at the Horizon Hill Wind Project in Oklahoma is also advancing well, and all major equipment has now been delivered to site. Turbine erection activities are underway, and we're pleased to report that 27 of the 34 wind turbines are fully assembled. Construction of the transmission interconnection is also underway. Although our turbine erection activities are progressing, the critical path to our schedule is the completion of the transmission line, which unfortunately is seeing some delay.

<unk> and testing processes have commenced the solar facility is beginning to generate electricity and is expected to achieve full commercial operations in the second half of 2023.

Speaker 3: The solar facility is beginning to generate electricity and is expected to achieve full commercial operations in the second half of 2022.

Speaker 3: This project will deliver approximately $9 million of adjusted EBITDA annual.

This project will deliver approximately $9 million of adjusted EBITDA annually.

Speaker 3: Construction at the Horizon Hill Wind Project in Oklahoma is also advancing well, and all major equipment has now been delivered to site.

Construction at the Horizon Hill Wind project in Oklahoma is also advancing well and all major equipment has now been delivered to site.

Speaker 3: Turbine erection activities are underway and we're pleased to report the 27 of the 34 wind turbines are fully assembled. Construction of the transmission interconnect...

Turbine erection activities are underway and we're pleased to report the 27 of the 34 wind turbines are fully assembled.

Construction of the transmission interconnection is also underway.

Speaker 3: Although our turbine erection activities are progressing, the critical path to our schedule is the completion of the transmission line, which unfortunately is seeing some delay. As a result, we're now expecting to reach commercial operations during the first half of 2024.

Although our turbine erection activities are progressing the critical path to our schedule is the completion of the transmission line, which unfortunately is seeing some delay as a result, we're now expecting to reach commercial operations during the first half of 2024.

John Kousinioris: As a result, we're now expecting to reach commercial operations during H1 2024. At our White Rock East and West projects, equipment deliveries are well advanced, and the final blade sets are due to arrive in August. In the meantime, tower assembly has commenced, along with the construction of the transmission interconnection. Horizon Hill and White Rock will contribute adjusted EBITDA of over CAD 100 million annually to our company. Finally, our Mount Keith 132 kV expansion project is also making progress, with the gas-insulated switchgear being installed in August. The project will achieve commercial operations in H2 2023 and contribute approximately CAD 7 million of adjusted EBITDA annually. These projects, along with the Kent Hills rehabilitation, constitute the largest construction program that TransAlta has taken on in recent memory. Given the economic and construction environment we're facing, we're overall pleased with how our projects are tracking.

Speaker 3: At our White Rock East and West projects, equipment deliveries are well advanced and the final blade sets are due to arrive in August . In the meantime, tower assembly has commenced along with the construction of the transmission interconnection.

And our white rock eastern West projects equipment deliveries are well advanced in the final blade sets, they're due to arrive in August in the meantime Tower Assembly has commenced along with the construction of the transmission interconnection.

Speaker 3: Horizon Hill and White Rock will contribute a justity of over $100 million annually to our company.

Horizon human White rock will contribute adjusted EBITDA of over 100 million annually to our company.

Speaker 3: Finally, our Mount Keith 132 kV expansion project is also making progress, with the gas-insulated switch gear being installed in August . The project will achieve commercial operations in the second half of 2023 and contribute approximately $7 million of adjusted EBITDA annual.

Finally, our Mount Keith $1 32 Kv expansion project is also making progress with the gas insulated switch gear being installed in August the project will achieve commercial operations in the second half of 2023 and contribute approximately $7 million of adjusted EBITDA annually.

Speaker 3: These projects, along with the Ken Hills Rehabilitation, constitute the largest construction program that TransAlta has taken on in recent memory. Given the economic and construction environment we're facing, we're overall pleased with how our projects are tracking. We're only slightly above budget on our QUS projects and we're broadly on track with our timing for all of the projects.

These projects along with the Kent Hills rehabilitation constitute the largest construction program that trans Alpha has taken on in recent memory.

Given the economic and construction environment, we're facing we're overall pleased with how our projects are tracking we're only slightly above budget on our Q U S projects and we're broadly on track with our timing for all of the projects.

John Kousinioris: We're only slightly above budget on our 2 US projects. We're broadly on track with our timing for all of the projects. Within our development pipeline, we currently have 418 MW of advanced-stage generation and transmission projects that we're advancing towards final investment decisions. They represent additional growth capital of approximately CAD 730 million. They range from wind generation at Tempest to battery storage at WaterCharger. I'm pleased to share that we've added our Pinnacle One and Two projects to our advanced-stage development pipeline. Pinnacle One and Two will be a highly flexible and quick-ramping peaking facility in Alberta, designed to respond to volatile price environments. As renewables penetration advances over time in the province, our expectation is that demand for fast-ramping, highly responsive, flexible supply will be needed as a complement.

Speaker 3: Within our development pipeline, we currently have 418 megawatts of advanced stage generation and transmission projects that we're advancing towards final investment.

Within our development pipeline. We currently have 418 megawatts of advanced stage generation and transmission projects that were advancing towards final investment decisions. They represent additional growth capital of approximately $730 million.

Speaker 3: They represent additional growth capital of approximately $730 million.

Speaker 3: They range from wind generation at tempest to battery storage at water.

They range from wind generation attempt to battery storage at water chart.

Speaker 3: I'm pleased to share that we've added our Pinnacle I and II projects to our advanced stage development.

I'm pleased to share that we've added are pinnacle, one and two projects to our advanced stage development pipeline clinical wanted too will be a highly flexible and quick ramping peaking facility in Alberta designed to respond to volatile price environment.

Speaker 3: Pinnacle 1 and 2 will be a highly flexible and quick ramping peaking facility in Alberta, designed to respond to volatile price environments.

Speaker 3: As renewables penetration advances over time in the province, our expectation is that demand for fast ramping, highly responsive, flexible supply will be needed as a complement.

As renewables penetration advances overtime in the province, our expectation is the demand for fast ramping highly responsive flexible supply will be needed as a complement our pinnacle, one and two projects, we will leverage our existing infrastructure and interconnection that keep bills to deliver exactly this type of capacity.

John Kousinioris: Our Pinnacle 1 and 2 projects will leverage our existing infrastructure and interconnection at Keephills to deliver exactly this type of capacity. The project comprises 4 11 MW Wärtsilä generating units. The engines will be connected in pairs, with each pair linked to the grid independently. We expect approvals and permits to be issued in Q4, with a potential in-service date in the H2 of 2025. We also continue to advance our growth pipeline. As you recall, in 2022, we added almost 2 GW to our renewable development pipeline across all our regions, providing significant progress towards our longer-term goal of having 5 GW of projects in the pipeline. For 2023, we have an in-year stated goal of adding another 1,500 MW of new sites to our pipeline to replenish our growth in the longer term.

Speaker 3: Our Pinnacle 1 and 2 projects will leverage our existing infrastructure and interconnection at key pills to deliver exactly this type of capacity.

Speaker 3: The project comprises four 11 megawatt worth silage generating.

The project comprises 411 megawatt where silver generating units the engines will be connected in Paris with each pair linked to the grid independently.

Speaker 3: The engines will be connected in pairs with each pair linked to the grid independently.

Speaker 3: We expect approvals and permits to be issued in Q4 with a potential in-service date in the second half of 2025. We also can carry out a

We expect approvals and permits to be issued in Q4 with a potential in service date in the second half of 2025.

We also continued to advance our growth pipeline.

Speaker 3: As you recall, in 2022, we added almost 2 gigawatts to our renewable development pipeline across all our all-old- revolves, hospitals, public He the

As you recall in 2022, we added almost two gigawatts to a renewable development pipeline across all our regions, providing significant progress towards our longer term goal of having five gigawatts of projects in the pipeline.

Speaker 3: providing significant progress towards our longer term goal of having 5 gigawatts of projects in the pipeline.

Speaker 3: For 2023, we have an in-year stated goal of adding another 1,500 megawatts of new sites to our pipeline to replenish our growth in the longer term.

For 2023, we have an in year stated goal of adding another 500 megawatts of new sites to our pipeline to replenish our growth in the longer term.

John Kousinioris: In the quarter, we added an additional 344 MW of future development opportunities, and so far this year, we've added 630 MW, or about 42% of our goal. Notably, in the second quarter, we acquired a 50% interest in the 320 MW Tent Mountain Pumped Hydro Energy Storage Project here in Alberta and a combined 300 MW of wind prospects in the US and Australia. We see continuing strength in power prices in Alberta and the Pacific Northwest. In Alberta, forward power prices for the balance of the year are trading higher as a result of continuing conditions of tighter supply resulting from generation outages, delays in new asset entry, and persisting transmission constraints that are limiting imports. We also continue to see supportive prices in adjacent markets, which are experiencing lower than normal hydrology.

Speaker 3: In the quarter, we added an additional 344 megawatts of future development opportunities. And so far this year, we've added 630 megawatts, or about 42% of our goal.

In the quarter, we added an additional 344 megawatts of future development opportunities and so far this year, we've added 630 megawatts or about 42% of our goal.

Speaker 3: Notably, in the second quarter, we acquired a 50% interest in the 320 megawatt tent mountain pumped hydro energy storage project here in Alberta and a combined 300 megawatts of wind prospects in the US and Australia.

Notably in the second quarter, we acquired a 50% interest in the 320 megawatt 10th Mountain pumped Hydro energy storage project here in Alberta, and a combined 300 megawatts of wind prospects in the U S and Australia.

Speaker 3: We see continuing strength in power prices in Alberta and the Pacific Northwest. In Alberta, forward power prices for the balance of the year are trading higher as a result of continuing conditions of tighter supply resulting from generation outages, delays in new asset entry, and persisting transmission constraints that are limiting import.

We see continuing strength in power prices in Alberta, and the Pacific Northwest and Alberta forward power prices for the balance of the year, our trading higher as a result of continuing conditions of tighter supply, resulting from generation outages delays in new asset entry and persisting transmission constraints that are limiting it.

Speaker 3: We also continue to see supportive prices in adjacent markets, which are experiencing lower than normal hydraulics.

Imports. We also continue to see supportive prices in adjacent markets, which are experiencing lower than normal hydrology with.

Speaker 3: With our strong results this quarter and improved market expectations for the rest of the year, we are once again pleased to increase our financial guidance for 2022.

John Kousinioris: With our strong results this quarter and improved market expectations for the rest of the year, we are once again pleased to increase our financial guidance for 2023. We're now expecting Alberta power prices to settle the year between CAD 150 to 170 per MWh, about CAD 25 per MWh higher than our guidance in Q1. We're raising our expectations for adjusted EBITDA to a range of CAD 1.7 to 1.8 billion, representing an increase of 17% over the midpoint of our prior guidance. Free cash flow is now expected to be in the range of CAD 850 to 950 million, an increase of 29% at the midpoint compared to our guidance at Q1. I'll now turn it over to Todd for further discussion on the quarter's financial results.

With our strong results this quarter and improved market expectations for the rest of the year. We are once again pleased to increase our financial guidance for 2023.

Speaker 3: We're now expecting Alberta power prices to settle the year between 150 to 170 dollars per megawatt hour. About 25 dollars per megawatt hour higher than our guidance in Q1.

We're now expecting Alberta prices.

Power prices to settle the year between 150 to $170 per megawatt hour about $25 per megawatt hour higher than our guidance in Q1.

Speaker 3: We're raising our expectations for adjusted EBITDA to a range of 1.7 billion to 1.8 billion, representing an increase of 17% over the midpoint of our prior guidance. And free cash flow is now expected to be in the range of 850 million to 950 million, an increase of 29% at the midpoint compared to our guidance at Q1. I'll now turn it over to Todd for further discussion on the quarter's financial results.

We're raising our expectations for adjusted EBITDA to a range of $1 7 billion to $1 8 billion, representing an increase of 17% over the midpoint of our prior guidance and free cash flow is now expected to be in the range of $850 million to $950 million, an increase of 29% at the midpoint compared to our guy.

<unk> at Q1.

I'll now turn it over to Todd for further discussion on the quarter's financial results.

Speaker 4: John and good morning everyone. I'll kick off my comments with a more detailed note overview of our Alberta Portfolio performance.

Todd Stack: Thank you, John, and good morning, everyone. I'll kick off my comments with a more detailed overview of our Alberta portfolio performance. When we announced our guidance in December, our outlook was based on Alberta power prices ranging between CAD 105 to 135 per MWh. Spot prices in Q2 2023 continued to exceed our expectations, settling at CAD 160 per MWh versus CAD 122 in 2022. Year-to-date, pricing through the H1 has been stronger than expected at CAD 151 per MWh, and we expect this strength to continue through the end of the year. As John noted, we now expect spot prices to average between CAD 150 to 170 for the full year.

Thank you John and good morning, everyone.

I'll kick off my comments with a more detailed overview of our Alberta portfolio performance.

Speaker 4: When we announced our guidance in December , our outlook was based on Alberta power prices ranging between $105 to $135 per MW.

When we announced our guidance in December our outlook was based on Alberta power prices ranging between 105 to $135 per megawatt hour.

Speaker 3: Spot prices in the second quarter of 2023 continued to exceed our expectations, settling at $160 per MWh versus $122 in 2022.

Spot prices in the second quarter of 2023 continue to exceed our expectations settling at $160 per megawatt hour versus the $122 in 2022.

Speaker 3: Year to date, pricing through the first half of the year has been stronger than expected at $151 per MWh, and we expect this strength to continue through the end of the year. As John noted, we now expect spot prices to average between $150-$170 for the full year.

Year to date pricing through the first half of the year has been stronger than expected at $151 per megawatt hour and we expect this strength to continue through the end of the year as John noted, we now expect spot prices to average between 150 to $170 for the full year.

Todd Stack: Overall, we continue to realize higher merchant power pricing for energy and ancillary services across the merchant fleet in H1 of the year. We're able to optimize our available capacity across all fuel types. The ability of our hydro fleet to capture peak pricing was demonstrated throughout Q2 with a realized energy price of CAD 199 per MWh, which represented a 25% premium over the average spot price and delivered a 53% stronger realized price versus 2022. Similarly, our gas fleet exceeded our expectations, capturing peak pricing throughout Q2 with a realized merchant price of CAD 202 per MWh, which represented a 27% premium to the average spot price. Our merchant wind fleet realized an average price of CAD 75 per MWh, which is below the average price of CAD 96 we saw last year.

Speaker 3: Overall, we continue to realize higher merchant power pricing for energy and ancillary services across the merchant fleet in the first six months of the year, and we're able to optimize our available capacity across all fuels.

Overall, we continue to realize higher merchant power pricing for energy and ancillary services across the merchant fleet in the first six months of the year and we're able to optimize our available capacity across all fuel types.

Speaker 3: The ability of our hydro fleet to capture peak pricing was demonstrated throughout the second quarter with a real life energy price of $199 per megawatt hour, which represented a 25% premium over the average spot price and delivered a 53% stronger realized price versus 2022.

The ability of our hydro fleet to capture peak pricing was demonstrated throughout the second quarter with a realized energy price of $199 per megawatt hour, which represented a 25% premium over the average spot price and delivered a 53% stronger realized price versus 2022.

Speaker 3: Similarly, our gas fleet exceeded our expectations, capturing peak pricing throughout the quarter, with a realized merchant price of $202 per MWh, which represented a 27% premium to the average spot price.

Similarly, our gas lead exceeded our expectations, capturing peak pricing throughout the quarter with a realized merchant price of $202 per megawatt hour, which represented a 27% premium to the average spot price.

Speaker 3: Our merchant wind fleet realized an average price of $75 per megawatt hour, which is below the average price of $96 we saw last year. But on a year-to-date basis, the merchant wind fleet has realized an average price of $83 per megawatt hour, which is tracking 11% higher than what the wind fleet realized in the first half of 2022.

Our merchant wind fleet realized an average price of $75 per megawatt hour, which is below the average price of $96. We saw last year, but on a year to date basis. The merchant wind fleet as realized an average price of $83 per megawatt hour, which is tracking 11% higher than what the wind fleet realized in the first half of 2022.

Todd Stack: On a year-to-date basis, the merchant wind fleet has realized an average price of CAD 83 per MWh, which is tracking 11% higher than what the wind fleet realized in H1 2022. Looking at the balance of the year for 2023, we have approximately 3,600 GWh of Alberta gas generation hedged at an average price of CAD 102 per MWh, and roughly 88% of our required natural gas volumes are hedged at an attractive price of CAD 2.27 per GJ. Our hedging activities aim to mitigate the impact of unfavorable market pricing on the Alberta gas fleet, and we continue to retain a significant open position in order to realize higher pricing during times of peak market demand, which was demonstrated in our strong Q2 and year-to-date results. Our financial results for Q2 were strong.

Speaker 3: Looking at the balance of the year for 2023, we have approximately 3600 gigawatt hours of Alberta gas generation hedged at an average price of $102 per megawatt hour. And roughly 88% of our required natural gas volumes are hedged at an attractive price of $2.27 per gigajoule.

Looking at the balance of the year for 2023, we have approximately 3600 gigawatt hours of Alberta gas generation hedged at an average price of $102 per megawatt hour and roughly 88% of our required natural gas volumes are hedged at an attractive price of $2.27 per gig control.

Speaker 3: Our hedging activities aim to mitigate the impact of unfavorable market pricing on the Alberta Gas Fleet, and we continue to retain a significant open position in order to realize higher pricing during times of peak market demand, which was demonstrated in our strong Q2 and year-to-date results.

Our hedging activities aimed to mitigate the impact of unfavorable market pricing on the Alberta gas fleet and we continue to retain significant open position in order to realize higher pricing during times of peak market demand, which was demonstrated in our strong Q2 and year to date results.

Speaker 3: Our financial results for the second quarter were strong. As John noted, we generated $387 million of adjusted EBITDA and an exceptional $278 million of free cash.

Our financial results for the second quarter were strong as John noted, we generated $387 million of adjusted EBITDA and an exceptional $278 million of free cash flow.

Todd Stack: As John noted, we generated CAD 387 million of adjusted EBITDA and an exceptional CAD 278 million of free cash flow. Our performance in Q2 was led by the gas fleet with adjusted EBITDA of CAD 166 million, a 155% improvement over last year. The Gas segment benefited from expanding gross margins in the Alberta fleet through higher realized prices and lower input costs as hedged and market prices for natural gas declined significantly from last year. The Hydro segment also outperformed with an adjusted EBITDA of CAD 147 million, a 67% increase to Q2 2022. Hydro benefited from strong realized pricing, as well as from a 20% increase in production over 2022 levels due to higher water resources in Q2. Higher water resources were driven by timing of the seasonal runoff and higher precipitation. The Wind and Solar segment underperformed quarter-over-quarter.

Speaker 3: Our performance in the second quarter was led by the gas fleet with adjusted EBITDA of $166 million, a 155% improvement over last year.

Our performance in the second quarter was led by the gasoline with adjusted EBITDA of $166 million.

Our 50, 155% improvement over last year.

Speaker 3: The gas segment benefited from expanding gross margins in the Alberta fleet through higher realized prices and lower input costs as headed and market prices for natural gas declined significantly from last year.

The gas segment benefited from expanding gross margins in the upper to fleet through higher realized prices and lower input costs as hedged and market prices for natural gas declined significantly from last year.

Speaker 3: The micro segment also outperformed with an adjusted EBITDA of $147 million, a 67% increase to the same quarter in 2017.

The Hydro segment also outperformed with an adjusted EBITDA of $147 million or 67% increase to the same quarter in 2017.

Speaker 3: Hydro benefited from strong realized pricing as well as from a 20% increase in production over 2022 levels due to higher water resources in the port.

Hydro benefited from strong realized pricing as well as from a 20% increase in production over 2022 levels due to higher water resources and support.

Speaker 3: Higher water resources were driven by timing of the seasonal runoff and higher precipitation.

Higher water resources were driven by timing of the seasonal run off and higher precipitation.

Speaker 3: The wind and solar segment underperformed quarter over quarter. Although we brought in new production from the Garden Plain Facility, we experienced lower overall production due to pervasive, weaker wind and solar resources in all regions compared to the same quarter last year.

The wind and solar segment underperformed quarter over quarter, Although we brought on new production from the garden same facility, we experienced lower overall production due to pervasive weaker wind and solar resources in all regions compared to the same quarter last year.

Todd Stack: Although we brought on new production from the Garden Plain facility, we experienced lower overall production due to pervasive weaker wind and solar resources in all regions compared to the same quarter last year. We also experienced lower realized merchant pricing in Alberta and lower environmental attribute revenue. Quarterly variability in wind resource is expected, and we remain confident in our fleet's ability to realize its long-term average production levels. Energy marketing had similar performance to last year, and in the quarter delivered CAD 49 million of gross margin and CAD 43 million of adjusted EBITDA, which is another great result for the segment. Corporate costs increased by CAD 9 million, primarily due to higher incentive accruals reflecting our strong performance, and were also impacted by higher spending on strategic and growth initiatives and from the impact of inflationary pressures.

Speaker 3: We also experienced lower realized merchant pricing in Alberta and lower environmental attributes.

We also experienced lower realized merchant pricing in Alberta, and lower environmental attribute revenue.

Speaker 3: Quarterly variability in wind resources expected, and we remain confident in our fleet's ability to realize its long-term average production level.

Quarterly variability in wind resource as expected and we remain confident in our fleets ability to realize its long term average production levels.

Speaker 2: Energy marketing had similar performance to last year and in the quarter delivered $49 million of gross margin and $43 million of adjusted EVA data, which is another great result for the segment.

Energy marketing had similar performance to last year and in the quarter delivered $49 million of gross margin and $43 million of adjusted EBITDA, which is another great result for the segment.

Speaker 2: Corporate costs increased by $9 million, primarily due to higher incentive accruals reflecting our strong performance. And we're also impacted by higher spending on strategic and growth initiatives and from the impact of inflationary pressure.

Corporate costs increased by $9 million.

Primarily due to higher incentive accruals, reflecting our strong performance and were also impacted by higher spending on strategic and growth initiatives and from the impact of inflationary pressures.

Speaker 2: Overall, TransAlto's results again exceeded our expectations and delivered a great first half of 2023.

Todd Stack: Overall, TransAlta's results again exceeded our expectations and delivered a great H1 of 2023. The strong performance of our hydro fleet continues to benefit our shareholders. In Q2, the hydro assets generated CAD 147 million of EBITDA and are well on track to deliver over CAD 500 million this year. This compares to over CAD 500 million of EBITDA in 2022 and over CAD 300 million in 2021. Although energy production and ancillary service volumes vary quarterly, they remain largely consistent on an annual basis. This provides long-term predictability and a floor to cash flows that is unique to this asset class. In Q2, while the strong water flows increased our energy sales, it did at times limit our ability to provide ancillary services into the market from these units. This resulted in lower ancillary sales from the hydro segment year over year.

Overall <unk> results again exceeded our expectations and delivered a great first half of 2023.

Speaker 2: The strong performance of our hydro fleet continues to benefit our shareholders. In the second quarter, the hydro assets generated $147 million leave a doubt and are well on track to deliver over $500 million this year.

The strong performance of our Hydro fleet continues to benefit our shareholders in the second quarter. The hydro assets generated $147 million of EBITDA and are well on track to deliver over $500 million. This year.

Speaker 2: This compares to over $500 million of EBITDA in 2022 and over $300 million in 2020.

This compares to over $500 million of EBITDA in 2022 and over $300 million in 2020.

Speaker 2: Although energy production and in silvery service volumes vary quarterly, they remain largely consistent on an annual basis.

Although energy production and ancillary service volumes vary quarterly they remained largely consistent on an annual basis.

Speaker 2: This provides long-term predictability and a floor to cashmose that is unique to this asset kit class.

This provides long term predictability and a floor to cash flows that is unique to this asset class.

Speaker 2: In Q2, while the strong water flows increased our energy sales, it did at times limit our ability to provide ancillary services into the market from these units.

In Q2, while the strong water flows increased our energy sales it did at times limit our ability to provide ancillary services into the market from these units.

Speaker 2: This resulted in lower ancillary sales from the hydro segment year over year.

This resulted in lower ancillary sales from our hydro segment year over year.

Speaker 2: When this occurs, we are able to backstop the ancillary service sales with our gas fleet, which we did in Q2. During the quarter, we sold approximately 200 gigawatt hours of ancillary services from the gas fleet.

Todd Stack: When this occurs, we are able to backstop the ancillary service sales with our gas fleet, which we did in Q2. During the quarter, we sold approximately 200 GWh of ancillary services from the gas fleet. Realized pricing continues to be strong with a premium on spot electricity prices of roughly 25% and with ancillary services earning approximately 50% of spot prices. Together, the higher realized prices on both energy and ancillary services and higher energy flows more than offset the impact of lower ancillary service volumes in the hydro segment. Before I turn things back to John, I'll turn to TransAlta Renewables to highlight key details of our acquisition announcement. As John mentioned, we are pleased to announce a path forward on our simplification efforts. We've entered into a definitive agreement where TransAlta will acquire all the issued and outstanding publicly held common shares of TransAlta Renewables.

When this occurs we are able to backstop the ancillary service sales with our gas fleet, which we did in Q2.

During the quarter, we sold approximately 200 gigawatt hours of ancillary services from the gas fleet.

Speaker 2: Realized pricing continues to be strong with a premium on spot electricity prices of roughly 25% and with ancillary services earning approximately 50% of spot price.

Realized pricing continues to be strong with a premium on spot electricity prices of roughly 25% and with ancillary services, earning approximately 50% of spot prices.

Speaker 2: Together, the higher realized prices on both energy and ancillary services and higher energy flows more than offset the impact of lower ancillary service in the hydro sector.

Together, the higher realized prices on both energy and ancillary services and higher energy flows more than offset the impact of lower ancillary services volumes in the hydro segment.

Speaker 2: Before I turn things back to John , I'll turn to TransAltar Renewables to highlight key details of our acquisition announcement.

Before I turn things back to John alternate Transalta renewables to highlight key details of our acquisition announcements as.

Speaker 2: As John mentioned, we are pleased to announce a path forward on our simplification efforts.

As John mentioned, we are pleased to announce a path forward on our simplification efforts.

Speaker 2: We've entered into a definitive agreement where TransAlta will acquire all the issued and outstanding publicly held common shares of TransAlta Renewable.

We've entered into a definitive agreement, where Transalta will report will acquire all the issued and outstanding publicly held common shares of Transalta renewables.

Todd Stack: The CAD 13 offer from TransAlta represents an 18.3% premium to TransAlta Renewables closing share price at 10 July 2023, and a 13.6% premium based on the prior 20-day volume weighted average price of the TransAlta Renewables common shares. Each TransAlta Renewables shareholder will have the ability to elect to receive CAD 13 in cash per TransAlta Renewables share, or 1.0337 TransAlta shares per TransAlta Renewables share, or a combination of cash and shares. In each case, consideration is subject to proration, with the maximum cash consideration being fixed at CAD 800 million and the maximum share consideration being equal to 46.4 million TransAlta shares. Upon closing of the transaction, the pro forma ownership of the combined company will be approximately 85% held by current TransAlta shareholders and 15% held by current TransAlta Renewables shareholders.

Speaker 2: The $13 offer from TransAlta represents an 18.3% premium to TransAlta Renewables' closing share price at July 10, 2023 and a 13.6% premium based on the prior 20-day volume weighted average price of the TransAlta Renewables common share.

The $13 offer from Transalta represents represents an 18, 3% premium to Transalta renewables closing closing share price at July 10, 2023, and a 13, 6% premium based on the prior 20 day volume weighted average price of the Transalta renewables common shares.

Speaker 2: Each TransAlta Renewable shareholder will have the ability to elect to receive $13 in cash per TransAlta Renewable share or 1.0337 TransAlta shares per TransAlta Renewable share or a combination of cash.

Each transalta renewables shareholder will have the ability to elect to receive $13 in cash for transalta renewable share or 1.0337, transalta shares for transalta renewables share or a combination of cash and shares in each case consideration is subject to proration with the maximum cash.

Speaker 2: In each case, consideration is subject to proration, with the maximum cash consideration being fixed at $800 million and the maximum share consideration being equal to 46.4 million in terms of all the share.

<unk> be fixed at $800 million and the maximum share consideration being equal to $46 4 million trends altra shares.

Speaker 2: Upon closing of the transaction, the pro forma ownership of the combined company will be approximately 85% held by current TransAlta shareholders and 15% held by current TransAlta Renewable shareholders.

Upon closing of the transaction the pro forma ownership of the combined company will be approximately 85% held by current transalta shareholders and 15% held by current Transalta renewable shareholders.

Speaker 2: The board of directors of each company has independently determined that the transaction is in the best interest of their company and fair to their shareholders.

Todd Stack: The board of directors of each company has independently determined that the transaction is in the best interest of their company and fair to their shareholders. The transaction was also unanimously approved by the independent members of the TransAlta Renewables board, and they have unanimously recommended that RNW shareholders vote in favor of the transaction. In terms of next steps, we expect to obtain an interim order from the Court of King's Bench of Alberta establishing the process for TransAlta Renewables shareholder approval, and we'll mail out the management information circular to TransAlta Renewables shareholders on or about 25 August. The special meeting of TransAlta Renewables shareholders to consider the arrangement is expected to take place on or about 26 September.

The board of directors of each company as independently determined that the transaction is in the best interest of their company and fair to their shareholders. The.

Speaker 2: The transaction was also unanimously approved by the independent members of the TransAlta Renewables Board and they have unanimously recommended that R&W shareholders vote in favour of the transaction.

The transaction was also unanimously approved by the independent members of the Transalta Renewables Board and they have unanimously recommended that our NW shareholders vote in favor of the transaction.

Speaker 2: In terms of next steps, we expect to obtain an interim order from the Alberta Court of King's Bench establishing the process for TransAlta Renewable Shareholder approval, and we'll mail out the management information circular to TransAlta Renewable Shareholders on or about August 25th.

Yeah.

In terms of next steps, we expect to obtain an.

Interim order from the Alberta court of teams bench, establishing the process for Transalta renewables shareholder approval and we'll mail out the management information circular to transalta renewable shareholders on or about August 25.

Speaker 2: Special meeting of Trans-Althera-Nobal's shareholders to consider the arrangement is expected to take place on or about September 26th.

The special meeting of Transalta renewables shareholders to consider the arrangement is expected to take place on or about September 26th.

Speaker 2: The arrangement must be approved by at least two thirds of the votes cast by TransAlta Renewable shareholders represented at the meeting and by a simple majority of the minority of public shareholders of TransAlta Renewables represented at the meeting.

Todd Stack: The arrangement must be approved by at least two-thirds of the votes cast by TransAlta Renewables shareholders represented at the meeting and by a simple majority of the minority of public shareholders of TransAlta Renewables represented at the meeting. The transaction is subject to regulatory approvals and other customary closing conditions and is expected to close in early October. With that, I'll turn the call back over to John.

The arrangement must be approved by at least two thirds of the votes cast by Transalta renewable shareholders represented at the meeting.

And by a simple majority of the minority of public shareholders of Transalta renewables represented at the meeting.

Speaker 2: The transaction is subject to regulatory approvals and other customary closing conditions and is expected to close in early October . With that, I'll turn the call back over to the moderator.

The transaction is subject to regulatory approvals and other customary closing conditions and is expected to close in early October and with that I will turn the call back over to John .

Speaker 2: Thanks Todd. As I look at our strategic priorities for 2023, our primary goal is to continue delivering clean power solutions to and be the supplier of choice for customers that are focused on sustainable growth and decarbonization.

John Kousinioris: Thanks, Todd. As I look at our strategic priorities for 2023, our primary goal is to continue delivering clean power solutions to, and be the supplier of choice for, customers that are focused on sustainable growth and decarbonization. In 2023, we are focused on progressing the following key goals. Reaching final investment decisions on the equivalent of 500 MW of additional clean energy projects across Canada, the United States, and Australia, delivering CAD 75 to 100 million in incremental EBITDA. Achieving COD on the Garden Plain Wind, Northern Goldfields Solar, and Mount Keith Transmission projects while progressing the White Rock Wind and Horizon Hill wind projects to completion early in 2024. Expanding our development pipeline by 1,500 MW with a focus on renewables and storage. Completing the rehabilitation of Kent Hills Wind. Advancing the long-term contractiveness of our Alberta electricity portfolio.

Thanks, Todd as I look at our strategic priorities for 2023, our primary goal is to continue delivering.

Delivering clean power solutions too and be the supplier of choice for customers that are focused on sustainable growth and decarbonization.

Speaker 2: In 2023, we're focused on progressing the following key goals. Reaching final investment decisions on the equivalent of 500 megawatts of additional clean energy projects across Canada, the United States and Australia and delivering 75 to 100 million in incremental leave at that.

In 2023, we're focused on progressing the following key calls reaching final investment decisions on the equivalent of 500 megawatts of additional clean energy projects across Canada, the United States, and Australia, and delivering $75 million to $100 million in incremental EBITDA.

Speaker 2: Achieving COD on the Garden Plain Wind Northern Goldfield Solar and Mount Keep transmission projects while progressing the White Rock Wind and Horizon Hill Wind projects to completion early in 2020.

Achieving the garden plate, when northern Goldfield solar and mouth keep transmission projects, while progressing the white rock wind and Horizon Hill wind projects to completion early in 2024.

Speaker 2: expanding our development pipeline by 1,500 megawatts with a focus on renewables and storage, completing the rehabilitation of...

Expanding our development pipeline by 1500 megawatts with our focus on renewables and storage completing the rehabilitation of capsules win.

Speaker 2: advancing the long-term contractiveness of our Alberta electricity portfolio.

Advancing the long term contracted miss of our Alberta electricity portfolio.

Speaker 2: delivering permanent financing for our Oklahoma growth projects, and achieving EBITDA and free cash flow within our increased guidance range.

John Kousinioris: Achieving permanent financing for our Oklahoma growth projects, and achieving EBITDA and free cash flow within our increased guidance ranges. I'd like to close by highlighting what I think makes TransAlta a highly attractive investment and a great value opportunity. First, our cash flows are robust and underpinned by a high-quality and highly diversified portfolio. Our business is driven by our contracted wind and solar portfolio, our unique, reliable, and perpetual hydro portfolio, and our efficient gas portfolio, all of which are complemented by our world-class asset optimization and energy marketing capabilities. The acquisition of TransAlta Renewables will further diversify and increase the contractiveness of our cash flows. Second, we're a clean electricity leader with a focus on tangible greenhouse gas emissions reductions.

Delivering permanent financing for our Oklahoma growth projects, and achieving EBITDA and free cash flow within our increased guidance ranges.

Speaker 2: I'd like to close by highlighting what I think makes TransAlta a highly attractive investment and a great value offer.

I'd like to close by highlighting what I think makes trends out a highly attractive investment and a great value opportunity first our cash flows are robust and underpinned by our high quality and highly diversified portfolio, our businesses driven by our contracted wind and solar portfolio are unique reliable and perpetual hydro portfolio in our ifs.

Speaker 2: First, our cash flows are robust and underpinned by a high quality and highly diversified portfolio. Our business is driven by our contracted wind and solar portfolio, our unique, reliable, and perpetual hydro portfolio, and our efficient gas portfolio, all of which are complemented by our world-class asset optimization and energy marketing.

Gas portfolio, all of which are complemented by our world class asset optimization and energy marketing capabilities. The acquisition of Transalta renewables will further diversify and increase the contracted this of our cash flows.

Speaker 2: the acquisition of TransAlta Renewables will further diversify and increase the contractiveness of our cash.

Speaker 2: Second, we're a clean electricity leader with a focus on tangible greenhouse gas emissions reduction.

Second we're a clean electricity leader with a focus on tangible greenhouse gas emissions reductions. This year, we adopted a more ambitious cotwo emissions reduction target of 75% by 2026 from 2015 levels and our board has recently approved our commitment to net zero by 2045.

Speaker 2: This year, we adopted a more ambitious CO2 emissions reductions target of 75% by 2026 from 2015 levels. And our board has recently approved our commitment to net zero by 2045.

John Kousinioris: This year, we adopted a more ambitious CO2 emissions reductions target of 75% by 2026 from 2015 levels. Our board has recently approved our commitment to net zero by 2045. Third, as noted earlier, we have a diversified and growing development pipeline and a talented development team focused on realizing its value. Fourth, our company has a sound financial foundation. Our balance sheet is strong, and we have ample liquidity to pursue and deliver growth. Finally, our people. Our people are our greatest asset, and I want to thank all our employees and contractors for the excellent work they have done to deliver our exceptional quarter. Thank you. I'll turn the call back over to Kiara.

Speaker 2: Third, as noted earlier, we have a diversified and growing development pipeline and a talented development team focused on realizing its value. And fourth, our company has a sound financial foundation, our balance sheet is strong, and we have ample liquidity to pursue and deliver growth.

Third as noted earlier, we have a diversified and growing development pipeline and a talented development team focused on realizing its value and fourth our company has a sound financial foundation, our balance sheet is strong and we have ample liquidity to pursue and deliver growth.

Speaker 2: Finally, our people. Our people are our greatest asset, and I want to thank all our employees and contractors for the excellent work they have done to deliver our exceptional quarter. Thank you. I'll turn the call back over to Kiara.

Finally, our people our people are our greatest asset and I want to thank all our employees and contractors for the excellent work they have done to deliver our exceptional quarter. Thank you I'll turn the call back over to Keira.

Speaker 5: Thank you, John . Michelle, would you please open the call for questions from the analyst?

Chiara Valentini: Thank you, John. Michelle, would you please open the call for questions from the analysts and media?

Thank you John Michelle would you. Please open the call for questions from the analysts.

Operator 1: Thank you. Ladies and gentlemen, we will now begin the question and answer session. Should you have a question, please press star followed by the 1 on your touch-tone phone. You will hear a 3-tone prompt acknowledging your request, and your questions will be pulled in the order they are received. Should you wish to decline from the polling process, please press star followed by the 2. If you are using a speakerphone, please lift the handset before pressing any keys. Your first question comes from Dariusz Lozny with Bank of America. Please go ahead.

Thank you ladies and gentlemen, we will now begin the question and answer session should you have a question. Please press star followed by the one on your Touchtone phone, you'll hear three tons.

Speaker 1: Should you have a question, please press star followed by the one on your touch tone phone. You will hear three tone prompt acknowledging your request and your questions will be pulled in the order they are received. Should you wish to decline from the polling process, please press...

Lodging are requesting your questions will be pulled in the order. They are received should you wish to decline from the polling process. Please press star followed by the Q for you.

If you are using a speaker phone please lift the handset before pressing any keys and your first question comes from Darius larceny with.

Bank of America. Please go ahead.

Speaker 6: Hey guys, good morning. Thank you for taking my question. Maybe just at the outset, I was wondering if I could get your thoughts on.

Dariusz Lozny: Hey, guys. Good morning. Thank you for taking my question. Maybe just at the outset, was wondering if I could get your thoughts on the announcement yesterday from the Alberta Commission that put a pause on new applications for wind and solar. I don't believe there should be much of a material impact to your pending projects in the pipeline, but maybe if you can comment on that and maybe more broadly, how do you see this sort of impacting your longer-term plans as far as where to concentrate your development pipeline? Thank you.

Hey, guys. Good morning, Thank you for taking my question.

Just at the outset I was wondering if I could get your thoughts on the.

Speaker 6: The announcement yesterday from the Alberta Commission that put a pause on new applications for wind and solar. I don't believe there should be much of a material impact to your pending projects in the pipeline, but maybe.

The announcement yesterday from the Alberta Commission that put a pause on new applications for wind and solar.

I don't believe there should be much of a material impact to your pending projects in the pipeline, but maybe if you can.

Speaker 6: Comment on that and maybe more broadly, how do you see this sort of impacting your longer-term plans as far as where to concentrate your development pipeline?

Comment on that and maybe more broadly.

How do you see this sort of impacting your longer term plans as far as where to concentrate your development pipeline. Thank you.

Speaker 2: Yeah, good morning Darius and thanks for that question. I mean, look. The impact of the announcement yesterday will be limiting at least for a period of time, the advancement of renewable project in the province for that 6 month period while there's consideration being given to the pathways going forward. I have to say that, you know, from our own perspective, we have raised.

John Kousinioris: Yeah, good morning, Dariusz, and thanks for that question. Look, the impact of the announcement yesterday will be limiting, at least for a period of time, the advancement of renewable project in the province for that six-month period while there's consideration being given to the pathways going forward. I have to say that from our own perspective, we have raised, in the past, the importance of making sure that we have a balanced approach to the growth that we're seeing in renewables in the province. I think people have heard me say this before, it's like a three-legged stool, and it's critical that the grid is clean, but also reliable and affordable. I think spending a bit of time to review how the system maintains affordability and reliability as we begin to transition towards a lower-emitting grid is critical.

Yes. Good morning, Dario said, thanks for that question I mean look.

The impact of the announcement yesterday.

We'll be limiting at least for a period of time the advancement of renewable project in the province for that six month period, while there's consideration being given to the pathways going forward.

I have to say that.

You know from our own perspective, we have raised.

Speaker 2: you know, in the past, the importance of making sure that we have a balanced approach to the growth that we're seeing in renewables in the province. I think it's, people have heard me say this before, it's like a three-legged stool and it's critical that the grid is...

Yeah.

In the past the importance of making sure that we have a balanced approach to the growth that we're seeing in renewables in the province, I think it's it's people have heard me say this before it's it's like a three legged stool and it's critical that the greatest is clean, but also reliable and affordable and I think spending a bit of time to Reeves.

Speaker 2: clean, but also reliable and affordable. And I think spending a bit of time to review how the system maintains affordability and reliability as we begin to transition towards the lower emitting grid is critical. So we're looking forward to that consultation process that we'll be having that.

<unk>, how the system maintains affordability and reliability as we begin to transition towards the lower meeting grid is critical so we're looking forward to that consultation process that we'll be having that that we'll we'll evolve the Alberta Utilities Commission, we take a long term view on our development.

John Kousinioris: We're looking forward to that consultation process that we'll be having that will involve the Alberta Utilities Commission. We take a long-term view on our development pipeline in Alberta, and I can tell you, it's business as usual for us in terms of trying to advance our projects here. In specific response to a couple of your questions, we don't really see it having a significant impact on our advanced-stage projects. WaterCharger and Tempest have Alberta Utilities Commission approval, and we continue to advance those forward and are working hard to get them completed and announced this year. Pinnacle One and Two, which we've just announced, would be gas investments in the province, so again, they wouldn't be impacted by the halt. As we understand it, that is being put in place as a result of the Alberta Utilities Commission decision.

Speaker 2: will involve the Alberta Utilities Commission. We take a long term view on our development pipeline in Alberta and I can tell you it's business as usual for us in terms of trying to advance our projects here. In specific response to a couple of your question, you know, we don't really see it having a significant impact on our advanced stage projects. Water Charger and Tempest have Alberta Utilities Commission approval and we continue to advance.

Pipeline in Alberta, and I can tell you it's business as usual for us in terms of trying to advance our.

Our projects here in specific response to a couple of your question, we don't really see it having a significant impact on our advanced stage projects water Charger and Tempus half, Alberta Utilities Commission approval and we continue to advance.

Speaker 2: those forward and are working hard to get them completed and announced this year. Pinnacle 1 and 2, which we've just announced would be gas investments in the province. So again, they wouldn't be impacted by the halt. As we understand it, that is being put in place as a result of the Alberta Utilities Commission decision. In terms of...

Forward and are working hard to get them completed.

And announced this year.

Pinnacle, one and two which we've just announced would be would be gas investments in the province, So again they wouldn't be impacted.

By the hall as we understand it that is being put in place as a result of the Alberta Utilities Commission.

John Kousinioris: In terms of where we're thinking overall in Alberta, I would say that we continue to be committed to all of our decarbonization and net zero targets. We continue to see demand for renewables in the province. We expect renewables growth to continue once this review is completed in the province. We are, though, for sure, I would say, turning our minds to what other attributes the system will require in Alberta as it evolves in the coming decade. Having fast response battery and some peaking capacity that can create that reliability and stability that the market will need periodically is also something we're looking at, and that's really what Pinnacle One and Two are all about, along with WaterCharger.

<unk> in terms of.

Speaker 2: You know, where we're thinking overall in Alberta, I would say that we continue to be committed to all of our decarbonization and that's zero targets. We continue to see demand for renewables in in the province. We expect.

We know where we're thinking overall in Alberta, I would say that we continue to be committed to all of our de carbonization at zero targets, we continue to see demand for.

For renewables in the province, we expect kind of renewables growth to continue once this review is completed in the in the province, we are though for sure I would say turning our minds to what other attributes the system will require an alberta as it evolves in the coming decade and having.

Speaker 2: kind of renewables grows to continue once this review is completed in the province. We are though for sure, I would say, turning our minds to what other attributes the system will require in Alberta as it evolves in the coming decade and having, you know, a lot of

Speaker 2: fast response battery and some peaking capacity that can create that reliability and stability that the market will need periodically is also something we're looking at and that's really what Pinnacle 1 and 2 are all about along with Water Charge.

Fast response battery at some peaking capacity that can create that reliability and stability that the market will need periodically is also something we're looking at and Thats really what pinnacle, one and two are all about along with water chartered.

Dariusz Lozny: Great. Thank you for that detail. Really appreciate it. If I could ask one more on the updated guidance for the full year. Obviously very robust results, CAD 200 million more on free cash flow. To the extent that the balance of the year continues to come in above expectations, is there any possibility of perhaps raising the cash contribution in the RNW buy-in, or is it more or less set as you guys announced earlier in July, and that's how you plan on proceeding?

Speaker 6: Great. Thank you for that detail. Really appreciate it. If I could ask one more on the updated guidance for the full year, obviously very robust results, $200 million more on free cash flow. To the extent that the balance of the year continues to come in above expectations,

Great. Thank you for that detail really appreciate it.

If I could ask one more.

Updated guidance for the full year, obviously vary.

A very robust results 200 million more on free cash flow.

To the extent that the balance of the year continues to come in above expectations is there any possibility of perhaps raising the cash contribution in the our NW buy it or is it more or less set as you guys announced earlier.

Speaker 6: Is there any possibility of perhaps raising the cash contribution in the R&W buy-in or is it more or less set as you guys announced earlier in July and that's how you plan on...

Earlier in July and that is how you plan on proceeding.

Speaker 2: Yeah, no, so the transaction with the trans alto renewables is fixed. There is from our perspective, no prospect of any change in the composition of the consideration for that transaction.

John Kousinioris: Yeah, no. The transaction with TransAlta Renewables is fixed. There is, from our perspective, no prospect of any change in the composition of the consideration for that transaction.

Yeah, no. So the transaction with Transalta renewables is fixed areas.

From our perspective, no prospect of any change in the composition of the consideration for that transaction.

Speaker 3: I just say that we are conscious that when the transaction closes, there might be some movement and shareholder interests from Transel to renewable side. And so you'll notice that we did reinstate our NCIB program back in May. And so we're...

Todd Stack: I'd just say that we are conscious that when the transaction closes, there might be some movement in shareholder interests from TransAlta Renewables' side. You'll notice that we did reinstate our NCIB program back in May, and so we're very much able to go out and support the stock if there is some churn.

I would just say that we are we are conscious that when the transaction closes there might be some movement and shareholder interests from transalta renewable side and so you'll notice that we did reinstate our CIP program back in May and so.

Speaker 3: very much able to go out and support this talk if there is some churn.

Pretty much able to go out and support the stock if there is some churn.

Dariusz Lozny: Okay. Thank you both very much. I'll turn it over here.

Okay. Thank you both very much I'll turn it over here.

John Kousinioris: Thanks.

Speaker 1: Your next question comes from Mark Jarvey with CIBC. Please go ahead.

Thanks. Your next question comes from Mark Jarvi with CIBC. Please go ahead.

Operator 1: Your next question comes from Mark Jarvi with CIBC. Please go ahead.

Speaker 7: Yeah, thanks, Gordon. So just coming back to the moratorium, a couple other questions. One, do you think this will have any impact on?

Mark Jarvi: Yeah. Thanks, Gordon. Just coming back to the moratorium, a couple other questions. One, do you think this will have any impact on, I guess, the outlook for pricing or ancillary services here if there is a little bit of slowdown in the, I guess, the penetration to ramp up in renewables? Just maybe clarify, you said nothing, no impact on Tempest, WaterCharger. What about some of the, I guess, the next phase of projects like a Riplinger or SunHills? I guess the last little question would be, if they do constrain where you can site new projects, can you talk a little bit about the ability to build on existing sites, whether it's your thermal sites or legacy wind sites?

Yes, thanks, good morning.

So just coming back to the moratorium because of other questions. One do you think this will have any impact on I guess the outlook for pricing in our ancillary services here. If there is a little bit of a slowdown in the <unk>.

Speaker 7: I guess they'll look for pricing or ancillary services here if there is a little bit of slowdown in the penetration ramp up of renewables. And then just maybe clarify, you said nothing, no impact on Tempest, water charger. What about some of the, I guess, the next phase of projects like a Rippling or Sun Hills? And I guess the last little question would be if they do constrain where you can cite new projects.

So the penetration ramp up in renewables and then some.

Maybe clarify you said nothing no impact on Tempus water charter what about some of the I guess the next phase of projects like our Ripplinger Sun Hills.

So the logical question you would be so if they do constrain where you can cite new projects. How can you talk a little bit about the ability to build on existing sites, whether it's your thermal sites our legacy wind sites.

Speaker 7: Can you talk a little bit about the ability to build on existing sites, whether it's your thermal sites or legacy wind sites?

John Kousinioris: Yeah. Mark, maybe I'll start with the back half of your question. Look, as we were progressing our development pipeline, the projects that were sort of next up in terms of moving through the process for us would've been Riplinger and SunHills Solar. I think generally, we would've been looking to begin advancing approvals for those projects kind of in the back half of this year and the early part of next year. I would say that those projects, which we continue to work on, would be a little bit delayed in terms of being sort of in the permitting queue to get them completed. We'll see how the consultation progresses. I think there's a strong desire on the part of the province to ensure reliability in the grid, which makes sense for us. That's something that we've been speaking to.

Yeah.

Speaker 2: You know, Mark, I, I, maybe I'll start with the back half of your question. Look, as we were progressing our development pipeline, the projects that were sort of next up in terms of moving through the process for us would have been rippling and Sun Hill solar. And I think generally we would have been looking.

You know mark.

Maybe I'll start with the back half of your question.

Look as we were progressing our development pipeline the projects that were sort of next up in terms of moving through the process for us would have been ripplinger and southern Hills solar and I think generally we would've been looking to begin advancing approvals for those projects kind of in the back half of this year and the <unk>.

Speaker 2: To begin advancing approvals for those projects kind of in the back half of this year and the early part of next year. So I would say that those projects, which we continue to work on would be a little bit delayed in terms of being sort of in the permitting queue to get them.

Early part of next year, So I would say that those projects, which we continue to work on would be a little bit delayed in terms of being sort of in the permitting queue to get them.

Speaker 2: Um, you know, we'll see how the consultation progresses. I think there's a strong desire on on the part of the province to ensure reliability in the grid, which, which makes sense for us. That's something that we've been.

Completed.

We'll see how the consultation progresses I think theres a strong desire on the part of the province to insurer.

Reliability and the grid, which makes sense for us that's something that we've been speaking to you and.

Speaker 2: speaking to and you know also the notion of making sure that various stakeholders in rural parts of the province that are being impacted by the dramatic renewables growth that we've seen have been addressed.

John Kousinioris: Also the notion of making sure that various stakeholders in rural parts of the province that are being impacted by the dramatic renewables growth that we've seen have been addressed. You also have to remember that our development pipeline also has an extensive exposure to projects in the United States and Australia, and we're able to accelerate and kind of move the focus of the growth that we have into different jurisdictions. From a long-term perspective, I don't think we're expecting much in the way of change. It's sort of business as usual. On your question on pricing, when we look at sort of 2024, the balance of 2023, and into probably even 2025, I would say, Todd, I'm not sure that we think that the announcements are going to have much in the way of a significant impact. There's plenty of projects that are under construction.

Also the notion of making sure that various stakeholders and rural parts of the province that are being impacted by the dramatic renewables growth that we've seen have been addressed.

Speaker 2: You know, you also have to remember that our development pipeline also has an extensive exposure to projects in the United States and Australia. And, you know, we're able to accelerate and kind of move the focus of the growth.

You also have to remember that our development pipeline.

<unk> has an extensive exposure to projects in the United States, and Australia, and we're able to.

Accelerated kind of move the focus of the growth that.

Speaker 2: that we have into different jurisdictions. But from a long-term perspective, I don't think we're expecting much in the way of change. It's sort of business as usual. On your question on pricing, when we look at 2024, the balance of 2023 and into probably even 2025, I would say Todd, I'm not sure that we think that the announced we're going to have much in the way of a significant impact. There's plenty of...

That we have into into different jurisdictions, but from a long term perspective, I don't think were expecting much in the way of change. It's it's sort of business as usual on your question on pricing when we look at sort of 2020 for the balance of 2023 and into.

Probably even 2025 I would say Todd I am not sure that we think that the announcements that we have much in the way of a significant impact.

Speaker 2: projects that are under construction, there's some large gas plants that are looking and coming in, most notably Kineckor and also the Suncorp plant at the tail end of next year. So, you know, the slow down would be, you know, projects that are still a number of years away from being able to see the light of day. So, I think in terms of our near-term view, you know, I...

There's plenty of projects that are under construction there. So large gas plants that are looking at coming in most notably Qinetiq core and also the suncor plant at the tail end of next year. So.

John Kousinioris: There's some large gas plants that are looking at coming in, most notably Connect Core and also the Suncor plant at the tail end of next year. The slowdown would be projects that are still a number of years away from being able to see the light of day. I think in terms of our near-term view, I'd say very little impact.

The slowdown would be projects that are still a number of years away from being able to see the light of day. So so I think in terms of our near term view.

Bob.

I see very little impact.

Speaker 7: Okay, that's very helpful and makes sense, John . And then just, you know, when you think about some of your growth objectives or the main growth objective, so the 2 gigawatts, 3.6 billion, and you're seeing, you know, things like this maybe delay in Alberta, you know, still some constraints on supply chain and cost, how would you frame that now in terms of your path forward on that? You know, if it takes a bit more time, I assume you guys are comfortable with that. How would you sort of frame…

Mark Jarvi: Okay. That's very helpful. Makes sense, John. Just when you think about some of your growth objectives or the main growth objective, so the 2 gigawatts, CAD 3.6 billion, and you're seeing things like this maybe delay in Alberta still some constraints on supply chain and cost. How would you frame that now in terms of your path forward on that? If it takes a bit more time, I assume you guys are comfortable with that. How would you frame your, I guess, willingness to stick to that timeline versus just continue to be disciplined and you've got excess cash you could use for the buyback? Just your updated views in terms of how aggressive you push for those goals right now.

Okay, that's very helpful and makes sense John .

And then just.

When you think about some of your growth objectives are the main growth objective.

Two gigawatt $3 6 billion.

And you are seeing you know things like this maybe delay in Alberta.

Still some constraints on an on supply chain and cost.

How would you frame that now in terms of your path forward on that if it takes a bit more time I assume you guys are comfortable with that how would you sort of frame. Your I guess willingness to fix that timeline versus just continue to be disciplined in context.

Speaker 7: your willingness to stick to that timeline versus just continue to be disciplined and you know you've got excess cash to use for the buyback. Sort of your updated views in terms of how aggressive you push for those goals right now.

Excess cash can you just for the buyback just sort of.

This updated views in terms of how aggressive you push those those goals right now.

John Kousinioris: Yeah. Look, I'll begin by saying that the TransAlta Renewables acquisition is, at least from our own perspective, a pretty significant acquisition of generation. We're acquiring the economic interest in that balance, 1.2 gigs, essentially, of generation that we didn't effectively own as a result of the structure that was there. In terms of the incremental projects going forward, look, we're remaining super disciplined. We won't do projects until we've de-risked them as much as we possibly can and are comfortable with the contractual terms or, when you're looking at projects like WaterCharger, that our optimization team is ready to go in terms of what they will be doing to create value for our shareholder in those projects. We think our targets are appropriate ones. We continue to advance them. We like our 418 MW of advanced stage project that we're seeing get through.

Speaker 2: Yeah, you know, look, I'll begin by saying that the TransAlta, TransAlta renewables acquisition is at least from our own perspective, a pretty significant acquisition of generation. I mean, we're acquiring kind of the economic interest in that balance, you know, 1.2 gigs essentially of generation that we didn't effectively own as a result of the structure that was there. But in terms of the incremental projects going forward, look, we're remaining super disciplined. We won't do projects until we've de-risked them as much as we possibly can and are comfortable with the contractual terms. Or, you know, when you're looking at projects like water charger, that our optimization team is ready to go in terms of what they will be doing to create value for a shareholder in those projects.

Yes.

Look I'll begin by saying that the trans Alpha Transalta renewables.

Acquisition is at least from our own perspective, a pretty significant act.

The acquisition of generation I mean, we're acquiring kind of the economic interest in that balance one two gigs essentially up of generation that we didn't effectively all in as a result of the structure that was there but in terms of the incremental.

Projects going forward look we're remaining super.

Disciplined we will do projects until we derisk them as much as we possibly can and are comfortable with the <unk>.

Contractual terms or when youre looking at projects like water charger better optimization.

<unk> team is ready to go in terms of what they will be doing to create value for our shareholder in those projects. So we think our targets are appropriate ones. We continue to advance them, we like our 418 megawatts of advanced stage.

Speaker 2: So, you know, we think our targets are appropriate ones. We continue to advance them. We like our 418 megawatts of advanced stage.

Speaker 2: project that we're seeing get through. I think for us, we're just going to remain super disciplined on on our capital expenditures. We're not going to pull the trigger on projects unless...

<unk> that we're seeing get through.

John Kousinioris: I think for us, we're just going to remain super disciplined on our capital expenditures. We're not going to pull the trigger on projects unless we're getting the kind of returns that we need for them and with the appropriate contingency that we have. We think prices have stabilized, I would say. I think over the last little bit, what used to be about CAD 1.5 million a megawatt for development has inched up, I'd say, Todd, closer to CAD 2 million. It's kind of staying around CAD 2 million. On the wind side, we're a little bit concerned about the supply chain in kind of 2025-ish, 2026-ish. There's a lot of wind development that is going place, and there's work to do for the OEMs to be able to supply all of that.

I think for US, we're just going to remain super disciplined on our capital expenditures were not going to pull the trigger on projects unless we're getting the kind of returns that we need for them and.

Speaker 2: we're getting the kind of returns that we need for them. And, you know, with the appropriate contingency that we have, we think prices have stabilized. I would say, I think over the last little bit, you know, what used to be.

Without the appropriate contingency that we have we think prices have stabilized I would say I think over the last little bit.

What used to be about $1 million $5 a megawatt for development has inched up I'd say Todd closer to two but it's kind of staying around too on the wind side, we're a little bit concerned about the supply chain and kind of 25 ish 26 ish Theres a lot of wind development that is going places.

Speaker 2: About a million and a half dollars of megawatts for development has inched up by say Todd closer to two, but it's kind of staying around two On the wind side we're a little bit concerned about the supply chain and

Speaker 2: kind of 25 ish, 26 ish. There's a lot of wind development that is going place and there's work to do for the OEMs to be able to supply all of that. But it's pretty much.

There's work to do for the Oems to be able to supply all of that but it's pretty much.

John Kousinioris: It's pretty much steady as she goes from a TransAlta perspective and always with the view of making sure we're creating value for our shareholders. We will be, at our investor day in November, looking to update our targets. Broadly speaking, to the end of the decade, it's amazing how quickly time goes by, so stay tuned for that. I don't think there'll be any surprises in terms of what our approach is going forward.

Speaker 2: steady as she goes from a trans alga perspective and always with a view of making sure we're creating value for our shareholders. We will be at our investor day in November looking to update our targets. Broadly speaking to the end of the decade, it's amazing how quickly time goes by. So stay tuned for that, but I don't think there'll be any surprises in terms of what our approach is going.

Eddie as she goes from a transalta perspective, and always with a view of making sure we're creating value for our shareholders we will be.

At our Investor day in November looking to update our targets.

<unk> speaking to the end of the decade, it's amazing how quickly time goes by so stay tuned for that but I don't think there'll be any surprises in terms of what our approach is going forward.

Mark Jarvi: Just a follow-up to that. You talked about maintaining good returns. How would you frame the returns on the advanced stage projects now that you have in front as you come to a final investment decision? I'm particularly interested to see how the returns on something like Pinnacle 1 and 2 would square against some of the other projects that are in the advanced stage.

Speaker 7: And just a follow-up that you talked about, you know, maintaining, you know, good returns. How would you frame the returns on the advanced stage projects now that you have in front as you come to a final investment decision? And you know, particularly interested to see how the returns on something like technical one and two with square against some of the other projects that are in the advanced stage.

And just a follow up you talked about maintaining.

Good returns how would you frame the returns on the advanced stage projects now that you have in front and as you come to a final investment decision.

Particularly interested to see how the returns on something like pinnacle wanting to its square against some of the other projects that are in advanced stage.

Speaker 2: Yeah, I mean, look, we look at it as, we assess each project in line of the sort of risk elements associated with the project. So we've got like an overall sort of hurdle rate that we can to target for the company and then it either goes down or it goes up depending on the characteristics specifically that the project has, including whether or not you can put debt financing on it, how easy it is to actually construct it, how content we are, the data, what the contracting strategy is. So it is a, uh,

John Kousinioris: Yeah, look, we assess each project in light of the risk elements associated with the project. We've got an overall hurdle rate that we tend to target for the company, and then it either goes down or it goes up depending on the characteristics specifically that the project has, including whether or not you can put debt financing on it, how easy it is to actually construct it, how confident we are in the data, what the contracting strategy is. It is a, how do you put it's sort of a sliding scale in terms of the way we look at it. Certainly, projects like our WaterCharger, Pinnacle-type projects would be higher returning projects than contracted renewables. They need to be, candidly, given that there's a merchant component to what they have.

Yes, I mean look we look at it as a.

We assess each for each projects in light of the sort of risk elements associated with the projects. So we've got like an overall sort of hurdle rate that we tend to target for the company and then it either goes down or it goes up depending on the characteristics specifically that the project has including whether or not you can put that financing on it how easy it is to ask.

Constructed how confident we are the data out what the contracting strategy is so it is a.

How do you put it sort of sliding scale in terms of the way we look at it certainly projects like our water charger pinnacle type projects would be higher returning projects, then kind of contracted renewables they need to be candidly given that theres a merchant component to what they have so our focus in those projects would be to get our captain.

John Kousinioris: Our focus in those projects would be to get our capital out of them as quickly as we possibly can. We expect much higher returns. Whereas if you have a project that you've contracted for 15 or 20 years and gives you that stability of cash flow and the ability to put project financing or other debt against it's a different assessment. I don't know if that gives you the kind of color that you need, but we do look at it from a broad portfolio perspective, I'd say. Todd, I don't know if you have anything else to add to that?

A lot of them as quickly as we possibly can so we expect much higher returns, whereas if you have a project that you've contracted for 15 or 20 years and gives you that stability of cash flow and the ability to put project financing or other debt against it it's a different.

It's a different assessment, so I don't know if that.

It gives you the kind of color that that you need but we do look at it from a broad portfolio perspective, I'd say, Todd I don't know if you have anything else to add to that.

Todd Stack: Well, I was just going to add, look, clearly, inflation is higher, underlying rates are higher.

Well I was just going to add clearly clearly inflation is higher underlying brain certifier.

John Kousinioris: For sure. Yeah.

Todd Stack: We've taken that into consideration, even on what I would call the standard fully contracted-

Taking that into consideration even about what what I would call. The standard fully contracted wind facility on our return expectations. So I would say that return expectations are inching up.

John Kousinioris: Yeah

Todd Stack: wind facility on our return expectations. I would say the return expectations are inching up. John really dove into the detail about merchant is really a whole different spectrum of return expectations.

And John really go into the detail about merchant is really a whole different a whole different spectrum of return expectations.

Mark Jarvi: No, that makes sense, and good to hear the returns are inching up. What would you say would be the premium required, or can you quantify in terms of basis points or percentage-wise for that merchant exposure?

No that makes sense and good to hear their turns are inching up what would you say it would be the premium required can you quantify in terms of basis points or percentage wise.

For that merchant exposure.

John Kousinioris: Let's put it this way. It's several hundred basis points higher than it would be for contracted renewables from a TransAlta perspective. Well north of 10%, let's put it that way.

Oh.

It lets put it this way, it's several hundred basis points higher than it would be for contracted renewables from a tread valves perspective so.

Well north of 10%, let's put it.

Todd Stack: Well north. Yeah.

John Kousinioris: Yeah. Well north.

Yes.

Mark Jarvi: Yep. Okay. All right. Thanks, John. Thanks, Todd.

Okay, alright, thanks, Shawn Thanks, Scott.

Operator 1: Your next question comes from Ben Pham with BMO Capital Markets. Please go ahead.

Your next question comes from Ben Pham with BMO capital markets. Please go ahead.

Ben Pham: Hi. Thanks. Maybe just to start off on the clean electricity growth plan. Can you talk about some of the moving parts on White Rock, Horizon? You talked about the timing being revised. If I may, context on the CapEx movement and a little bit of movement on the EBITDA for Horizon Hill.

Hi, Thanks.

More often.

Clean electricity.

Growth plan can you talk about some of the moving parts on.

White rock Horizon, you talked about timing being revised the ne context on.

And our Capex on Loopnet.

A little bit of movement on the EBITDA per horizon.

John Kousinioris: Yeah, Ben, you came across as pretty muted, but I think I caught the gist of what you were asking. In terms of the timing on the plan, look, our advanced stage projects are probably about another 25% to 30% of the targeted EBITDA that we want. We do expect to be bringing some of those forward. We like the fact that they're in multiple jurisdictions. There's an Alberta feel to them, but also a feel in Australia, where we continue to progress things going forward. We remain confident in hitting our target, in terms of getting financial investment decisions on the 2 gigs by the end of 2025. We are seeing appropriate returns, I think, for the projects generally.

Yeah Ben U.

You came across is pretty muted, but I think I caught the gist of what you were you were you were asking I mean in terms of the timing on the plan.

Look.

Our advanced stage projects are.

Probably about 25% to 30% of the targeted EBITDA that we want we do expect to be bringing some of those forward.

The fact that they are in multiple jurisdictions is in Alberta feel to them, but also feel.

In Australia, where we continue to progress things up going forward, we remain confident in hitting our target.

In terms of getting financial investment decisions on the two gigs by the end of 2025.

Seeing appropriate returns I think for the projects generally, but given the inflationary environment that we see like we're even being more cautious than usual in terms of buttoning down.

John Kousinioris: Given the inflationary environment that we see, we're even being more cautious than usual in terms of buttoning down the cost of developing the projects and de-risking them as much as possible. That's generally the approach. Todd?

The cost of developing the projects and derisking them as much as possible. So.

That's generally the approach Todd and.

Todd Stack: John, sorry, Ben was commenting on specific issues around Horizon Hill.

John Sorry, you said there was a bedroom commenting on specific specific issues around horizon Hill, sorry in white rock delays in capital cost creep in there I think Ben.

John Kousinioris: Oh, sorry.

Todd Stack: White Rock delays and capital cost creep in there, I think, Ben. As John updated in the call, the construction of the turbines facilities is going extremely well. Lots of progress there. It really is the transmission interconnections, I think, on both sites, that are really critical path and driving delays. There's just some equipment supply in there, and then the final interconnections that need to be done.

So as John updated in the call that the construction of the turbines facilities is going extremely well.

Lots of progress there and it really is the transmission interconnections.

I got both sites that are that are really critical path to driving delays and theres just some equipment supply in there and then the final interconnections that need to be done.

John Kousinioris: Yeah, sorry, Ben. I didn't quite catch that.

Yeah, sorry, Ben.

I did.

Ben Pham: Oh, no, that's okay. It's good to get the broader view first, too, on that. Can you also comment on why I know there's snowpack in Alberta that's helping out that side, but we're seeing mostly drought conditions elsewhere. Is this more regional difference? Maybe just any comments on how you think about the resource projections you have in years with Q2 being quite soft, and how does it feed into even how you underwrite projects as well?

That's okay. It's good at the product and the first two on that.

Can you also comment on.

Why is I noticed snow snow.

Snowpack in Alberta, that's helping out.

LIBOR.

We're seamlessly drought conditions elsewhere or is it just more of a regional.

The difference and then maybe just any comments on.

How do you think with the resource projections, you have engineers with Q2 being quite quite stark.

<unk> continue even how you underwrite projects as well.

Todd Stack: Well, I think we did see an early melt this year, a lot of the water came through in Q2 versus some that often spills into July in our Q3 results. We saw a lot of the melts come in Q2, we did see high precipitation in the period as well. Long term, clearly, if the melt comes in Q2, we'll have less production in Q3. As we kind of talk through there, even though we got the extra energy in the water in Q2, it did impact our ancillary services sale. If we get a little bit less water in Q3, we have the opportunity to offer more into the ancillary market from the facilities. Longer term, we're still confident in the long-run hydrology there, really no concerns on the long run average production that we get from those facilities.

Well I think I think we did see an early melt this year and a lot of water came through in Q2 versus some that often spills into July and in our Q3 results. We saw a lot of the melts come in Q2, but we did see high precipitation in the period as well long term I mean, clearly if the milk comes in Q2, we'll have less.

<unk> in Q3, but as we kind of.

You know talk through there.

Even though we got the extra energy in the water in Q2, it did impact our ancillary services sales. So if we get a little bit less water. In Q3, then we have the opportunity to offer more into the ancillary market from the facilities longer term, we're still confident in the long run the hydrology there.

And really no concerns on the long run average production that we get from those facilities, yes, I mean, the kind of variability. We're seeing is kind of within the zone of what our expectations would be and we have seen over the.

John Kousinioris: Yeah, the kind of variability we're seeing is kind of within the zone of what our expectations would be and what we've seen over more than a decade of data that we have. In fact, it goes a lot longer than that. This year, we had a lot of water in June. I think, Ben, as you know, we don't have as much storage as we'd like on our systems here in Alberta, you can't actually store the water. We've got to spill it and manage the river flows as we go forward. In light of the overall management that we do there and the constraints that we have in the facilities, to Todd's point, we ran them, and disproportionately more energy was generated from the fleet rather than ancillary services, but our gas fleet picked up the slack on the AS side.

More than a decade of data that we have in fact, it goes a lot longer than that I mean this year, we had a lot of water in June .

I think Ben as you know, we don't we don't have as much storage as we'd like on our systems here in Alberta. So you can actually store the water. We've got a we've got a spill it and manage the river flows as we go.

Forward so in light of the overall management that we do there and the constraints that we have in the facilities to Todd's point be random.

And there was disproportionately where energy was generated from the fleet.

Rather than ancillary services, but our gasoline picked up the slack on the AI side.

Ben Pham: Maybe just one last one, if I may. You mentioned, in response to the question around the 2025 targets, RNW being quite a significant transaction. Are you maybe suggesting that, really, when you think about RNW on a proportionate basis, you've effectively met your 2025 targets in a sense, because there was some sort of M&A in it? Can you confirm, you mentioned around Investor Day, there's going to be probably no change in methodologies. It's still going to be on a growth basis, that guidance? You may want to relook at that?

Maybe just one last one if I may you had mentioned.

In response to the question around the 'twenty 'twenty five targets <unk>.

And quite a significant transaction.

Are you maybe suggesting that.

It really like when you throw in <unk> on a proportionate.

You have to actually next year.

In 'twenty five targets in a sense because it wasn't sort of M&A.

Can you confirm you mentioned around.

Investor Day is going to be probably no no change in methodologies, it's going to be it still going to be on a gross basis.

Guidance or you mean on a re look at that.

John Kousinioris: Yep. Look, when we talk internally about what we're doing, when you look at the TransAlta Renewables acquisition, we're spending quite a bit of money for that. It is growth from our perspective. We're preserving cash flows from those assets. We're not sort of explicitly saying that, Check, we've made the 2-gigawatt target. We continue to advance and trying to add incremental megawatts going forward, we're confident of moving that forward. The key criteria for us is just making sure that the projects that we do create value for our shareholders. If all we needed to do was hit 2 gigs, we could do it, you may not get the kind of projects from the company that you'd want us to have. We're going to stay disciplined. In terms of Investor Day, yeah, you will be seeing sort of growth.

Yes.

Look when we talk internally about.

You know, what we're doing and when you look at the Transalta renewables acquisition I mean, we're spending quite a bit of money for that it is growth from our perspective, we're preserving cash flows from from those assets, we're not sort of explicitly saying that check.

We've made the the two gigawatt target, we continue to advance and trying to add incremental.

Megawatts.

Going forward and we're confident of moving that forward. The key criteria for US is just making sure that the projects that we do create value for our shareholders.

If all we needed to do with it two gigs we could do it but you may not get the kind of projects from the company that you'd want us to have so we're going to stay disciplined in terms of Investor day, you will be seeing sort of gross we're not proposing to change the methodology or anything like that it'll be very much as we worked through it similar to what youre seeing there.

John Kousinioris: We're not proposing to change the methodology or anything like that. It'll be very much as we work through it, similar to what you're seeing now in terms of a long-range megawatt target, broad-speaking, an annual pathway, EBITDA targets for the company, and kind of our expectations on what the capital spend would be based on the best information we have at the time.

Now in terms of our long range.

Megawatt target.

Speaking on annual pathway EBIT.

EBITDA targets for the company and kind of our expectations on what the capital spend would be based on the best information we have at the time.

Ben Pham: Okay, that's great. Thank you.

Okay. That's great. Thank you.

John Kousinioris: Thank you, Ben.

Thank you Beth.

Operator 1: Your next question comes from Robert Hope with Scotiabank. Please go ahead.

Our next question comes from Rob Hope with Scotiabank. Please go ahead.

Robert Hope: Morning, everyone. Just one for me. I want to ask about conceptually how you're thinking about the peaker plant at Keephills. As we see Canaccord and Cascade, or Cascade, SunHills, and the Suncor project enter service, is the expectation that kind of your coal-to-gas conversions could be seeing less utilization and won't have that ramping capacity that will be required in a renewable-heavy environment so that this peaker investment is allowing you to use existing infrastructures and interconnection to better meet the more volatile pricing environment?

Good morning, everyone just one for me.

I want to thank I want to ask about conceptually how are you thinking about the peak or plants at key pills.

As we see <unk> and Cascade or Cascade.

And these projects enter service is the expectation that kind of your coal to gas conversions could be seeing.

Less utilization and won't have that ramping capacity that will be required in a renewable happy.

Environment, So that this peak or investment.

Is allowing you to use existing infrastructure and interconnection to better meet the more volatile.

Pricing environment.

John Kousinioris: Yeah. Good morning, Rob, first of all. Look, I think the way you've characterized it is sort of an appropriate one as we see the evolution of the fleet. When you look at our coal-to-gas units now, we tend to describe them, and I think you've heard us describe them, as kind of Alberta peaking units. There'll be periods of time where they'll be running at relatively high capacity factors, and there'll be other periods of time that we won't need them as much. I think you've hit the nail on the head when you're looking at not just Pinnacle one and two, but even WaterCharger, for example. Those are products that will be oriented towards meeting what we anticipate will be increasing intermittency in the grid and more significant volatility in terms of price movement.

Yes.

Good morning, Ralph first of all.

Look.

The way you've characterized it.

It's sort of an appropriate one and we see it as we see the evolution of the fleet. When you look at our coal to gas units now we tend to describe them and I think you've heard us describe them as kind of Alberta, peaking units will be there'll be periods of time, where there'll be running at relatively high capacity factors and there'll be other periods of time that we wont need the mismatch, but I think you've hit the nail on the head.

When youre looking at not just pinnacle, one and two but even water charger for example.

Those are products that will be oriented towards meeting what we anticipate will be.

Increasing intermittency and the grid and more.

<unk> volatility in terms of price movement, so having fast response.

John Kousinioris: Having fast response products will be critical, I think, going forward, both to meet the reliability that the grid is going to need, but also from our own perspective, to create value for our shareholders. Different products under each of the different assets. Some of them are more, what I would call, energy arbitrage assets. Some will be able to provide more ancillary services support. We're very much looking, as it relates to Alberta, kind of two pathways. One would be an overall renewables build-out in time as the province continues to make its transition to decarbonization. Secondly, what are those kind of reliability, fast responding, capacity products that the province is going to need to ensure the stability of the grid? Those are the two pathways that we're looking at from an investment perspective.

<unk> will.

We will be critical I think going forward both.

To meet the reliability that grade is going to need but also from our own perspective.

Value.

And for our shareholders different products under each of the under each of the different assets. Some of them are more what I would call energy arbitrage.

Assets some.

Will it be able to provide more ancillary services support, but we're very much looking as it relates to Alberta kind of two pathways one would be in overall.

Renewables build out in time.

As the province continues to make its transition to decarbonization and secondly, what are those kind of reliability fast response, saying fast responding sorry, our capacity product set the province is going to need to ensure the stability of the grid. So those are the two pathways that we're looking at from an investment perspective.

Robert Hope: All right. Appreciate that. Actually, maybe one follow-up. You did add some hedges in 2024 and 2025 that looks like to be good pricing. Overall, how are you thinking about the kind of trade-off of adding hedges in 2024 and 2025 versus where the forward curve is, as well as just maintaining optionality?

Alright, I appreciate that and actually maybe one follow up.

You did add some hedges in 'twenty four 'twenty five that it looks like to be a good pricing, but overall how are you thinking about the kind of tradeoff of adding hedges in 'twenty four 'twenty five versus where the forward curve is as well as just maintaining optionality.

John Kousinioris: Yeah. Look, our hedging team is in there and feel, I think, that the kind of pricing that we're getting in, and I'll talk mostly about 2024, because 2025 is a ways away. The market isn't all that liquid. We're getting, I would say, some reasonable early liquidity in terms of 2024. I think we're seeing prices that are in the high 90s right now that are there. The team is happy with what they're seeing. They're layering on hedges. You have to remember, we also have our C&I business, which is a multi-year business which provides hedging that goes out, typically, I think on average around 3 years, I would say, Todd, going forward.

Yes.

Look our our hedging team is in there and.

You don't feel I think that the kind of pricing that we're getting in and I will talk mostly about 24, because 25 is a ways away.

And you know the market isn't all that liquid, but we're getting I would say some reasonable early liquidity in terms of 'twenty 'twenty four I think we're seeing prices that are in the high nineties right now.

That are there the team is.

Is happy with what they're seeing they're layering on and just you have to remember we also have our C&I business, which is a multi year business, which provides hedging that goes out.

Typically I think on average around three years I would say Todd going forward. So we continue to do what we've always done and that is look at our internal modeling, where we think the fundamental price is going to be.

John Kousinioris: We continue to do what we've always done, and that is look at our internal modeling, where we think the fundamental price is going to be, how do we de-risk elements of the fleet, at the same time leaving enough open length in the fleet to be able to capture kind of the volatility that we expect will increase. I think as time goes by, it'll become less about what you made in the 60% of the hours in the marketplace, but much more about how you did in that 25% to 30% of stronger hours in the market. We're really focused on that part of the market and shifting the capabilities of our fleet to be responsive there.

How do we de risk elements of the fleet at the same time, leaving enough open links.

In the.

In the fleet to be able to capture kind of the volatility that we expect will increase I think as time goes by it will become less about.

You know what you made in the 60% of the hours in the marketplace, but much more about how you did in that 25% 30% of stronger hours in the market and we're really focused on that part of the market and shifting the capabilities of our fleet to be responsive there.

Robert Hope: Thank you.

Thank you.

Operator 1: Your next question comes from Andrew Kuske with Credit Suisse. Please go ahead.

Your next question comes from Andrew Kuske with Credit Suisse. Please go ahead.

Andrew Kuske: Thanks. Good morning. I guess the first question is for John, and it ties into some of your last comments there. When we look at the Alberta power market, we're having higher highs and lower lows. A very bifurcated market with maybe longer-term prices starting to average down a bit. Some of that's reflected in your hedging program where 2024 for 2025, kind of flat on price, but you've got your gas hedges at a greater dollar value. Carbon prices obviously go up each year. All of that implies kind of lower margins. I guess when you think about all that, is that kind of base load hedging program to give business stability and certainty on a high degree of the cash flows, and then you're trying to capture around it for that sort of 25% of the market where there's maybe a greater volatility?

Thanks, Good morning, I guess, the first question for John and it ties into some of your last comments there when we look at the Alberta power market for having higher highs and lower lows very bifurcated market with maybe a longer term prices certain average down a bit.

Some of that's reflected in your hedging program, where 24 for 25 kind of flat on price, but you have got your gas hedges at a greater dollar value carbon prices office to go up each year all of that implies kind of lower margins.

So I guess when you think about all of that is is that.

Kind of Baseload hedging program to give business stability and certainty on high degree with the cash flows and then youre trying to capture around it.

For that sort of 25% of the market, where there's maybe a greater volatility.

John Kousinioris: I think, Andrew Kuske, good morning, by the way, you've captured it sort of exactly right. That is the mindset. What's interesting is, in the past, when we've talked about average hours, they were really meaningful, at least from my own perspective, because the standard deviation around that was a little bit tighter, if you see what I'm saying. Whereas now, the path to the average is what's really going to matter, I think, as you go to 2024, 2025, 2026. We've had these kind of discussions, I know with you in the past, and others. I think you've got it exactly right. It's how do you kind of de-risk the base and create that sense of predictability? That is both a revenue item and a cost item with the gas that we're procuring to kind of lock in margin as we go forward.

I think I think Andrew good morning by the way you've captured it sort of exactly right.

That is the mindset and the what's interesting is.

In the past when we've talked about average hours.

They were really meaningful at least from my own perspective, because there was the standard deviation around that was a little bit tighter if you see what I'm, saying, whereas now the path to the averages what's really going to matter I think you should go to 'twenty four 'twenty five 'twenty six we've had these kind of discussions.

I know with you in the past that others.

So so I think you've got it exactly right. It's how do you kind of.

De risk the debates and create that sense of predictability in that has both a revenue.

Item at a cost item with the gas that we're procuring.

Lock in.

Margin as we go forward and then making sure that you've got fast response fast responding leg to be able to take advantage of.

John Kousinioris: Making sure that you've got fast responding length to be able to take advantage of the volatility when it comes. Candidly, to create reliability for the grid here in the province of Alberta.

The volatility when it comes in and candidly to create <unk>.

Our liability for the.

The grid here in the province of Alberta.

Andrew Kuske: Okay. That's great. I appreciate that. Then maybe just on Pinnacle 1 and 2, and if we could maybe geek out a little bit on some of the op conditions on those units. It's been a while since I've looked at them, but my recollection is sort of 2 to 3 minutes to full load on a ramp rate, 10 minutes for efficiency and about a 8,000 heat rate. Is that all about broadly right?

Okay. That's great appreciate that and then maybe just on pinnacle, one and two and if I could maybe kick out a little bit on some of the op Bob conditions on those units, it's been a while since I've looked at them but.

My recollection is sort of like two to three minutes to full load on a ramp rate 10 minutes for efficiency and about 8000 heat rate is that all about broadly right.

John Kousinioris: Yeah. I think in terms of the ramp rates that you have, you've got it pretty much bang on the mark. I think their heat rate is probably a little bit higher, but at least from our own perspective, they'll be running at times when the heat rate isn't going to matter all that much from a pricing perspective. If you see what I mean, Andrew?

Yes, I think in terms of the.

The ramp rates that you have you've got it pretty much bang on the Mark I think theyre heat rate is probably a little bit higher but at least from our own perspective, they'll be running at times when the heat rate isn't going to matter all that much from a pricing perspective, if you see what I mean, Andrew.

John Kousinioris: What really matters is the speed with which they're able to respond, and that's our focus. The other thing I would say is they were an opportunistic purchase that we made probably two years ago now. They became available on the market, and in anticipation of the evolution of the market, we picked them up for pennies on the dollar. Let's put it that way. We're shipping them up here now from the Pac Northwest and look forward to advancing them.

What really matters is the speed with which they are able to respond and thats. Our focus the other thing I would say is they were an opportunistic purchase that we made.

Probably two years ago now they became available on the market and in anticipation of the evolution of the market.

We picked them up for pennies on the dollar let's put it that way so.

We're shipping them up here now from the Pac northwest and look forward to two advancing them.

Andrew Kuske: The pennies on the dollar, that sounds like very high ROIs.

So the pennies on the dollar that sounds like very high Rois.

John Kousinioris: That's the goal.

That's the goal.

Andrew Kuske: Okay. That's a good goal to have. Thank you.

Okay. That's a good goal to have thank you.

John Kousinioris: Thanks so much, Andrew.

Thanks, so much.

Operator 1: Your next question comes from Naji Baydoun with iA Capital Markets. Please go ahead.

Your next question comes from.

Now they do with <unk> capital markets. Please go ahead.

Naji Baydoun: Hi. Good morning. I just wanted to go back a bit to the topic of growth and CapEx pressures. Seeing a bit of sort of higher dollar investments on the wind side. I guess with things like WaterCharger and Pinnacle, and maybe it's just a function of those specific assets in that specific market, but are you seeing sort of better risk-adjusted returns on the solar storage side maybe versus wind? If that's the case, what are some of the ways that maybe you can accelerate development on that side of the house, seeing as how most of the pipeline today is made up of wind projects?

Hi, good morning.

Wanted to go back a bit to the topic of some growth from now on.

Capex pressures.

Seeing a bit of a sort of higher.

So with all the investments on the wind side.

I guess with things like water charger clinical and maybe it's just a function of those specific assets in that specific market, but are you seeing sort of better let's.

Risk adjusted returns on the solar storage side, maybe even versus wind and if thats the case.

What are some of the ways that maybe you can accelerate development on that side of the house seeing as how most of the pipeline today is made up of wind projects.

John Kousinioris: Yeah. Good morning, Naji. I would say, if you were to kind of draw a spectrum of kind of returns, I would say that we would see probably the lower level of returns more in contracted solar, I would say. Higher returns in contracted wind. Look, we have particular expertise in wind. For us, that's a core part of our business. Then it gets higher in the spectrum as you begin moving towards some of the peaking gas capacity that we're looking at, and then some of the battery storage that we would be looking at. I would say that even when we look at Tent Mountain and some of the pump storage that we have, the kind of returns we would expect for those projects would be significantly higher. We do look at it from a portfolio perspective.

Yes.

Good morning Dodgy.

I would say.

If you were to kind of draw a spectrum of kind of returns I would say that we would see probably a lower level of returns more in contracted solar I would say.

Higher returns and contracted wind and look we have.

Particular expertise in wind.

And for US that's a core part of our business and then it gets higher in the spectrum as you begin moving towards.

Some of the peaking gas capacity that we're looking at and then.

Some of the battery storage that we would be looking at and I would say that even when we look at.

Like 10 mountain than some of the pump storage that we have the kind of returns we would expect for those projects would be significantly.

Higher we do look at it from a portfolio perspective, there is a finite amount of.

John Kousinioris: There is a finite amount of storage and kind of peaking gas that we would put in, because what's critical, I think, for those kind of assets is to have those really strong optimization capabilities that you need to be able to extract value from them. We definitely have that in Alberta, so that is a focus for us. It's not something that is pervasive in terms of all parts of North America. We continue to focus on, I would say our investments still are oriented towards green. You'll see the company continuing to execute on renewables as we go forward. We'll be opportunistic, I think, on natural gas investments that we think we can add value to as a company. We think that we can get acceptable risk-adjusted returns for all of those types of projects as part of the portfolio that we're building out.

Storage and kind of peaking gas that we would put in because what's critical I think for those kind of assets is to have those really strong optimization capabilities that.

But you need to be able to extract value from them, we definitely have that in Alberta. So that is a focus for us it's not something that is pervasive in terms of all parts of North America. So we continue to focus on I would say our investments still oriented towards screen you will see the company continuing to execute on renewed.

<unk> as we go forward, we'll be we'll be opportunistic I think on natural gas.

Investments that.

That we think we can add value to as a as a company and we think that we can get acceptable risk adjusted returns for all of those types of projects as part of the portfolio that we're building out.

Naji Baydoun: Okay. Understood. I also wanted to get your thoughts on the sort of emissions credit, be it inventory or annual generation. Does that change at all with the RNW buyout, either in terms of the amount or strategy? Just how are you thinking about the sort of emissions credits post RNW?

Okay understood.

I also wanted to get your thoughts on the sort of emissions credits.

Inventory or.

The old generation does that change at all would be our NW buyout.

Either in terms of the amount of subsidy or just how are you thinking about the.

Sort of emissions credits post aren't W.

John Kousinioris: Great. Yeah, we can talk about that.

Great Yeah, we can talk about that yet.

Todd Stack: Yeah, not a real big change, Naji. Renewables was typically selling the credits that it produced on an annual basis, TransAlta Renewables wasn't actually even carrying an inventory balance. That balance was all developed and held and strategized at the TransAlta Corp level from both the hydro and the wind assets, as well as purchased credits. You'll notice we are carrying a fairly large balance in there, and we have a lot of internal discussions about how and when to utilize those credits. You'll see in Q2, we chose not to retire any credits, and simply pay the CAD 50 obligation from last year's production. We'll continue to look to how to optimize that inventory level.

Not a real big change now.

Renewables was typically selling the credits that are produced on an annual basis, and so transalta renewables wasn't actually even carrying in inventory balance that balance was all developed and held and strategize that the Transalta Corp level from both the hydro and wind assets as well as purchased credits so.

I mean, you'll notice we are carrying a fairly large balance in there and we have a lot of internal discussions about.

How and when to utilize those credits Youll see in Q2, we we chose not to retire any credits.

And simply pay $50 obligation from last year last year's production and we will continue to look to how to optimize that inventory level.

Naji Baydoun: Okay. No changes to the strategy then. Maybe just one last question. The hydro's, again, on track for a very strong year. I think in the past, in a more normalized power price environment, I think you were talking sort of a CAD 200 million-ish run rate EBITDA number for the hydro fleet. Is that still the right number given what we're seeing in the market and how the dynamics are playing out? Or do you think that that number could be materially higher?

Okay. So no changes such as you then maybe just one last question so the hydro.

Then on track for a very strong year I think in the past and a more.

The normalized power price environment, I think you were talking.

Sort of a $200 million ish run rate to EBITDA number for the hydro fleet is that still the right number given what we're seeing in the market and how the dynamics are playing out or do you think that that number could be materially higher.

John Kousinioris: Well, I think you're right, your memory's right, Naji. I think when we were first thinking about the post-PPA period, and we were thinking of our hydro performance, I think it was actually around CAD 240 million, that we were thinking the hydro run rate was going to be, and that was a little bit of a guess. We've seen it, I think in 2021, it was around CAD 300 million, and 2022, it was just a little bit over CAD 5. Look, we're tracking to another, let's call it 500-ish year on the hydro fleet. Look, we've had really elevated pricing, I would say, in the province of Alberta over the course of at least the last two years. If you were to sort of ask me what I think kind of a normal run rate is, we'll see how the markets develop in 2024 and 2025.

Well we have.

So I think Youre right your memories right G. I think when we were first thinking about.

The post PPA period than we were thinking about hydro performance I think it was actually around $240 million that we were thinking the hydro run rate was.

It's going to be and that was a little bit of a guess.

<unk> seen it I think in 'twenty, one it was around $300 million.

22 it was.

Just a little bit over five and look we're tracking to another let's call. It 500 this year on the hydro fleet.

That really elevated pricing I would say in the province of Alberta over the course of at least the last two years.

You were to sort of asked me, what I think kind of a normal run rate is I mean, we'll see how the markets develop in 'twenty four 'twenty five we would expect sort of average pricing to come down a little bit.

John Kousinioris: We would expect sort of average pricing to come down a little bit. We would also expect volatility to be pretty meaningful. The ability, I think, of the hydro fleet to capture those economic rents, I think, will remain high. Will they be CAD 500 million? That's a big number. The low CAD 200s feels low-ish, I think, from my perspective, as we go forward.

But we would also expect volatility to be pretty meaningful so the ability I think of the hydro fleet to capture those economic rents I think will remain I believe the $500 million.

That's up.

It's a big number.

<unk>.

The the low two hundreds fields.

Low ish I think from my perspective, as we go forward I think when we put those numbers out there in the two hundreds it was really predicated on sort of the last 10 years or 20 years of the average is backward looking so probably in that 60 to $70 price range I think we see a step change up from their carbon impact on power prices in Alberta, we will have a real impact.

Todd Stack: Yeah, I think when we put those numbers out there in the 200s, it was really predicated on sort of the last 10 years or 20 years of averages.

John Kousinioris: It is backward looking.

Todd Stack: probably in that CAD 60 to 70 price range. I think we see a step change up from there. Carbon impact on power prices in Alberta will have a real impact somewhat through the balance of the decade, but then even into the 2030s will be very dramatic on the long-term power price. It will go up and down, but I think the trend is definitely for much stronger prices over the next 10 years than we saw in, say, the 2010s.

You're somewhat through the balance of the decade, but then even into the 2000 <unk> will be very dramatic.

Long term power price. So it will it will it will go up and down but I think the trend is definitely for much stronger prices over the next 10 years that we saw in say the 2000 tens and obviously I think as the as the grid changes and evolves with more renewables coming in I think the value of Pi.

John Kousinioris: Naji, I think as the grid changes and evolves with more renewables coming in, I think the value of hydro and the kind of reliability and ancillary services support that it provides in the marketplace will increase over time. I think we're really well-positioned with the fleet.

Hydro and the kind of reliability and ancillary services support that it provides in the marketplace will actually.

My view is it should increase over time, so so I think I think.

We're really well positioned with the fleet.

Naji Baydoun: That's great detail. Thank you.

So that's great. That's all thank you.

John Kousinioris: Thank you.

Yeah.

Operator 1: Your next question comes from Patrick Kenny with National Bank Financial. Please go ahead.

Thank you. Your next question comes from Patrick Kenny with National Bank Financial. Please go ahead.

Patrick Kenny: Yeah, good morning. John, I know you've had a whole day to think about it, but assuming there is a slowdown in renewables in Alberta beyond the six-month period here, how would you think about the commercial tension surrounding the next phase of corporate PPAs in Alberta? Do you think there might be an opportunity over this six-month period to strike while the iron's hot related to some of your uncontracted renewable capacity in the province?

Yeah. Good morning, John I know you've had a whole day to think about it but assuming there is a slowdown in renewables in Alberta beyond the six month period here how might this change.

Or how much how would you think about the commercial tension.

Surrounding the next phase of corporate Ppas in Alberta, and do you think there might be an opportunity over the six month period to strike while the iron is hot related to some of your own contracted renewable capacity in the province.

John Kousinioris: Good morning, Patrick. Look, you're right. It's been 24 hours, I think, almost to the hour, since the announcement has come up. Look, it's a decision that we know the province of Alberta wouldn't have taken lightly. I think they see some of the pressure points in the province, and they're hearing some of the feedback they're getting from folks in parts of the province, and they want to make sure that we do this in a thoughtful way. We completely understand that. I do think, to your point, that those projects that are through the queue, let's put it that way, like our Tempest project, I think are in a particularly good position now, to be able to get PPAs and move on from a contracting perspective given their, I would say, comparative scarcity.

Yeah, Good morning, Patrick.

Look.

Youre right its been its been.

24 hours I think almost to the hour since the.

The announcement has come up and.

Look.

It's a decision that we know the province of Alberta.

It wouldn't have taken.

I think they see some of the pressure points in in the province, and Theyre hearing some of the feedback you're getting from.

From folks in parts of the province, and they want to make sure that we do this in a thoughtful way. So we completely understand that I do think to your point.

Those projects that are through the queue, let's put them.

Put it that way look our Tempest project.

I think our in a particularly good position now.

To be able to get.

Ppas and move on from a contracting perspective, given there I would say comparative scarcity.

John Kousinioris: I also am hopeful that it means that we can do more like we did with Lafarge on some of the other renewables that we have, where we can get longer contracted contracts for some of our merchant renewables fleet. Not so much from hydro, but certainly from the wind that we have in Alberta to be able to meet sort of the ESG and environmental goals that third parties have. As you know, Alberta's really the only truly deregulated market in the country. The good thing about it is that there's people that are trying to meet their needs or coming to Alberta to kind of get the supply that they need to meet them. The challenge is, I think this is what is reflecting the province's position, is that incremental build-out isn't necessarily built on fundamental supply and demand balances within the province.

I also am hopeful that it means that we can do more like we did with with Lafarge up some of the other renewables that we have where we can get longer contracted.

Contracts for some of our merchant renewable fleet not so much from hydro, but certainly from the wind that we have in Alberta to be able to meet sort of ESG and environmental goals that that third parties have as you know Alberta is really the only truly deregulated market.

In the country so.

The good thing about it is that there is people that are trying to meet their needs are coming to Alberta to kind of get the supply that they need to meet them. The challenge is and I think this is what is reflecting the province's position is that that.

That incremental build out isn't necessarily built on fundamental supply and demand.

Balances within the proppant said, so it's a balancing act.

John Kousinioris: It's a balancing act in terms of going forward.

In terms of going forward.

Patrick Kenny: Okay. That's great. Thank you. Then, I guess it's been less than a month since you announced the roll-up transaction. Just given the stock has performed well, I guess validating your strategy of simplifying the story, I know the near-term priority is closing RNW here, but are there any other corporate structure optimization opportunities that you might be able to point to that might serve to keep this valuation momentum going beyond cleaning up RNW?

Okay. That's great. Thank you.

And then.

I guess, it's been a less less than a month since you.

Announced the roll up transaction, but.

Just given the August performed well I.

I guess validating your strategy of simplifying the story.

I know the near term priority is closing are in W. Here, but are there any other corporate structure optimization opportunities.

You might be able to point to that.

Might serve to keep this valuation momentum going beyond <unk>.

Cleaning up our W.

John Kousinioris: Look, we're focused on getting the RNW transaction done in that late September, actually early October timeframe. It's a critical thing that we need to do. We're pleased that it's been well received in the marketplace. We're focused on our upcoming investor day where we're going to talk about kind of our pathways going out for the balance of the decade. Our M&A team, we have a small team, but they're a very capable team. They're continually looking at the funnel. It's a very wide funnel of opportunities that arise, and they see stuff that ranges from renewables in each of our three jurisdictions to alternative fuels, which is kind of new, to even occasionally some natural gas opportunities that might exist. We're still active from that perspective. Very mindful, Patrick, on just the cost of things.

Yeah, I mean look.

We're focused on getting the <unk> transaction done.

In that late September actually early October timeframe. It's.

It's a critical thing that we need to do we're pleased that it's been well received in the marketplace. We're focused on our upcoming Investor day, where we're going to talk about kind of our pathways going out for the balance of the decade.

Our M&A team, we have a small team, but they are a very capable team. They get there. They are continually looking at the funnel, it's a very wide funnel of <unk>.

Opportunities that arise and they see stuff that ranges from you know.

Renewables in each of our three jurisdictions to alternative fuels, which is kind of new to even occasionally some natural gas opportunities that might exist. So we're still active from that perspective very mindful Patrick.

Our cost of things.

John Kousinioris: We still find assets in the M&A market to be a bit expensive, I would say. That doesn't mean that there aren't opportunities there. I think there are. We're going to be super disciplined and make sure that if we proceed with something, whatever we pay makes sense for our shareholders.

We still find assets in the M&A market to be a bit expensive I would say that doesn't mean that there are opportunities. There I think there are but we're going to be super disciplined and make sure that that if we proceed for something whatever we pay makes sense for our shareholders.

Patrick Kenny: Okay. That's great. Thank you very much, and have a great weekend.

Okay. That's great. Thank you very much and.

Great weekend.

John Kousinioris: Thanks, Patrick.

Thanks, Patrick.

Operator 1: Your next question comes from Chris Varcoe with Calgary Herald. Please go ahead.

Your next question comes from Chris <unk> with Calgary Herald. Please go ahead.

Chris Varcoe: Hi, John. With all of the renewable projects in Alberta that have been proposed over the last couple of years, what impact do you think it's having on the Alberta market? You talked about reliability concerns and some of the other issues, and I guess just taking a big picture, what are some of the broader impacts you're seeing?

Hi, John with all of the renewable projects in Alberta that had been proposed over the last couple of years what impact do you think it is having on the on the Alberta market and you talked about reliability concerns that some of the other issues that I guess, just taking a big picture what are some of the broader impacts you're seeing.

John Kousinioris: Yeah. Good morning, Chris. In terms of the renewable build-out coming into the province, first of all, I would say we have a lot to be proud of here in the province in terms how much we've decarbonized the grid, and I think that journey continues. I think if you go back, like probably even 5 years ago, certainly 10 years ago, our emissions per megawatt generated in the province were probably more than double what they are today. A tremendous amount has been accomplished, and a lot of that was on the back of the shift from coal to natural gas. We have seen significant renewables build-out in the province. That isn't surprising to us given the state of the marketplace here in Alberta and, as a deregulated market, particularly given corporate ESG requirements.

Good good morning, Chris.

In terms of the renewable buildup coming into the province, I mean, I think so first of all I would say we have a lot to be proud of here in the province in terms, how much with decarbonize, the grid and I think that journey.

Continues so I think if you go back Oh, gosh like probably even five years ago, certainly 10 years ago, our engagements per megawatt generated in the province for probably more than double what they are today. So a tremendous amount has been accomplished in a lot of that was on the back of kind of the shift from call to now.

Natural gas.

Have seen significant renewables build out in the in the province that isn't surprising to us given kind of the state of the.

Marketplace here in Alberta and the.

A deregulated market, particularly given corporate ESG requirements I think there was a rush should I think continues to be demand.

John Kousinioris: I think there was a rush, and I think continues to be demand for renewables in the marketplace. In terms of impacts, look, we've been talking for quite a while to, here in Alberta, frankly, everywhere, because it's similar challenges we're seeing everywhere that we operate, about the importance of aligning the importance of having clean generation with affordability and reliability. What we're seeing with the renewables is, more, I would say a few things. When it's a windy day or a super sunny day, you've got a lot of renewables generation that is actually in the marketplace. Then if all of a sudden the wind dies down or all of a sudden we're getting to dusk and we're getting into the evening, the solar just goes away. It's not like it's 50 MW.

For renewables in the marketplace in terms of impacts look we.

We've been talking for quite a while too.

Here in Alberta, frankly everywhere, because it's similar challenges, we're seeing everywhere that we operate about the importance of kind of aligning aligning.

The importance of having clean generation with affordability and.

Reliability and what we're seeing with the renewables is.

More I would say.

A few things so when it's a windy day or a super Sunny day, you've got a water renewables generation that that is actually in the marketplace and then if all of a sudden the wind dies down or all of a sudden.

We're getting to dusk and we're getting into the evening. The solar just goes away and it's not like it's 50 megawatts. If large amounts of generation that are online offline. If you see what I'm, saying, so that increases the kind of volatility that you're seeing in the marketplace and really from an Alberta perspective, that's up to you.

John Kousinioris: It's large amounts of generation that are online, offline, if you see what I'm saying. That increases the kind of volatility that you're seeing in the marketplace. Really, from an Alberta perspective, that's up to our gas. I'm saying gas because the little bit of coal we have left is going to be converted to gas to backstop that and make sure that is there, and in a way that is reliable and affordable for Albertans. I think the other element with the renewables build-out is, I think it does create pressure on transmission.

Gas and I'm, saying gas because the little bit of coal. We have left is going to be converted to gas to backstop that and make sure.

But that.

Is there.

And in a way that is reliable and affordable for Albertsons I think the other element with our renewables build out is I think it does create pressure on transmission, we have more dispersed generation coming across the.

John Kousinioris: We have more dispersed generation coming across the province and building out that transmission that you need to be able to take the power where it's being generated and move it to the populated areas or the industrial areas of the province is an incremental cost burden that we need to be mindful of. Finally, just from a regulatory permitting, supply chain, and making sure that stakeholders in parts of the province that have seen quite a bit of development are being heard is another third factor that I think needs to be addressed. There's a lot of change.

The province, and kind of building out that.

Transmission that you need to be able to take the power, where it's being generated and move it to the populated areas, where the industrial areas of the province is an incremental.

<unk>.

Cost burden that we need to be mindful of and finally, just from a regulatory permitting supply chain.

Making sure that stakeholders seeing in parts of the province that have seen quite a bit of development are being heard is that there is another third factor.

That I think meets needs too.

Be addressed so so there's a lot of change it's come relatively quickly and we're seeing some of the impacts of that and I think the province is trying to just make sure that we have thoughtful pathways going forward and that the case I think is an appropriate pace to maintain that three legged stool.

John Kousinioris: It's come relatively quickly and we're seeing some of the impacts of that, I think the province is trying to just make sure that we have thoughtful pathways going forward and that the pace, I think, is an appropriate pace, to maintain that three-legged stool of clean, reliable, and affordable for our province.

Clean reliable and.

And affordable for our province.

Chris Varcoe: Just to follow up, sort of a two-part question here. Maybe I'll start with the first one, and that is, you mentioned the stakeholders in rural Alberta being impacted. What are you hearing from rural landowners when you're proposing renewable projects, and how are you addressing their concerns?

Just a follow up sort of a two part question here, maybe I'll start with the first one and that is you mentioned the stakeholders in rural Alberta being impacted but what are you hearing from rural landowners when youre proposing renewable projects and how are you addressing their concerns.

John Kousinioris: Yeah, I think from a stakeholder's perspective, I think it's very diverse. At least our experience would be that there isn't a single voice or a singular view on what we're seeing when we're out there getting things developed. I think there is a significant group of individuals that are welcoming of the development that's taking place in the sense of creating revenue streams for them and creating economic opportunities for people in those jurisdictions. I think of our operations in Southern Alberta and now even East Central Alberta. For sure, there's jobs that are being created and opportunity for some of the landowners to create revenue. I think folks that have concerns, they're legitimate concerns and we listen to them, and it has everything to do with impacts to birds and bird migration, bats to sightlines, candidly, in terms of being able to see.

Yes, I think I think from our stakeholders perspective.

I think it's very very diverse I don't think there is at least our experience would be that there isn't a single.

Voice or a singular view on on what we're seeing when we're out there getting things developed I think.

There is a significant group of individuals that are welcoming of the development, that's taking place in the sense of creating revenue streams for them.

And you know, creating economic opportunities for people in those jurisdictions I think of our operations in southern Alberta, and now even essential Alberta for sure. There is theres drops that are being created an opportunity for some of the land owners to create revenue I think folks that have concerns there legitimate concern.

And we listened to them and it has everything to do with impacts to birds at bird migration bass to sidelines candidly.

In terms of being able to see and we look at the beautiful part of the world. So.

John Kousinioris: We live in a beautiful part of the world, so being able to have that view that you've always had in an appropriate way, I think is a appropriate view, and people express it and it's our responsibility to hear that out. It does impact how we site things. It impacts where we site them. I can tell you, we take the reclamation obligations that we have when it's all done very seriously. We've actually-reclaimed the first wind farm that was built in Alberta, so we have a sense of what that's about and returning the land to the state that it was in. We also have, as you know, years and years, honestly, decades, of experience with mine reclamation. It is critically important that work is done, and it's done from people that are determined to do it in an appropriate way.

Being able to have that view that you've always had in an appropriate way I think is a appropriate view and people express it and it's our responsibility to hear that out it does impact how we cite things it impacts where we cite them and I can tell you we take the reclamation obligations that we.

Half when it's all done very very seriously.

We've actually <unk>.

Reclaimed the first wind farm that was built in Alberta. So we have a sense of what that's about and returning the land to the state that it was in.

We also have as you know years and years candidly shades of experience with mine reclamation. So it is critically important so that work is done and it's from people.

That are determined to do it in an appropriate way. So hopefully that gives you a bit of a flavor there isn't a singular.

John Kousinioris: Hopefully that gives you a bit of a flavor. There isn't a singular voice. It's everything from a spectrum of opportunity to concern about what happens at the end of the life of a wind farm, and everything in between.

Voice, it's everything from a spectrum of opportunity too concerned about what happens at the end of the life of a wind farm and everything in between.

Chris Varcoe: Just to ask you, what signal do you think the pause is sending to the industry? Will it impact your investment decisions, or do you think the industry's investment decisions, such as perhaps looking to other jurisdictions because of the pause?

And just asking what signal do you think the pause is sending to the industry will it impact your investment decisions or do you think the industry's investment decisions such as perhaps looking at other jurisdictions because of the pause.

John Kousinioris: Look, I think a lot of the companies that I think are in the vanguard of building out new generation in Alberta also have projects in other jurisdictions. They look at deploying capital in multiple places, and they are. I look at our company, we're in Canada, the US, and Australia, and the development environment and opportunity sets are relatively similar in all those jurisdictions. To a certain extent, you're agnostic about where you go. I think with respect to this pause that we're seeing to have the consultation done, it's six months. We take a long-term view in terms of our projects. There's still a lot of projects that are effectively grandfathered and are being built out, including ours, and we're committed to seeing those through.

Yes look.

I think a lot of b.

A lot of the companies that I think are in kind of a band guard building out new generation in Alberta also have projects in other jurisdictions. So so they look at.

Deploying capital in multiple places in the yard I look at our <unk>.

Company, where in Canada, the U S and in Australia and.

You know the development environment of opportunity sets are relatively similar in all those jurisdictions, so to a certain extent you're agnostic.

<unk> about where you go I think with respect to this.

Pause that we're seeing to have the consultation done it's up to six months we.

We take a long term view in terms of our projects Theres still a lot of projects that that are effectively grandfathered at are being built out including ours and.

We're committed to seeing those through.

John Kousinioris: I think we'll end up with a thoughtful response from the Alberta Utilities Commission and the government when the consultation process is done. I think we'll end up being better developers and builders of these assets as they go forward. I can only speak for our company, and not other companies, but we're staying the course and the projects that we would've been putting in the development or in the permitting queue imminently, we're continuing to work out on and develop with a view to seeing them being realized eventually in the longer term.

I think we'll end up with a.

Yeah.

We'll end up with.

I think a thoughtful response from the Alberta Utilities Commission and the government when the consultation process is done and I think it will.

We will end up being better developers and builders.

Of these assets. They go for it I mean, I can only speak for our company.

And on other companies, but it's we're staying the course that the projects that we would have been putting in the development or in the permitting Q sort of imminently.

We're continuing to work out and developed with a view to seeing them being realized eventually in the longer term.

Yes.

Chris Varcoe: Thank you.

Thank you.

Operator 1: Of course. Take care.

Operator 1: Ladies and gentlemen, as a reminder, should you have a question, please press star followed by the one.

Well ladies apparel.

Should you have a question. Please press star followed by the one.

Operator 1: There are no further questions at this time. Please proceed.

There are no further questions at this time. Please proceed.

Chiara Valentini: Thank you, everyone. That concludes our call for today. If you have any further questions, please don't hesitate to reach out to the TransAlta investor relations team later today or further on to next week. Thank you so much.

Thank you everyone that concludes our call for today. If you have any further questions. Please don't hesitate to reach out to the Transalta Investor Relations team later today or.

Next week. Thank you so much.

Operator 1: Ladies and gentlemen, this concludes your conference call for today. We thank you for participating and ask that you please disconnect your lines.

Ladies and gentlemen, this concludes your conference call for today, we thank you for participating in a say you. Please disconnect your lines.

Okay.

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Okay.

Yes.

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