Q1 2026 AltaGas Ltd Earnings Call

April 30, 2026

Operator: Good morning, ladies and gentlemen. Thank you for standing by. Welcome to the AltaGas Q1 2026 financial results call. My name is Julie, and I will be your operator for today's call. All lines have been placed on mute to prevent any background noise. If you have any difficulties during the conference, please press star then zero for operator assistance at any time. After the speaker's remarks, there will be a question-and-answer session. As a reminder, this conference call is being broadcast live on the Internet and recorded. I would now like to turn the conference over to Aaron Swanson, Vice President of Investor Relations. Please go ahead.

Speaker #2: All lines have been placed on mute to prevent any background noise. If you have any difficulties hearing the conference, please press R, then 0, for operator assistance at any time.

Speaker #2: After the speakers' remarks, there will be a question-and-answer session. As a reminder, this conference call is being broadcast live on the internet and recorded.

Speaker #2: I would now like to end the conference over to Aaron Swanson. Vice President and Customer Relations, please go ahead. Good morning, and thank you for joining AltaGas's first quarter 2026 results conference call.

Aaron Swanson: Good morning, thank you for joining AltaGas' Q1 2026 results conference call. This call is being webcast, and we encourage following along with the supporting slides that can be found on our website. Speakers this morning will be Vern Yu, President and Chief Executive Officer, and Sean Brown, Executive Vice President and Chief Financial Officer. We're also joined by Randy Toone, President of Midstream, Blue Jenkins, President of Utilities, and Jon Morrison, Senior Vice President of Corporate Development and Investor Relations. We will refer to forward-looking information on today's call. This information is subject to certain risks and uncertainties as outlined in the forward looking information disclosure on slide 2 in the presentation. Prepared remarks will be followed by a question-and-answer session. I will now turn the call over to Vern.

Aaron Swanson: Good morning, thank you for joining AltaGas's Q1 2026 results conference call. This call is being webcast, and we encourage following along with the supporting slides that can be found on our website. Speakers this morning will be Vern Yu, President and Chief Executive Officer, and Sean Brown, Executive Vice President and Chief Financial Officer. We're also joined by Randy Toone, President of Midstream, Blue Jenkins, President of Utilities, and Jon Morrison, Senior Vice President of Corporate Development and Investor Relations. We will refer to forward-looking information on today's call. This information is subject to certain risks and uncertainties as outlined in the forward looking information disclosure on slide 2 in the presentation. Prepared remarks will be followed by a question-and-answer session. I will now turn the call over to Vern.

Speaker #2: This call is being webcast, and we encourage following along with the supporting slides that can be found on our website. Speakers this morning will be Vernon Yu, President and Chief Executive Officer; and Sean Brown, Executive Vice President and Chief Financial Officer.

Speaker #2: We're also joined by Randy Toon, President of Midstream; Blue Jenkins; President of Utilities; and John Morrison, Senior Vice President of Corporate Development and Investor Relations.

Speaker #2: We will refer to forward-looking information on today's call. This information is subject to certain risks and uncertainties as outlined in the forward-looking information disclosure on slide 2 in the presentation.

Speaker #2: Prepared remarks will be followed by a question-and-answer session. I will now turn the call over to Vernon.

Speaker #3: Thanks, Aaron. Good morning. Thanks for joining our Q1 results conference call. I'm going to kick things off by reviewing highlights from the quarter. Including our strong financial and operating performance.

Vern Yu: Thanks, Aaron. Good morning. Thanks for joining our Q1 results conference call. I'm gonna kick things off by reviewing highlights from the quarter, including our strong financial and operating performance. I'll provide an update on our growth projects, review our backlog of organic growth opportunities, and I'll close by discussing the evolving global LPG market. After that, Sean will cover our financial results and provide an update on our 2026 outlook. Let's start on slide 4. We had record financial results in Q1, reflecting strong performance from both midstream and utilities, which benefited from constructive energy fundamentals. We delivered normalized EBITDA of CAD 818 million and normalized EPS of CAD 1.33. These results exceeded our expectations and put us in a very strong position for the balance of the year.

Speaker #3: Then I'll provide an update on our growth projects, review our backlog of organic growth opportunities, and I'll close by discussing the evolving global LPG market.

Speaker #3: After that, Sean will cover our financial results and provide an update on our 2026 outlook. Let's start on slide 4. We had record financial results in Q1.

Speaker #3: Reflecting strong performance from both Midstream and Utilities. Which benefited from constructive energy fundamentals. We delivered normalized EBITDA of $818 million. And normalized earnings per share of $1.33.

Speaker #3: These results exceeded our expectations and put us in a very strong position for the balance of the year. As a result, we are anticipating 2026 results to land at the top end of our guidance range.

Vern Yu: As a result, we are anticipating 2026 results to land at the top end of our guidance range, with the potential to exceed the upper end of the range if we continue to see strength in the LPG export market. Q1's financial performance improved our balance sheet, with leverage closing at 4.4 times, down from 4.7 times at year-end and slightly below our 4.5 to 5 times target range. Operationally, our export terminals average approximately 125,000 barrels per day. Midstream through book continues to see strong growth, with our Montney infrastructure realizing 14% year-over-year growth in volumes, which included a full quarter of volumes from Pipestone too. At our Utilities business, colder than normal weather supported customer demand. Heating degree days were 5% above normal in DC and 10% above last year's levels.

Speaker #3: With the potential to exceed the upper end of the range, if we continue to see strength in the LPG export market. Q1 financial performance improved our balance sheet.

Speaker #3: With leverage closing at 4.4 times, down from 4.7 times at year-end, and slightly below our 4.5 to 5 times target range. Operationally, our export terminals average approximately $125,000 per day.

Speaker #3: Midstream throughput continues to see strong growth. With our Montview infrastructure realizing 14% year-over-year growth in volumes, which included a full quarter of volumes from Pipestone too.

Speaker #3: At our utilities business, colder than normal weather supported customer demand. Heating degree days were 5% above normal in DC and 10% above last year's levels.

Speaker #3: We continued to advance several strategic initiatives. Including taking delivery of a new VLGC time tracker. Further extending our pipeline modernization programs and the execution of a second behind-the-meter data center connection agreement.

Vern Yu: We continue to advance several strategic initiatives, including taking delivery of a new VLGC time charter, further extending our pipeline modernization programs, and the execution of a second behind the meter data center connection agreement. Let's move to our growth projects, and we'll start with REEF on the last call. Construction on REEF Phase 1 and Optimization One continues to progress well. REEF Phase 1 is now roughly 75% complete with all major modules on-site. Placement of the two remaining jetty spans will be done shortly, and construction on the final phase of the railroad utility corridor is about to kick off. Notably, over 1.4 million hours have been worked on REEF without serious injury. The project currently has about 90% of its total capital costs incurred or committed, and 80% of these costs are under fixed-priced EPC contracts.

Speaker #3: Let's move to our growth projects and we'll start with refunds locked up. Construction on reef phase one and optimization one continues to progress well.

Speaker #3: Reef phase one is now roughly 75% complete with all major modules on site. Placement of the two remaining jetty spans will be stunned shortly and construction of the final phase of the railroad utility corridor is about to kick off.

Speaker #3: Notably, over 1.4 million hours have been worked on reef without serious injury. The project currently has about 90% of its total capital costs, incurred or committed, and 80% of these costs are under fixed-priced EPC contracts.

Speaker #3: Reef optimization one is in its early days of construction and we continue to expect completion in the second half of 2027. Optimization one is agreements and will add $30,000 per day of propane export capacity.

Vern Yu: REEF Optimization One is in its early days of construction, and we continue to expect completion in H2 2027. Optimization One is backed off by long-term commercial agreements and will add 30,000 barrels per day of propane export capacity. We also continue to advance engineering and costing for REEF Optimization Two, another brownfield expansion that will bring 60,000 barrels per day of incremental Canadian export capacity. We have now received all the permits we require to start construction. Slide 6 shows the recent progress that we've made at REEF. You can see we're nearing completion of the onshore construction for the facility, and jetty construction continues to progress on plan. At completion, REEF will nearly double AltaGas's global export capacity and will substantially increase Canadian trade exports to Asia. Slide 7 sets out our organic project backlog.

Speaker #3: We also continue to advance engineering and costing for reef optimization two, another brownfield expansion that will bring $60,000 per day of incremental Canadian export capacity.

Speaker #3: We have now received all the permits we require to start construction. Slide 6 shows the recent progress that we've made at Reef. You can see we're nearing completion of the onshore construction for the facility.

Speaker #3: And jetty construction continues to progress on plan. At completion, reef will nearly double AltaGas's global export capacity. And will substantially increase Canadian trade exports to Asia.

Speaker #3: Slide 7 sets out our organic project backlog. Utilities modernization, customer adds, data centers, and large volume commercial opportunities in Utilities. Global export, extraction and fractionation expansions, gas storage, and gathering and processing projects in Midstream.

Vern Yu: Utilities modernization, customer adds, data centers, and large volume commercial opportunities in utilities. Global export, extraction and fractionation expansions, gas storage, and gathering and processing projects in midstream. Slide 8 highlights our system modernization runway. Across DC, Maryland, Virginia, and Michigan, we have more than 5,000 miles of pre-1970s pipe that needs to be replaced to enhance safety and reliability. This pipe replacement gives us decades of system modernization investment opportunities. To facilitate that, we have $1.5 billion US modernization programs that have been approved by regulators across our four jurisdictions. Modernization capital and normal course customer adds allow us to grow rate base at an average of 8% per year while improving the safety and reliability of our system. Each mile we replace reduces the risk of leaks, service disruptions, operating costs, and safety incidents for the communities we serve.

Speaker #3: Slide 8 highlights our system modernization runway. Across DC, Maryland, Virginia, and Michigan. We have more than 5,000 miles of pre-1970s pipe that needs to be replaced to enhance safety and reliability.

Speaker #3: This pipe replacement gives us decades of system modernization investment opportunities. To facilitate that, we have 1.5 billion US modernization programs that have been approved by regulators across our four jurisdictions.

Speaker #3: Modernization capital and normal-course customer adds allow us to grow rate-based at an average of 8% per year, while improving the safety and reliability of our system.

Speaker #3: Each mile we replace reduces the risk of leaks, service disruptions, operating costs, and safety incidents for the communities we serve. We show our robust investment capacity on slide 9.

Vern Yu: We show our robust investment capacity on slide 9. This allows us to invest CAD 5 billion over the next 3 years while remaining within our target credit metrics, and CAD 3.5 billion of that will be allocated to organic growth. These investments support our long-term earnings and dividend growth outlook of 5% to 7% per year. With that growth being backed off by low risk cost of service for take or pay cash flows. Let's move to slide 10, where we shift to the global LPG market. The disruption to Middle East supply is expected to have lasting impacts. At its peak, 1.3 million barrels per day of LPG supply was offline with the closure of the Strait of Hormuz. This has doubled spot propane spreads from pre-conflict levels.

Speaker #3: This allows us to invest $5 billion over the next three years, while remaining within our target credit metrics. And 3.5 billion of that will be allocated to organic growth.

Speaker #3: These investments support our long-term earnings and dividend growth outlook of 5 to 7 percent per year. With that growth being backed off by low-risk, cost-of-service or take or pay cash flows.

Speaker #3: Let's move to slide 10, where we shift to the global LPG market. The disruption to Middle East supply is expected to have lasting impacts.

Speaker #3: At its peak, 1.3 million barrels per day of LPG supply was offline, with the closure of the Strait of Hormuz. This has doubled spot propane spreads from pre-conflict levels.

Speaker #3: Based on the damage to key Middle East LPG export infrastructure, a significant portion of this production could be offline for an extended period of time.

Vern Yu: Based on the damage to key Middle East LPG export infrastructure, a significant portion of this production could be offline for an extended period of time. This supply disruption has driven more conversations with our Asian customers, who are now placing increased value on energy security, which highlights Canada as one of the most reliable sources of global LPG supply. A great example is what we are seeing in China, where Canada's share of China's total propane imports has grown from zero to over 11% in the past year. The initial shift happened after US tariffs were implemented as Canadian LPG replaced US LPG supply. Demand for Canadian LPG in China was accelerated with the Middle Eastern supply disruption. Turning to slide 11, we highlight some of the shifting trade dynamics for LPGs across Asia.

Speaker #3: The supply disruption has driven more conversations with our Asian customers. Who are now placing increased value on energy security. Which highlights Canada as one of the most reliable sources of global LPG supply.

Speaker #3: A great example is what we are seeing in China. Where Canada's share of China's total propane imports has grown from zero to over 11% in the past year.

Speaker #3: The initial shift happened after US tariffs were implemented. As Canadian LPG replaced US LPG supply. Demand for Canadian LPG in China was then accelerated, with the Middle Eastern supply disruption.

Speaker #3: Turning to slide 11, we highlight some of the shifting trade dynamics for LPGs across Asia. Overall, we're seeing strong demand across our traditional Asian markets, including China, South Korea, and Japan.

Vern Yu: Overall, we're seeing strong demand across our traditional Asian markets, including China, South Korea, and Japan, where AltaGas represented approximately 6% of Canada's total national trade value in Q1. Since the onset of the conflict in Iran, we've seen incremental demand from markets that have historically relied on Middle Eastern supply. This includes multiple countries in Southeast Asia. In fact, we've recently delivered our first cargo into Indonesia. We're also advancing discussions in South Asia, where customers are looking for long-term supply diversification opportunities. This growing and diversified demand for Canadian LPGs reinforces the value of AltaGas's global export platform. Finally, turning to slide 12, we reiterate our strategic priorities. We remain focused on growing, de-risking, and strengthening the enterprise. We have materially advanced our key growth projects, and we've added several high-quality projects to our growth backlog that enhances our long-term outlook.

Speaker #3: Where AltaGas represented approximately 6% of Canada's total national trade value in Q1. Since the onset of the conflict in Iran, we've seen incremental demand from markets at a historically relied on Middle Eastern supply.

Speaker #3: This includes multiple countries in Southeast Asia. In fact, we've recently delivered our first cargo into Indonesia. We're also advancing discussions in South Asia, where customers are looking for long-term supply diversification opportunities.

Speaker #3: This growing and diversified demand for Canadian LPGs reinforces the value of AltaGas's global export platform. Finally, turning to slide 12, we reiterate our strategic priorities.

Speaker #3: We remain focused on growing, de-risking, and strengthening the enterprise. We have materially advanced our key growth projects, and we've added several high-quality projects to our growth backlog that enhances our long-term outlook.

Speaker #3: I'll now turn it over to Sean to walk through our financial results. Thanks, Vern. And good morning, everyone. As Vern noted at fantastic quarter and a very strong start to the year, with consolidated normalized EBITDA of $818 million, a 19% increase from last year, and a new quarterly record for the company.

Vern Yu: I'll now turn it over to Sean to walk through our financial results.

Sean Brown: Thanks, Vern, good morning, everyone. As Vern noted, a fantastic quarter and a very strong start to the year with consolidated normalized EBITDA of CAD 818 million, a 19% increase from last year and a new quarterly record for the company. For today's call, I'll start by providing a detailed review of performance across our Utilities and Midstream segments, touch on the strength of our balance sheet, and finish with our 2026 outlook. Turning to slide 13, the Utility segment delivered normalized EBITDA of CAD 555 million, an 11% increase year-over-year. These strong results were driven by incremental revenue from positive rate case outcomes in DC and new interim rates in Virginia, as well as continued modernization investments and stronger asset optimization, the benefits of which we share with our customers.

Speaker #3: For today's call, I'll start by providing a detailed review of performance across our utilities in midstream segments, touch on the strength of our balance sheet, and finish with our 2026 outlook.

Speaker #3: Turn to slide 13. The Utility segment delivered normalized EBITDA of $555 million, an 11% increase year over year. These strong results were driven by incremental revenue from positive rate case outcomes in D.C. and new interim rates in Virginia.

Speaker #3: As well as continued modernization investments and stronger asset optimization. The benefits of which we share with our customers. The segment also benefited from a $35 million gain on the partial settlement of WGL's post-retirement pension plan.

Robert Catellier: The segment also benefited from a CAD 35 million gain on the partial settlement of WGL's post-retirement pension plan. These results were partially offset by lower retail performance and higher G&A expenses, with the latter related to employee incentive plans linked to our share price. During the quarter, we deployed CAD 146 million of capital in the utility segment, including CAD 56 million towards modernization programs and CAD 23 million on new growth initiatives. These investments are focused on delivering long-term safety and reliability while extending our network to serve our expanding customer base. Capital spending plans in the quarter were partially curtailed by cold weather, limiting construction activity, which we expect will catch up as the year progresses. In the quarter, we signed our second data center connection agreement to provide natural gas for backup power generation to an existing 15MW data center in Virginia.

Sean Brown: The segment also benefited from a CAD 35 million gain on the partial settlement of WGL's post-retirement pension plan. These results were partially offset by lower retail performance and higher G&A expenses, with the latter related to employee incentive plans linked to our share price. During the quarter, we deployed CAD 146 million of capital in the utility segment, including CAD 56 million towards modernization programs and CAD 23 million on new growth initiatives. These investments are focused on delivering long-term safety and reliability while extending our network to serve our expanding customer base. Capital spending plans in the quarter were partially curtailed by cold weather, limiting construction activity, which we expect will catch up as the year progresses. In the quarter, we signed our second data center connection agreement to provide natural gas for backup power generation to an existing 15MW data center in Virginia.

Speaker #3: These results were partially offset by lower retail performance and higher G&A expenses, with the latter related to employee incentive plans linked to our share price.

Speaker #3: During the quarter, we deployed $146 million of capital in the utility segment, including $56 million towards modernization programs, and $23 million on new growth initiatives.

Speaker #3: These investments are focused on delivering long-term safety and reliability while extending our network to serve our expanding customer base. Capital spending plans in the quarter were partially curtailed by cold weather.

Speaker #3: Limiting construction activity, which we expect will catch up as the year progresses. In the quarter, we signed our second data center connection agreement to provide natural gas for backup power generation to an existing 15-megawatt data center in Virginia.

Speaker #3: Both of our announced data center projects have the potential for larger follow-on phases and we continue to advance various opportunities across all of our jurisdictions.

Robert Catellier: Both of our announced data center projects have the potential for larger follow-on phases, and we continue to advance various opportunities across all of our jurisdictions. Turning to slide 14, we highlight our ongoing regulatory initiatives with active rate cases in Maryland, Virginia, and Michigan. During the quarter, we filed a rate case in Michigan seeking $61 million in incremental revenue, a 10.75% allowed ROE, and a weather normalization adjustment mechanism consistent with our de-risking priority. In connection with the Michigan rate case, we also filed a 5-year $284 million modernization program extension. We continue to engage constructively with regulators and other stakeholders with a focus on balancing customer affordability with the safe and reliable delivery of service.

Sean Brown: Both of our announced data center projects have the potential for larger follow-on phases, and we continue to advance various opportunities across all of our jurisdictions. Turning to slide 14, we highlight our ongoing regulatory initiatives with active rate cases in Maryland, Virginia, and Michigan. During the quarter, we filed a rate case in Michigan seeking $61 million in incremental revenue, a 10.75% allowed ROE, and a weather normalization adjustment mechanism consistent with our de-risking priority. In connection with the Michigan rate case, we also filed a 5-year $284 million modernization program extension. We continue to engage constructively with regulators and other stakeholders with a focus on balancing customer affordability with the safe and reliable delivery of service.

Speaker #3: Turning to slide 14, we highlight our ongoing regulatory initiatives. With active rate cases in Maryland, Virginia, and Michigan. During the quarter, we filed a rate case in Michigan, seeking US $61 million in incremental revenue, a $10.75% allowed ROE, and a weather normalization adjustment mechanism consistent with our de-risking priority.

Speaker #3: In connection with the Michigan rate case, we also filed a five-year US $284 million modernization program extension. We continue to engage constructively with regulators and other stakeholders with a focus on balancing customer affordability with the safe and reliable delivery of service.

Speaker #3: Turning to slide 15, midstream delivered $273 million of normalized EBITDA up 39% year over year and above our expectations entering the quarter. The segment's outperformance was primarily driven by our exports platform.

Robert Catellier: Turning to slide 15, Midstream delivered CAD 273 million of normalized EBITDA, up 39% year-over-year and above our expectations entering the quarter. The segment's outperformance was primarily driven by our exports platform, which grew volumes and delivered strong merchant margins. During the quarter, we exported nearly 125,000 barrels a day of LPGs across 20 VLGCs at our Ripon and Ferndale terminals, with volumes up 5% year-over-year. We had 14 ships leave from Ripon, including one that shifted into Q1 from late 2025. Thanks to continued operational and logistical execution, we exported over 88,000 barrels per day from Ripon during the quarter, a new record for this facility. Utilization across our gas processing, fractionation, and extraction assets was strong, with throughput up 9% year-over-year.

Sean Brown: Turning to slide 15, Midstream delivered CAD 273 million of normalized EBITDA, up 39% year-over-year and above our expectations entering the quarter. The segment's outperformance was primarily driven by our exports platform, which grew volumes and delivered strong merchant margins. During the quarter, we exported nearly 125,000 barrels a day of LPGs across 20 VLGCs at our Ripon and Ferndale terminals, with volumes up 5% year-over-year. We had 14 ships leave from Ripon, including one that shifted into Q1 from late 2025. Thanks to continued operational and logistical execution, we exported over 88,000 barrels per day from Ripon during the quarter, a new record for this facility. Utilization across our gas processing, fractionation, and extraction assets was strong, with throughput up 9% year-over-year.

Speaker #3: Which grew volumes and delivered strong merchant margins. During the quarter, we exported nearly 125,000 barrels a day of LPGs across 20 VLGCs at our Ridley and Ferndale terminals.

Speaker #3: With volumes up 5% year over year. We had 14 shifts leave from Rivet, including one that shifted into the first quarter from late 2025.

Speaker #3: Thanks to continued operational and logistical execution, we exported over $88,000 barrels per day from Rivet during the quarter. A new record for this facility.

Speaker #3: Utilization across our gas processing fractionation and extraction assets was strong. With throughput up 9% year over year. This volume growth was led by our strong Motley footprint, where our strategically located assets provide a strong advantage to capture basin growth, driven by producers targeting liquids-rich formations across Western Canada.

Robert Catellier: This volume growth was led by our strong Montney footprint, where our strategically located assets provide a strong advantage to capture basin growth, driven by producers targeting liquids-rich formations across Western Canada. The quarter also included the first full quarter of operations at Pipestone Two, which continues to perform well and is adding critical gas processing and liquids handling capacity in the Alberta Montney. Looking ahead, we are well hedged but have some positive upside price exposure with approximately 82% of expected remaining 2026 global export volumes either tolled or financially hedged, with an average FEI to North America spread of approximately $20 per barrel on non-tolled volumes, while 18% of remaining volumes have open market pricing. Despite the FEI curve remaining heavily backwardated, we are starting to see the back end move higher as the Middle East conflict continues.

Sean Brown: This volume growth was led by our strong Montney footprint, where our strategically located assets provide a strong advantage to capture basin growth, driven by producers targeting liquids-rich formations across Western Canada. The quarter also included the first full quarter of operations at Pipestone Two, which continues to perform well and is adding critical gas processing and liquids handling capacity in the Alberta Montney. Looking ahead, we are well hedged but have some positive upside price exposure with approximately 82% of expected remaining 2026 global export volumes either tolled or financially hedged, with an average FEI to North America spread of approximately $20 per barrel on non-tolled volumes, while 18% of remaining volumes have open market pricing. Despite the FEI curve remaining heavily backwardated, we are starting to see the back end move higher as the Middle East conflict continues.

Speaker #3: The quarter also included the first full quarter of operations at Pipestone 2. Which continues to perform well and is adding critical gas processing and liquids handling capacity in the Alberta Motley.

Speaker #3: Looking ahead, we are well hedged, but have some positive upside price exposure with approximately $82% of expected remaining 2026 global export volumes either tolled or financially hedged.

Speaker #3: With an average FDI to North America spread of approximately $20 per barrel on non-tolled volumes, while 18% of remaining volumes have open market pricing.

Speaker #3: Despite the FDI curve remaining heavily backwardated, we are starting to see the backend move higher as the Middle East conflict continues. In addition, our entire 2026 Baltic Freight exposure is hedged through a combination of time charters, financial instruments, and tolling arrangements.

Robert Catellier: In addition, our entire 2026 Baltic trade exposure is hedged through a combination of time charters, financial instruments, and tolling arrangements. We also continue to manage frac spread exposure through our disciplined risk management program. Finishing up the discussion on our results, performance in the corporate and other segment was consistent with the prior year, with Blythe being relatively stable. Turning to slide 16, as Vern mentioned, we are highlighting that we now expect to be towards the top end of our 2026 guidance range, with the potential to exceed the upper end on continued strength in the LPG export market. This is driven by a strong Q1 in both the midstream and utility segments and what we have been seeing in our export business through April.

Sean Brown: In addition, our entire 2026 Baltic trade exposure is hedged through a combination of time charters, financial instruments, and tolling arrangements. We also continue to manage frac spread exposure through our disciplined risk management program. Finishing up the discussion on our results, performance in the corporate and other segment was consistent with the prior year, with Blythe being relatively stable. Turning to slide 16, as Vern mentioned, we are highlighting that we now expect to be towards the top end of our 2026 guidance range, with the potential to exceed the upper end on continued strength in the LPG export market. This is driven by a strong Q1 in both the midstream and utility segments and what we have been seeing in our export business through April.

Speaker #3: We also continue to manage frac spread exposure through our disciplined risk management program. Finishing up the discussion on our results, performance in the corporate and other segment was consistent with the prior year with Blythe being relatively stable.

Speaker #3: Turning to slide 16, as Vern mentioned, we are highlighting that we now expect to be towards the top end of our 2026 guidance range.

Speaker #3: With the potential to exceed the upper end on continued strength in the LPG export market. This is driven by a strong first quarter in both the midstream and utility segments, and what we have been seeing in our export business through April.

Speaker #3: Given the outperformance is more weighted to our midstream business, we have adjusted our expected EBITDA ranges for the year with midstream expected to contribute $44 to $48% of normalized EBITDA up from $42 to $46% previously.

Robert Catellier: Given the outperformance is more weighted to our Midstream business, we have adjusted our expected EBITDA ranges for the year, with Midstream expected to contribute 44% to 48% of normalized EBITDA, up from 42% to 46% previously. As noted, if LPG export spreads continue to stay elevated, there's potential for us to exceed the top end of the current guidance range, and we expect to update the market on this with our Q2 results at the end of July. As shown on slide 17, we've increased our 2026 capital budget to CAD 1.7 billion from CAD 1.6 billion. This increase is driven primarily by the sanctioning of Dimsdale Phase II during the quarter and improved visibility in key vendor milestone payments on project work.

Sean Brown: Given the outperformance is more weighted to our Midstream business, we have adjusted our expected EBITDA ranges for the year, with Midstream expected to contribute 44% to 48% of normalized EBITDA, up from 42% to 46% previously. As noted, if LPG export spreads continue to stay elevated, there's potential for us to exceed the top end of the current guidance range, and we expect to update the market on this with our Q2 results at the end of July. As shown on slide 17, we've increased our 2026 capital budget to CAD 1.7 billion from CAD 1.6 billion. This increase is driven primarily by the sanctioning of Dimsdale Phase II during the quarter and improved visibility in key vendor milestone payments on project work.

Speaker #3: As noted, if LPG export spreads continue to stay elevated, there is potential for us to exceed the top end of the current guidance range, and we expect to update the market on this with our Q2 results at the end of July.

Speaker #3: As shown on slide 17, we have increased our 2026 capital budget to $1.7 billion from $1.6 billion. This increase is driven primarily by the sanctioning of Dinsdale 2 during the quarter, and improved visibility in key vendor milestone payments on project work.

Speaker #3: As a reminder, the utilities capital is focused on modernization and system betterment to support safety, reliability, and network efficiency, and is expected to drive approximately a 10% year-over-year growth in rate base while the midstream capital is largely allocated to advancing REIT and the Dinsdale projects.

Robert Catellier: As a reminder, the Utilities capital is focused on modernization and system betterment to support safety, reliability, and network efficiency and is expected to drive approximately a 10% year-over-year growth in rate base, while the Midstream capital is largely allocated to advancing REEF and the Dimsdale projects. With the increase in capital coming from the Midstream segment, we now expect to allocate 31% of capital to Midstream and 65% of capital to Utilities, with the balance allocated to the Corporate segment. Let's now turn to our balance sheet on slide 18. We exited the quarter with a trailing twelve-month adjusted net debt to normalized EBITDA ratio of 4.4 times, modestly below our target range due to higher than expected EBITDA and our Q1 capital program being slightly below expectations due to cold weather limiting activity early in the year.

Sean Brown: As a reminder, the Utilities capital is focused on modernization and system betterment to support safety, reliability, and network efficiency and is expected to drive approximately a 10% year-over-year growth in rate base, while the Midstream capital is largely allocated to advancing REEF and the Dimsdale projects. With the increase in capital coming from the Midstream segment, we now expect to allocate 31% of capital to Midstream and 65% of capital to Utilities, with the balance allocated to the Corporate segment. Let's now turn to our balance sheet on slide 18. We exited the quarter with a trailing twelve-month adjusted net debt to normalized EBITDA ratio of 4.4 times, modestly below our target range due to higher than expected EBITDA and our Q1 capital program being slightly below expectations due to cold weather limiting activity early in the year.

Speaker #3: With the increase in capital coming from the midstream segment, we now expect to allocate 31% of capital to midstream and 65% of capital to utilities, with the balance allocated to the corporate segment.

Speaker #3: Let's now turn to our balance sheet on slide 18. We exited the quarter with a trailing 12-month adjusted net debt to normalized EBITDA ratio of 4.4 times.

Speaker #3: Modestly below our target range, due to higher than expected EBITDA and our first quarter capital program being slightly below expectations due to cold weather limiting activity early in the year.

Speaker #3: With the increase in our 2026 capital program, and taking into account the seasonality of our business, we would expect our leverage metric to be within our 4.5 to 5 times range when we exit 2026.

Robert Catellier: With the increase in our 2026 capital program and taking into account the seasonality of our business, we would expect our leverage metric to be within our 4.5 to 5 times range when we exit 2026. On slide 19, we highlight AltaGas' established history of delivering per share growth across our earnings, EBITDA, and dividends, which has resulted in significant outperformance in share price. Lastly, on slide 20, we highlight our attractive value proposition. Our low-risk infrastructure platform supports stable, growing earnings and cash flows underpinned by disciplined capital allocation and a robust organic growth pipeline. With that, I'll turn it back to the operator for the Q&A session.

Sean Brown: With the increase in our 2026 capital program and taking into account the seasonality of our business, we would expect our leverage metric to be within our 4.5 to 5 times range when we exit 2026. On slide 19, we highlight AltaGas' established history of delivering per share growth across our earnings, EBITDA, and dividends, which has resulted in significant outperformance in share price. Lastly, on slide 20, we highlight our attractive value proposition. Our low-risk infrastructure platform supports stable, growing earnings and cash flows underpinned by disciplined capital allocation and a robust organic growth pipeline. With that, I'll turn it back to the operator for the Q&A session.

Speaker #3: On slide 19, we highlight AltaGas's established history of delivering per share growth across our earnings, EBITDA, and dividends. Which has resulted in significant outperformance in share price.

Speaker #3: Lastly, on slide 20, we highlight our attractive value proposition. Our low-risk infrastructure platform supports stable growing earnings and cash flows underpinned by disciplined capital allocation and a robust organic growth pipeline.

Speaker #3: With that, I'll turn it back to the operator for the Q&A session.

Speaker #1: Thank you, ladies and gentlemen. We'll now conduct the analyst question and answer session. If you'd like to ask a question, press star, then the number one on your telephone keypad.

Operator: Thank you. Ladies and gentlemen, we will now conduct the analyst question-and-answer session. Your first question comes from Robert Catellier from CIBC Capital Markets. Please go ahead.

Speaker #1: If you'd like to withdraw your question, please press star two. One moment, please, while we compile the Q&A roster. And your first question comes from Robert Catelier from CIBC Capital Markets.

Speaker #1: Please go ahead.

Speaker #2: Hey, good morning, everyone. Just a couple of questions on the state of the LPG market. I was just curious what your experiencing in terms of capturing premium pricing to spot prices and separately versus the forward curve and happy to see the one fall profits, but obviously we're more interested in seeing what the path is to future expansions given the increased demand that you outlined.

Robert Catellier: Hey, good morning, everyone. Just a couple of questions on the state of the LPG market. Just curious what you're experiencing in terms of capturing premium pricing to, you know, spot prices and separately, versus the forward curve. Happy to see the windfall profits, but obviously we're more interested in seeing what the path is to future expansions given the increased demand that you outlined.

Robert Catellier: Happy to see the windfall profits, but obviously we're more interested in seeing what the path is to future expansions given the increased demand that you outlined.

Speaker #3: Good morning, Rob. Those are great questions. I think maybe just starting on the first one. What we're seeing in the physical market is similar to what you're seeing in the oil markets where the paper markets don't actually reflect pricing that you're seeing.

Vern Yu: Good morning, Rob. Those are great questions. I think maybe just starting on the first one. What we're seeing in the physical market is similar to what you're seeing in the oil markets, where the paper markets don't actually reflect pricing that you're seeing physically. I think in Q1, we were seeing physical sales trade at a significant premium to FEI, when historically those physical sales would trade roughly at a, at a very small premium or discount to FEI. Because of the lack of supply, you're seeing physical transactions. The pricing on physical transactions does not capture what's on the screen. On the forward market, obviously the curves moved up. It's obviously also highly backwardated. We continue to expect that backwardation will continue, but prices should remain high.

Speaker #3: Physically. So I think in the first quarter, we were seeing physical sales trade at a significant premium to FEI. When historically those physical sales would trade roughly at a very small premium or discount to FEI.

Speaker #3: So because of the lack of supply you've seen physical transactions, the pricing on physical transactions is not captured what's on the screen. On the forward market, obviously the curves moved up.

Speaker #3: It's obviously also highly backwardated. We continue to expect that that backwardation will continue, but prices should remain high. As of right now, you're not seeing any LPG move through the straight.

Vern Yu: As of right now, you're not seeing any LPG move through the straits, so the lack of supply is gonna get more and more acute as we move forward here. Finally on your, on your last question, I think all of this turmoil in the Middle East really highlights the value of secure and stable supply. Obviously, Canada has a big role to play in that, and we are very happy to note that we were able to get all of the construction permits we need for REEF Op-Two. We're progressing our capital cost estimate and commercial conversations are more tolling there, so we expect to push that forward sometime later this year. We're also working on seeing if we can do subsequent phases of REEF.

Speaker #3: So the lack of supply is going to get more and more acute as we move forward here. And then finally on your last question, I think all of this turmoil in the Middle East really highlights the value of secure and stable supply.

Speaker #3: Obviously Canada has a big role to play in that. And we are very happy to note that we were able to get all of the construction permits we need for Reef Opti 2.

Speaker #3: We're progressing our capital cost estimate and commercial conversations on more tolling there, so we expect to push that forward sometime later this year. And we're also working on seeing if we can do subsequent phases of Reef, and the most advanced one that we're working on there is working on the potential to export ethane out of Reef, but that's got a longer gestation period.

Vern Yu: The most advanced one that we're working on there is working on the potential, to export ethane out of REEF, but that's got a longer gestation period. I think we covered all your questions there, Rob.

Speaker #3: So I think we covered all your questions there, Rob.

Speaker #2: Yeah, that was very, very helpful. And then I just wondered if you could walk through your current outlook on the Motney and production outlook given currently elevated commodity pricing.

Robert Catellier: Yeah, that was very, very helpful. Then, I just wondered if you could walk through your current outlook on the Montney and production outlook given you know, currently elevated commodity pricing, the enhanced customer need for energy security and the recent Shell acquisition of ARC?

Speaker #2: The enhanced customer need for energy security and the recent shell acquisition of Arc.

Speaker #4: Hey, Rob. It's Randy Kuhn. Yeah, we're seeing a lot of activity in the Montney, and you can see even with Shell coming back into Canada quite significantly with the ARC acquisition.

Randy Toone: Hey, Rob, it's Randy Toone. We're seeing a lot of activity in the Montney. You can see even with Shell coming back in, into Canada quite significantly with the ARC acquisition, you can see that they really believe in the Montney. We really think that with this acquisition, LNG 2, Phase 2 is likely to go ahead by the end of the year. Again, that's just gonna enhance more Montney's drilling. With that, we'll just receive more LPG production coming with that. It really helps support our export position.

Speaker #4: You can see that they really believe in the Montney. We really think that with this acquisition, LNG 2 Phase 2 is likely to go ahead by the end of the year.

Speaker #4: And again, that's just going to enhance more Montney drilling, and with that, we'll see just more LPG production coming with that. So it really helps support our export position.

Speaker #2: Okay. Thanks, everyone.

Robert Catellier: Okay. Thanks, everyone.

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

Speaker #1: Your next question comes from Rob Hope from Scotiabank. Please go ahead.

Speaker #2: Yeah. Morning, everyone. I want to take a look at the volumes for Q1 out of Rippett. 89,000 barrels a day is above nameplate. Acknowledging that one ship did kind of drift from Q4 to Q1, can you speak to kind of what you think that facility could do in the near term if producers are willing to, we'll call it expedite supply to the West Coast?

Robert Hope: Morning, everyone. Wanted to take a look at the volumes for Q1 out of RIPET. 89,000 barrels a day is above nameplate. You know, acknowledging that one ship did kinda drift from Q4 into Q1, you know, can you speak to kind of what you think that facility could do in the near term if producers are willing to, we'll call it, expedite supply to the West Coast?

Speaker #4: Hi, it's Randy again. Our stability move products through Rippet is really highly dependent on our service agreement we have with the terminal operator. And right now we have the ability to do 85,000 barrels a day on average through the year.

Randy Toone: Hi, it's Randy again. You know, our current ability to move products through RIPET is really highly dependent on our service agreement we have with the terminal operator. Right now we have the ability to do 85,000 barrels a day on average through the year. You know, that's our goal is to do that at that average. We actually had a really good Q1, and we expect that to continue through the rest of the year. Our capacity there is 85,000 barrels a day.

Speaker #4: And so that's our goal is to do that average. And so we actually had a really good Q1 and we expect that to continue through the rest of the year.

Speaker #4: But our capacity there is 85,000 barrels a day.

Speaker #2: Yeah. Remember, Rob, in Q1 we had one vessel that was scheduled to be loaded in 2025 that slipped in the first couple of days of 2026.

Vern Yu: Yeah. Remember, Rob, in Q1, we had 1 vessel that was scheduled to be loaded in 2025 that slipped in the first couple days of 2026. That's why you're seeing us above that 85,000 barrels a day.

Speaker #2: So that's why you're seeing us above that 85,000 barrels a day. All right. Appreciate that. And then maybe just thinking about risk mitigation and the hedging for the global offshore business for the rest of the year.

Robert Hope: All right. Appreciate that. Then maybe just thinking about risk mitigation and the hedging for the global offshore business for the rest of the year. You know, you've locked in a good Q1, you're fairly well hedged for the rest of the year. You know, if we take a look out to Q4, you're 73% hedged and tolled now. You know, are you willing to leave a little bit more open just given how backwardated the curve is? Also just given the premiums in the physical market relative to the paper market.

Speaker #2: You've locked in a good Q1. You're fairly well hedged for the rest of the year. If we take a look out to Q4, you're 73% hedged and told now.

Speaker #2: Are you willing to leave a little bit more open, just given how backwardated the curve is? And also, just given the premiums and the physical market relative to the paper market?

Speaker #3: Rob, we're going to follow our normal course hedging strategy. And you'll see our hedge percentages move up as we move through the year. Sean, do you want to add any more to that?

Vern Yu: Rob, we're gonna follow our normal course hedging strategy, and you'll see our hedge percentages move up as we move through the year. Sean, do you wanna add any more to that?

Speaker #5: No, I think you know that we're right in our hedge policy or our hedge strategy of 80%, which does leave some exposure as they move through the year, but we'll continue to take that off as we move forward.

Sean Brown: No. I think you know that we're right in our hedge policy or our hedge strategy of 80%, which does leave some exposure as we move through the year. We'll continue to take that off as we move forward. As we talked about in our prepared remarks, the curve remains heavily backwardated. Having that 18% overall exposed, you know, should benefit us as we continue to progress here.

Speaker #5: And as we talked about in our prepared remarks, the curve remains heavily backwardated. So having that 18% overall exposed should benefit us as we continue to progress here.

Speaker #2: All right. Excellent. Thank you.

Robert Hope: All right. Excellent. Thank you.

Operator: Your next question comes from Patrick Kenny from National Bank Capital Markets. Please go ahead.

Speaker #1: Your next question comes from Patrick Kenny from National Bank Capital Markets. Please go ahead.

Speaker #6: Thank you. Hey guys, maybe just following up on that hedging question there, but more on the tolling front. I guess just given the rising customer demand and wider spreads, even a little bit longer term, just wondering how these recent global events have changed your tolling strategy, if at all, especially as it relates to contract duration.

Patrick Kenny: Thank you. Hey, guys, maybe just following up on that hedging question there, but more on the tolling front. I guess, you know, just given the rising customer demand and wider spreads even, a little bit longer term, just wondering how these, you know, recent global events have changed your tolling strategy, if at all, especially as it relates to contract duration. Maybe you can speak to where you're at with securing any additional time charters that might be needed to, say, maximize value for the next wave of tolling agreements related to Optimization Two.

Speaker #6: And maybe you can speak to where you're at with securing any additional time charters that might be needed to, say, maximize value for the next wave of tolling agreements related to optimization too?

Vern Yu: Thanks, Pat. Just as a quick reminder, we're about 60% to 65% tolled, starting next year when the 2027 NGL year kicks in. That's for obviously Ripon, Ferndale, REEF, and REEF Optimization One. I think we're bang on our objective of increasing the durability and stability of our cash flows. We're going to be out in the marketplace for REEF Optimization Two fairly shortly once we've got our capital costs nailed down. We're going to continue to target to have our total export book in that 60% to 65% range tolled. Obviously the strength of the global markets will be a tailwind when we have conversations with our customers.

Speaker #5: Thanks, Pat. So just as a quick reminder, we're about 60, 65 percent tolled starting next year when the 2027 NGL year kicks in. So that's for obviously Rippett, Ferndale, Reef, and optimization one.

Speaker #5: So, I think we're bang on our objective of increasing the durability and stability of our cash flows. So we're going to be out in the marketplace for Opti 2 fairly shortly, once we've got our capital costs nailed down.

Speaker #5: And we're going to continue to target having our total export book in that 60 to 65 percent range tolled. And obviously, the strength of the global markets will be a tailwind when we have conversations with our customers.

Speaker #5: So we're very positive leaning on the fact that we should be able to both increase the amount of tolling we have and the term of those tolling contracts.

Vern Yu: We're very positive leaning on the fact that we should be able to both increase the amount of tolling we have and the term of those tolling contracts. That's bang on. Sorry, what was the other part of the question, Pat?

Speaker #5: So that's bang on. Sorry, what was the other part of the question, Pat? Oh, yeah, sorry. The time charter. Obviously, we took another time charter this quarter.

Patrick Kenny: Time charter.

Vern Yu: Oh, yeah. Sorry. The time charter. Obviously, we took another time charter this quarter. We're gonna get another time charter later this year. That really covers off all of our merchant barrels. As we move forward, we're looking at potentially adding another one, contracting another one later this year. More to come on that.

Speaker #5: We're going to get another time charter later this year. That really covers off all of our merchant barrels. And as we move forward, we're looking at potentially adding another one later contracting another one later this year.

Speaker #5: So more to come on that.

Speaker #6: Okay. Perfect. Thanks for that, Color. And then I guess we're in with the balance sheet where you want it, sort of below the low end of your target range.

Patrick Kenny: Okay. Perfect. Thanks for that color. I guess we're in with, you know, the balance sheet where you want it, sort of below the low end of your target range. You know, starting to build some dry powder, especially if you do come in above the top end of your guidance. Can you speak to, you know, what types of midstream assets might not be in your organic backlog but, you know, might be attractive from a M&A tuck-in perspective just to, you know, help round out your value chain from wellhead to tidewater?

Speaker #6: Starting to build some dry powder, especially if you do come in above the top end of your guidance. Can you speak to what types of midstream assets might not be in your organic backlog, but might be attractive from M&A, tuck-in perspective, just to help round out your value chain from wellhead to tidewater?

Speaker #5: Yeah, I think, Pat, we get asked that question all the time. Obviously, we look at everything that's available for sale. But I think the key point is anything that we buy needs to be additive to the value chain as you point out.

Vern Yu: I think, Pat, we get asked that question all the time. Obviously, we look at everything that's available for sale. I think the key point is anything that we buy needs to be additive to the value chain, as you point out, and particularly needs to come with liquids handling and the ability to integrate into our global exports platform. The good news that we have is we have an abundance of organic growth projects in front of us where we're able to invest, I don't know, 3 times to 8 times build multiples, which are extremely attractive. Any inorganic investment is gonna be challenged to outcompete the organic opportunities we have in front of us.

Speaker #5: And particularly, it needs to come with liquids handling and the ability to integrate into our global exports platform. The good news that we have is we have an abundance of organic growth projects in front of us, where we're able to invest at three times to eight times build multiples, which are extremely attractive.

Speaker #5: So any inorganic investment is going to be challenged out. Compete the organic opportunities we have in front of us.

Speaker #6: And maybe just to follow up on the organic side—I mean, just having to compete with Dow and some other major projects—just curious your strategy around labor availability. Is there anything you're doing now to get ahead of what looks to be a rising cost environment and perhaps weaker productivity across the basin?

Patrick Kenny: Maybe just to follow up on the organic side, I mean, just having to compete with Dow and some other major projects, just curious to your strategy around labor availability. Anything you're doing now to get ahead of, you know, what looks to be a rising cost environment and perhaps weaker productivity across the basin?

Speaker #5: Yeah, we’ve performed really well over the last couple of years. And really, that’s based on the strategy of trying to get as much work built offsite as we can, in controlled manufacturing environments.

Vern Yu: We've performed really well over the last couple of years, and really that's based on the strategy of trying to get as much work built off-site as we can in controlled manufacturing environments. With REEF, you'll notice that almost everything that we do there is manufactured off-site and then brought on-site, and a small workforce is required to kinda Lego set the thing together. That was no different with Pipestone too. The other projects that we're pursuing right now will be executed on that type of principles, where we're minimizing the actual labor out in the field. I think that's a real strategic advantage for us.

Speaker #5: With Reef, you'll notice that almost everything that we do there is manufactured offsite and then brought onsite and a small workforce is required to kind of Lego set the thing together.

Speaker #5: That was no different with Pipestone 2. And the other projects that we're pursuing right now will be executed on that type of principles, where we're minimizing the actual labor out in the field.

Speaker #5: So, I think that's a real strategic advantage for us.

Speaker #6: Okay. That's great. Thanks, Vern.

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

Operator: Your next question comes from Maurice Choy from RBC Capital Markets. Please go ahead.

Speaker #1: Your next question comes from Morris Chow from RBC Capital Market. Please go ahead.

Speaker #2: Thanks, Ann. Good morning, everyone. Just want to touch on the opportunity set here. You mentioned the growing and diversified LPG exports to Asia. It sounds like you believe this demand will be durable even beyond the conflict.

Maurice Choy: Thanks. Good morning, everyone. Just want to touch on the opportunity set here. You mentioned the growing and diversified LPG exports to Asia. It sounds like you believe this demand will be durable even beyond the conflict. How would you characterize the incremental opportunity set in particular versus the maximum incremental potential at REEF?

Speaker #2: So how would you characterize the incremental opportunity set and in particular versus the maximum incremental potential at Reef?

Speaker #5: Well, Maurice, I think we've been very bullish about the long-term opportunity set. At Reef for quite some time. The determining factor ultimately of the ability to grow Reef is how egress works for natural gas and crude oil for the rest of production in Western Canada.

Vern Yu: Well, Maurice, I think we've been very bullish about the long-term opportunity set at REEF for quite some time. The determining factor ultimately of our ability to grow REEF is how egress works for natural gas and crude oil for the rest of production in Western Canada. If we're able to get all of the LNG facilities built that are currently out there, if we're able to get more data center infrastructure built in Alberta, all that's gonna drive natural gas drilling in Western Canada, which will provide a significant amount of liquids for us to export. The demand globally for Canadian LPG is extremely high. It's continuing to go up. I think the fact that we're transportationally advantaged into Japan, Korea, and China has always been there.

Speaker #5: So if we're able to get all of the LNG facilities built that are currently out there, if we're able to get more data center infrastructure built in Alberta, all that's going to drive natural gas drilling in Western Canada which will provide a significant amount of liquids for us to export.

Speaker #5: So the demand globally for Canadian LPG is extremely high. It continuing to go up. I think the fact that we're transportationally advantaged into Japan, Korea, and China has always been there.

Speaker #5: Now we're seeing Southeast Asia and South Asia looking to diversify for security of supply over both the Middle East and the US. So it really comes down to if we're able to make progress on these major projects and the MPO is successful, then we'll see benefits to us.

Vern Yu: We're seeing Southeast Asia and South Asia looking to diversify for security of supply over both the Middle East and the US. It really comes down to if we're able to make progress on these major projects and the MPO is successful, then we'll see benefits to us. The demand has always been there. It's rising, but we're limited by supply.

Speaker #5: So, the demand has always been there. It's rising, but we're limited by supply.

Speaker #2: Just as a quick follow-up to that, obviously, when you think about Reef 1, Opti 1, and Opti 2, you've got well over 100,000 barrels a day of capacity through these three projects.

Maurice Choy: Just as a quick follow-up to that. Obviously, when you think about REEF Phase 1, REEF Optimization One, and REEF Optimization Two, you've got, you know, way over 100,000 barrels a day of capacity through these three projects. Is there a way to characterize what the maximum potential capacity is on REEF? Because it sounds like you're suggesting this is not the limiter, it's more about LNG and crude oil export rather than at REEF.

Speaker #2: Is there a way to characterize what the maximum potential capacity is on Reef? Because it sounds like you're suggesting this is not the limiter.

Speaker #2: It's more about LNG and crude oil export rather than at Reef.

Speaker #5: Yeah. Reef ultimately will be able to export 500,000 barrels a day of LPG. Phase 1 is just under 60,000 barrels a day. Opti 1 is 30,000 barrels of propane.

Vern Yu: Yeah. REEF ultimately will be able to export 500,000 barrels a day of LPG. Phase One is just under 60,000 barrels a day. Optimization One is 30,000 barrels of propane. Optimization Two is 60,000 barrels of propane and butane. That's a sizable increase and a doubling of our global exports platform, but there's still lots more to come. Really, the speed and pace of those incremental phases, it will be dictated by overall egress on the basin.

Speaker #5: Opti 2 is 60,000 barrels of propane and butane. So that's a sizable increase and a doubling of our global exports platform, but there's still lots more to come.

Speaker #5: And really, the speed and pace of those incremental phases will be dictated by overall egress on the basin.

Speaker #2: That's great. If we could just finish off with the focus on the customers. How would you characterize the customer profile differences between China and India and Indonesia versus your more traditional Japanese and South Korean customers?

Maurice Choy: That's great. If I could just finish off with the focus on the customers. How would you characterize the customer profile differences between China, India, and Indonesia versus your more traditional Japanese and South Korean customers?

Speaker #5: Well, Japan and Korea are mostly the large trading houses. Which are integrated in their value chain. Chinese buyers are quite diverse and Sean will speak to this in a minute that we've got a strong credit backstopping for that type of business.

Vern Yu: Well, Japan and Korea are mostly the large trading houses, which are integrated in their value chain. Chinese buyers are quite diverse, and Sean will speak to this in a minute, that we've got a strong credit backstopping for that type of business. Into markets such as Vietnam and other Southeast Asian markets, it's really national petroleum companies that are the counterparties, and it's more diverse markets to China. Sean can talk about how we're seeing the credit quality of those Chinese buyers.

Speaker #5: Into markets such as Vietnam and other Southeast Asian markets, it's really national controlling companies that are the counterparties. And India is more diverse markets like China.

Speaker #5: So how we're seeing the quality of Chinese buyers. I mean, as per there is a shift. But when we contract with almost any business, we look for investor counterparties.

Sean Brown: I mean, as Vern alluded to, there is a shift, but I think when we contractually almost into the position of investment grade counterparties. When we talk about investment grade counterparties, we look at people with LCs. They can, you know, put up some of the core dealerships, you know, over and above for those LCs, usually from a Canadian dollar swap bank. Really no concerns from our perspective as we see the jurisdictional shift for LNG exports.

Speaker #5: Do we find investor counterparties? We look for people who want LCs and are some of the more interesting businesses what we really look for is those LCs from domestic banks.

Speaker #5: So really, the only concern is the recurring perspective either as we see some jurisdiction shift. Or we have seen recently.

Speaker #2: Got it. Thank you.

Maurice Choy: Got it. Thank you.

Speaker #1: Thanks, Vern. And the last question comes from Ben Pham from BMO Capital Markets. Please go ahead.

Sean Brown: Thanks, Chris.

Operator: The last question comes from Ben Pham from BMO Capital Markets. Please go ahead.

Speaker #2: Thank you, Mark. You had a couple of questions on Opti 2. And I'm curious, when you think about the potential probably of sanctioning is that project, is it more a question of really the demand pull on that project from international buyers versus more of a supply push that we've maybe seen historically for it?

Ben Pham: Thank you. Morning. Just had a couple questions on REEF Optimization Two. I'm curious, when you think about the potential probably of sanctioning that project, is it more a question of really the demand pull on that project from international buyers versus more of a supply push that we've maybe seen historically for it? Maybe secondary to that, can you add context around CapEx and returns? Is it more similar to a REEF project versus say an REEF Phase 1?

Speaker #2: And maybe secondary to that, could you add context around CapEx and returns? Is it more similar to a Reef project versus, say, an Opti Phase 1?

Speaker #5: Well, maybe I'll answer the latter part of that question first. Remember that Reef Phase 1, we're pre-building 100% of the jetty. We're pre-building the rail infrastructure.

Vern Yu: Well, maybe I'll answer the latter part of that question first. Remember that, REEF Phase 1, we're pre-building 100% of the jetty. We're pre-building the rail infrastructure, and we're pre-building the power generation. The build multiple on Phase 1 is gonna be in that 7 to 8 times, which is the, probably the highest build multiple of anything that's gonna happen at REEF. REEF Optimization One is an extremely capital efficient expansion, so that is not indicative of other phases. I think the way I'd characterize it, REEF Optimization Two is gonna be in between REEF Phase 1 and REEF Optimization One. On the supply push versus demand pull, obviously we're seeing lots of interest from Asia, so there should be stronger demand pull than we've seen historically.

Speaker #5: And we're pre-building the power generation. So the build multiple on Phase 1 is going to be in that seven to eight times, which is probably the highest build multiple of anything that's going to happen at Reef.

Speaker #5: Opti 1 is an extremely capital-efficient expansion. So that is not indicative of other phases. So I think the way I'd characterize it, Opti 2 is going to be in between Reef Phase 1 and Opti 1.

Speaker #5: On the supply push versus demand pull, obviously, we're seeing lots of interest from Asia. So there should be stronger demand pull than we've seen historically.

Speaker #5: But it's still early days of us having discussions with customers about tolling for Opti 2. So I think we'll just say stay tuned for further updates as we move along throughout the year.

Vern Yu: It's still early days of us having discussions with customers about tolling for REEF Optimization Two. I think we'll just say stay tuned for further updates as we move along throughout the year.

Speaker #2: Okay. Got it. And Vern, you mentioned earlier in comments beyond potential Opti 2, 60,000 barrels looking at ethane is there a reason why there's not looking for more LPG export first?

Ben Pham: Okay. Got it. Vern, you mentioned earlier in comments beyond potential REEF Optimization Two 60,000 barrels, look at ethane. Is there a reason why there's not looking for more LPG export first instead, just in a context that.

Speaker #2: Instead, just in the context that.

Vern Yu: Uh, I think we-

Speaker #5: Well, I think.

Speaker #2: 10,000 barrels you mentioned earlier?

Ben Pham: 1,000 barrels you mentioned earlier?

Vern Yu: We will be able to bring phases of different phases of REEF to market as supply grows, Ben. I think what we're trying to move ahead right now is we know there's gonna be good demand for Opte 2. That should meet the current forecast of LPG supply to the end of the decade. We currently in Alberta are extremely long ethane with no outlet market for it. There's hundreds of thousands of barrels that are getting reinjected into the natural gas stream. There's an obvious need there. Should LPG supply grow at a faster rate, we can bring subsequent phases of REEF to market very quickly. I wouldn't say that we're limited by our ability to increase capacity. It's really we wanna match that capacity growth to supply growth.

Speaker #5: We will be able to bring phases of different phases of Reef to market as supply grows, Ben. I think what we're trying to move ahead right now is we know there's going to be good demand for Opti 2.

Speaker #5: That should meet the current forecast of LPG supply to the end of the decade. We currently in Alberta are extremely long ethane with no outlet market for it.

Speaker #5: There are hundreds of thousands of barrels that are getting re-injected into the natural gas stream. So there's an obvious need there. Should LPG supply grow at a faster rate, we can bring subsequent phases of Reef to market very quickly.

Speaker #5: So, I wouldn't say that we're limited by our ability to increase capacity. It's really that we want to match that capacity growth to supply growth.

Speaker #2: Okay. That makes sense. And may I just one last one on the data center opportunities and WGL and Michigan as well. Can you remind us you got that 15-megawatt-second project?

Ben Pham: Okay, that makes sense. Maybe just one last one on the data center opportunities, WGL, and Michigan as well. Can you remind us, you got that 15 MW second project? Can you remind us what's in the backlog right now? Maybe context on average sizes, and is it still that estimated 1% potential uptick to the 8% you still think could materialize?

Speaker #2: Can you remind us what's in the backlog right now? Maybe context on average sizes and is it still that estimated 1% potential uptick to the 8% you're still think could materialize?

Speaker #5: Yeah. Hey, Ben. It's Blue. Yeah. You're spot on. So as you know, the first couple of projects that we brought on here are fairly small.

Donald Jenkins: Yeah. Hey, Ben, it's Blue. Yeah, you're spot on. As you know, the first couple of projects that we brought on here are fairly small. We talked about that first one in Maryland that expands in phases. This second one is for backup generation, existing center. We are in conversations, as you note, across both Virginia, Maryland, and Virginia. Those range anywhere from something that looks like this in, you know, the 15 or 20 MW up to the 50 MW. They're in various stages of assessment and FIDs on their side to move forward. We still think that looks like a 1% upside for us.

Speaker #5: We talked about that first one in Maryland, that had expansions in phases. This second one is for backup generation, at an existing center. We are in conversations, as you note, across both Virginia and Maryland, and those range anywhere from something that looks like this in the 15 or 20 megawatts, up to the 50 megawatts.

Speaker #5: But they're in various stages of assessment and FIDs on their side to move forward. But we still think that looks like a 1% upside for us.

Speaker #2: Okay. Got it. Thank you.

Ben Pham: Okay. Got it. Thank you.

Speaker #5: You're welcome.

Donald Jenkins: You're welcome.

Operator: This concludes the Q&A portion of today's call. I will now turn the call back over to Mr. Swanson.

Speaker #1: And this concludes the Q&A portion of today's call. I will now turn the call back over to Mr. Swanson.

Operator: This concludes the Q&A portion of today's call. I will now turn the call back over to Mr. Swanson.

Speaker #4: Great. Thanks. Thanks again to everyone for joining the call this morning. The investor relations team is around. If they don't have any further questions, have a great day.

Aaron Swanson: Great. Thanks. Thanks again to everyone for joining the call this morning. The investor relations team is around if anyone has any further questions. Have a great day.

Q1 2026 AltaGas Ltd Earnings Call

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