Good morning. My name is Jael, and I'll be your conference operator today.

At this time, I would like to welcome everyone to the Entergy's fourth quarter 2025 earnings conference call. All lines have been placed on mute to prevent any background noise. After the speaker's remarks, there will be a question and answer session. If you would like to ask a question during this time, simply press star, followed by the number one on your telephone keypad. If you would like to withdraw your question, press star one again. I will now turn the conference over to Liz Hunter, Vice President of Investor Relations for Entergy Corporation.

Good morning. Thank you, JL, and thanks to everyone for joining this morning. We will begin today with comments from Entergy's Chair and CEO, Drew Marsh, and then Kimberly Fontan, our CFO, will review results. In today's call, management will make certain forward-looking statements. Actual results could differ materially from these forward-looking statements due to a number of factors which are set forth in our earnings release, our slide presentation, and our SEC filings. Entergy does not assume any obligation to update these forward-looking statements. Management will also discuss non-GAAP financial information. Reconciliations to the applicable GAP measures are included in today's press release and slide presentation, both of which can be found on the Investor Relations section of our website. And now, I will turn the call over to Drew.

Thank you, Liz, and good morning, everyone. The last couple of years have been transformational for Entergy. While 2024 reshaped our long-term expectations through historical new demand for power, 2025 was affirmational as our successes continued. Today, I'll highlight our 2025 achievements and discuss our ongoing efforts to successfully execute on our customer-first strategy that creates value for all stakeholders. Starting with the financial results, we are reporting 2025 adjusted earnings per share of $3.91, which is in the top half of our guidance range. Continue to expect greater than 8% adjusted EPS annual growth through 2029, and our transparent Outlooks provide specific expectations by year. Turning to the customer, our initiatives to improve customer experience have yielded positive results. Based on JD-powered data, Intergy's utility remains in first quartile for Neftra Motor Score for both residential and business customers. Three jurisdictions were in the top quartile for residential NPS, and Intergy Texas was ranked number one in customer satisfaction for business electric service in the south among mid-sized utilities. Our work to meet our customers' needs while maintaining low rates is being recognized, and this will remain a key focus for us going forward. We had 4% sales growth in 2025, driven by a 7% increase in industrial sales, continuing a long history of strong growth rooted in the advantages of our service area. We anticipate the sales growth trend to accelerate with an expected 8% compound annual growth rate through 2029 from 2025 and driven by 15% industrial growth. Last year, we signed electric service agreements totaling approximately 3.5 gigawatts. There were several noteworthy customer announcements which give us confidence in our outlooks for growth from data centers and traditional industrial segments. Customers achieved important development milestones, including those in the steel, petrochem, and LNG sectors. In fact, with Hyundai Steel's $5.8 billion planned investment in Ascension Parish, Louisiana earned Business Facilities Platinum Deal of the Year, which pushed the feat two years in a row after the Meta AI Data Center project in 2024. before. We also had new data center announcements in Arkansas, Louisiana, and Mississippi, including both co-location developers and high school. Energy service area remains attractive, starting with our low electricity rates and vertical

integration, business-friendly environment, welcoming communities, and proven workforce.

Our geographic location provides access to diverse energy sources and robust infrastructure that are attractive to industrial customers. Our integrated stakeholder engagement is also an advantage, as we bring parties together to discuss potential development solutions and a common understanding of benefits. We continue to have meaningful conversations with potential new customers to secure additional growth to benefit all of our stakeholders. And our pipeline is unchanged at 7 to 12 gigawatts for data centers and 3 to 5 gigawatts for other industries. We have clear line of sight on equipment to serve 8 gigawatts of incremental load above our current plan. We've also confirmed EPC engagement for projects in our outlooks and beyond. Intergy has distinguished itself with a long history of greater than 5% compound annual large industrial growth over the past 16 years. We know how to attract new business and serve new large low customers while delivering positive outcomes to all our stakeholders from operational execution to affordability. The economic development activity has paid off as all of our states achieved record employment milestones in 2025. From the beginning, our hyperscale electric service agreements were developed with guiding principles that account for both the new customers' goals and impacts for our existing customers and communities. For our residential customers, we estimate the data center contracts in place today will generate approximately $5 billion in rate offsets from their fair share of contributions to fixed costs during the life of the contracts. That equates to more than $5 per residential customer per month on average, and that has the potential to grow with additional data center contracts. Customers will also see improved reliability and resilience from new generation and transmission infrastructure built to the latest standards. In addition, new, more efficient power plants will lower fuel costs for all customers. Our operating companies have implemented programs such as Superpower Mississippi and Next Generation Arkansas made possible by data center revenues that will improve reliability and reduce outages for all customers in those jurisdictions. Our long-term data center contracts include early termination penalties and minimum bills to ensure that other customers aren't left to pay for investments needed as a result of adding large loads to the system. Plus, on their own, these customers will create real value for our communities, including benefits from jobs, an increased tax base, and economic development. These are just a few examples of how data center growth is enhancing Intergy's efforts to support customers and communities every day. Beyond data centers, our operating companies have implemented many other ways to help manage customer rates and benefit our communities. That starts with cost discipline, including an ongoing focus on O&M efficiency and scrubbing our capital projects to ensure the best outcomes for customers. Our teams work closely with regulators to manage bill levels and volatility, which includes use of tools like deferred fuel collections, state and federal grants, tax incentives, philanthropic support, and securitization. Our operating companies also proactively engage customers to ensure they are aware of programs to help manage bills, including energy efficiency programs, LIHEAP funds for qualifying customers, and a power-to-care program for low-income seniors. Currently, we are exploring new rate offerings, such as demand response and time-of-use rates, to complement our average bill and deferred payment options. This year, our employees delivered more than $100 million in economic benefits to the communities we serve through philanthropy, volunteerism, and advocacy. That includes our employees volunteering for approximately 170,000 hours in our communities last year, the equivalent of roughly 81 full-time employees. Our employees are also focused on delivering benefits to customers from our four-year capital Because of our track record, we know what it takes to successfully execute large projects. With a $43 billion capital plan through 2029 to support customer needs, we have a sizable build cycle ahead. In 2025, we invested $8 billion to benefit customers with about half of that in generation. That includes significant work on Orange County Advanced Power Station, which is entering the final stages ahead of a summer in-service date, and Delta Blues in Mississippi. Looking ahead, new generation is a big part of our customer-centric plan. We have several projects in early stages that will come online in the next few years, including Franklin Farms Units 1 and 2 and Waterford 5 in Louisiana, Legend and Lone Star in Texas, Ironwind in Arkansas, and the Vicksburg Advanced Power Station in Traceview in Mississippi. We also have five owned and contracted solar resources approved or in progress totaling 740 megawatts. Including gas, solar, and battery storage, we have nearly 9 gigawatts approved and under construction towards our planned 13 gigawatts of new capacity to serve and support customers over the next four years. In 2025, our nuclear fleet operated safely and reliably, achieving a 90% unit capability factor. All refueling outages, including major turbine and generator projects, were completed on The team also delivered more than 35 megawatts of additional clean capacity from plant upgrades and replacement of older equipment. Looking ahead at Waterford III, previous investments in low-pressure turbines have paved the way for a 45 megawatt upgrade later this year. Turning to energy delivery, we invested about $3.5 billion in 2025, which includes accelerated resilience projects to support customer growth and to improve reliability. Thus far, we have invested $800 million in approved accelerated resilience work, including 17 substation upgrades and 59 line hardening projects, upgrading more than 15,800 structures. In total, our four-year, $17 billion customer-led energy delivery capital plan includes new construction on more than 570 miles of 500 kV lines and 175 miles of other transmission lines, as well as investment in new substations. This also includes $1.4 billion of approved projects to harden more than 45,000 assets. System resilience is a key area of focus, and we are planning to continue progress on delivering that value to customers. To that end, Intergenia New Orleans filed an application for the second phase of its resilience program, requesting approval for up to $400 million in projects. While we have and will put forward recommendations for projects that have both resilience and cost-benefit value for customers, We recognize it's important that we balance near-term affordability with the need to continue to strengthen our system. The topic of reliability is never more in focus for us and our customers than when faced with a storm. A couple of weeks ago, winter stormed particularly in North Louisiana and Mississippi. Throughout the event, we worked closely with state and local leaders to stay aligned on our restoration efforts. Our generation fleet operated well, providing critical energy to serve customers who could take power. At the same time, our distribution and transmission lines were impacted by significant ice accumulation, well over an inch in some places. Burn disrupted 170,000 of our customers. But ultimately, we restored power for more than 360,000 cumulative outages. because many customers were impacted multiple times due to ongoing tree damage from the heavy ice. Damage resembled a strong hurricane, but with more dangerous icy restoration conditions afterward. In fact, we replaced more poles, more miles of wire, and repaired more substations than we did for Hurricanes Beryl or Francine in 2024. Our employees, contractors, and mutual assistance workers performed very well in these dangerous and difficult conditions. I sincerely appreciate their hard work and dedication to safely and quickly bring power back. Legislative and regulatory processes support our ability to successfully execute initiatives to provide long-term benefits to our customers. In 2025, Arkansas passed the Generating Arkansas Jobs Act, which materially improves utilities' ability to make critical generation and transmission investments needed for economic development in the state. The act paved the way for assets like Jefferson Power Station and the Cypress Solar and Battery Project. Meanwhile, Texas passed legislation enabling rider recovery of MISO capacity costs, which historically were recovered in base rates. A year ago, I said that our 2025 regulatory calendar would be busy, and it was. Our regulators made tremendous headway to benefit our communities and to advance customer growth. They approved routine updates to base rates and riders, as well as major transmission projects and new generation, both modern gas and renewables. All of these projects will modernize our infrastructure, provide customer reliability benefits, and support growth that's critical for our communities. Our regulators are also considered policy issues aimed to promote economic development. For example, the Louisiana Public Service Commission in December voted to adopt a policy proposal referred to as the Louisiana Lightning Initiative, which provides a path for utilities to efficiently meet the needs of large new loads, RFP exemptions, and an expedited review in specified situations, with all actions subject to prudence review. This policy will align with Louisiana's broader lightning speed initiative to better coordinate among critical state permitting offices and allow us to bring new customers online faster, which will attract new business to Louisiana. You may recall that Arkansas and Mississippi also adopted rules and processes to foster economic development and attract projects that have speed to market as a top priority. There are a few other regulatory updates since our last earnings call that I'd like to highlight. The Arkansas Public Service Commission approved the special rate contract for Google. They also approved construction of the Jefferson Power Station and established a benchmark against which to measure the cost. In December, Intergy Louisiana filed with an upfront purchase price of $1.5 billion as well as $300 million of investment for maintenance and improvement. This is an attractive opportunity to acquire additional energy and capacity sooner and at a lower cost than a new build alternative, as Louisiana continues to experience significant customer growth. We requested a decision from the LPSC by the end of this year to allow for an acquisition early next year. In November, Energy Louisiana also filed a request for approval to construct the Segno and Votol solar units. These projects were safe harbored earlier this year, earlier last year, and will be attractive resources to support customer clean energy demand. For our 2026 regulatory calendar, we're planning for another productive year. In addition to the projects I just mentioned, we have four major generation and transmission projects that are awaiting commission decisions in the year. Arkansas Cypress Solar with battery storage, the Babel to Weber 500kV project, and the Waterford 6 and Westlake combined cycles in Louisiana, which were filed yesterday. Later this month, Intergy Arkansas will file its first base rate case since 2015. Following 10 years of formula rate, our current expectation is to request a rate change of well below 3%, and it could be lower for residential customers, which will support our continued efforts to invest for the benefit of our customers while being mindful of affordability. Our goal is to receive a commission determination by the end of this year for rates effective at the beginning of 2027 and a renewed formula rate plan starting with the 2028 forward test year. The formula rate plan benefits our customers and other stakeholders through predictability and ease of implementation while supporting continuous regulatory oversight. In addition, we expect to implement the Generating Arkansas Jobs Act rider in the next few weeks, supporting economic development. And the combined total rate change for residential customers between the rider and the rate case is expected to be at or below recent FRP rate changes and also maintain Intergy Arkansas' competitive position with rates well below the national average. Mississippi, New Orleans, and Louisiana will file their formula rate plans between now and May, and Intergy Texas expects to request updates to its transmission and distribution riders as needed. energy texas also plans to utilize the generation rider after orange county power station is placed in service which will trigger a base rate case in 2027. 2025 was an affirmational year building on our continuing transformation i appreciate everything our employees have done to create value for our customers and as a result all of our stakeholders as we move into 2026 we will continue to put the customer first in everything that we do. Before I turn it over to Kimberly, I'm excited to announce that we will host an investor day on June 9th in New York City. We will continue the conversation on the significant opportunities that we see ahead, including five-year outlooks as we've done in the past. And now, Kimberly will review our 2025 financial results as

well as our outlooks. Thank you, Drew. Good morning, everyone. As Drew said, 2025 was another important year in our growth journey. I'll review our 2025 results and then provide an overview of 2026 and our longer term outlooks. Starting with earnings, our adjusted EPS for the year was $3.91, as shown on slide four. Our results reflected strong sales growth and the effects of investments made for our customers. The increases were partially offset by higher other O&M and an increase in our share count from settling equity forwards. Earnings contribution from sales growth for the year was positive, including the effects of weather. Excluding weather, retail sales increased approximately four percent. Industrial sales were the largest contributor at around seven percent, including sales for new and expansion projects that continue to ramp up their operations the highlights of our four-year plan are shown on slide five our retail sales outlook remains very strong off of 2025 weather adjusted results we expect eight percent retail sales compound annual growth driven by 15 percent industrial growth through 2029 data centers are the primary driver along with growth from a variety of traditional gulf south industries including transportation or lng primary metals industrial gases petrochemicals and agricultural chemicals as a reminder we take a conservative approach with hyperscale data centers we only include them in our plan once we have an esa in place and we include them at the minimum bill levels our customer-centric capital plan is now 43 billion dollars two billion higher than our preliminary plan presented at eei the increase includes the investment for the cottonwood generating station that drew mentioned for 2026 our capital plan is 11.6 billion dollars approximately 3.6 billion dollars higher than 2025 reflecting the step up in investment to support our customer growth the equity associated with our four-year plan is unchanged at 4.4 billion dollars at the lower end of our target range of 10 to 15 percent of the total capital plan our forecast also includes 1 billion dollars of hybrids in the back half of the forecast we have been proactive in addressing our equity needs selling forward contracts through our atm program as well as the block transaction we executed last march we've taken significant price risk off the table, and we have ample time to raise capital. For our 2026 through 2029 equity need, about 45% is already contracted, meaning we wouldn't need to transact again until well into 2027. In February, after year end, we settled an additional $345 million, or about 4.6 million shares we are using those funds to continue to invest for the benefit of our customers slide six summarizes our credit ratings and affirms that our credit metric outlooks remain better than rating agency thresholds for 2025 we estimate that moody's cash flow from operations free working capital to debt is greater than 17 percent and smp's ffo to debt is approximately 16 percent both well above the agency's thresholds moody's metric includes approximately 550 million dollars for nuclear ptcs that were monetized in 2025. without the ptcs 2025's estimated moody's metric is still well above our 15 percent target based on final miso prices and strong nuclear production we also recorded nuclear production tax credits in our 2025 results we plan to monetize these credits in 2026 and estimate that the net proceeds will be approximately 215 million dollars tax credits will ultimately provide benefits to customers beyond 2025 our credit metric outlooks are strong with ethical to debt above our thresholds throughout the outlook period achieving our 15% target for Moody's metric during the period, giving us capacity to manage events in the business as they occur. As a reminder, because the value of nuclear PTCs is highly dependent on average revenue per megawatt hour, we do not include cash benefits in our cash flow or credit metric outlooks beyond 2026. Our financial health is bolstered by all the work we've done to strengthen our balance sheet and create benefits for customers. including structuring large customer ESAs to protect existing customers and our credits, improving our pension-funded status, and receiving constructive regulatory mechanisms. As Drew discussed, in late January, Winter Storm Fern impacted our service area. Our preliminary estimate for restoration costs is up to $300 million for Louisiana, up to $200 million for Mississippi, and approximately $60 million for Arkansas. the majority of the costs being capital. Our current expectation is that these costs will be recovered through normal mechanisms. Our adjusted EPS guidance and outlook are shown on slide 7. Throughout the outlook period, we continue to see very strong growth, driven by our customer-centric capital plan, and our long-term compound annual growth remains strong at greater than eight percent. Slide eight provides additional detail behind our guidance assumptions. For 2026, we expect continued benefits from strong sales growth, especially as data centers increase their usage. Our guidance also includes the effects of investments made for customers, including regulatory actions and increases in depreciation, property taxes, and financing costs. Share effect will also be a driver as our fully diluted average share count increases. Additional information on specific drivers for the year as well as detailed quarterly considerations are included in the appendix of our earnings call presentation. We have a very strong growth story that supports our plans to invest in reliability and resilience to better serve our customers. We have a solid base plan consistent with our strategic objectives and a strong customer pipeline, including 7 to 12 gigawatts of data center opportunities. And we have secured critical equipment to bring additional customers online. We're very proud of what we have accomplished, and we are working hard to make 2026 another successful year, continuing to prioritize the needs of our customers to create value for all of our key stakeholders. We have a very unique growth opportunity before us, and we're excited about what the future holds. and now the Intergy team is available to answer questions.

At this time, I would like to remind everyone in order to ask a question, please press star as in the number one on your telephone keypad. Once again, that is star one. In the interest of time, we ask that you please limit your questions to one primary and one follow-up question. Thank you. And now we'll pause for just a moment while we compile the Q&A roster. Our first question comes from the line of Char Pureza of Wells Fargo. Your line is open.

Morning, morning. Q, just on the large load ramp, HUD-8 was the most recent announcement. Was phase one of that project already partially in plan and with the formal FID, does that kind of put some upward pressure on rate-based growth, or is phase two the upside? I guess maybe just help us frame if there are other probably weighted projects in 26 and 27 as well. Two-part question.

I would think about HUD-8 and similarly sized data centers like we think about our probability weighted industrial growth overall. So that would have been included in the probability weighting there. Certainly, we're seeing positive progress in that space, and so that increases that probability weighting, but it would not be a separate discrete item like a hyperscaler.

And also, Jarrett, just part of what they've announced doesn't add to the capital plan, and I'm not sure what you mean by phase one and phase two, but additional incremental growth in that customer would likely require incremental capital for capacity.

Got it. Yeah, I guess there's going to be a second phase they've talked about that could be fairly material. Okay, and then, Drew, I want to ask on the large load protections you have as you kind of put the CapEx into plan. I mean, we've seen at least one data center walk away from a project despite having assigned ESA, obviously different state than yours, of course. Just remind us on the level of comfort, the collateral requirements, et cetera. You have some lumpy projects there which can be sizable so it can move the needle should one of these customers walk Just maybe overall, just on the ESA environment and the protections there.

On the overall large load customers, including not just the hyperscalers, but also co-locators like a HUD-8, we have significant credit requirements that require things like termination fees, that sort of thing, as well as minimum bills. And what we've included in our forecast is only the minimum bill. So certainly there's, to the extent that they run up to their full capacity, there's opportunity there, but to the extent that they choose to not run or not continue, there's the termination payments that protect us there as well, and those are backstopped.

Got it, and then just maybe one quick one I'll squeeze in is I know the prior update noted four and a half gigs of power equipment associated with potential upsides. Is any part of that spoken for at this point? Have you started to expand those expectations given continued large load expansions? Is cottonwood potentially added to that number? Thanks.

Yes, sure. We have about eight gigawatts of turbines and other plant island equipment available for growth. We haven't turned those into specific projects tied to ESAs at that point, but if you recall that turbine schedule that we showed you, those are all the gray projects there. We continue to have really positive conversations with our customers and would expect to be able to continue to grow our portfolio, but certainly we don't have anything specific here. That is lumpy, as you well know, but we have the opportunity to add incremental. I will note that cottonwood that was added into the capital plan does not replace one of those turbines. That's existing capacity that provides additional space in Louisiana to continue to meet customer needs, but it doesn't replace any of those turbines.

Okay. That's perfect. Thank you guys so much. Appreciate it. Thank you.

Your next question comes from the line of Julian Dumoulin-Smith of Jefferies. Your line is open.

Good morning. It's Paul Zimbardo on for Julian. Thanks for taking the line. Good morning, Paul. Great. The first, just a quick clarification. I think you said the CapEx change increases cottonwood. Are there other major changes going on, or is it really just the cottonwood being rolled in?

Pardon, Paul. It's largely cottonwood. There's a little bit of capital from 25 that rolled into 26. The overall increase there is not fully incremental versus what we had in 25, but most of what's there is cottonwood.

Okay. Okay, great. That's what I thought. And then you had the comment around the $5 per month of customer bill savings from the data centers that you've kind of secured to date. Are there good ways to think about it? I know it's difficult. Rules of thumbs or just ways to think about potential future savings from that data center pipeline for customers?

I would think about that as the data center's contribution to embedded fixed costs. So there's not a good rule of thumb. It's going to depend on the size of the data center. But in general, what you're doing there is you're essentially, you've got your embedded fixed costs that you're spreading over more KWHs. So the size of their KWHs is going to drive what that opportunity is. But there's not, I don't have a good rule of thumb for you.

Yeah, and I would add to that, Paul, that we think that that's conservative because there are other things that the customers are benefiting from, and I listed some of those in my remarks, like fuel efficiency and things like that, that are important contributions, more reliability, more resilience from the new infrastructure, not to mention all the community benefits like taxes and so forth. So there is a lot of value for customers, but we thought it would be important to label that fixed cost contribution part because it is significant.

Okay, that makes sense. And if I could squeeze in one more quick, just after the Jefferson approval and the Texas generation approval, noting that Louisiana has that lightning amendment, have you seen kind of customer preferences shifted between different states? Any color would be helpful.

there? No, no real change among states. You know, the customers that we have in our states are continuing to invest where they are. And they are very comfortable with with the rules where they are. But I think it will help attract incremental customers, potentially. And so we've seen we've seen some support for that as well, but I don't think it's causing pull from one of our jurisdictions to another jurisdiction at this point.

Okay.

Your next question comes from the line of Jeremy Tonette of JPMorgan. Your line is open.

This is Diana Niles on the call for Jeremy. Going back to the customer benefits from data centers and the $5 billion in rate-based offsets, Could you provide some color on what buckets this covers, whether that's, you know, transition required for new load or previously consolidated resilience investments? Any color there would be appreciated.

Yeah, good morning, Diana. You know, as I said, I would think about that as contribution to incremental cost. So that is things like in Louisiana, they had storm costs that were already securitized that customers were paying for. They're paying a contribution to that. In Mississippi, we had announced Superpower Mississippi, where we added incremental capital with no increase in rates because the revenues coming in from the hyperscalers there were providing room to continue to invest in resilience and reliability. And then as you think about going forward, that incremental revenue is helping to offset future rate changes as you make investments.

Great. Thank you. Is there one more, if I may, the Cottonwood addition to the plan, just sort of already contemplated in your outlooks going forward or to what extent do we need to look at future approvals to think about the inclusion in the plan?

Yeah, so Cottonwood is included. It's in our... We added it into our capital plan. It is pending regulatory approval, but from an EPS Outwood perspective it just moves us in the range, but it doesn't change our ranges.

Great. Thank you very much.

Your next question comes from the line of David Arcaro of Morgan Stanley. Your line is open.

Hey, thank you. Good morning. I was wondering what updates should we expect at the investor day coming up in June? Is that a natural time when you might expect more data center contracting clarity to come in or capital projects to be approved and added to the plan? any, you know, specific update that might be incremental in June?

Yeah, so I appreciate that question, David. So, you know, we never know exactly when a data center contract might land, you know, but certainly we're going to give you more color around the data centers and how we're positioning ourselves and things like that. We'll give you a little bit of a longer outlook, and you typically have been going out five years from that period. And we'll try to get a couple more of our leaders in front of you so that you have a chance to talk to a little more depth in our team so you have a chance to really understand perhaps the various jurisdictions and what those mean and what they're trying to do. So those are the kind of things that we would try to update you on to give you more comfort around the plan that we've laid out. And if we're fortunate, maybe we'll have something to announce, but the timing, you never know about the timing for a large customer contract.

Yeah, got it. That makes sense. That's helpful. And then I'm just curious, more broadly, what's the latest feedback that you're getting from the political and regulatory standpoint related to data center activity? Are you seeing, you know, is it continued support here as you continue to accelerate, or are you seeing increased pushback challenges locally to the

activity that's popping up? Yeah, thank you, David. That's another good question. So we still continue to have strong support for the data centers in our jurisdictions. You know, the lightning initiative that I mentioned in Louisiana is a good example of that. That was just at the end of last year. And we continue to see strong support in other jurisdictions, not to mention a lot of customer interest and a lot of customer activity. So we see a lot of positive movement and it continues to bode well for the expectations that we've laid out for you all. In fact, I think they've probably strengthened since we talked to you last quite a bit. There still is some concern about things like affordability and rates, and I outlined a lot of the things that we are doing. In fact, you know, the comments about existing customer benefits from contribution to fixed costs and other things are, we think, really important to continue to maintain the positive momentum in our jurisdictions. But right now, we continue to see very positive momentum from both customers and communities about data centers.

Okay, great. Appreciate the call. Thank you. Thank you.

Again, if you would like to ask a question, please press star and the number one on your telephone keypad. Your next question comes from the line of Andrew Wiesel of Scotiabank. Your line is open.

Hey, thanks. Good morning, everyone. Good updates. Hope you guys are getting ready for Mardi Gras. First question, I wanted to clarify a little bit the forecast for retail sales growth on page five. I see you increased the CAGRs, but the numbers in the bar chart went down. Am I right? That's just because you rolled forward the starting point from 24 to 25, and I know you're not showing the forecast in absolute terms, but if my math is correct, I think your forecast for 28 to 29 went up by about 2 terawatt hours or 4 to 5 percent, and if so, is that driven by a small number of specific projects, or would you call that broad-based growth?

Relative to the roll forward of the year and what you're seeing on the dimensions there on the chart we can get you the specifics on 28 and 29 to confirm your terawatt number but you know we have seen this step up from 27 to 28 29 as these large customers continue to ramp on the ones that we've made significant announcements on and then you know any adjustments to the

probability weightings would also show up there um but does that sound about right are they going up

by about five percent i think overall i would look at the you know we looked at the 15 off of the 25 base. I don't have those other numbers right off the top of my head, but we can certainly double check them and circle back with you, Andrew. Okay, fair enough. Directionally, it seems like

it's certainly going up, though. Next question. Regarding the meta contracts, help me understand the pushback or confusion around contract terms. It seems like meta structure disleases as a series of four-year subcontracts under an entity owned by Blue Owl with the ability to exit or renew every four years, yet you and regulators are describing it all as a 15-year structure. And, of course, the new gas plants will have a much longer useful life of a few decades. I certainly don't want to put words in anyone's mouth, but help us understand the two different perspectives and how to reconcile these four-year terms versus the 15 years and how that may or may not create risk for investors or ratepayers and why there seems so...

Yeah, I would think of it as two separate transactions. So on the electric service agreement side, we have a 15-year term with a subsidiary of META backstopped all the way at the parent. That is the service agreement, and that has all the provisions that I mentioned earlier around termination fees and minimum bills and those sorts of things. Separately, what META has pursued is a transaction with Blue Owl where they are structuring the capital that they're spending on their side. referencing are and I don't have the details on all those terms but they're separate and apart from the ESA that they have with okay so who's the ultimate guarantor on your ESA is a parent is meta all the way up okay great thank you so

much that's very clear appreciate it thank you Andrew and I don't know if you heard earlier but you know there's we're worried that we might be sirens in the background because of all the Mardi Gras floats that are getting escorted around

down right now sounds fun your next question comes from line of david paz of wolf your line is open

hello um this with the uh eight gigawatts of uh gas turbine available availability what what level of flexibility do you have in the equipment delivery period so just thinking about the chart from the ei i think there were some what's called open slots in the 28 to 30 period Are those, you know, to the extent you don't have a new announcement, say, this year, for instance, you know, how would you kind of fill those in? Would you just push those out a little and just maybe better explain how to think about the cadence?

Hey, David, this is Drew. So thanks for that question. First of all, we fully expect to utilize the turbines that we have ordered on the timeline, that we have them ordered. We have customers that would move them forward if they could. We fully expect to utilize the turbines that we have. For some reason, we don't have contractual arrangements. We don't have ESAs in place for customers when we need to start making payments on these turbines. We're likely to get reimbursement agreements from customers, so that shouldn't be a problem for us financially. but we fully expect to meet the timeline that those turbines are on so I think that's that's

where we are right now great okay that makes sense thank you thank you there are no further

questions at this time Liz I will now turn to call back over to you Liz thank you JL and thanks

to everyone for participating this morning our annual report on form 10k is due to the SEC on March 2nd and provides more details and disclosures about our financial statements. Events that occur prior to the date of our 10-K filing that provide additional evidence of conditions that existed at the date of the balance sheet would be reflected in our financial statements in accordance with generally accepted accounting principles. Also, as a reminder, we maintain a webpage as part of Entergy's Investor Relations website called Regulatory and Other information which provides key updates of regulatory proceedings and important milestones on our strategic execution. While some of this information may be considered material information, you should not rely exclusively on this page for all relevant company information. And this concludes our call. Thank you very

much. This concludes today's conference call. You may now disconnect.