Exelon Corporation

Hello and welcome to Exelon's third quarter earnings call. My name is Gigi and I'll be your event specialist today. All lines have been placed on mute to prevent any background noise. Please note that today's webcast is being recorded. During the presentation, we'll have a question and answer session. You can ask questions by pressing star 1 1 on your telephone keypad. If you would like to view the presentation in a full screen view, Click the full screen button by hovering your computer mouse cursor over the PowerPoint screen. Press the Escape key on your keyboard to return to your original view. And finally, should you need technical assistance, as a best practice, we suggest you first refresh your browser. If that does not resolve the issue, please click on the Help option in the upper right-hand corner of your screen for online troubleshooting. It is now my pleasure to turn today's program over to Andrew Plenge. Vice President of Investor Relations, the floor is yours.

Thank you, Gigi, and good morning, everyone. Thank you for joining us for our 2025 Third Quarter Earnings Call. Leading the call today are Calvin Butler, Exelon's President and Chief Executive Officer, and Jean Jones, Exelon's Chief Financial Officer. Other members of Exelon's Senior Management Team are also with us today, and they will be available to answer your questions following our prepared remarks. Today's presentation, along with our earnings release and other financial information, can be found in the Investor Relations section of Exelon's website. We would also like to remind you that today's presentation and the associated earnings release materials contain forward-looking statements which are subject to risks and uncertainties. You can find the cautionary statements on these risks on slide two of today's presentation or in our SEC filings. In addition, today's presentation includes references to adjusted operating earnings and other non-GAAP measures. Reconciliations between these measures and the nearest equivalent gap measures can be found in the appendix of our presentation and in our earnings release. It is now my pleasure to turn the call over to Calvin Butler, Excellence President and CEO.

Thank you, Andrew, and good morning, everyone. We are happy to have you with us today for our third quarter earnings call. As we reach the last months of 2025, the 25th year since Excellence founding, our employees continue to execute with excellence, serving our customers communities, and shareholders. We reported earnings of 86 cents, which was stronger than anticipated due to slightly warmer weather and a mild storm season, along with timing-related drivers. We continue to reaffirm our operating earnings guidance for 2025 of $2.64 to $2.74 per share, and we look forward to closing out the year strong. We also continue to deliver some of the best operational performance in the industry. In fact, We now have the final results of our reliability benchmarking for last year, and our four utility operating companies are ranked one, two, four, and seven out of our peer set, improving upon last year's already stellar one, three, five, and eight rankings. I could not be prouder of the way our employees show up every day whether it's selecting, planning, and operationalizing the right investments to avoid outages or being the fastest to get customers back online if the power does go out. This performance has real value, particularly when you consider that a typical major storm can cost hundreds of thousands of dollars for the average customer, depending on its size. Our operational North Star is to continuously improve upon this performance, offering above average performance at below average rates to the communities we have the privilege and honor of serving. Results like that show we're living up to that standard. As it pertains to rate cases, we remain on track for our gas distribution rate case at Delmarva Power and our Atlantic City electric rate case. We also filed a rate case at Petco Maryland with the decision required per statute by August of 2026. The filing supports the company's commitment to delivering safe, reliable, and resilient service while further preparing the local grid for future clean energy demands. Our filing also demonstrates true focus on customer value, reflecting strong O&M cost containment and robust projected benefits from specified reliability investments that significantly exceed their cost. Outside of rate cases, We have seen more progress in our states and at PJM when it comes to advancing solutions to meet the growing need for reliable and resilient power. Last week, Illinois passed the Clean and Reliable Grid Affordability Act, which directly supports resource adequacy by expanding the annual budget for energy efficiency, broadens the types of assets eligible for the distributed generation rebate, and creates an energy storage procurement plan. It also requires the Commission and other state agencies to develop four-year integrated resource plans and gives the ICC discretion to facilitate transmission projects that support state goals. This marks the next chapter in Illinois energy transition, and we look forward to working with policymakers on implementing this next set of programs. In Maryland, the commission initiated a request for merchant generator proposals for up to three gigawatts of new energy supply. The process attracted several submissions. Though the disclosed capacity levels have fallen short of their target, and we will learn in December which of those projects the Maryland Department of Natural Resource Power Plant Research Program might recommend. And PJM is working through its critical issue fast path process for options to better accommodate new large loads. assisting our states as they navigate unprecedented levels of growth. We are encouraged by the breadth and amount of engagement in that process, and we look forward to finding solutions that ensure customers can rely on cost-effective power supply. And as we have stated, these efforts are welcomed and necessary, but they are not enough. There is a significant anticipated shortfall in supply and hoping that markets alone will fill its will fill it puts too much risk on customers that increasingly depend on affordable supply to power their lives. All states need to leverage all available options to bring control, certainty, and customer benefits to securing power. These options help ensure that all customers continue to have reliable access to energy and that the states can participate more fully in the economic development opportunities from artificial intelligence and onshoring. The supply challenge is real, and we know utilities can be a key partner in helping the state solve it, whether it's supporting investments in the demand side like energy efficiency, distributed and community solar and storage, or even owning more traditional generation plants. We stand ready to work with our states as they seek opportunities to address growing energy security needs in a manner that fits their goals. The demand for power is not slowing down. Our large load pipeline now stands at over 19 gigawatts as we have finalized our cluster study approach and now account for our first transmission security agreement at PECO. The innovative TSA approach ensures we strike the right balance in prioritizing large loads while ensuring our existing customers are protected. Furthermore, we now have at least 27 gigawatts either waiting Signed TSAs are in active cluster studies, with many more behind those. Additional details on our large load outlook can be found in the appendix. Connecting new business is expected to be just one of the drivers of the anticipated growth in transmission investment in our next four-year plan. This new business will also drive broader needs for the grid, which get identified in reliability assessments like PJM's open windows. and it helps drive inter-RTO opportunities like MISO Tranche 2.1 segment running through ComEd's territory. We will be monitoring the recommendations coming out of PJM's latest open window over the next three months to determine if any of the solutions we have proposed, either individually or with partners, are selected. With no project greater than 3% of our four-year plan we are focused on bringing all of our customers along at the appropriate pace, while also ensuring we can earn a fair return of 9% to 10% on the equity capital provided by our investors. With rate-based growth of 7.4% through 2028 and a balanced financing plan, we expect to grow our earnings at an annualized rate of 5% to 7%, with the expectation of always delivering at the midpoint or better of that range. I will now ask Jean to cover more details on our regulatory updates and financial performance.

Jean? Thank you, Calvin, and good morning, everyone. Today I will cover our third quarter financial update along with our financial and regulatory outlook for the remainder of 2025. Starting on slide five, we present our quarter-over-quarter adjusted operating earnings blocks. Exxon earned $0.86 per share in the third quarter compared to $0.71 per share in the third quarter of 2024, reflecting higher results of $0.15 over the same period. Earnings are higher in the third quarter relative to the same period last year, driven primarily by $0.12 of higher distribution and transmission rates, net of associated depreciation, and $0.06 associated with the ability to seek deferral treatment of the Pico extraordinary storms earlier this year and favorable storm conditions at BGE. This favorability is slightly offset primarily by interest expense. These results are ahead of the expectations noted in our prior quarter call, primarily due to better than normal storm conditions, timing of O&M spend, and tax timing at PICO. As we close out the year in the fourth quarter, we remain on track to achieve operating earnings of 264 to 274 per share with the goal of delivering at midpoint or better. Our fourth quarter guidance assumes the reversal of timing, including O&M, distribution earnings at ComEd, and PICO taxes. Fair and reasonable outcomes for open rate case proceedings, including reconciliations at BGE, PEPCO, Maryland, and ComEd, and normal weather and storm activity. Finally, we reaffirm our annualized operating earnings growth rate of 5 to 7 percent through 2028, with the expectation to be at the midpoint or better of that range. Turning to slide six, I will now review the regulatory activity across our platform. Starting with the base rate case activity, we continue to make progress on the Delmarva power gas distribution rate case filed last September, with the final settlement conferences held in October. As a reminder, the filing seeks to recover reliability investments, such as aging pipe replacements, and it also seeks recovery of LNG plant upgrades, which would protect customers from price volatility during peak periods. We anticipate an order in the first quarter of 26. At Atlantic City Electric, settlement discussions continue as we seek recovery for grid improvements and modernization investments in line with New Jersey's Energy Master Plan and the Clean Energy Act. We continue to anticipate an order by the end of the year. Finally, on October 14th, PEPCO filed an electric base rate case in Maryland, requesting a net revenue increase of $133 million, utilizing a fully forecasted test year. The request supports key infrastructure investments to modernize aging infrastructure and improve reliability while also supporting Maryland's clean energy goals. As part of the filing, PEPCO, through an independent firm, found that $38 million of investments generate nearly $262 million in benefits to customers through avoided outage and restoration costs as well as avoided O&M expenses over the next 20 years. The filing also offers a suite of programs and resources that help manage rising energy costs increase awareness of energy usage, and provide direct assistance to those who need it most. Per statute and orders expected from the Maryland Public Service Commission in August of 2026. Beyond base rate cases at ComEd, we remain on track for our first reconciliation under the new multi-year plan framework, where we continue to robustly support the spend submitted for reconciliation throughout the final briefing process. An ALJ proposed order is expected later today, and the ICC will issue a final order by December 20th. In Maryland, we continue to await decisions on our final reconciliations from the first BGE and PEPCO Maryland multi-year plans, along with the Commission's order on the lessons learned proceeding to support future filings. We look forward to moving forward with an approach that best aligns stakeholders' interests in balancing affordability, reliability, and the state's economic development and energy policy goals. Finally, turning to slide seven, I will conclude with updates on our balance sheet activity. where we've continued to de-risk our financing plan and ensure cost-effective capital to invest for the benefit of our customers. In September, PICO issued $1 billion in debt, completing all of our planned long-term debt issuances for the year. The strong investor demand and attractive pricing we've achieved in our debt offerings is supported by the strength of our balance sheet and by the low-risk attributes of our platform. We continue to seek opportunities to take advantage of current market dynamics to de-risk our plan. This includes utilizing our pre-assurance hedging strategy and pricing future equity needs to settle through forward agreements under the ATM, reducing interest rate and share price exposure. Through the third quarter, we have priced nearly half of our equity needs through 2028, including all of our annualized equity needs in 2025 and $663 million, or 95% of our 2026 annualized equity needs, which we expect to settle next year. In line with our last earnings call, we continue to project 100 to 200 basis points of financial flexibility on average over the Moody's downgrade threshold of 12%, approaching 14% at the end of our guidance period. We also continue to advocate for language that incorporates all tax repairs for calculating the corporate alternative minimum tax. As a reminder, favorably addressing all repairs in the minimum tax calculation would result in an increase of approximately 50 basis points in our consolidated credit metrics on average over the plan. Thank you, and I'll now turn the call back to Calvin for his closing remarks.

Thank you, Jean. As we approach the end of our 25th year as Exelon, we are working to add to our legacy of excellence, delivering on our commitments to our customers, our communities, and our investors. Many of you may have seen us ring the opening bell at NASDAQ last month, and I was honored to represent our company alongside some of our longest-tenured employees. Standing next to me were just a few of our more than 2,500 employees who have been with us and our local energy companies for 25 years or more. Our operating companies have over 800 years of collective experience delivering energy to customers provided by dedicated employees who keep the lights on and the gas flowing day in and day out, no matter the conditions. And they are the reason our utilities are ranked as the best or among the best in the business for reliability. They also can't do it without smart, targeted investments in our grid. It's why 98% of the net profit earned at our utilities generated with fair returns on the shareholder dollars entrusted with us have been reinvested back into the system over the last five years. Those investments not only deliver top-notch service, they also boost local economies. With every $1 million creating eight jobs, or $1.6 million of economic output. So we don't take this performance or the responsibility of supporting our communities for granted. And we know it will take continued discipline to ensure that we can provide high levels of service at below average prices for another 25 years and beyond. We will continue to advocate that our jurisdictions provide fair recovery for our investments with the expectation that service remains high, that we treat all users of the grid fairly and equitably, and that we put our customers first. Our priorities this year do just that, ensure we earn that right to provide our customers top-notch value every day. For example, We continue to focus a dedicated team on pulling cost out of our business to keep cost growth below inflation. We push our business lines to work smarter and leverage technology, providing better service at lower cost. We advocate for rate-making constructs that ensure we can plan, invest, and operate as efficiently as possible, benefiting from alignment and forward-looking planning. We continue to support and leverage customer assistance programs like LIHEAP and to advance rate designs that support the customers who need it most. And we advocate for fair policies that can equitably serve growing load while instilling greater confidence in resource adequacy. That includes developing our innovative TSA approach, which we have filed for our first customer with FERC and are proposing as part of tariff adjustments at ComEd. And it's why we're increasingly advocating that our jurisdictions take more control over their power supply. They can complement supply induced by better designed markets with solutions like utility-owned generation that regulators oversee, giving them control, certainty, and cost benefits for customers that markets alone don't offer. We look forward to closing out 2025 strong. earning an ROE aligned with allowed levels in the 9% to 10% range, and delivering against our guidance of $2.64 to $2.74 per share, always with the goal of midpoint or better, while maintaining a strong balance sheet. There would be no better way to celebrate our 25th year's Exelon and further cement our foundation to deliver consistent growth and long-term value for another 25 years. Gigi? We are now ready for questions on the line.

Thank you. If you would like to ask a question, simply press star 1-1 on your telephone keypad. Our first question comes from the line of Char Purezza from Wells Fargo.

Char, good morning.

Good morning, Calvin. How are you doing?

I'm good, man. Welcome back.

Appreciate it. Luckily, there's no news flow in this space, and it's been kind of relaxing.

That's just our way of saying we missed you.

Yeah, I miss you, too. I miss you, too. So, Kevin, just obviously resource adequacy was very topical in your prepared remarks. Maybe just starting with Maryland... Just your broad thoughts around the RFP. I mean, you've been out there talking about regulated solutions to solve the needs there, and now Constellation just came out with their own solutions, ironically, this morning. Can we just get a sense on how you're thinking about the process, the timing, and then your views on sort of these competing options that were proposed this morning? Thanks.

Thank you, Char, and appreciate the question. Let me first begin by saying, that we commend the state of Maryland for initiating the process. And while we appreciate that they received some responses, our view is that they fall short of what's needed for the state and for PJM more broadly. Having said that, we're happy to see that several parties stepped up and actually talked about adding supply. Let's be clear, this is all about solving the problem and bringing energy costs under control for our customers. And that's what we're focused on, affordability and reliability each and every day. Customers have voiced very strongly that they're frustrated with high energy costs, and we are frustrated too. But overall, we are encouraged to see a reply to the RFP. And like I said, the disclosed need fell short of the goal, and we'll have to see what the Maryland Department of Natural Resources and other stakeholders recommend to the PSC. But we are more than willing to step up. And as we've said before, Char, If the competitive market is willing to step up and fill this need to meet us where we are at this time and not relying on the old rules of the past, we're okay. But it's time to move forward and continue to be progressive and aggressive in what we're trying to do for the state.

Got it. That's perfect. That's actually consistent with what you've been saying. And then maybe just, Calvin, shifting to Pennsylvania, there's obviously two bills sitting at the House and Senate around resource adequacy. I think they reconvene in November. I guess thoughts there, and more importantly, can the wires companies kind of strike a middle ground with the IPPs, maybe around a long-term resource addicts agreement structure that is also being proposed in the legislation versus this kind of push-pull around rate-basing generation or doing nothing and letting the market dictate new builds? So I guess how are the discussions in Pennsylvania going? Do you think you could strike a deal there?

First off, we are committed to working with all the parties. from the governor's office to the IPPs and, of course, with our peers in the state. Mike Innocenzo, our chief operating officer, is here, and I know he's been, as former CEO of PECO, he's been very engaged in that discussion as well. Mike, anything to add?

Yeah, sure. Thanks, Calvin, and thanks, Char, for the question. Discussions in Pennsylvania continue to go very well. As you're aware, Pennsylvania is a little different space in that they continue to be an exporter, continue to see the value of being an exporter, leveraging our natural resources in Pennsylvania. and continue to see the advantage of being an exporter in terms of economic development, and look as that is an opportunity to solve that. There are two active bills, one in the Senate, one in the House, that are being discussed. At the same time, we're talking with the governor's offices about on all of the above solutions, including longer-term PPAs, contracts. So I think you'll start to see more activity, probably more likely in the spring. Candidly, they're in the middle of budget discussions in Pennsylvania right now, which is taking most of the legislative space. We've seen some active discussions with the governor's office. In addition, I don't know if you saw that the PUC hired a party to do a third-party study on that, and I think that will also inform where we go in the spring.

Okay, that's perfect. Thanks so much for the clarity there, and Calvin, big congrats on the results. I appreciate it.

Thank you, Shari. It is good to hear you.

Thank you. One moment for our next question. Our next question comes from the line of Paul Zimbardo from Jefferies.

Hi.

Good morning, team. Thank you. I was hoping you could unpack the new Illinois legislation a little bit just in terms of what you see the investment opportunities, energy efficiency, transmission for some of these distributed resources. If you could just kind of unpack that a little bit, it would be helpful. Thank you.

Sure. Sure, Paul. I will start, and I will lean to my colleague, Gene, to help with that discussion as well. But as you know, on the last night of the fall veto session, Illinois passed what is called Senate Bill 25, the Clean and Reliable Grid Affordability Act, and it really focused on two things, Paul. It's around state new customer programs as well as state policy and resource adequacy. It enhanced the energy efficiency program, which is one of the quickest and most efficient ways to improve resource adequacy. And it laid out a target of 3 gigawatts of storage by 2030. That is significant. And it also expanded the opportunities for consumers to leverage distributed generation rebate programs and also advancing virtual power plant approaches and mandating time of useful. rate offerings, which, by the way, ComEd already offers some time of use rate offerings. So this is in furtherance of that and telling people if you're going to come into the market, we're going to evolve into that area. And finally, it also focuses on the broader role that the state can play in developing that integrated resource plan that I mentioned in my opening comments. So we think this gives the state further opportunity, and this is how they're looking at it, to demonstrate leadership and energy policy while also supporting economic development. And let me tell you from ComEd's point of view and Exelon's point of view, any opportunity we can to invest in the grid to keep that number one spot of reliability and resiliency and to create jobs and economic development in the state, we're leaning in with them. And I know our CEO, Gil Kionis at ComEd, has been in discussions with not only the commission but the governor on what's next, but we're very actively engaged in that process.

Excellent. Thank you very much. And as we all start to think about fourth quarter and maybe a little bit of a sneak peek, I like that transmission slide where you show the large step up in rate base in 2028. And obviously that doesn't all hit earnings in 2028. As we think about 2029 and that roll forward, is it fair to think about the stronger growth year than 2020? You say below the midpoint of the range. Is it fair to think 2029 is stronger within the range?

We'll give formal guidance on the Q4 call, Paul, but I think you're thinking about it right. We've got a lot of transmission opportunities to drive the solutions necessary as we see all this demand come in. We're very excited about transmission on the competitive side as well. You probably saw that we were active in the open window, both with partners but also solutions just from an Exelon perspective. And we think we'll have clarity there by the end of the year on some of that, roll that into the Q4 update. None of that is contemplated in our guidance, nor is it in the 10 to 15 billion of transmission that we talk about outside the window. But what I would also say is a lot of those solutions, all of those solutions are 2030, 2032. So the spend is sort of around the corner outside of the planning period. But what it does is it speaks to sort of the strength and the length of the continued growth in our rate base. We always aim to be at that 7% to 8% to drive the 5% to 7%. And I think this just positions us well to execute in the upper portion of that 7% to 8%.

Okay, excellent. I'll thank you. I had to try 2029. See you all soon.

All right, Paul. I saw the effort. Thank you.

Thank you. One moment for our next question. Our next question comes from the line of Nicholas Campanella from Barclays.

Good morning, Nick.

Hey, good morning. Thanks for taking my questions. Maybe just, you know, you kind of mentioned it in the prepared remarks around repairs and the CMAT, but just is this something that you think you kind of get clarity on by year end and potentially consideration for the financing outlook as we kind of prepare for the disclosures out to 29? Or just what's the kind of timeline there to get that clarification? Thank you.

Yeah, we're hopeful for the end of the year. We know the IRS is working on additional sort of guidance for CAMTI, and so hopefully we get that clarity by the end of the year. We do know some guidance was put out. The way it was written didn't achieve sort of the full intent, and so we're still working on that. But what I would say, though, is that, as we've talked about, that would be incremental cushion to the balance sheet and would be factored into the full update for our financing plan on Q4. But pleased to see progress there. Just want to hopefully close it out here in this year.

And I guess if you had the opportunity to use that cushion, is it less equity needs or accelerate CapEx further, just cognizant of the different pushes and pulls there?

Yeah, we want to stay on that path to 14%, as we mentioned. So this would be good momentum towards that 14% by the end of the planning period. And I think we would, you know, we've got equity in there. We've got hybrids. We've got additional capital coming in. So we'll put all that together and make sure that we deliver kind of the most efficient plan while we maintain that 14% or better, but also driving the 5% to 7% mid-spring or better. So we'll factor that all in, but I would say that that's just helpful as we think about the cushion towards that 14%.

That's great. And then just if I could really quick, I know it's small, but just that the Ace Ray case has been going on for a long time. And you're still saying that you're on track to settle this case. And maybe you can kind of talk a little bit about what's kind of informing the view that settlement's still on the table and why this wouldn't just go to a final order in the coming months here. Thank you.

No, thank you, Nick. To your point, you know, that case was filed in November of 2024. And I need to give the Atlantic City Electric team and Tyler Anthony, the CEO of Pepco Holdings, a lot of credit because they've been working with the commission and all stakeholders, including our governor, and just making sure that we're being transparent, talking about each and every investment, where it's needed, and what the shared goals of the parties are. And that's why we're encouraged that we can get to settlement. But it is a process. And we do anticipate... that that will happen by the end of the year. But at the same time, they do have the right to implement the interim rates subject to refund. So I believe that keeps all of the discussions moving forward in the settlement on the table because under law, once you implement it, then it's subject. So they're saying, let's get it right, right out the gate. And that's what they've been working on from day one. And I know we've been talking to both gubernatorial candidates on where we're going and what we're trying to do in that partnership. So that's why we're encouraged.

Thanks so much.

Welcome.

Thank you. One moment for our next question. Our next question comes from the line of Jeremy Tonette from JP Morgan Securities, LLC.

Good morning, Jeremy.

Hi, good morning.

Just want to pivot a little bit here, if we could, towards the Amazon TSA. It seems like there's been some developments there. Just wondering if you could provide us, I guess, your most updated thoughts on this part of the business.

Yeah, so what we've started to do for our large load is implement what we're calling a transmission services agreement. And so with that, the first one that we did was the one that you mentioned with the PECO Data Center. in the data center in PICO's territory. We like this because it does a couple things. One, it helps really kind of solidify projects, right, and kind of maybe weed out any speculative projects, but it also protects the rest of our customer base. So it's similar to what we've had historically on the distribution side where you have deposits and letters of credit and other things that sort of that help protect the other customers should the demand that we build for not show up. And so We executed our first one there in the PECO territory, but we've now also filed in the ComEd service territory a large load tariff, which would ask that all large loads greater than 50 megawatts sign these agreements. And so that, we think, does the two things that I mentioned, right? Kind of really firm up the commitments, but also protect other customers should the demand not rise. And I think, you know, what we also tried to do on slide 13 of the deck is to show you kind of how that pipeline of large load is kind of filtering into the high probability column. You can see in the column of the 47 gigawatts of the ones that we're studying, which ones are still being studied, which ones have already been studied and are awaiting a TSA. Once we get that TSA signed, we would move it into the high probability. So that's a way to kind of keep track of how different load and different megawatts are moving from one category to the next.

Got it. That's helpful. Thanks. And just wondering, I guess, any thoughts, I guess, on, you know, the $10 to $15 billion of transmission capex and, you know, thinking about probability weighting, all this and everything. As you outlined there, we've seen a number of your peers across the space lift their growth outlooks. And just wondering, I guess, you know, what opportunities Exxon sees to stay kind of competitive with those type of growth rates?

Yeah, I think we are running our core business really, really well. Transmission and distribution operations, first quartile for all operations, delivering above average performance with below average rates, continue to have met or actually exceeded all of the guidance, upgraded S&P. So I think the core business is running really, really well. And as we think about additional growth, that comes to your point in the form of transmission and energy security solutions. But you also know us at Exxon, we're not going to put anything in the plan that isn't certain and bankable. And so as we look for transmission, for example, I mentioned earlier, we do have some proposals in front of PJM in the current window. We'll know more about those proposals by the end of the year. And once we have certainty on those, those will come in. And we'll put them in the plan so that you don't have to speculate or probability-weight some of them that once they're in, you know that we feel very certain about them. But as I mentioned before, you know, we're focused on delivering really in the high end of what we've committed to. And as we see some of these opportunities materialize in the back end of our plan, then we can start to think about that. But let's focus on the execution first and getting them in. And, of course, we'd always love to be talking to you about more, but we're going to focus on what's executable and build it in and put it into the plan once we know it's certain.

Got it. That's helpful. Thank you.

Thank you. One moment for our next question. Our next question comes from the line of David Arcaro for Morgan Stanley.

Good morning, David.

Hey, thanks so much. Good morning. Let's see, I had a quick question on that large load pipeline that you've laid out on slide 13. I was just wondering, If you could just maybe characterize how you probability weight that 47 gigawatt pipeline. I appreciate the extra detail you provided there. But like in aggregate, are those still less likely to move forward or for some of those is it just more of a matter of timing where eventually those could become, you know, more advanced stage projects?

I think it's more a matter of timing. But what we're really trying to do is before we move it to that column, do two things. One, complete the cluster study. So all of the load is now studied in a cluster approach so that we can give more certainty to the customers on time and time to connect and other associated questions, location, et cetera. We want to go through that first. And then from there, once we provide that information to customers, have them sign the TSA agreement. So that's kind of a two-step process, which once Once it goes through that, you can have you and us and our states and our customers can have much more certainty around this is highly probable and it'll go into that 18 plus column. So that's how we're thinking about it. But I would tell you it's all real. It continues to grow. If you look at the chart, right, you've got six that have already been studied and just awaiting TSA signing. You've got 20 across the Mid-Atlantic and Illinois that is actively being studied and then another 20 that is ready to be in the next cluster study. So we've seen this grow over the last couple of years that we've been talking about this from six gigawatts to 18 highly probable and 47 studied or awaiting to be studied. And so I think that speaks to, there's a lot of certainty around this, but until we tell you, until we go through those two steps, we don't count it highly probable. That's the process we're following now.

David, I would just add, that is what's significant about that. You've probably heard the discussion around a lot of double counting that may be taking place across the country in the industry. Our process helps eliminate that and really focus on who's real and who's not.

Yeah, absolutely. That makes sense. Thanks for that color there. And I guess on that time to connect, I guess what is the time to connect that you're seeing for new data center projects that are getting into that 47 gigawatt, getting into the cluster study process what is the maybe wait time or when when are you able to offer power in your service territory for new data centers you know I'll start with that general it depends it depends on size location and

the ramp-up period, but Mike Innocenzo and his CEOs have been involved in this process from day one, and I'll look to Mike to give any further clarity.

Yeah, I mean, I would just say that I would expand on the, it depends, I would say the things that we do to try to shorten that, we understand the speed is really important. First thing we start with is where do we have capacity on the grid? So our first discussion with any data center would be where's existing capacity, where's existing infrastructure? You've seen that So, for example, the North Point One in PECOS territory, where we've used the site of a former facility, and by, you know, they signed the TSA agreement just a couple of months ago, and by the spring, it'll be PECOS' largest customer on their site. So, where we can use existing infrastructure, existing capacity, we're doing everything we can to connect them. We're working with our customers on the ramp-up time so that we can connect them quickly within a year or two, or even less than that, as an example of North Point. with existing facilities and ramp that up, and then working with PJM in terms of expediting the process for any of the long-term investments that are needed for updating the grid for some of the larger loads.

And if I can, David, let me share with you, you've got the back end of what operations takes over. Over a year and a half ago, we centralized all of our large accounts, our data center accounts, to really work with the customers in the strategic planning process just last month we had our 25 largest customers in chicago and really started talking to them about what you need where you're going and what is your ramp up time on certain things in across our jurisdictions so it's not just one state we're working with them about what we have across our footprint which once again elevates the size and scale of exelon because we're in multiple jurisdictions and we can help meet that need. So we started this process a long time ago, and we get up in the strategic planning process before we even start talking about shoveling ground.

Okay, great. Thank you so much.

Welcome. Thank you for the question.

Thank you. At this time, I would now like to turn the conference back over to Calvin Butler for closing remarks.

Well, first off, let me just say thank you. Thank you for taking the time today. and for being part of our 25-year journey at Exelon. We appreciate your support, and we look forward to seeing many of you next week at EEI. We're looking forward to the discussion, and just the constant dialogue means a lot to us, and I know for our employees to be engaged in. And so with that, Gigi, this concludes the call.

Thanks to all our participants for joining us today. This concludes our presentation. You may now disconnect. Have a good day.