Chris Ellinghaus

Chris Ellinghaus asked about the impact of cold weather snaps on first-quarter performance, particularly in Florida, and inquired about the sustainability of customer growth in Florida City Gas (FCG) service areas. He also sought details on the benefits and potential cost savings from the company's new ERP system and questioned the Florida Public Service Commission's depreciation study decision.

Answer

Beth Cooper, Executive Vice President, Chief Financial Officer, Treasurer, and Assistant Corporate Secretary, noted weather normalization in Maryland, potential impacts in Delaware and Florida (with rate design limiting variability), and highlighted strong operational performance during the cold snap. She also mentioned O&M expenses as a percentage of gross margin as a key metric for ERP benefits. Jeff Householder, Chair of the Board, President, and Chief Executive Officer, specified Port St. Lucie, Vero Beach, and Brevard County as high-growth FCG areas and detailed ERP efficiencies in customer service, supply chain, field operations, and finance. Jim Moriarty, Executive Vice President, General Counsel, Corporate Secretary, and Chief Policy and Risk Officer, expressed surprise at the depreciation study outcome, which prompted the FCG rate case filing, and commented on the potential helpfulness of a constructive Supreme Court order.

Chris Ellinghaus asked about the potential impact if a constructive order regarding RSAM comes out of the Supreme Court, given the previous sympathy shown during oral arguments.

Answer

Jim Moriarty, Executive Vice President, General Counsel, Corporate Secretary, and Chief Policy and Risk Officer, stated that a constructive Supreme Court decision would ultimately be helpful, as it would address the validity of RSAM, an issue they are no longer dealing with directly. He believes supporting that approach helps all Florida utilities filing rate cases.

Chris Ellinghaus asked about the progress and anticipated timeline for the Nevada alternative ratemaking workshops, the company's thoughts on ROE in light of the recent UNS Gas outcome and its 100 basis point improvement target, the nature of the 7% longer-term base Southwest Gas rate base growth (excluding Great Basin upside), the permanence of parent leverage for Great Basin funding and the potential to push down financing costs, and the timing of potential larger dividend increases.

Answer

Justin Brown, President of Southwest Gas Corporation, stated that Nevada workshops are nearing conclusion, with draft regulations expected in the next month or two, and that the UNS Gas decision was directionally positive, setting parameters for future utility cases. He confirmed the 7% rate base growth reflects consistent utility investment, excluding Great Basin or other one-off opportunities. Jay Foer, Senior Vice President and Chief Financial Officer and Treasurer, clarified that parent leverage for Great Basin is not expected to be permanent, as Great Basin is anticipated to generate substantial cash flow to the parent post-service, and that larger dividend increases are likely once Great Basin is in service.

Chris Ellinghaus inquired about the progress of the Nevada workshops for alternative ratemaking. He also asked for thoughts on the UNS Gas outcome regarding ROE and its incorporation into the 100 basis point improvement target. Additionally, he sought confirmation that the 7% longer-term base Southwest Gas rate base growth excludes consolidated figures and any future Great Basin upsides. Finally, he questioned if parent leverage for Great Basin funding would be permanent and if larger dividend growth is expected once Great Basin is in service.

Answer

Justin Brown, President of Southwest Gas Corporation, detailed the Nevada workshops' progress, focusing on draft language and stakeholder consensus, with anticipated draft regulations in the next month or two. He noted the UNS Gas decision was directionally positive and constructive, and that the company would learn more as other utilities proceed. He confirmed the 7% rate base growth is for the utility, not consolidated, and excludes additional Great Basin opportunities. Jay Foer, Senior Vice President and Chief Financial Officer and Treasurer, Southwest Gas Holdings, stated that parent leverage is not expected to be permanent, as Great Basin will generate substantial cash and dividends to the parent, and confirmed that larger dividend growth is fair to expect once Great Basin is in service.

Chris Ellinghaus inquired about the additional component contributing to the margin increase on slide 16 beyond rate relief and customer growth. He also asked about the Great Basin FERC filing timeline, whether the company prefers to maximize the expansion in the first phase, and the perceived timeline and progress of Nevada's alternative rate-making process.

Answer

Rob Stefani, CFO of Southwest Gas Holdings, clarified that the additional margin increase includes recovery mechanisms on interest. Justin Brown, President of Southwest Gas Corporation, confirmed the target November 2028 in-service date for Great Basin, with a FERC filing in Q4 2026, and stated a preference for maximizing the initial expansion for economies of scale. Regarding Nevada's alternative rate-making, he explained the ongoing workshop process and the flexibility to request formula rates even after the initial rate case filing, targeting March 2026 for the rate case.

Chris Ellinghaus inquired about the components of the margin increase on slide 16 beyond rate relief and customer growth, the FERC filing timeline and review schedule for Great Basin, the preference for a full expansion in the first phase, and the perceived timeline and process for Nevada's alternative rate-making.

Answer

Rob Stefani, CFO of Southwest Gas Holdings, clarified that the additional margin increase includes recovery mechanisms on interest. Justin Brown, President of Southwest Gas Corporation, confirmed targeting Q4 2026 for the FERC filing for Great Basin, aiming for a quick supplemental open season to maintain the November 2028 in-service date, and agreed that maximizing the initial expansion is preferred for economies of scale. Regarding Nevada, Justin discussed the ongoing workshop process, potential for consensus regulations, and flexibility to request formula rates after the initial rate case filing, targeting March 2026.

Chris Ellinghaus of Siebert Williams Shank asked about the expected timeline for the Nevada SB 417 rulemaking process and the company's strategic thinking regarding the Arizona System Integrity Mechanism (SIM) cap, including the possibility of an accelerated rate case. He also questioned the drivers of the corporate segment's performance and the key milestones for adjusting the Great Basin CapEx forecast.

Answer

Justin Brown, President of Southwest Gas Corporation, explained that the Nevada rulemaking process could be completed within a year, leveraging experience from a similar prior electric bill. For Arizona, he confirmed the company is evaluating all options, including accelerating the next rate case or filing for a rehearing on the SIM to clarify perceived confusion. Robert Stefani, SVP & CFO, attributed the positive corporate segment results to interest savings from debt paydown. Brown also stated that signed precedent agreements from shippers are the critical milestone required before updating the Great Basin CapEx forecast.

Chris Ellinghaus inquired about the expected timeline for the Nevada SB 417 rulemaking process, the company's strategy in Arizona following the cap on the System Integrity Mechanism (SIM), the drivers of corporate segment results, and what milestones are needed for the Great Basin project to be included in forward-looking CapEx guidance.

Answer

Justin Brown, President of Southwest Gas Corporation, explained they are evaluating options in Arizona, including accelerating the next rate case or filing for a rehearing on the SIM to clarify perceived confusion. For the Great Basin project, he stated that signed precedent agreements are the critical milestone needed before a FERC filing, which would then provide confidence to update CapEx forecasts. Robert Stefani, SVP & CFO, added that interest savings from debt paydowns were a key positive contributor to the corporate segment's results.

Chris Ellinghaus asked about the expected timeline for the Nevada SB 417 rulemaking process and its impact on the next rate case filing. He also questioned the strategy in Arizona regarding the System Integrity Mechanism (SIM) cap, the cadence for a new rate case with formula rates, and sought clarity on commissioners' comments. Additionally, he asked about the drivers of corporate segment results and what milestones for the Great Basin project would trigger an update to long-term guidance.

Answer

Justin Brown, President of Southwest Gas Corporation, stated that the Nevada rulemaking process could be completed within a year and would complement the next rate case. In Arizona, he confirmed the company is evaluating options like accelerating a rate case or filing for a rehearing on the SIM to clarify perceived confusion among commissioners. Robert Stefani, SVP & CFO, attributed the corporate segment's performance partly to interest savings from debt paydowns. Justin Brown added that for the Great Basin project, obtaining signed precedent agreements from shippers is the critical milestone required before updating capital expenditure guidance.

Chris Ellinghaus followed up on disclosure, asking if extended visibility requires only effective formula rates or also greater clarity on the committed queue and TSMC expansions. He also inquired about the future of the RES DSM component of O&M relative to 2026, and whether the appetite for such programs is permanently reduced or could return due to cost of living pressures. Finally, he asked about the company's vision and timeline for clarity on additional TSMC expansions.

Answer

Chairman, President, and CEO Ted Geisler clarified that extended disclosure is primarily about the timing and consistency of cost recovery, as formula rates enable steady, gradual rate changes and predictable cost recovery, overcoming regulatory lag. Senior Vice President and CFO Andrew Cooper explained that RES DSM programs are regulatory and recovered through rates, with the commission discontinuing some, leading to a condensed program and offsetting O&M benefits. Geisler added that the commission focused on programs with the greatest customer impact, retiring legacy ones, and is committed to affordability. Regarding TSMC, Geisler stated they are in active discussions on timing and potential expansion, and will articulate infrastructure needs once TSMC solidifies its plans.

Chris Ellinghaus followed up on disclosure, asking if extended visibility beyond formula rates also requires greater clarity on the committed queue and TSMC's future expansions. He also inquired about the future outlook for the RES DSM component of O&M relative to 2026, and whether the commission's reduced appetite for these programs is permanent or could return due to cost of living pressures. Finally, he asked about the company's visibility into additional TSMC expansions and the expected timeline for clearer details.

Answer

Chairman, President, and CEO Ted Geisler clarified that extended disclosure is primarily about consistent cost recovery, as regulatory lag, not demand clarity, challenges linear growth, and formula rates would provide predictable recovery. CFO Andrew Cooper explained that RES DSM programs are regulatory and offset gross margin, with a recent reduction due to commission decisions. Ted Geisler added that the commission thoughtfully focused DSM funding on high-impact programs for those most in need, while retiring legacy ones, and remains focused on affordability and cost reduction. Regarding TSMC, Ted Geisler stated they are in active discussions on announced fabs and potential expansions, and will articulate utility infrastructure needs once TSMC solidifies its plans.

Chris Ellinghausen asked if the goal for reducing Q1 seasonality in the gas business is to make Q1 look more like a traditional Q2. He also inquired about the M&A landscape and Centuri's aspirations for tuck-in acquisitions, visibility into timing for data center potential, and whether storm revenue potential has increased proportionately with the scaling of the non-union side.

Answer

Chris Brown, President and CEO, Centuri, confirmed the goal is to deliver 7%+ gross profit margin in the gas business for all four quarters. He stated tuck-in acquisitions would target white space in the Midwest and more geographic presence in electrical transmission/distribution. For data centers, $1.3 billion is being tendered, with bookings expected in the first six months. He confirmed that increased non-union headcount provides more upside potential for storm revenues.

Chris Ellinghaus asked about Centuri's goal for reducing Q1 seasonality in the gas business, aiming for smoother year-round performance. He also inquired about M&A activity and tuck-in acquisition aspirations, visibility into data center project timing and expected bookings, and whether the potential for storm revenues has increased proportionally with the scaled Non-union capacity.

Answer

Chris Brown, President and CEO, confirmed the goal is to achieve 7%+ gross profit margin in the gas business for all four quarters, eliminating seasonality. For M&A, he noted Centuri's strong organic growth platform, with tuck-in aspirations focused on white space in the Midwest and expanding electrical transmission/distribution presence. Regarding data centers, he stated $1.3 billion of real, funded projects are currently being tendered, with bookings expected in the first six months. He also confirmed that the increased headcount in the Non-union business, primarily for day-to-day services, provides more upside potential for storm-related revenues and margins.

Chris Ellinghaus of Siebert Williams Shank & Co. asked if the slightly electric-skewed bookings mix was a strategic choice and whether the increased backlog inherently leads to margin accretion. He also sought clarification on whether price escalators in MSA extensions were at historical norms or more elevated.

Answer

President & CEO Christian Brown stated the bookings mix was coincidental and that the primary benefit of the large backlog is improved predictability, which in turn supports better margins and resource planning. EVP & CFO Gregory Izenstark clarified that MSA renewals involve a full re-evaluation of unit pricing, enabling the company to achieve greater price increases than what is typical with standard annual escalators.

Chris Ellinghaus asked if IDACORP would maintain a mid-year rate case cadence if they forego filing in mid-2026. He also inquired about factors influencing residential customer growth moderation in late 2025, potential lumpiness in residential growth due to new large employers, and the weather impact on sales for the year. Furthermore, he sought an estimate for 2027 large load growth and questioned if 2025 represented peak ADITC usage given CapEx acceleration. Finally, he asked for insights into the company's dividend payout target and minimum acceptable range.

Answer

Lisa Grow, President and CEO, and Tim Tatum, VP of Regulatory Affairs, stated that while mid-year has been historical, they constantly monitor financials and could file at other times, such as the fall, if needed. Lisa Grow attributed residential growth to interest rates and market activity, expecting continued strong growth driven by new employers like Micron. Brian Buckham, SVP, CFO, and Treasurer, noted a 1.5% year-over-year sales growth on a weather-adjusted basis of 2.3%, indicating weather impact, but did not provide a specific weather impact number. He confirmed 2027 would be a significant ramp-up year for large load growth but did not provide an exact number. Brian Buckham clarified that 2025 was not necessarily peak ADITC usage, as various factors influence it, including book equity, unrecovered expenses, and rate case filings. Lisa Grow explained that the dividend payout target aims to avoid issuing equity for dividends, focusing on company investment, and that recommendations to the board are made based on current conditions.

Chris Ellinghaus asked if foregoing the mid-year rate case this year means IDACORP expects to maintain a similar mid-year cadence going forward. He also inquired about factors affecting residential customer growth, such as interest rates, and whether large new employers will lead to lumpiness in residential growth over the next five years. He sought an estimate for the weather impact for the year and an estimate for large load growth in 2027. Additionally, he asked if 2025 was peak ADITC usage and for insights into the dividend payout target, including minimum acceptable ranges or growth rates.

Answer

Lisa Grow (President and CEO) stated that while a mid-year cadence has been historical, they constantly review their financial situation. Tim Tatum (VP of Regulatory Affairs) added that fall filings targeting a June 1st effective date are also an option. Lisa Grow noted that interest rates are key drivers for residential growth, but recent activity suggests some relief, with strong overall growth driven by large employers and planned subdivisions, though it could be lumpy. Brian Buckham (SVP, CFO, and Treasurer) indicated weather impacted sales, with a 1.5% year-over-year sales growth on a weather-adjusted basis being 2.3%, and confirmed 2027, 2028, 2029, and into the 2030s are expected to be significant large load ramp years. Brian Buckham clarified that 2025 was not necessarily peak ADITC usage, as it depends on book equity, unrecovered expenses, and rate case filings. Lisa Grow stated they continuously review the dividend payout, aiming to avoid issuing equity for dividends, and make recommendations to the board within their stated range.

Chris Ellinghaus of Siebert Williams Shank & Co. inquired about the 3,800 MW project pipeline, the potential for another step-up in the 2027 IRP load forecast, the possibility of accelerating gas generation plans, the procedural schedule for the current rate case, and the financial impact of irrigation demand in the second quarter.

Answer

CEO Lisa Grow confirmed that another IRP load forecast increase is a 'fair assumption' and that accelerating gas generation is a scenario being analyzed. SVP & COO Adam Richins added that large load inquiries are up 30% year-over-year. SVP, CFO & Treasurer Brian Buckham detailed that strong irrigation demand, driven by low precipitation, boosted sales by 15% year-to-date. VP of Regulatory Affairs Tim Tatum stated the rate case schedule is expected in the coming weeks.

Chris Ellinghaus of Siebert Williams Shank & Co. inquired about the composition of the 3,800 MW prospective customer pipeline, whether it was included in the IRP, and if the load growth forecast could see another significant increase in the 2027 IRP. He also asked about the potential need to increase and accelerate gas resource plans due to tax bill uncertainties, the timing for the rate case procedural schedule, and the specific impact of irrigation demand in the second quarter.

Answer

CEO Lisa Grow confirmed the pipeline is mostly data centers and that another IRP load growth increase is a 'fair assumption.' She also acknowledged that accelerating gas resource plans is a scenario being analyzed. SVP & COO Adam Richins added that large load inquiries are up 30% year-over-year. VP of Regulatory Affairs Tim Tatum stated the rate case schedule is expected in the coming weeks. SVP, CFO & Treasurer Brian Buckham explained that Q2 irrigation demand was significant, with sales up 15% year-over-year due to very low precipitation, though it was relatively flat on a weather-adjusted basis.

Chris Ellinghaus of Siebert Williams Shank inquired about the composition of the 3,800 MW customer pipeline, the potential for another significant increase in the load forecast in the 2027 IRP, the impact of potential tax changes on the resource mix, the timeline for the general rate case procedural schedule, and the drivers behind Q2 irrigation sales.

Answer

CEO Lisa Grow confirmed the pipeline is mostly data centers and that another IRP load forecast increase is a "fair assumption." SVP & COO Adam Richins noted a 30% year-over-year increase in large load inquiries. SVP, CFO & Treasurer Brian Buckham explained that while Q2 temperatures were comparable to last year, very low precipitation drove a significant increase in irrigation pump usage. VP of Regulatory Affairs Tim Tatum expects the rate case schedule in the coming weeks.

Chris Ellinghaus asked about the expected filing cadence for the acquisition, the impact of the new data center tariff (UM2377) on residential customer prices, the prorated effect of the $25 million cost reduction from 2025, and how the Washington acquisition might aid additional large load growth.

Answer

Maria Pope (President and CEO) stated that filings are expected in the next 30-60 days, with regulatory approval taking 11-12 months. She explained that the data center tariff is expected to initially reduce residential and small business customer prices by about 2%, growing over time. Joseph Trpik (SVP of Finance and CFO) clarified that the $25 million cost savings from 2025 would become full-year, permanent savings in 2026, with new programs building upon them. Maria Pope added that the Washington acquisition would leverage existing relationships with high-tech and data center customers for economic development.

Chris Ellinghaus asked about the expected filing cadence for regulatory approvals, the impact of the new data center tariff (UM2377) on residential customer prices, the timing and effectiveness of the $25 million cost reduction program, and how the Washington acquisition could aid additional large load growth.

Answer

Maria Pope (President and CEO, Portland General Electric) stated filings are expected in the next 30-60 days, with an 11-12 month regulatory process. She explained the data center tariff would initially reduce residential and small business customer prices by about 2%. Joseph Trpik (SVP of Finance and CFO, Portland General Electric) clarified the $25 million cost savings in 2025 were a cumulative program, with full-year benefits expected in 2026 and further savings planned. Maria Pope noted Eastern Washington's focus on economic development and leveraging existing customer relationships for large load growth.

Chris Ellinghaus of Siebert Williams Shank asked about the impact of the Fair Act on investment timing, the planned utilization of Performance-Based Ratemaking (PBRs) under the Power Act, and whether the recent MOU affects future use of recovery mechanisms.

Answer

CEO Maria Pope stated that the Fair Act's rate timing is manageable and highlighted its benefits, such as multi-year ratemaking. She noted PBRs will connect to core work like clean energy. CFO Joe Trpik clarified the MOU and ARM are one-time items, serving as a bridge to a future multi-year plan.

Chris Ellinghaus inquired about the timing and geographical distribution of the 3-gigawatt data center pipeline, the strategy for filing Certificates of Public Convenience and Necessity (CPCNs) in advance of specific resource needs, the company's engagement with the Montana Commission regarding the NorthWestern Energy merger, and the general scale and number of data centers within the pipeline.

Answer

President and CEO Linn Evans clarified that 600 MW from Microsoft and Meta are anticipated by 2030, with other 3 GW+ opportunities being aggressively negotiated for a 2027 ramp-up. Senior Vice President and Chief Utility Officer Marne Jones explained that CPCN filings require specific facts, but the company is actively in equipment queues, as are their customers. Linn Evans added that the merger's discovery phase with the Montana Commission is proceeding as expected. Marne Jones noted that Microsoft and Meta are existing customers looking to expand, and the Tallgrass Crusoe project represents a significant portion of the pipeline, with Linn Evans highlighting the potential for large, hyperscale data centers due to available land in Cheyenne.

Chris Ellinghaus inquired about the timing and geographical distribution of Black Hills Corporation's 3 GW data center pipeline, specifically how much falls within or beyond the five-year plan, and the company's ability to file CPCNs proactively given equipment queue tightness.

Answer

Linn Evans, President and CEO, clarified that the existing Microsoft and Meta demand is projected to reach 600 MW by 2030, with other pipeline negotiations targeting the 2027 timeframe for service ramp-up. Marne Jones, Senior Vice President and Chief Utility Officer, added that while CPCNs require specific facts, the company is in equipment queues and navigating the process for speed to market, with customers also securing equipment. Regarding the NorthWestern Energy merger, Mr. Evans stated they are in the discovery phase with the Montana Commission, receiving anticipated questions. For data center scale, Ms. Jones noted Microsoft and Meta's expansion interest and the significant contribution of the Tallgrass Crusoe project to the pipeline. Mr. Evans highlighted the availability and affordability of land in Cheyenne, Wyoming, suggesting large, hyperscale data centers.

Chris Ellinghaus of Siebert Williams Shank inquired about the expected trajectory of the 19% industrial growth, whether new data center announcements are incremental to the existing pipeline, and the outlook for insurance expenses.

Answer

SVP & Chief Utility Officer Marne Jones explained that digital load growth is not strictly linear and varies by project. President & CEO Linden Evans confirmed that the new Crusoe/Tallgrass data center announcement is incremental to the current 500 MW forecast and will be added to the plan upon contract execution. CFO & SVP Kimberly Nooney noted that insurance costs are expected to be flat year-over-year for the new policy period starting July 1, 2025.

Chris Ellinghaus of Siebert Williams Shank inquired about the expected trajectory of digital and industrial load growth, whether a new Wyoming data center announcement is incremental to the company's pipeline, and the anticipated run rate for insurance expenses.

Answer

SVP & Chief Utility Officer, Marne Jones, explained that industrial growth, while significant, is not expected to be strictly linear. President & CEO, Linden Evans, confirmed the new data center opportunity is incremental to their existing pipeline and that forecasts will be updated as contracts are signed. CFO & SVP, Kimberly Nooney, noted that insurance costs are expected to be flat year-over-year for the new policy period, which is a positive development for 2026.

Chris Ellinghaus of Siebert Williams Shank inquired about the expected shape of digital and industrial load growth, whether new data center announcements in Wyoming are incremental to the existing pipeline, and the outlook for insurance expenses for the remainder of the year.

Answer

Marne Jones, SVP & Chief Utility Officer, explained that industrial growth is not expected to be strictly linear, with varying ramp rates for data centers and blockchain. President & CEO Linden Evans confirmed that the recent data center announcement is incremental to their existing pipeline and will be added to forecasts upon contract execution. CFO & SVP Kimberly Nooney clarified that insurance costs are expected to be flat year-over-year for the period starting July 1, 2025, which will be a benefit heading into 2026.

Chris Ellinghaus inquired about the expected trajectory of digital and industrial load growth, whether new data center announcements in Wyoming are incremental to the existing pipeline, and the run-rate for insurance expenses following a high first quarter.

Answer

SVP & Chief Utility Officer, Marne Jones, clarified that industrial growth is not strictly linear due to varying ramp rates. President & CEO, Linden Evans, confirmed that recent data center announcements are incremental to their forecast and will be added to the plan upon contract execution. CFO & SVP, Kimberly Nooney, stated that insurance costs are expected to be flat year-over-year following the July 1 renewal, providing a benefit moving into 2026.

Chris Ellinghaus asked about the solar pipeline outside New Jersey and if recent Executive Orders have altered the geographic diversity strategy for CEV. He also sought color on the proportionality of recontracting price improvement versus capacity for S&T growth, and the timing of growth. Additionally, he inquired about CEV's technology opportunities for upside, potential storage opportunities, CapEx upside, and how regulators appreciate NJR's hedging strategy.

Answer

Stephen D. Westhoven, President and CEO, stated that about 50% of CEV's forward projects are outside New Jersey, pursuing projects in friendly regulatory environments. For S&T, he explained that doubling earnings by 2027 is largely due to recontracting and rate cases, emphasizing the advantage of expanding existing infrastructure. He discussed leveraging grid interconnections with distributed generation and battery power for CEV's technology upside, confirming this suggests storage opportunities and CapEx upside. He noted regulators are aware of the hedging strategy's benefits in mitigating customer costs.

Chris Ellinghaus inquired about the solar pipeline outside New Jersey and whether recent executive orders have altered the company's geographic diversity strategy for Clean Energy Ventures (CEV). He also asked for color on the proportionality of recontracting price improvement versus capacity in Storage and Transportation, the timing of growth, and elaboration on CEV's technology opportunities for upside, including potential CapEx implications. Finally, he questioned if regulators fully appreciate the benefits of NJR's hedging strategy.

Answer

Stephen D. Westhoven, President and CEO, stated that approximately 50% of CEV's forward-looking projects are outside New Jersey, with the company continuing to pursue projects in friendly regulatory environments. He reiterated that S&T earnings are expected to double by 2027 due to recontracting at Leaf River and Adelphia Gateway, emphasizing the need for infrastructure expansion. For CEV, he highlighted opportunities to optimize existing grid interconnections with distributed generation and battery power, which could lead to CapEx upside. He confirmed that regulators are aware of and appreciate the benefits of the hedging strategy, which significantly mitigates costs for customers.

Chris Ellinghaus of Siebert Williams Shank & Co. asked for a decision timeline on the Leaf River expansion, color on the Storage and Transportation segment's quarterly strength, confirmation of a public disclosure for the Adelphia settlement, a breakdown of the utility gross margin, and whether rising PJM power prices could offset potential tax-related headwinds for solar project economics.

Answer

CEO Stephen Westhoven indicated a FERC filing for the Leaf River expansion is expected in the coming months and confirmed a public disclosure will follow the Adelphia settlement. He attributed S&T strength to a robust natural gas market and agreed that rising power prices support new solar investment. CFO Roberto Bel added that the strong utility margin was driven by both the new rate case and operational expense improvements.

Chris Ellinghaus of Siebert Williams Shank asked about the potential for Oregon's market to normalize in 2026, the performance of the Strata acquisition versus expectations, and any involvement in Idaho's Micron projects.

Answer

CEO Brian Gray expressed uncertainty about a full Oregon recovery in 2026, viewing a comprehensive funding bill as unlikely in the short term. He stated that Strata's performance, excluding weather, was 'right on plan' and represents an upside opportunity. He also confirmed that Knife River is in discussions regarding the Micron projects in Idaho.

Chris Ellinghaus of Siebert Williams Shank asked for an update on the Snyder project and its remaining CapEx, details on the Q4 credit provision, and the status of project financing for Crossrails. He also questioned the inclusion of licensing royalties in 2025 revenue guidance and whether declining lithium-ion prices would lead to margin expansion and a pricing differential between the U.S. and Australia.

Answer

CEO Robert Piconi confirmed the Snyder demonstration unit is complete with no material 2025 CapEx planned. CFO Michael Beer explained the Q4 credit provision was a conservative reserve for a delayed 2022 license payment and that Crossrails financing is being actively pursued. Beer stated that gravity royalties are not a material part of the 2025 revenue guidance. Piconi affirmed that he expects margin expansion in 2025 due to lower battery costs and confirmed a pricing advantage exists for its Australian projects, which are not subject to U.S. tariffs.