With a combined revenue of $21 trillion and $2.1 trillion in profits, the 2026 Fortune 500 is the definitive list of America's largest companies.

Fortune 500

Almost $20 trillion in revenue—and a record-breaking $1.87 trillion in profits. Introducing the 2025 Fortune 500, the definitive list of the biggest companies in America.

The Fortune 500, in its 70th year in 2024, ranks the biggest U.S. companies by revenue.

The Fortune 500, in its 69th year in 2023, ranks the biggest U.S. companies by revenue.

This year’s Fortune 500 marks the 68th running of the list.

This year’s Fortune 500 marks the 67th running of the list.

Providing electricity in Pennsylvania, Kentucky, and the U.K., the energy company has over 10 million customers across its different regions of operation. But a March 2021 deal is likely to remake the company's geographic profile; in the deal, PPL agreed to sell its U.K. utility business to the British company National Grid, while buying National Grid's Rhode Island unit, The Narragansett Electric Co.

This year's Fortune 500 marks the 66th running of the list.

F500-2020-408-PPL

The Allentown, Pa.-based utility provides power to some 10 million customers in Pennsylvania, Kentucky, and the U.K.

This year's Fortune 500 marks the 65th running of the list.

This year's Fortune 500 marks the 64th running of the list.

This year's Fortune 500 marks the 63rd running of the list.

Here are the World's Most Admired Companies for 2016 as ranked in their industries. See who made the list.

World's Most Admired Companies

This year's Fortune 500 marks the 62nd running of the list.

This year's Fortune 500 marks the 61st running of the list. Wal-Mart claims the top spot again. See who made the list.

Wal-Mart stayed on top as its sales crept closer to half-a-trillion dollars. Apple moved into the top five. And UnitedHealth Group continued its steady climb. 

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Established in 1920, PPL is a U.S. energy company that provides electricity and natural gas to approximately 3.5 million customers, operating through three main segments: Kentucky Regulated, Pennsylvania Regulated, and Rhode Island Regulated. The company supplies electricity to customers in Pennsylvania, Kentucky, Virginia, and Rhode Island, and delivers natural gas to customers in Kentucky and Rhode Island. PPL also generates electricity from power plants located in Kentucky.

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Q4 2024

PPL (PPL): Company Profile, Stock Price, News, Rankings

legacy

Good day, and welcome to the PPL Corporation Fourth Quarter twenty twenty four Earnings Conference Call. All participants will be in a listen only mode. Please note this event is being recorded. I would now like to turn the conference over to Andy Ludwig, Vice President, Investor Relations. Please go ahead.

Good morning, everyone, and thank you for joining the PPL Corporation conference call on fourth quarter and full year twenty twenty four financial results. We provided slides for this presentation on the Investors section of our website. We'll begin today's call with updates from Vince Sorgy, PPL President and CEO and Joe Bergstein, Chief Financial Officer. I will conclude with a Q and A session following our prepared remarks. Before we get started, I'll draw your attention to Slide two and a brief cautionary statement.

Our presentation today contains forward looking statements about future operating results or other future events. Actual results may differ materially from these forward looking statements. Please refer to the appendix of this presentation and PPL's SEC filings for a discussion of some of the factors that could cause actual results to differ from the forward looking statements. We will also refer to non GAAP measures, including earnings from ongoing operations or ongoing earnings on this call. For reconciliations to the comparable GAAP measures, please refer to the appendix.

Thank you, Andy, and good morning, everyone. Welcome to our fourth quarter investor update. Turning to Slide four. I'm very proud of our PPL team and all we accomplished in 2024 in executing our Utility of the Future strategy. Most importantly, we continue to deliver electricity and natural gas safely, reliably and affordably to our 3,500,000 customers in Pennsylvania, Kentucky, Rhode Island and Virginia.

This included top quartile transmission and distribution reliability in Kentucky, Pennsylvania and Rhode Island and generation reliability in Kentucky that remains among the nation's best. This was a fantastic result considering we saw some of the worst storms in our company's history as our crews were called upon time and time again to restore power for our customers. To combat the more frequent and severe storms, we increased our vegetation management spending compared to plan to enhance reliability and reduce storm related outages. And we'll continue to review our vegetation management programs going forward to effectively balance reliability versus cost for our customers. Moving to our financial performance, we delivered ongoing earnings of $1.69 per share, the midpoint of our original 2024 guidance.

While we are disappointed that we fell a penny short of the increased ongoing earnings midpoint guidance of $1.7 per share due to some very mild weather in the December, we're confident that the increased vegetation spend was in the best interest of all of our stakeholders in closing out the year. Turning to other 2024 highlights. We executed $3,100,000,000 of planned infrastructure investments on time and on budget to strengthen grid reliability and resilience and advance the safe, reliable, affordable and cleaner energy mix. We also continued our focus in becoming more efficient and keeping energy affordable, achieving the top end of our cumulative annual O and M savings target of $130,000,000 from a 2021 baseline through continued deployment of smart grid technology, automation and data science. As shared on our third quarter call, we completed the integration of Rhode Island Energy into PPL, exiting the transition services agreement we entered with National Grid when we acquired Rhode Island Energy in May 2022.

The integration involved exiting more than 130 transition services in phases over the past two years with careful attention paid to minimizing any impacts on our customers and employees along the way. Overall, I'm immensely proud of the strong collaboration and teamwork that took place across PPL and with National Grid to achieve this success. Moving to Slide five. Today, we announced an updated business plan that strengthens and extends our runway for annual earnings and dividend growth, while supporting the delivery of safe, reliable and affordable energy for our customers. In connection with this update, we announced our 2025 ongoing earnings forecast range of $1.75 to $1.87 per share.

The midpoint of this range, $1.81 per share, represents 7% growth from our original 2024 forecast midpoint and year end result of $1.69 per share. Looking beyond 2025, we are extending our 6% to 8% annual earnings and dividend growth through at least 2028, which is based off the 2025 forecast midpoint. Given the strength of our updated plan, we are confident that we can achieve the top half of our targeted growth rate range over this period. Underpinning these updated targets is a refreshed capital plan that includes $20,000,000,000 in expected infrastructure investments from 2025 through 2028. This compares to $14,300,000,000 in our prior plan period.

Our updated plan includes a mix of investments aimed at strengthening the grid against current and future weather impacts, speeding up our ability to restore power when storms strike and advancing a cleaner energy mix without compromising on reliability and affordability. These critical investments are expected to drive average annual rate base growth of between 9.510% through 2028, up from 6.3% over the prior plan period, which strengthens the predictability of our growth targets. In support of customer affordability and a critical component of our strategy, we remain hyper focused on improving operational efficiency across the enterprise. As for every dollar of O and M we can take out of the business, we can fund an average $8 of capital without impacting the customer bill. I'm very proud of how our teams across PPL have embraced the drive to innovate and work smarter and more efficiently for our customers.

We continue to expect cumulative annual O and M savings of at least $175,000,000 through 2026 based off the 2021 baseline. Given the significant increase in capital needs in our updated plan, we expect to need $2,500,000,000 of equity through 2028. This supports our strong credit metrics, which we expect to maintain throughout the plan period. Finally, today we also announced a quarterly common stock dividend of $0.2725 per share. This represents approximately a 6% increase from the current quarterly dividend, which is at the lower end of our target range given the significant capital investment needs in our updated plan.

Turning to Slide six. Over the past year, we've made substantial progress in our Utility of the Future strategy, which sets us up well heading into 2025. We've restructured our business and realigned departments and teams across PPL to better execute the strategy, implement best practices across the enterprise, increase operational efficiencies and drive continuous improvement. These changes have already begun to yield significant benefits. We also kicked off an IT transformation initiative that will bring alignment of our systems across PPL.

This included engaging with some of the world's leading technology companies, exploring new opportunities to apply cutting edge technology to the utility industry to deliver a better experience for our customers and employees. As we continue to make decisions and plan for the future, we will increasingly use AI and other advanced technologies to inform our decisions, optimize our asset planning and maintenance, better manage supply and demand on the grid and empower our customers through digital solutions and better service. I'm convinced our investments in technology will deliver better results at lower cost for our customers. Over the past year, we've also begun to execute our planned generation replacement strategy in Kentucky that will advance a reliable, affordable and cleaner energy mix. Last fall, for instance, we broke ground on construction of a new six forty megawatt combined cycle natural gas plant at our Mill Creek facility.

And throughout 2024, we continue to advance our plans for development of two forty megawatts of new company owned solar and and 125 megawatts of battery storage. We continue to drive innovation and invest in research and development, partnering with more than 30 different organizations on over 175 R and D initiatives, including one of the industry's leading carbon capture projects at our Cane Run combined cycle natural gas plant in Kentucky. In addition, we've developed common design and operation standards across our utilities that will continue to bring advanced technologies, best practices and more robust engineering and construction specifications for future grid designs. And while wildfire risks are low throughout most of the areas we serve, we take nothing for granted when it comes to public safety. And in 2024, we implemented wildfire mitigation plans at all of our utilities.

We remain committed to help drive economic development in our service territories, including supporting significant data center build out as we recognize that data center growth and expansion is key to America's future economic competitiveness and national security. Finally, we continue to engage with key stakeholders to strengthen resource adequacy in PJM. In Pennsylvania specifically, we continue to advocate for a state focused no regret strategy that addresses impending energy shortfalls and provides the state with additional tools to help protect customers from price volatility and reliability concerns. We believe one way to do this is to allow regulated electric utilities to invest in generation resources up to and including owning and operating generation again. This would complement the competitive market by addressing resource adequacy gaps rather than relying solely on market forces to deliver a solution.

Turning to Slide seven and a brief regulatory update. We continue to advance on several key regulatory proceedings across our jurisdictions and expect to file a few more this year. Starting in Kentucky, LG and NKU continue to advance their latest integrated resource plan through the Kentucky Public Service Commission's review process. Since it was filed last October, the process has proceeded as expected with a public hearing scheduled for May 13. Our analysis continues to support the need for additional generation capacity by the end of the decade, and we've updated our capital plans to reflect our recommended path forward.

Informed by this IRP, we expect to file a CPCN request later this quarter to address near term generation needs. Finally, we anticipate filing a base rate case in Kentucky later this summer with our current stay out period ending on July 1. As a reminder, LG and E and KU's last base rate increase was about four years ago in July 2021. Turning to Pennsylvania, PPL Electric Utilities continues to await a PUC decision on our petition to increase the distribution system improvement charge cap to 9% of revenue from the current cap of 5%. In late November, a PUC administrative law judge recommended the denial of our petition.

Despite that recommendation, we continue to believe in the merits of our request. We've since filed exceptions to the recommended decision and await a final order from the commission. Also in Pennsylvania, we continue to evaluate the timing of our next rate case, where we've not had a base rate increase since 01/01/2016. The team has done an outstanding job of making critical investments, while becoming more efficient, resulting in solid financial performance over that time period. We are evaluating the timing of a Pennsylvania rate case given increased capital investment needs, continued frequency and intensification of storms and overall inflationary impacts.

Turning to Rhode Island. In late December, Rhode Island Energy filed its annual electric and gas infrastructure safety and reliability plans for fiscal year twenty twenty six, which covers investments from April of this year through March of twenty twenty six. Our electric ISR filing seeks a total budget of about $260,000,000 for infrastructure investments, including nearly $90,000,000 for advanced metering functionality, which has already been approved by the Rhode Island Public Utility Commission, as well as certain costs for vegetation management and other costs relating to maintaining safety and reliability. Our gas ISR filing, meanwhile, seeks a total budget of about $225,000,000 to sustain and enhance the safety and reliability of our gas distribution system. Hearings on both plans will be conducted in March with a decision expected by April 1.

Meanwhile, we continue to expect to file a base rate case in Rhode Island in the fourth quarter of twenty twenty five following conclusion of our stay out period on October 1. Remember that as part of our transition plans for Rhode Island Energy, we had agreed not to file for a base rate increase until we had been off the transition service agreement with National Grid for a full twelve months. We completed the transition services in September of twenty twenty four. Moving to Slide eight and an update on data center development in our service territories. We continue to see substantial interconnection requests in Pennsylvania and now have over 56 gigawatts in our queue.

While we continue to recognize that there's likely duplication in that figure, we have nearly nine gigawatts in advanced stages of development. We estimate potential transmission capital investment of between $600,000,000 and $700,000,000 for these projects. We've included about $400,000,000 in our updated capital plan, which was prioritized based on the requested interconnection dates. As we've shared previously, we expect that each new data center connection in Pennsylvania will lower transmission costs for customers, with savings expected to ramp up over the next several years as data centers begin to pay more significant transmission costs. In Kentucky, we were pleased to announce our first hyperscale data center customer in Jefferson County, the latest example of the state's success and our support in attracting economic development.

The joint venture between PowerHouse Data Centers and Po companies will involve development of a 400 megawatt data center campus located in Louisville. The first one hundred and thirty megawatts are expected to come online in October 2026, with demand growing to the full 400 megawatts by 2028. Meanwhile, active data center requests in Kentucky continue to meaningfully increase and have doubled since our Q3 call with nearly six gigawatts of potential demand in our queue. In summary, we continue to see robust demand in both states and look forward to continuing to support these important customers. I'll now turn the call over to Joe for the financial update.

Thank you, Vince, and good morning, everyone. Let's turn to Slide 10. CPL's fourth quarter GAAP earnings were $0.24 per share compared to $0.15 per share in Q4 twenty twenty three. We recorded special items of $0.1 per share during the fourth quarter, primarily due to integration and related expenses associated with the acquisition of Rhode Island Energy and IT transformation costs. Adjusting for these special items, fourth quarter earnings from ongoing operations were $0.34 per share, a decrease of $0.06 per share compared to Q4 twenty twenty three.

On an annual basis, our 2024 GAAP earnings were $1.2 per share compared to $1 per share in 2023. Adjusting for special items recorded throughout the year, our 2024 ongoing earnings were 1.69 per share, an improvement of $0.09 per share compared to our 2023 results. Turning to the ongoing segment drivers for the fourth quarter on Slide 11. Our Kentucky segment results were flat compared to the fourth quarter of twenty twenty three. Kentucky's results were driven by higher sales volumes, primarily due to favorable weather compared to last year.

The favorable weather impact was offset by higher operating costs, which included the higher vegetation management costs as Vince mentioned earlier. Our Pennsylvania regulated segment results were also flat compared to the same period a year ago. Pennsylvania's results were primarily driven by higher transmission revenues, offset by higher operating costs in several areas, including increased vegetation management costs and an increase in uncollectibles. Our Rhode Island segment results decreased by $0.03 per share compared to the same period a year ago. This decrease was primarily driven by lower transmission and distribution revenues, which included a favorable annual ISR true up recognized in Q4 twenty twenty three.

Finally, results at Corporate and Other decreased by $0.03 per share compared to the same period a year ago. The decrease was primarily due to higher interest expense from increased holding company debt balances and higher income taxes driven by higher tax credits that were recognized last year. Moving to Slide 12. We continue to build a track record of delivering our 6% to 8% annual growth target and achieved 7% growth from $1.58 our original 2023 forecast midpoint. Looking ahead, we remain extremely confident in our growth and the plan we've rolled out today strengthens that even further.

We've extended our 6% to 8% annual EPS growth target another year to 2028 and expect to achieve growth in the upper half of that range. At our updated plan, our growth will be driven by the significant investment needs and the corresponding rate based growth across the enterprise. In connection with that investment, we do expect to experience some regulatory lag over this period while needing equity to support this meaningful growth, and we are shifting from earnings driven by rate based growth and O and M savings to growth primarily driven by rate based growth. Our updated plan clearly positions PPL to deliver strong, sustainable growth for shareholders and improve service for our customers for years to come. Moving to Slide 13, we've provided a walk from the midpoint of our original 2024 ongoing earnings of $1.69 per share to our 2025 forecast midpoint.

Starting with our Kentucky segment, we project results to increase by $0.05 per share in 2025. The increase is projected to be driven by higher sales volumes due to a return to normal weather and modest weather normalized growth, lower operating costs and higher AFUDC income related to new generation and AMI projects. These increases are expected to be partially offset by higher interest expense due to higher projected debt balances as we finance our capital investments. In Pennsylvania, we also project segment results to increase by $0.05 per share in 2025. Returns on additional capital investments in transmission and lower operating costs are projected to be partially offset by higher interest expense due to higher debt balances.

Rhode Island segment results are expected to increase by $0.04 per share in 2025 compared to our 2024 results, primarily due to increased rider revenue from capital investments and lower operating costs, partially offset by higher interest expense. Finally, we project our corporate and other results to decrease by $0.02 per share in 2025, primarily due to higher interest expense. Our 2025 earnings forecast does not include the impact of any base rate cases in any of our jurisdictions, as we do not expect any rate increases to take effect until January 2026 at the earliest. Turning to Slide 14. Over the next four years, we have planned capital investments of $20,000,000,000 to meet the growing demand needs on our networks to continue to provide reliable service and enhance the overall customer experience and to support economic expansion in our service territories.

This includes advancing industry leading grid modernization, expanding and hardening our transmission and distribution networks, improving the safety of our natural gas networks, implementing our approved generation replacement plan in Kentucky and building new generation that is necessary to support future load growth. This plan represents a $5,700,000,000 increase in capital investments compared to the prior four year plan of nearly $4,000,000,000 of that increase expected to occur between 2025 and 2027. Most of the increase in that timeframe is projected to be in Kentucky and Pennsylvania. In Kentucky, we see nearly $1,300,000,000 of additional investments related to new generation to support the growing demands in our service territory and additional environmental retrofits on our coal fleet. The new generation investments assumed in our plan aligns with the recommended resource plan submitted in our IRP, including two combined cycle natural gas plants with 34,031 in service dates and 400 megawatts of battery storage by 2028.

We also project about $500,000,000 of additional transmission and distribution investment to strengthen and modernize the grid, which is critical given more intense and frequent storms, including significant impacts from tornadoes. In Pennsylvania, we see nearly $1,000,000,000 of additional distribution system investment needed to support grid resiliency and another $200,000,000 of transmission investments to support data center growth. In addition, we added nearly $600,000,000 of IT investments across the enterprise. These needed upgrades will enhance cybersecurity, improve our customers' experience and enhance the efficiency of our back office functions like finance, supply chain and human resources. We continue to expect significant investment needs into the end of this decade as reflected in our 2028 forecast of $5,000,000,000 This includes investments needed to continue to replace aging infrastructure, increase reliability and resiliency and construct new generation in Kentucky to support growing demand and economic development in the region.

Turning to Slide 15. These additional capital investments are projected to lead to annual rate base growth of 9.8% from 2024 to 2028. This compares to annual rate base growth of 6.3% in our prior planned period from 2023 to 2027. As shown on the slide, two thirds of our rate base relates to investments in our electric T and D networks given the significant needs as we strengthen and modernize the grid. The percentage of our total rate base related to coal generation is expected to be less than 11% by the end of twenty twenty eight, down from about 16% today.

Coal will remain a critical generation resource for us in Kentucky well into the future, especially given the expected low growth in the region. However, as our coal plants reach the end of their useful lives with the next significant transfer retirements expected in the mid-2030s, we continue to expect to replace that coal generation with a mix of natural gas, renewables and energy storage solutions. In summary, you can see the updated capital needs drive meaningful growth in the company's rate base. While we are transitioning to a more traditional rate based growth driven model, delivering operating efficiencies will remain central to our strategy to continue to support customer affordability. We remain keenly focused on optimizing our business, which will allow us to continue to make prudent investments in the most efficient manner.

Moving to an update on PBL's credit on our financing plan for 2025 on Slide 16. We continue to believe that having one of the sector's strongest balance sheets is a clear strategic advantage that provides the company with significant financial flexibility. And our updated business plan maintains strong credit metrics throughout, while supporting our earnings growth targets. This includes maintaining a 16% to 18% FFO to debt ratio and a holding company to total debt ratio below 25%. We expect equity needs of $2,500,000,000 over the planning period to fund the growth associated

with the increased capital investments. We plan to

establish an ATM program to support these to In terms of debt financing, we have limited near term refinancing risk with only $550,000,000 of total utility maturities in 2025. And we continue to maintain limited floating rate debt exposure with approximately 5% of total long term debt at year end. Our solid financial foundation keeps us very well positioned to execute our updated business plan and growth targets while we deliver value for customers and shareowners. Moving to Slide 17, we continue to view the dividend as an important piece of total shareowner return. Today, our Board of Directors declared a quarterly cash dividend of 0.271 quarter dollars per share to be paid on April 1 to shareholders of record as of March 10.

This results in an annualized dividend of $1.09 per share compared to our prior annualized dividend of $1.03 per share, approximately a 6% increase. We continue to target future dividend growth within 6% to 8% per year. We expect dividend growth to remain at the lower end of the range through the current planned period given the meaningful CapEx plan. The combination of PPL's EPS growth and current dividend yield continues to provide investors with attractive total return proposition in the range of 9% to 12%. This concludes my prepared remarks.

I'll now turn the call back over to Vince.

Thanks, Joe. In closing, I remain as excited as ever about PPL's future. We have positioned the company as an agile, forward looking organization poised for long term growth and success. That growth is backed by a robust capital plan featuring $20,000,000,000 in infrastructure improvements from 2025 to 2028. Through at least 2028, we offer investors visible and predictable long term earnings per share growth in the top half of the 6% to 8% range with dividend growth closer to 6% given the significant capital investments in the updated plan.

It's also a plan that our customers can afford and one where they can continue to expect reliable service and continued improvement to the overall customer experience. We maintain one of the strongest balance sheets in our sector, a clear strategic advantage that provides significant financial flexibility. And importantly, we have a strong track record of operational excellence, consistently delivering top quartile transmission and distribution reliability and top decile generation reliability. We have the right strategy for the right time. Our vision is to be the best utility in The U.

S. And we're absolutely determined to achieve this vision. With that operator, let's open it up for questions.

We will now begin the question and answer session. The first question today comes from Durgesh Chopra with Evercore ISI. Please go ahead.

Hey, good morning, team. Sorry, I was on mute talking to myself. Congrats on the update here and the capital plan raise. Just I had two questions. One, on the Kentucky CPCN, maybe just updated thoughts there.

What are you as you get closer to that filing, how many Megawatts capital investment? I assume it's included in the $1,300,000,000 capital increase for Kentucky, but just thoughts there and when to expect to find decision?

Yes, Vitesh. So what we've updated in the capital plan is our recommended resource plan that we had in the IRP that we had filed and is currently going through review with the commission. In total for generation in the plan, we've added about $2,500,000,000 That includes two new combined cycle plants with a 02/1930 and 02/1931 in service date, includes 400 megawatts of additional battery storage projects within service dates in the 2028 timeframe. That is needed to cover us before the CCGTs come online with expected load growth from large load customers in Kentucky. And then it also includes some additional environmental spend on the coal fleet, including the FCR on Gen.

color. Presumably that all of that will be captured in the CPCN filings or are those going to be staged?

Yes. That is that's consistent with the recommended resource plan, which will be the basis for the CPCN. We'll file that by the end of the first quarter. We would expect a decision by the fourth quarter.

Excellent. Thank you. And then just quick follow-up question on the equity issuance. Just should we assume that ratable $2,500,000,000 or just any current timing on how you're going to issue that equity?

Yes, Virgus, it's Joe. So, I mean, look, we have flexibility on the timing of those issuances given the quality of the balance sheet. And as I indicated, we may complement that ATM with other equity like financing structures. So, but let me look, I think for modeling purposes, you could assume something in the order of $400,000,000 to $500,000,000 this year and then sort of tracking the capital plan as we go through the planned period. But again, we'll be flexible and we'll take advantage of the market conditions as we have the funding needs.

Excellent. Thank you guys. I appreciate the time.

The next question comes from Paul Zimbardo with Jefferies. Please go ahead.

Hi, good morning. Thank you very much. To follow-up on the equity side of the equation, if you could help unpack the comment you had about complement with other equity like financing structures. Is that that there's other equity linked in the debt? That's something you could do to reduce equity financing?

If you could just explain that a little bit, please.

Yes, sure, Paul. I mean, yes, and you're right. There's obviously hybrids get 50% equity treatment from the agencies. And so, so I think from a base assumption, we view the ATM as a cost effective tool to issue that equity, but there's other means to do that. And so we'll be, as I said, opportunistic around that and there's points in times that there's funding means that are more efficient than others.

And so given the balance sheet and the position that we're in, we just have we have the flexibility to do that. So we'll take advantage of market conditions as they come.

Okay. I understand there. And then shifting back to Kentucky generation and just the data center opportunities now that you kind of have built the entire 400 megawatt bucket. Just if hypothetically there was a one gigawatt data center in Kentucky, could you just describe like what kind of length, the ability to serve you have pro form a for the new combined cycles that you're adding?

So our when we think about reserve margins in Kentucky, right, our summer margins for this year are just over 20%, Paul, and then winter is around 27 ish percent. With the in service date of our Mill Creek CCTT Mill Creek five, which is expected to go in service in 2027, we would be able to accommodate the 400 megawatts of data center that we recently announced, but not much more. As you know, with the load load that we're projecting, right, and with what we filed in the IRP for the two additional cCGTs going to service in 3031. That's why we're also including 400 megawatts of batteries to provide an interim solution between that first CCGT going online in 2027 and then the second two in 3031. So that's really the basis for that battery solution in that 2028 timeframe.

a pickup in Kentucky load, whatever class that would require more generation, is that fair?

The next question comes from James Kennedy with Guggenheim. Please go ahead.

Hey guys, good morning. Congrats, Michael. Thanks for taking the questions. So Vince, if I can just come back to resource adequacy in Pennsylvania. You mentioned regulated generation in the prepareds.

It seems like some stakeholders still want to wait for competitive entry. So I guess maybe just some more color on what you see as a pathway forward here in this legislative session. And in your view, how much of a time cushion really remains?

Yes. Look, I would obviously, this is a major legislation around energy policy in the state. We are clearly an energy leader in PJM as really the state that drives most of the generation in PJM as we know. So energy policy in PA will be critical as we think about state resource adequacy, but also PJM. So obviously, there's been no legislation proposed yet.

We are very actively engaged with the governor's office, various legislators, of course, with the PUC. I would say those discussions remain constructive and we would expect some proposed legislation to be proposed in this legislative session, perhaps as early as the spring or summer. We've talked a bit about what could be in that legislation. I think there's a number of things that we've heard from various legislators. Obviously, we're talking quite a bit about permitting utilities to invest in and ultimately own and operate generation again in rate base.

So that could be one. They could create incentives within the bill for utilities and the market, I. E, the IPP to enter into long term power purchase agreements beyond what is currently allowed under our default service plans, which is pretty limiting. We've seen ideas floated with proposals like the Texas Energy Fund. Senator Yar has the Baseload Energy Development Fund, very similar to the Texas Energy Fund low cost financing to help lower the cost of new entry for generation.

So I could see any or all of those potentially making it into legislation and again will support ultimately whatever the state wants to do that supports getting generation built in Pennsylvania and supporting PJM resource adequacy.

Okay, got it. And then just on the Pennsylvania data center spend, so you rolled in $400,000,000 I think with this update, but there's more to go. So just how should we think about cadence of updates on that balance? Will you update throughout the year? Do you have to wait for customer announcements?

Yes, sure. We'll certainly be able to provide updates on that as we go through the year as we kind of think about Pennsylvania and the six gigawatts or so that's in the queue. Obviously, we believe there's duplication in that number. But as we kind of peel that back a bit, right, we have the nine gigawatts of projects in advanced stages. So we have a higher degree of confidence on those.

But kind of if I take like a fiftyfifty probability, the projects that would kind of fit in that fiftyfifty bucket, that nine goes to like 12 or 13. So we'll certainly be keeping an eye on those projects as they progress through the development process and move up into that advanced stage. But you're right, up to $600,000,000 to $700,000,000 we've only included $400,000,000 in the plant. And clearly, we'll provide updates to that as those projects continue to move in the development phase.

The next question comes from Jeremy Tonet with JPMorgan. Please go ahead.

Just wanted to, I guess, circle back on customer bills and how you think about that at this point in time, the amount of headroom there. Given a big step up in capital, just wondering how you feel about that dynamic going forward?

Yes. Jeremy, it's a great question, right. And I'll just reiterate and you guys notice about us and our strategy all along that we keep affordability top of mind and front and center and it is such a key component of our strategy. It's why we remain so focused on driving efficiencies across the business, right? We've talked about that eight:one ratio for every dollar of O and M we can take out of the business.

We can fund on average $8 of CapEx and not impact the customer bill. So even beyond the $1.75 to $26 we will remain laser focused on continuing to drive cost out of the business, primarily for affordability reasons. When we look at this plan update, we believe that we can execute the updated plan without unduly impacting affordability as we would expect average bill increases to generally remain within the rate of inflation. So again, we think our customers can afford this plan.

Got it. Thank you. And then ahead of upcoming filings in Kentucky, just wondering any more thoughts you could provide with conversations with the commission, stakeholders there given the newer composition of the commission? Just wondering any other thoughts there.

Nothing out of the ordinary. This should be a clean CPCN. It'll track the IRP recommended resource plan. So obviously, the commission is reviewing the IRP right now. We would expect them to issue their order on the IRP by mid July.

That's just how that process progresses. Obviously, we're not waiting for that decision necessarily before we would file our CPCN, but a lot of consistency there. So not expecting there to be any surprises at the commission level with these filings.

Got it. And just a quick last one, if I could. The 6% to 8% EPS CAGR you outlined there, just wondering, I guess, how you see the cadence of growth across that? When do you expect 7% next year? Or just wondering if there's any dynamics to that trajectory?

Yes. Generally, I would say it's linear. So we're continuing to maintain linear growth off of our new midpoint for 'twenty five.

Got it. That's helpful. I'll leave it there. Thanks.

The next question comes from Paul Patterson with Glenrock Associates. Please go ahead.

So just to sort of follow-up here, with the potential for new generation, utility owned generation, It would appear in the current auction environment that that could substantially lower costs wholesale costs. And I'm just sort of wondering how you see that working and when the soonest I mean assuming that let's say you did get legislation this year, when that could show up if you follow what I'm saying to sort of a timing on that?

Yes. So as I think about the capacity options maybe more broadly, Paul, right, our governor actually negotiated a settlement with PJM to cap the auctions at a ceiling of $3.25 per megawatt day and a floor of $1.75 That's for the next two auctions. And look, I don't think it's unreasonable to believe that those auctions wouldn't clear at the caps of $3.25 a lot will go into those when you think about just the higher load curves coming from data centers across all of PJM, seeing a lot of interest as we know clearly from us but also our peers. So clearly, we're expecting that demand curve to go up. Look, at those higher prices though, I would expect some of the generation that was in the queue to retire in the prior auction would likely come back in.

So that could help mitigate some price increases. But ultimately over the next two auctions, I don't think it's unreasonable that we'll see that cap cleared.

PPL (PPL) Q4 2024 Earnings Call Transcript

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