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DATE
Monday, Nov. 3, 2025 at 11 a.m. ET
CALL PARTICIPANTS
President and Chief Executive Officer — Ralph A. LaRossa
Executive Vice President, Chief Financial Officer — Daniel J. Cregg
Vice President, Investor Relations — Carlotta N. Chan
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TAKEAWAYS
Non-GAAP Operating Earnings Guidance -- Narrowed to $4 to $4.06 per share, previously $3.94 to $4.06 per share, reflecting results through the first nine months.
Third-Quarter Net Income -- $1.24 per share for Q3 2025, up from $1.04 per share in Q3 2024, driven by new electric and gas base distribution rates effective October 2024 and higher returns on capital investment.
Third-Quarter Non-GAAP Operating Earnings -- $1.13 per share in non-GAAP operating earnings for Q3 2025 compared to $0.90 per share in Q3 2024.
PSE&G Third-Quarter Net Income -- $515 million in net income versus $379 million in Q3 2024, reflecting the full impact of the October 2024 rate case.
PSE&G Quarterly Capital Investment -- $1 billion invested and $2.7 billion for the first nine months, aligned with a $3.8 billion full-year regulated capital plan.
Five-Year Capital Investment Outlook -- Plan reaffirmed at $22.5 billion to $26 billion for 2025 through 2029, without need for new equity or asset sales.
Nuclear Generation (Q3 2025) -- 7.9 terawatt hours produced, compared to approximately 8.1 terawatt hours in Q3 2024.
Nine-Month Nuclear Output -- 23.8 terawatt hours for the first nine months, up slightly from 23.3 terawatt hours for the same period in 2024.
PSEG Power and Other Third-Quarter Net Income -- Net income was $107 million versus $141 million in Q3 2024, with non-GAAP operating earnings of $50 million compared to $69 million in Q3 2024.
Hope Creek Nuclear Cycle Extension -- Moved from 18 to 24 months, expected to yield more megawatt hours and future O&M savings.
Salem Upgrade Project -- Aims to add 200 megawatts between 2027 and 2029, targeting increased baseload carbon-free dispatchable supply.
Data Center Load Pipeline -- Large load inquiries rose to 11.5 gigawatts, nearly all attributed to data center and edge computing demand.
Mature Data Center Applications -- Increased from 2,600 megawatts to 2,800 megawatts, reflecting incremental activity.
PJM Base Residual Auction -- Cleared approximately 3,500 megawatts of nuclear capacity at $329 per megawatt-day for the energy year June 1, 2026 through May 31, 2027.
Liquidity Position -- $3.6 billion total available, including $330 million in cash at quarter end; variable rate debt at $400 million, representing 4% of total debt as of September 30, 2025.
Moody’s Credit Opinion -- Recent review resulted in no change to PEG or PSE&G credit ratings or outlook.
Customer Growth -- Electric and gas customer counts each grew approximately 1% over the past year, cited as primary distribution margin drivers under decoupled model.
Energy Efficiency Investment -- Up to $2.9 billion planned over six years, with $1 billion in on-bill repayment options for customer upgrades.
Long-Term Non-GAAP EPS Growth Target -- Reaffirmed at 5%-7% compound annual growth in non-GAAP operating earnings through 2029, supported by capital spending and nuclear PTC environment.
Dividend Growth Commitment -- Statement of ability to provide consistent and sustainable dividend growth, enabled by strong balance sheet and capital allocation.
Affordability and Supply-Demand Balance -- Explicit statement that supply-demand imbalance in New Jersey and PJM region poses future reliability and affordability challenges unless addressed.
Recent Contract Extension -- Five-year extension secured as the operation service provider for Long Island Power Authority through 2030.
SUMMARY
The company highlighted successful execution of its regulatory-driven capital plan and confirmed no current plans to issue equity or divest assets to fund growth. Management identified ongoing legislative and regulatory processes in New Jersey regarding generation adequacy, with load growth primarily from data center projects remaining a central business driver. Senior leadership described collaborations with policymakers to address resource adequacy, including support for proposed legislation promoting competition for new instate generation. A recent transition in Hope Creek’s nuclear refueling cycle and ongoing upgrades at Salem were outlined as initiatives targeting operational improvements and capacity growth.
LaRossa stated, we expect the capacity market impact on customer bills next June will be limited by two factors. First, the FERC approved price collar that will extend to at least the upcoming capacity auction in December and two, gradualism of the basic generation supply mechanism that feathers in changes over a three-year period
Discussion detailed continued movement of data center projects through the interconnection queue, predominately smaller-scale and “edge computing” focused as opposed to “hyperscale” expansion.
Management signaled continued review and roll-forward of capital and rate base forecasts on the next quarterly call, incorporating evolving policy and load factors.
Explicit reference was made to discussions with both gubernatorial candidates and frequent engagement with the Board of Public Utilities for upcoming regulatory initiatives.
INDUSTRY GLOSSARY
SIP (Conservation Incentive Program): A mechanism that decouples weather and economic sales variances from a utility’s distribution margin to encourage conservation and energy efficiency.
PJM: Regional transmission organization that coordinates the movement of wholesale electricity in parts of the Eastern U.S., including New Jersey and Pennsylvania.
Base Residual Auction: PJM’s primary forward capacity market mechanism securing committed generation for a future delivery year at a market-clearing price.
PTC (Production Tax Credit): Federal tax credit designed to support certain forms of power generation, particularly relevant to nuclear plants after recent legislative changes.
FRR (Fixed Resource Requirement): Alternative capacity market approach under PJM rules, allowing large utilities to meet obligations via self-supplied resources rather than direct market participation.
BPU (Board of Public Utilities): The regulatory agency overseeing utilities in New Jersey.
GSMP (Gas System Modernization Program): Regulatory program enabling PSE&G to invest in and recover costs for upgrades to gas utility infrastructure.
Full Conference Call Transcript
Carlotta N. Chan: Thank you, Carlotta, and thank you all for joining us to review the results we announced this morning and to discuss our outlook for the business over the remainder of the year.
Ralph A. LaRossa: Public Service Enterprise Group Incorporated reported a solid third and year-to-date operating and financial results reflecting the expected positive impact of the new rates from the October 2024 distribution rate case settlement that benefited the full third quarter. Our results through the first nine months enable us to narrow our 2025 non-GAAP operating earnings guidance to the upper half of the range at $4 to $4.06 per share, from prior guidance of $3.94 to $4.06 per share. At PSE and G, we invested approximately $1 billion in the quarter and $2.7 billion over the first nine months of 2025. All part of our planned full-year $3.8 billion regulated capital spending program.
This program is focused on replacing and modernizing New Jersey energy infrastructure meeting load growth and expanding energy efficiency programs that lower energy demand and customer bills. During the quarter, Public Service Enterprise Group Incorporated nuclear supplied the grid with 7.9 terawatt hours of reliable carbon-free baseload energy while providing Public Service Enterprise Group Incorporated with the financial flexibility to fund our regulated investment. Our 100% owned Hope Creek unit completed a 499-day continuous run since its last refueling outage and we recently completed work to extend its fuel cycle from eighteen to twenty-four months. Positioning the unit to produce more megawatt hours going forward.
Also during the past quarter, the Board of Trustees of the Long Island Power Authority approved a five-year contract extension for us to continue as the operation service provider for the electric service on Long Island and in the Rockaways through 2030. We are executing on Public Service Enterprise Group Incorporated's growth plan with a focus on operational excellence, and rigorous cost discipline to maintain reliability and provide value for our customers. The need for our investment in leadership has never been more than now. With the significant and growing supply-demand imbalance in New Jersey, and the entire PJM region.
To address this resource adequacy imbalance, which will adversely impact both reliability and affordability for customers in the future if it's not addressed, we are actively collaborating with current and potential future policymakers to develop real solutions in New Jersey and ensure we can affordably meet our customers' energy needs, next governor of New Jersey will be faced with addressing a broad set of rising costs. And implementing practical solutions to get to the root cause of these cost pressures will be a focus.
Carlotta N. Chan: These cost pressures have many sources.
Ralph A. LaRossa: For example, the latest Rutgers Eagleton poll showed that 36% of likely voters cited taxes as the top problem facing New Jersey. While 21% said it was affordability. Other topics trail these two leading concerns. With 6% pointed specifically to housing affordability and 5% saw utility cost as the top problem in the state. We stand ready to work with the incoming administration to do our part to keep rates as low as possible in the short term work on longer-term solutions to add supply. While the supply-demand imbalance remains significant and growing problem, we expect the capacity market impact on customer bills next June will be limited by two factors.
First, the FERC approved price collar that will extend to at least the upcoming capacity auction in December and two, gradualism of the basic generation supply mechanism that feathers in changes over a three-year period here in New Jersey. This assumes other supply-related costs remain the same preserving the reduction of from other charges expected to come off the bill. One energy topic where there is broad common ground is that New Jersey needs to add generation supply to reduce its overreliance on the PJM capacity market and ensuring continuing reliability and affordability for customers with imports having grown to over 40% of our generation consumption.
Legislation has been introduced that allows electric distribution companies to compete to participate in offering supply solutions. We are supportive of legislation that would increase competition for generation supply should New Jersey decide to pursue new in-state generation. In addition, we have sites with grid connection capability and pipeline supplies as well as the in-house expertise to build new supply here in New Jersey with prevailing wage labor. Now turning to Public Service Enterprise Group Incorporated nuclear, continue to implement projects designed to optimize our plants and increase megawatt production.
In addition to the Hope Creek fuel cycle extension I mentioned earlier, our Salem upgrade project will bring an incremental 200 megawatts to the grid during the 2027 to 2029 timeframe, as this kind of baseload carbon-free dispatchable power continues to increase in scarcity value. We also note the potential significance of the recent Department of Energy notice, has now become FERC rulemaking, seeking to accelerate interconnection of large loads in a way that is timely, fair and affordable for customers. The notice is requesting that FERC take final action by 04/30/2026. There are many positive elements to this proposal, but it will take a while before we see the ultimate impact of the rulemaking.
So to summarize, we delivered a solid operating quarter for our customers and our financial results through the first nine months enable us to narrow our full-year 2025 non-GAAP operating earnings guidance to the upper half of the range at $4 to $4.06 per share. From our prior guidance of $3.94 to $4.06 per share. We are also reaffirming Public Service Enterprise Group Incorporated's five-year non-GAAP operating earnings growth outlook of 5% to 7% through 2029 as we continue to pursue incremental opportunities to our long-term forecast including the potential to contract our nuclear output under multiyear agreements potential utility investments to address near-term need for additional supply to the growing customer demand.
Notably, our balance sheet continues to enable us to fund Public Service Enterprise Group Incorporated's five-year capital investment program of $22.5 billion to $26 billion without the need to issue new equity or sell assets and provides the opportunity for consistent and sustainable dividend growth. Before I conclude, I would like to recognize the outstanding performance of both our transmission and distribution system Both demonstrated exceptional reliability and resiliency for our customers. This collective achievement reflects the hard work, dedication and technical expertise of everyone at Public Service Enterprise Group Incorporated. Now as you know, tomorrow is election day in New Jersey. Let me say this clearly.
Public Service Enterprise Group Incorporated has been around for over a century, and we have worked successfully with every New Jersey administration on both sides of the aisle with aligned objectives for the state's advancement. Based on our meetings with both candidates for governor, I have every that we will do so again with the new incoming administration. I'll now turn the call over to Dan, who'll walk you through our financial results and the outlook for the remainder of 2025 and then rejoin the call for Q and A.
Daniel J. Cregg: Ralph, and good morning to everybody. For the third quarter, Public Service Enterprise Group Incorporated reported net income of $1.24 per share in 2025, compared with $1.04 per share in 2024 And non-GAAP operating earnings were $1.13 per share in 2025 compared with $0.90 per share in 2024. We've provided you with information on Slides seven and nine regarding the contribution to net income and non-GAAP operating earnings by business for the third quarter and nine months ended 09/30/2025. Slides eight and ten contain waterfall charts that take you through the net changes for the quarter and year-to-date periods over the prior year and non-GAAP operating earnings per share also by major business.
Let's start with PSE and G, which reported third-quarter net income and non-GAAP operating earnings of $515 million 2025 compared to $379 million in 2024. The utilities results were driven by the implementation of new electric and gas base distribution rates that took effect in October 2024 to recover a return of and on previous capital investments totaling more than $3 billion and higher working capital recovery. Beginning on Slide eight, with the PSE and G column, our distribution margin increased by $0.30 per share compared to the year-ago period. Largely reflecting the impact of the rate case plus recovery of and return on PSE and G's capital investments.
On the expense side, distribution O and M costs were $0.02 per share higher compared to the 2024. And depreciation and interest expense rose by $0.01 per share and $0.02 per share respectively compared to the 2024. Reflecting higher levels of depreciable plant investment and long-term debt at higher interest rates. Lastly, the timing of taxes recorded through an annual rate. Tax rate which nets to zero over a full year, had a net favorable impact of $0.02 per share in the third quarter compared to the prior year period.
Following severe heat storms in June, when PSE and G hit its electric system peak for the year, weather conditions during the third quarter as measured by the Temperature Humidity Index, were 3% cooler than normal and 7% cooler than the 2024. As a reminder, the Conservation Incentive Program, or SIP, program mechanism decouples weather and other economic sales variances from a significant portion of our distribution margin, while helping PSE and G promote the widespread adoption of energy conservation including energy efficiency and solar programs. Under the SIP, the number of electric and gas customers is the primary driver of this distribution margin. And each segment grew by approximately 1% over the past year.
On the capital front, as Ralph mentioned earlier, PSE and G invested approximately $1 billion during the third quarter. Totaling $2.7 billion for the first nine months. Our plan for the full year of 2025 regulated capital investment remains approximately $3.8 billion and our five-year regulated capital investment plan of $21 billion to $24 billion through 2029 is unchanged. In the 2025, PSE and G began deploying their new energy efficiency programs. And we anticipate investing up to $2.9 billion over a six-year period under that program.
This program totals includes approximately $1 billion of on-bill repayment options to help our customers finance their energy efficiency equipment and appliances and provides customers with energy information and options to manage their energy use and lower their bills. Now moving on to PCG Power and Other. For the third quarter, Public Service Enterprise Group Incorporated Power and Other reported net income of $107 million in 2025 compared to $141 million in 2024 and non-GAAP operating earnings were $50 million in 2025 compared to $69 million in 2024. Referring again to the third quarter waterfall on slide eight, Net energy margin rose by $0.01 per share compared to the prior year quarter.
While generation was down in the quarter due to the Hope Creek refueling outage, overall power pricing and market revenues were higher than in the 2024. O and M was $0.05 per share unfavorable compared to the 2024. Mostly driven by the scheduled refueling of our 100% owned Hope Creek nuclear unit. As Ralph mentioned, our Hope Creek unit has successfully transitioned from an eighteen to twenty-four month refueling cycle going forward which is expected to yield additional megawatt hours as well as O and M savings over the long term. Depreciation expense was $0.01 per share favorable and interest expense rose by $0.02 per share reflecting incremental debt at higher interest rates.
And taxes and other were $0 per share favorable compared to the 2024. On the operating side, the nuclear fleet produced approximately 7.9 terawatt hours during the third quarter compared to approximately 8.1 terawatt hours in the 2024. For the nine months ended 09/30/2025, nuclear generation was approximately 23.8 terawatt hours, up slightly from 23.3 terawatt hours for the same period of 2024. Capacity factors for the nuclear fleet were 92.493.7%, for the quarter and nine-month period ended 09/30/2025, respectively. In July, PCG nuclear cleared approximately 3,500 megawatts of its eligible nuclear capacity in PJM's base residual auction at the market clearing price of $329 per megawatt day for the energy year 06/01/2026 through 05/31/2027.
Touching on some recent financing activity. As of the September, Public Service Enterprise Group Incorporated had total available liquidity of $3.6 billion including approximately $330 million of cash on hand And on the financing front, in August, PSE and G issued $450 million of 4.9% medium-term notes due August 2035 And later in August, Public Service Enterprise Group Incorporated redeemed at maturity $550 million of notes that carried a coupon of 0.8%. Overall, Public Service Enterprise Group Incorporated had significant liquidity at the end of the third quarter which remained relatively unchanged from the end of the second quarter.
TCG's variable rate debt at the September consisted of a 364-day term loan at Public Service Enterprise Group Incorporated Power for $400 million which matures in December 2025. And commercial paper. As of September 30, our level of variable rate debt represents approximately 4% of our total debt. And in October, Moody's published updated credit opinions on Public Service Enterprise Group Incorporated PSENG, with no change to either credit ratings or outlook. Looking ahead, our solid balance sheet supports the execution of Public Service Enterprise Group Incorporated's five-year capital spending plan. Dominated by regulated CapEx, without the need to sell new equity or assets and provides for the opportunity for consistent and sustainable dividend growth.
In closing, we are narrowing Public Service Enterprise Group Incorporated's full-year 2025 non-GAAP operating earnings guidance to 4 point to $4.6 per share from $3.94 to $4.6 per share. This updates Public Service Enterprise Group Incorporated's solid results through the first nine months of 2025. And we are also reaffirming our long-term 5% to 7% compound annual growth and non-GAAP operating earnings through 2029. Supported by our capital investment programs and the nuclear PTC threshold. update our rate base and long-term earnings CAGRs and discuss this outlook all during our year-end call in February 2026. This concludes our formal remarks And operator, we are now ready to begin the question and answer session.
Operator: Thank you. Ladies and gentlemen, we will now begin the question and answer session for members of the financial community. May do so by pressing the star and the number two. You're on a speakerphone, please pick up your handset before entering your request. First question is from Shahriar Pourza with Wells Fargo. Please proceed with your question.
Shar Pourreza: Hey, guys. Good morning. Hey, who's that? Hey, Sean. Welcome. Well, welcome back, Sean. Just like we did with many of your peers over the last twelve months, Welcome back. I can hear you. I appreciate. You almost had me tongue tied and that never happened, so I appreciate that. So Ralph, just obviously the elections could be kind of this key threshold for data center deals in the state. We've seen data center customers walk away from local politics issues in kind of both the regulated and even deregulated markets. Artificial Island is obviously it's a great So kind of curious if there is any pressure points forming there?
And then obviously one of your favorite questions is any updates on potential timelines?
Ralph A. LaRossa: Yes. No, thanks, Shore. I'll let Dan, as we have been doing over the last couple of calls here, answer timeline. Conversation. But look, I would say this, and it's it's more of a generic answer to you on the election and what we can expect post Tuesday. And that is we will see. As I said in my kind of my closing comments, we fully expect to be able to work with both sides of the aisle. We've done it in the past. It's a proven track record by this company, and we feel really, really confident that's going to continue. As we move forward here in 2026.
Specific to center opportunities in New Jersey, they really haven't slowed down. We have some information in the deck about how that has continued and we expect it to continue. Few of those jobs have moved a little bit further along in the queue depending upon, whether you look at our queue or PJM's queue as an example and I'll just point you to one that showed up today. It's public information. There's a TEAC meeting that's taking place tomorrow at PJM. And there are some additional load that's been identified for a job in Kenilworth that is our supplement one of our supplemental projects. So they continue to arrive here in New Jersey. We haven't seen a hyperscale level.
And we have talked about that for many times. And we expect these to be smaller, not ones that we're making big announcements about And we don't expect those smaller, less in size announcements to be something that we're talking about whether it's at the utility or at power. Dan, do you want to talk more about the timeline? No. I mean, think Ralph covered it. I think we'll we'll get a little bit more color from both of the candidates who's been a whole bunch of stuff they've talked about during the campaign. This hasn't been the highest topic with respect to data centers as much with respect to affordability generally on things that have touched us.
But we'll get more color as the election ends and we find out where they're gonna go. But in the in the meantime, I think it's everything that Ralph said, and we're continuing to move forward.
Shar Pourreza: Okay, great. And then just lastly, that helpful. And then just on the 11 gigawatts, the large load pipeline that's obviously growing. Just I know I don't want to front run the CapEx update and the roll forward, but let me attempt anyway. But just on the grid capacity, just Dan, talk about Ralph, just the grid capacity that's there to convert those into signed agreements versus how much transmission and distribution needs you're going to have as you start to convert? Thanks.
Ralph A. LaRossa: Well, again, I think a little bit of that is front running some policy. That will exist here in New Jersey, right? So the first and I talk a lot about the fact that the new governor will need to make some policy decisions that will help us plan the grid for the long term. Right now, we have capacity on our grid. That's based upon the current topology. If we see new generation come in large scale, thousand megawatt plants that are showing up, that may change the grid topology a little bit. If we see more solar and more batteries that may change the topology a little bit.
So I'd be front running to say that, you know, I could tell you that, which is why we're gonna give you that full phone roll forward in February.
Shar Pourreza: Okay. Perfect. No. Thanks so much, guys. Appreciate it. See you in a few days. And, Ralph, thanks for remembering me after, the garden leaf. Thanks, guys. Bye.
Operator: Who was that? Our next question is from the line of Jeremy Tonet with JPMorgan. Please proceed with your question.
Jeremy Tonet: Hi, good morning. Hey, Jeremy. Hey. Just wanted to pick up on the conversation with regard to potential data center contracting here. And wondering if you might be able to comment, I guess, on the flavor of conversations between your New Jersey versus Pennsylvania assets. Is there any discernible difference, I guess, in the tone of those conversations?
Daniel J. Cregg: I wouldn't say difference in the tone of conversations, Jeremy, but I think that you're seeing different types of entities being involved between the two states. I think you have more of a forward-leaning appetite in Pennsylvania which is enabling more to happen and more to happen on a bigger scale. And I think in New Jersey, have not seen that as much with respect to the incentives so what you're seeing is still some interest in the state and some sizable interest in the state. But at a smaller scale. So I think that's probably the biggest differentiation between the two locations.
Jeremy Tonet: Got it. That's helpful. Thanks for that. And as it relates to, I guess, supply additions and working with stakeholders in state, just wondering if you might be able to expand a little bit more beyond that, I guess, far as what type of constructs, Peg will be interested in, be it, you know, regulated generation, unregulated generation, or just any other color in general on, this topic?
Ralph A. LaRossa: Yes. So Jeremy, it's a great question. Look, we have said for many months, we have indicated in public settings that are more than willing to help the state achieve its goals in a regulated capacity. Right? We know we absolutely think that we could provide some solutions for gas generation that's in a regulated manner. We also think we can continue. We've done large scale solar on some brownfield sites, some landfill sites, the past. So we could do more on the solar front We think there's an appetite now for some regulated storage and we're looking forward to taking part in that. See how that plays out over the next few months.
And we know that many both candidates have been talking a lot about, new nuclear. Now on new nuclear, we have also been very, very pointed in our responses in saying that we're not looking to put our own capital work but we want to enable solutions for the state. And that's where our site comes in and we think that long term that'll provide us with some great some revenue opportunities whether it be for you know, our operating and maintenance activities or security activities, you know, spent fuel storage. There's many, many things that we can do on that front without putting our own capital to work. And so that's that's the way we've been approaching it.
And that's the way we'd like to see things play out. More opportunities for us in baseload generation from a gas standpoint that would be regulated. And certainly more we can do on the solar and the battery fronts as well. And I think if you look at both candidates and their platforms, you really see, you know, one they're all they're they're both talking about everything. Right? They're at all these options that are out there. The real question is to what degree? And I think you will see one with one candidate that might be leaning a little more towards the gas fired units and another candidate that leads a little more towards solar and batteries.
But both candidates are talking about in the all of the above strategy, which we support and we will be part of.
Jeremy Tonet: Got it. That's, very helpful. Thank you.
Operator: The next question is from the line of Nicholas Joseph Campanella with Barclays. Please proceed with your question.
Nicholas Joseph Campanella: Good morning. Thanks for taking my questions. How are you, Nick? So I hey. I'm good. Hope you're doing well. So look. Just the contracting discussion you know, we did see the multistate kind of proposal advocating for bring your own generation. And the need to kind of fast track and permit fast you know, fast track the permitting for some of these data centers, but there just seems to be an overall stress on bring your own generation across the states in PJM. And how is that causing the conversation around the nuke to evolve? And is it fair to say that any deal at this point now have to come with additionality commitments?
Whether that's upgrades, new gas, batteries, or otherwise, just you know, maybe you can kinda talk to that a little bit if that's the right take.
Ralph A. LaRossa: Yeah. Are you talking about the DOE? Nick, in that The DOE letter from the DOE. Oh, I'm just so I think there's just been various calls by whether it's in Pennsylvania, New Jersey, or, you know, Maryland, on just the need to, to for data centers to bring their own generation now. And I'm just wondering how that impacts incumbent generators that were you know, interested in, you know, potentially signing front of meter deals.
Daniel J. Cregg: Yeah. Nick, I would say that if I'm capturing your question, right, that there has been more dialogue around it There has not been anything from the standpoint of requirements related to what must happen. And so I think from that perspective, I think it almost does tie in a little bit to what Ralph is talking about with respect to the DOE letter. Which is trying to set some standards and trying to I would say, fast track things, but get things moving where there is a little bit of a log jam. There's been a discussion about a whole host of topics BYOG is one of them. But there's nothing that's mandatory from that perspective.
There's nothing about additionality that's mandatory from that perspective. And different counterparties have different environmental profiles that are important to them. Not against the backdrop of anything that is required either. So I think what you're seeing is continued dialogue around some topics that are of interest. Are not precluding anything from happening one way or another.
Nicholas Joseph Campanella: Okay. Alright. I appreciate that. And then, you know, there's been a lot of EPS CAGR updates this quarter. And you know, I guess maybe you can kinda help position to the street. You know, you're doing nine and a half percent year over year growth. 25% through '20 off of, '24. I see that on slide five. I know the past five to 7% CAGR, that's not linear. But just from our perspective, you know, we know where the capacity auctions have cleared at. We know where prices have gone.
Just what are some of the negatives that we should be thinking about that kind of put you back within the 5% to 7% range as we kind of think through what you can deliver on in '26?
Daniel J. Cregg: What I would tell you is our update is coming in February and we're not gonna piecemeal elements of it before we get there. So we'll give you a fulsome update when we give you the
Nicholas Joseph Campanella: No problem. Thank you.
Ralph A. LaRossa: Thanks, Nick.
Operator: The next questions are in the line of David Keith Arcaro with Morgan Stanley. Please proceed with your question.
David Keith Arcaro: Hey, thanks so much. Good morning. Hey, David. One quick clarification or maybe additional piece of data. Was just wondering what the level of mature applications would be in that data center activity that you've quoted in the past?
Ralph A. LaRossa: Yes. So I think we moved that from 2,600 to 2,800. Awesome. Got it. I think that's the information that's in the deck. Thanks for that. And then That's the right number. 2,600 to 2,800. Great. Okay. Perfect. And then as you sketch out the utility growth outlook, and roll forward, I was just curious if you give your perspective now on how do you manage the affordability concerns, maybe outside of just the generation front as you're planning the next iterations of your utility CapEx programs and looking at the T and D rate outlook, how are you weaving in just considerations around affordability?
Ralph A. LaRossa: Well, look, we always think about affordability no matter what we do here from a company standpoint. Whether it's, you know, I could point you to our o and m slides that are in the deck. And how we've held O and M relatively flat over a longer period of time. I could talk to you about know, the way we're implementing our AMI system right now and how we've done that. Not only from a standpoint of cost and keeping rates down, but also from, you know, the impact on employees and the just transition of those folks into different positions. So affordability is not something new to us.
I appreciate it's a it's a harder topic in different circles. But it's the way we've operated. And you've heard us many times talk about the fact that we're making any big announcements about expense savings. We normally just operate in that manner and we'll continue to do that. That said, we've also in the past worked through different mechanisms with the regulator to spread costs out differently. And I'll I'll go back twenty years when the decision was made to change the depreciable life of our gas assets. And that cost was recovered in a different way from customers.
So there are things that we can do working with the regulator to come up with solutions to keep T and D rates flat. We've done that recently. We'll continue to look at options for that. But this is not just an affordability issue. Right? This is quickly becoming a reliability issue. And the resource adequacy is going to drive us to solutions that are going to increase supply as the demand comes online. We have to find supply David, I don't any other way to say it. And I think both of the candidates for governor in New Jersey recognize that. They've both said that.
Again, their solutions might be a little bit different, but how we get there is the only It's not if we're gonna get there. We need more supply in the state.
David Keith Arcaro: Great. Yeah. That's really helpful color. Much appreciated, and see you soon.
Ralph A. LaRossa: Thanks, David.
Operator: The next question is from the line of Bill Appicelli with UBS. Please proceed with your question.
Bill Appicelli: Hey, good morning. Hey, Bill. Just following up on some of those comments you just made about finding supply. I mean, there would be sense of urgency, I think, behind that, right? Is there an opportunity here in the veto session to push for some legislation that could support this? Or do you think this is more likely something that has to be dealt with under a new administration? Look, there's been a lot of things that have happened in state in the past, not just from an energy standpoint, but other topics that have been handled in lame duck And so I'm not sure whether or not that'll be the approach that's taken here.
Or will be one that's taken in '26. But I do know it's gonna be a hot topic. One way or the other. And so I personally would like to see us move faster, from a state standpoint. I think it would help us you know, both from an affordability standpoint, but also from an economic development standpoint. We as I mentioned earlier, you know, we've been we've some headroom in the in the system today, and we've been using that up. If we're gonna continue to grow this state, and, again, both candidates would like to see us continue to grow the state, then one of the fundamental things we'll need is enough supply.
And that's where I put my economic development hat on, and I say, let's get moving sooner than later. And well, if we could have those discussions starting on Wednesday, it couldn't be soon enough. Right. And then just, you know, along those same lines, I mean, how do you evaluate know, the framework for that? Right? Would this be, you know, in terms of evaluating how much generation you potentially would need from a regulated basis? Would there be sort of an RFP approach that you could then bid on? I mean, I'm not sure if you guys could sort of describe how you would envision such a mechanism coming out. Yeah.
I look, I think that the BPU could hold some sort of an auction. I think we could go to some sort of an FRR think, again, I don't want to front run anybody. I think it'd be rude to do that. So I won't. But I will tell you, it all starts with the same four questions that we've been banging the table about, right? One, we've got to figure out what load we're going to supply. Right? We gotta figure out what the reliability targets are gonna be. Three, it's gonna be emissions. Right?
And what are the emissions profiles we're willing to accept both if we're in a build our own generation or import it from our neighbors. Both of those have different impacts and how that plays out. And then the last thing is the definition of affordability. We talk about affordability but we rarely define it, whether it's at the state level or at the, at federal level, to be honest. Is it going to be CPI, is it going to be regional CPI, it going be state CPI, what is it going to be? And I think as we move forward answering those four questions is fundamental to putting together an integrated resource plan.
Bill Appicelli: Got it. And then just lastly on the outlook for the forward curves, I mean, can you maybe just speak to where you see those relative to maybe your fundamental view or at least relative to where the PTC floor is that's embedded in your outlook? Yeah. I'm going to let Dan answer that one. He sees that a little bit more, but I mean, we look out four years the way others do. So I'll give it to you, Dan.
Daniel J. Cregg: Yes. Bill, I think you've seen some recent strength within the market and we've been saying for some time that if you just think about all the fundamentals that are going on in the discussion that everybody's having, it's been pretty tough to try to you know, land a plan on exactly what's gonna happen from a load perspective. But the numbers are a little bit staggering. And so even a lower end of the range would imply a need for incremental supply. And then if you think about the supply discussions, those have always moved towards the concept of we need to move quickly because at the end of the day, generally, it's gonna come out all that fast.
These think about time for turbines and everything else. And so all of that leads you to a little bit of a more bullish place. If you look out the forward curve, haven't seen quite as much bullishness. We've seen some of that come up. I think that feels a little bit more like a fundamental move than just some interim period of time. Although, we do end up having some of those too. It seems like every time we go into winter and we get a cold day, you see a little bit of movement out the curve. But I do think fundamental should support a stronger price as we go forward, but the forwards are the forwards.
Bill Appicelli: Okay. Great. Thank you.
Daniel J. Cregg: Yep.
Ralph A. LaRossa: Thanks, Bill.
Operator: The next question is from the line of Nick Amicucci with Evercore ISI. Please proceed with your question.
Nick Amicucci: Hey, good morning guys. Hey, Nick. I think you get a I think you get a welcome as well. I think this is our first quarterly call with you. Asking a question. Oh, well, thanks. I appreciate that. I just wanted to dig into a little bit on Hope Creek, just kind of the extension of the fuel cycle there. Kind of what undertakings were done? I mean, was that kind of a an enhanced fuel offering or how should we kind of think about that? Is there opportunities to kind of extend that even further? Yes. No, Nick, it really is a lot simpler people might make it out to be.
It's just shuffling of the fuel, some different changes in the fuel design, but we didn't change a new fuel supplier as a result, right? So this is something that's been done in the quite a bit. And we joked a lot about it. We had a CFO that always gave us a hard time about doing upgrades at a plant that we only had a visibility for three years of a life for. But he did his he did the right thing and held us accountable to a little longer term life before we made long term investments.
So while Dan did that, were getting smart about the changes that we could make there and we're following what the rest of the industry has done. I will tell you though, we also at the same time did a lot of other things at that plant to continue to reinforce both the asset itself, but also some efficiencies.
And talk about things that you might not pay attention to, but we changed out some of the insulation in cooling tower which just changes the efficiency of that of the cooling tower, and it just allows us the draft that the cooling tower is going to increase, which allows you to keep the megawatts up in the middle of the summer when at other times the heat and humidity might reduce the draft flow through that stack. So were looking all the time for it. And in that case, no big announcements, but I know we're running more efficiently in the summer months which by the way is the same time we have the higher prices, right?
So lots of different things that we're doing down there and, team's doing a nice job for us in identifying those opportunities. But specific to your question, on the fuel, not a big not a big change compared to what others have done in the industry, and no real opportunity at Hope Creek to make that an additional change. But maybe at Salem. And I know there are some operators that are looking at move from a twelve to eighteen year cycle at PWRs. The VWR sorry. Eighteen to twenty-four months. The PWRs is what we just did at Hope Creek.
Nick Amicucci: Great. Thanks. That's all I got. Thanks.
Operator: The next question is from the line of Paul Cimbardo with Jefferies. Please proceed with your question.
Paul Cimbardo: Good morning. Good morning, Paul. I don't. Thank you. Dan, just to follow-up on the conversation on the forward curve. Obviously, there's been a pretty big move even as of late. Could you share some light on kind of what the hedging profile looks like at Power for the next few years? And just if there's been any change changes, I know we had the nuclear PTC a little bit ago, just any overall thoughts you could give in the positioning would be great. Thanks.
Daniel J. Cregg: Yes. And Paul it isn't much and it's not very different from the characterization that we provided in the past. I mean, said we were historically, this goes back pre PTC to a fairly ratable three-year hedging cycle The PTC changed that because if you're taking a look at a overall hedging portfolio that you're trying to manage risk with, you have a risk protection from the PTC. So we said we varied from that a little bit because of the PTC. But the way we've described it is just not radically different from that ratable method. And I think if you think about it generally in those terms, you'll in the ballpark of where we are.
And that's how we've been describing it and I think that's still a good way to describe it for you.
Paul Cimbardo: Okay. That makes sense. And then on the capital refresh, just to make sure I understood correctly, It sounds like you will have kind of a bigger capital refresh when we do that fourth quarter roll forward. Is that a fair interpretation? Or do you need some of that political and regulatory clarity and just it's not fourth quarter event, but sometime later in 2026? No. We will be doing a normal roll forward of everything on our fourth quarter call. I think that's the simple way to think about the message.
Paul Cimbardo: Okay. Thank you, team.
Daniel J. Cregg: Yep. Thank you.
Operator: Thank you. Next question is from the line of Carly S. Davenport with Goldman Sachs. Please proceed with your question.
Carly S. Davenport: Hey, good morning. Good morning. Thanks for just one quick one for me on the utility side. Just as you get towards kind of the end of the GSMP to extension period, Can you just share sort of the latest there and discussions about refreshing that program as we near 2026?
Ralph A. LaRossa: Yeah. We're continuing to have those discussions, Carly. And I wouldn't again, I won't wanna front run any of that. It's taking place right now. But we're in we're in continuous negotiations and are ongoing with the BPU.
Carly S. Davenport: Okay. Got it. Great. I'll I'll leave it there. Thank you.
Ralph A. LaRossa: Thanks, Carly.
Operator: Thank you. The next question is from the line of Anthony Crowdell with Mizuho. Please proceed with your question.
Anthony Crowdell: Hey, good morning guys. Thanks for squeezing me in with all the welcome greetings. Anthony, I my only question was am I welcoming you to the devil's bandwagon? It's a big question. We'll we'll talk about I'm it. I agree. I'm on it. They much better than my Rangers. I guess two questions. One is I'm sure you guys have met with both candidates. When they talk about affordability, do you think they're focused on the supplier generation side or the wire side? Do they understand the differences in the PGM impact versus just investing in the grid infrastructure? And then I have a follow-up. Yes. No, Anthony, question. They absolutely understand the difference.
They also understand that the customer gets one bill. And so what we need to we need to work together with whoever is successful is working on that one bill. And so that's why we keep talking about supply. It's not our traditional lane. We're here to help on that. But we are really pounding the table about the integrated resource plan. No matter what happens going forward. Because without that, we'll we'll just continue to flounder. We lived on the backs of some capacity in the area for quite some time, and now we have this challenge here. But I don't I don't wanna at all give anybody an indication that either candidate doesn't understand the issue.
They absolutely understand the issue. And they know where they know where it is.
Anthony Crowdell: And then the follow-up, kind of the same topic. You your company is the only company with both you know, wire PJM wires exposure, but also merchant generation PJM. And as we're all looking for, whether it's a data center contract or a large load customer contract, Is it possible that both segments of your business the wires company and the generation given the backdrop of affordability and everything else, that they actually both could win or outperform at the same time The worry is when you see this election going on and that a very high attractive price on a generation if something came about on a data center or any type of large contract.
Would actually hurt the wires business or vice versa. I'd just leave it there.
Ralph A. LaRossa: No, it's a very fair question, Anthony, but it's one that we think about every day because we're at the end of the day, hired by the shareholders and that's where our heads at. And we do think that there's continues to be an opportunity to you know, benefit from having both of the assets. I'll say it in that term from a generation standpoint and from a utility standpoint, I think it's showed up in the way we've been able to finance the utility. That was the reason we originally talked about holding on to nuclear. It helps us in the state and conversations. Helps us with our unions. Having a common union there.
So just to remind everybody that is key. But we are laser focused on added value for the shareholder and we're trying to look at that balance every day to get that optimization. So I think there is a win-win. And how it how it plays out will be based upon a lot of different factors over the next couple of years here.
Anthony Crowdell: Great. Thanks for taking my questions. Newark gets some air traffic controls, we'll see you down in Hollywood.
Ralph A. LaRossa: Alright. See you then. Thanks, Jeff. Thank you.
Operator: Our last question is from the line of Andrew Weisel with Scotiabank. Please proceed with your question. Hey, good morning, everybody. Thanks for including me.
Andrew Weisel: Good morning, Andrew. First question is on the balance sheet. You've obviously long touted the strength of that and the lack of need for external equity. I am expecting in a few months, we'll see a pretty sizable increase to the capital plan. Maybe how are you thinking about that at this point? I don't expect specifics, but are you thinking that you'll be able to continue to say no equity?
Ralph A. LaRossa: Look, think I'm gonna start off and give it to Dan the way I've I've talked about this quite a bit. Both Dan and his predecessors have handled our balance sheet extremely well, and I don't I don't think any of that's going to change as we have more opportunities in front of us. And Dan can give you any more he wants to do there. Yeah. And there's not a lot without going into what we would be saying in the fourth quarter. I think we've been able to manage the business pretty well and manage the needs that we've had pretty well. And I think we're continue to be able to do that.
We'll we'll provide the fulsome roll forward in the fourth quarter, which will include capital, rate base, and overall earnings growth.
Andrew Weisel: Okay. Great. And Next on affordability, obviously, it's been talked a lot about today, and I can't watch a World Series or football game without being reminded about it. But one, different approach I wanna maybe think about is, obviously, no one likes seeing their bills go up and it's been a real hard slog to get new supply added. But New Jersey is a pretty wealthy state overall. How are you thinking about it in terms of not only overall affordability, but focusing on low and lower income customers. There's a lot of existing programs and talk about expanding or adding new programs.
Is that maybe a different strategy that maybe could be pursued both by you and the state overall?
Ralph A. LaRossa: Yeah, no, it's again, very good question. It is absolutely something I think it will depend upon who is successful. And how this plays out. But know, both candidates talk about how they have to look at things a little bit differently dependent upon the customer or in their case, the taxpayer that they've that they're taking care of. So, we have done that in the past Andrew. And I'm I'm gonna give you one example here where, you know, Kim Hanuman and her team at the utility reaches out all the time.
And we're doing analysis over the past week just to try to see where things might play out from a snap standpoint and the impact on our customer base. And we identified about 500,000 customers that could be impacted in how we could think about those customers and making sure that we take that into account as we are in a shutoff period now for collections and how that's all handled. So our team looks at that level of detail on a regular basis and very proud of them for doing that. And I think that, at the end of the day, brings us a lot of, goodwill in the state.
Not only from our customer base, also from our policymakers. Wanna add anything to that? Andrew, I think the only other thing I would add is we show a percent of wallet slide in our in our decks we have for a long time. And if you take a look at that slide, there's actually two lines on that. One of them is for the average customer. One of them is for a lower income customer. And given the lower income and given the share of wallet, you would think that it would be a higher percent of their income given the fact that the denominator is lower. And in fact, it's not.
And that, I think, is a credit to the programs that are in place and the things that are done throughout the state and that we do ourselves to help some of those that are most in need. So that is always a focus and will continue to be as we go forward.
Andrew Weisel: Great. Yep. I appreciate how much you guys have been proactive on that front. One last one, if I could, just on the large load inquiries. Pretty significant pickup there to 11.5 gigawatts. Can you detail how much of that is data centers versus manufacturers? And then just very roughly the timing of the ramp-up schedules, how much of that is kind of 2627 versus the outer years, like, 09/30, or beyond?
Ralph A. LaRossa: Yeah. No. I don't have the level of detail on each of the years for you. So I don't I don't I wouldn't have that. But it is mostly data centers. I would say almost exclusively data centers in that. Number. There were some electric vehicle loads that were coming on that has not stayed up at the same level. So it's everything but it's also edge computing. More than it is hyperscalers. Again, just to reinforce that point, And I think the other thing that's really telling about the load and the interest is coming in, it's all sticking to around that 20% number that's actually coming to fruition, which we had talked about three or four calls ago.
We thought that was going to be the way this would play out and it's shown itself in the numbers as the total inquiries come in. Those that are actually moving to new business are staying around 20%. So again, of the team and the forecast that's been done there and give you a little bit of a more flavor than maybe just looking at the two numbers.
Andrew Weisel: Very good. Thank you for all the info.
Ralph A. LaRossa: Thanks, Andrew.
Operator: Thank you. Ladies and gentlemen, I'd like to turn the floor back over to Mr. LaRosa for closing comments.
Ralph A. LaRossa: Well, thanks. I got I have a plan comment. I'm going to add another one. I was told by Carlotta today that this is Dan's tenth year as CFO, and so you're fortieth call Dan. So congratulations on getting there. I must be exhausting exhausted. You must be. But listen, all joking aside, we said a lot of thank yous and good luck to people moving into new roles and no place is that more important than in Trenton as we go through the next week. It's been a it's been a heck of a campaign. All the polls are saying it's close. We'll see how this plays out.
But what will not be close is our ability to work with whoever is successful. We stand ready. About rolling up our sleeves, we'll roll up our sleeves, our trousers, whatever else we need to do to make sure that we are here to help out and we're ready to work. So good luck to both candidates as they enter the last twenty-four hours of the campaign. And I look forward to seeing you all in Hollywood, Florida in the next, seven days or so. Take care.
Operator: Ladies and gentlemen, this concludes today's teleconference. Disconnect your lines at this time, and thank you for your participation.