Hello, everyone. My name is Greg, and I will be your conference operator today. At this time, I would like to welcome everyone to today's Entergy Corporation Third Quarter Earnings Call and Teleconference. I will now turn the call over to Liz Hunter, Vice President of Investor Relations for Entergy Corporation. Liz?

Good morning. Thank you, Greg, 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 GAAP 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. Today, we are reporting strong financial results as well as continued progress on business and regulatory matters. Starting with our quarterly financial results. Our adjusted earnings per share was $1.53. With our results to date and our biggest quarter behind us, we are narrowing our guidance, raising the bottom by $0.10. We also remain well positioned to achieve our long-term growth outlook. Kimberly will review the financial details in a moment. Turning to the business. Last quarter, we achieved the first quartile Net Promoter Score for utility residential service for the first time since we began tracking this metric. We're pleased to report that we've maintained our first quartile position. We are keenly focused on meeting the needs of our 3 million customers, and we believe our strategy will carry this momentum forward. Our focus on the customer starts with keeping our rates as low as possible. Again, we aim to maintain our average rates well below the national average through the remarkable commitment and creativity of our employees and a culture of continuous improvement. Today's share of wallet is roughly the lowest our customers have seen over the last 20 years. We expect it to stay in that range over the outlook period. Of course, there is more to it than that. We proactively manage the effect of fuel volatility on customers' bills, through fuel hedging programs and mechanisms to defer fuel costs during peak prices. For individual customers, we have developed tools to help them manage their bills, such as approved bill discounts for low-income seniors, payment options like average billing and payment timing, energy efficiency services, and customer assistance programs like Power to Care and LIHEAP advocacy. I'm proud to highlight that our digital LIHEAP platform recently received a Silver Best Practices Award from Chartwell for excellence in serving vulnerable customers. This tool streamlines access to energy assistance and provides real-time updates for customers in need. As we've worked to attract new hyperscale data center customers, we ensure they pay their fair share of energy infrastructure investments, while bringing other significant benefits to our communities, such as jobs, property tax payments, direct municipal infrastructure investment, and workforce development. This is consistent with their stated intent to be good neighbors. For example, at the recent groundbreaking announcement, Google said that they will protect energy affordability for existing customers by covering the full cost of powering the data center in West Memphis. They're also committed to making a significant community impact, including a $25 million fund to accelerate local energy efficiency efforts and workforce development. In September, Entergy Mississippi announced a new customer-focused initiative known as Superpower Mississippi. The initiative includes a $300 million investment to harden the grid and improve reliability with the goal of reducing outages for customers by half within 5 years. We're able to add this investment for grid improvements at no additional cost to Entergy Mississippi customers because of new revenues from Amazon and other large industrial customer investments in the state. Haley Fisackerly, our CEO in Entergy Mississippi, recently noted that customer rates would be 16% lower than they otherwise would have been due to these large customers, and that includes the incremental Superpower Mississippi investment. In customer growth news, in late September, Sempra reached its final investment decision for Phase 2 of its Port Arthur LNG project. In addition, a colocation data center, AVAIO announced an investment in the Entergy Mississippi service area. While these were included in our probability-weighted sales forecast, these developments continue to build confidence in our long-term outlook. As a reminder, we probability weight potential industrial customers in our plans, except for very large businesses, like hyperscale data centers, which we don't add to our plans until there is a signed electric service agreement. Because of our vertical integration, natural Gulf Coast advantages, thoughtful regulation, a long history of successfully working with large industrial projects, and now MISO's expedited connection mechanisms, we continue to see strong demand from businesses looking to locate in our service areas. This includes data centers and customers from traditional industrial segments. Our data center pipeline has continued to grow and now is extending from 7 to 12 gigawatts. This is based on active conversations with customers for whom we reasonably could expect to sign agreements within the next year or 2. With line of sight on incremental opportunities, we've added 4.5 gigawatts to our agreement for the purchase of power island equipment, including steam turbines, combustion turbines, and heat recovery steam generators. This addition represents 6 units that will be delivered in time to support commercial operations in 2031 to 2032. In total, we now have secured more than 19 gigawatts of capacity, 11 gigawatts of which is accounted for due to growth or other supply needs. That leaves 8 gigawatts for additional growth. We secured other critical equipment, including transformers and breakers, and we have secured 90% of materials required for our planned transmission projects through 2030. We also have agreements with EPCs for generation projects through mid-2029 and have line of sight for additional projects. We're also well positioned for solar projects. For our owned projects, we secured approximately 75% of our critical equipment, including generator step-up transformers, high-voltage breakers, and solar modules. We also have clear line of sight to the remaining 25% through our existing supplier relationships. In July, FERC approved MISO's Expedited Resource Addition Study, or ERAS process. We have since submitted 9 interconnection requests for 12 plants into the new process. 8 of these plants in our ERAS submission are in our plan and 4 are available for incremental growth. ERAS has worked well to support speed to market for customers trying to come online as quickly as possible as well as help us respond to the national security priority for rapid energy deployment to win the AI race. We expect to start receiving our first project approvals by the end of this year. With standardized designs for our generation projects and our transmission lines and our history of successful execution on large projects, we remain confident in our ability to manage our operations and execute on our capital plan. We are also well positioned to serve potential new customers above our current plan. For a customer base that continues to grow, perhaps it is no surprise that our system, as well as Entergy Arkansas and Entergy Texas, hit new peak loads in July. Our system performed well during these high load periods. Responding to that customer growth, Entergy Texas remains on track for the completion of the Orange County Advanced Power Station next spring. The plant's commissioning is underway and first fire is expected in December. Our other large generation and transmission projects are also on track. Last week, Entergy Mississippi broke ground on the Vicksburg Advanced Power Station. We also support customer growth, including the large customer that Entergy Mississippi signed this past February. Entergy Louisiana recently announced selections from its baseload generation RFP to support customer growth. That includes 2 combined cycle resources that will be self-built. For accelerated resilience, we expect to file Phase 2 plans in Louisiana and New Orleans within the next several months. This timing allows us to maintain operational momentum with our resilient investments. To date, our operating companies have invested about $580 million in approved resilience work. We've completed 32 line hardening projects, upgrading more than 13,000 structures, and we have hardened 10 existing substations to mitigate the impacts of both hurricane-force winds and storm surge. In addition, Entergy Texas was recently awarded $200 million in grant funding by the PUCT from the Texas Energy Fund for resilience projects with no cost to customers. The grant will allow for the hardening of more than 8,000 distribution poles covering 338 miles as well as hardening 16 transmission lines. We appreciate the proactive support from our state regulators and legislative bodies to improve the storm readiness of our system for the benefit of all customers. With the customer growth opportunity before us and excitement throughout our service areas, we continue to work with our stakeholders, including regulators, elected leaders, community leaders, and local vendors to meet customers' needs and to improve their outcomes. In August, the Louisiana Public Service Commission approved the settlement for generation and transmission resources needed to serve Meta. Meta's generational investment will bring significant benefits, including jobs, workforce development, and state and local tax income. As the LPSC Staff highlighted at the business and executive meeting, contracted minimum bills ensure that Meta is paying the incremental cost to serve them during the contract term without imposing costs on other customers. These features provide benefits to support keeping rates as low as possible for Louisiana customers. Last week, the Louisiana Public Service Commission also approved the 200-megawatt Bogalusa West Solar project, which was the first project approved through Louisiana's accelerated solar approval process. In Arkansas, the Public Service Commission approved the Generating Arkansas Jobs Act rider. This rider, enabled by the legislation this past spring, allows recovery for new economic development related and other customer-critical generation and transmission investments outside of the formula rate plan 4% cap. Additionally, it includes recovery of carrying costs on CWIP during construction, thus lowering costs for customers. Under the new rider, Entergy Arkansas filed in early August for the Jefferson Power Station approval. Also under the new rider, Entergy Arkansas filed for approval in September for Cypress Solar, a solar and battery storage facility to support economic development via Google's recently announced data center. Moving to Texas. In September, the Public Utility Commission approved the Legend combined cycle power station and Lone Star, a simple cycle peaking unit. They will provide efficient, reliable power to support the rapid growth in our Southeast Texas service area. While the commission approved the generation, it also implemented a cost cap at our filed cost estimates totaling $2.4 billion, including transmission, carrying costs, and contingency. As I noted earlier, we have already contracted with the EPC and secured the long lead time equipment, which comprised a significant portion of the construction costs. The Texas Commission also recently approved 2 large transmission projects that serve growth and improve reliability and resilience of the system. SETEX, the Southeast Texas Area Reliability Project at $1.4 billion 500 kV line and the Legend 230 kV line, which will serve industrial customers in Port Arthur, including Phase 2 of the Sempra LNG project. Separately, Entergy Texas filed for an increase in its DCRF rider. We expect a decision from the PUCT by the end of the year. These are exciting times in Entergy and exciting times for our industry. We are delivering unprecedented growth for our region and economic development that benefits the customers and communities we serve. At the same time, we are answering the call to support our national security through our rapid response to the energy needs of companies working to win the global AI race. All that while keeping rates as low as possible for our customers. The EEI Financial Conference is in a couple of weeks, and we'll share additional color regarding the strong foundations underpinning our differentiated growth story. Notably, our long-term customer sales growth outlook is robust, including continued support from both traditional industrial and data center customers. We are well positioned to support speed to market through our supply chain positioning, design choices, stakeholder engagement, and strong balance sheet. And we are successfully executing on critical issues that our existing customers care about, including keeping rates as low as possible and deploying resilience and reliability investments. We look forward to continuing this conversation with you at the EEI Financial Conference in a couple of weeks. I'll now turn the call over to Kimberly, who will review our financial results for the quarter.

Thank you, Drew. Good morning, everyone. We had another great quarter. I'll now walk through our financial results as well as our guidance and outlook, and I'll provide a look ahead to EEI. Starting with earnings. Our adjusted EPS for the quarter was $1.53, as shown on Slide 4. Primary drivers were strong sales growth and the effects of investments made for our customers, partially offset by higher other O&M and other operating expenses and an increase in our share count from settling equity forwards. Earnings contribution from sales growth was positive even with weather being milder this quarter compared to last year. Weather-adjusted sales for the quarter were once again very strong, increasing approximately 4.5%. Industrial sales were the largest contributor with more than 7% growth, primarily from new and expansion customers that continue to ramp up their operations. Slide 5 summarizes our credit ratings and affirms that our credit metric outlooks remain better than rating agency thresholds. In the quarter, S&P issued credit reports on each of our operating companies and Entergy Corp. Moody's also issued reports on Entergy Mississippi and Entergy New Orleans. Both agencies affirmed all ratings and outlooks. Last quarter, we discussed the nuclear tax credits earned in 2024. Since then, we have completed transactions to monetize these, which netted more than $535 million after transaction costs. We continue to work with our regulators on how and over what time period we will provide these benefits to customers. We expect this to happen over an extended period of time. 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 2025. We'll talk more about our credit at EEI, but I'll give you a quick preview. Our credit metric outlooks are strong with FFO to debt above our thresholds throughout the outlook period, achieving our 15% target during the period. Our financial health is bolstered by all the work we've done, including the structure of our new large customer ESAs to protect existing customers and our credit, improvement in our pension funded status, constructive regulatory mechanisms, and conservative planning assumptions. All of these have strengthened our balance sheet and created benefits for our customers. We continue to see strong underlying fundamentals and flexibility to meet our objectives. We are rolling forward our outlooks to 2029, shifting our 4-year capital and equity plans forward, as you can see on Slide 6. Our updated capital plan for 2026 through 2029 is $41 billion. The equity associated with that plan is $4.4 billion within the 10% to 15% range of the total capital plan. Our capital and equity plans include alternative financing assumptions, which shifts the capital outlay for some projects beyond our 2029 outlook. This better aligns the cash outflow with when assets are placed in service. We have been proactive in addressing our equity needs, selling forward contracts through our ATM as well as the block transaction we executed in March. We've taken significant price risk off the table and have ample time to raise capital, including through our ATM program. For our 2026 through 2029 equity need, about 45% is already contracted, which takes us well into 2027. Through the third quarter, we have settled approximately $800 million of equity forward. In October, after quarter end, we settled an additional approximately $330 million or about 5.7 million shares. We are using these funds to continue to invest for the benefit of our customers. Our adjusted EPS guidance and outlook are shown on Slide 7. As Drew mentioned, with solid results through the third quarter, we are narrowing our 2025 guidance range, raising the bottom by $0.10. Higher-than-planned revenue from weather as well as other planning updates have enabled us to manage the business and flex spending in areas that benefit our customers. Our Flex program helps us ensure that we deliver predictable adjusted EPS growth year in and year out while meeting our customer needs. Looking beyond 2025, we continue to see very strong growth driven by our customer-centric capital plan. Our adjusted EPS through 2028 remains unchanged, and as we add 2029 to our outlook period, our long-term compound annual growth remains strong at greater than 8%. Drew and I, along with our operating company leaders will be in Florida in less than 2 weeks, where we will talk about our strong customer growth story as well as our plans to invest in reliability and resilience to better serve our customers. We have a solid base plan consistent with our strategic objectives. As Drew discussed, we have a strong customer pipeline, including 7 to 12 gigawatts of data center opportunities, and we have secured critical equipment to bring additional customers online. Today, we have provided our adjusted earnings per share outlook and a high-level view of our preliminary capital and equity plans through 2029. At EEI, we will provide more details on these outlooks. We are excited about the opportunities before us and look forward to talking with you at EEI. And now the Entergy team is available for questions.

It looks like our first question today comes from Shar Pourreza with Wells Fargo.

It's actually Constantine here for Shar. Congrats on a great quarter. Maybe starting off on the updated CapEx plan and kind of the 4.5 gigawatts of the power island equipment. Is that directly associated with some of the more visible load in the current pipeline? Do you anticipate any incremental CapEx needs that would require regulatory approval before making it into the '29 plan? Just how should we be thinking about the upside here?

Constantine, it's Kimberly. The $41 billion includes the capital that's needed to support the load that is in the forecast. The 4.5 incremental gigawatts that Drew referenced would support additional customers that could come online. So we referenced 7 to 12 gigawatts in the data center. That's up from 5 to 10 in the last quarter. We've added, as you noted, additional plant power island equipment in order to support that. To the extent that those customers in that pipeline reach agreement, we would expect that you would need supplemental capital to support that, and that's what we plan ahead for here.

Okay. Perfect. And then maybe shifting to the longer-term outlook, kind of with the large load growth solidifying and under contract, you're locking in kind of the CapEx plans and the associated equipment. Do you see any opportunity to potentially guide on the longer-term EPS growth outlook beyond 2030 just as you kind of gain that visibility?

As you know, we added 2029 here. There’s certainly good visibility through that period. If we’re able to land additional customers, we’ll provide you that visibility. However, beyond that, we believe we have long-term opportunities that extend past this period.

Okay. Perfect. And just a quick follow-up on kind of the generation needs, kind of more broadly. Do you see customers agnostic to the resource mix? Or is there still a push for some renewable components as we've kind of seen with hyperscalers demanding for nuclear SMRs and other technologies?

We talk to our customers about all kinds of supply. Certainly, we've lined up here. Drew referenced both gas resources as well as renewable resources. We do have a pipeline of opportunity around renewables based on customer needs, but we also continue to look for ways to meet their needs to ensure that we are speed to market as well as meeting clean needs. So we think it's an all-of-the-above approach over time.

Yes, and Constantine, I'll just add that we are building this gas generation, but we have expectations that we will also do carbon capture at some point, and we are working on that actively. We have RFPs out in for some of our assets in Mississippi and in Texas to test that. We still have FEED studies going on at our Lake Charles Power Station in Louisiana. We're exploring various options to figure that out. We're supported by our data center customers that are wanting to achieve those same objectives. So we think we're well positioned to figure that out over time, but we don't have anything specific to announce today.

I wanted to expand a bit more on the future outlook. Some of the comments may have pointed out the capital moving closer to plant commercial operation dates, which might extend beyond the planned period. I'm curious if you could discuss the ongoing momentum across the plan and how it appears after the planned period, especially since you've mentioned in the past that this will accelerate towards the end of the decade.

Jeremy, it's Kimberly. I guess just to clarify, $41 billion through 2029, I referenced some plants that close outside the period. Some of that is alternate financing. So you don't see the spend in this period and all the spend would go out when that closes. So that was that reference there. But certainly, with the additional equipment that we've secured in the pipeline that we see, we would expect investment to continue well beyond this period.

Yes, and we do have turbine slots that are delivering for commercial operations in '29, '30 that still have not been announced as overall projects. There are still opportunities that could add additional capital in the out parts of our current outlook period.

Yes, that project is obviously in early stages. It was filed in September, but the customer is continuing to move forward with the ramp as we would expect. As you know, there are minimum bills associated with all of these large customers that help support during the construction period. But I don't see anything different on that ramp than where we have been similar to all of our other customers.

Yes, people are excited in Arkansas about that project. At Google's groundbreaking last month, the governor and many local leaders, including the Mayor of West Memphis, were present. There is also a 600-megawatt solar facility and a 350-megawatt battery that will support Google. This investment is currently being reviewed by the Arkansas Commission as well. We expect to navigate that process with the various stakeholders. At this point, there is significant support in Arkansas for the economic development this opportunity will bring.

Got it. And maybe just taking a step back overall, I guess, commercial discussions here with hyperscalers. At this point, I guess, how would you describe the tone or pace of discussions here? Is there more or less urgency to sign up incremental load at this point given the success that you've had so far?

Well, certainly, I would point to the raise from 5 to 10 to 7 to 12 gigawatts around our increased customer conversations. Those conversations cover all the things that we've talked about before, speed to market, getting to client, and also how the stakeholders and bringing the stakeholders along. As Drew said, in Arkansas, very excited about that transaction in Arkansas. We think the conversations continue to be strong and continue to support our incremental increase in that pipeline.

Got it. One last quick one, if I could, on the transmission side. Just given some of the load shed events due to storm activity earlier in the year, wondering how you think about the opportunity to deploy more transmission, enhance flexibility, such as increasing connectivity into Mississippi. Just wondering how you see the opportunity set at this point.

Yes, we do still see a robust transmission opportunity, but it will be customer-driven based on how the grid needs to adapt to continued growth in our service territory. Right now, we have a very robust over 400 miles of 500 kV line. We have a lot of 230 kV transmission that we are also building. We're getting ready to file in Louisiana, the Babel to Webre line. I think I talked about that last quarter, which is part of that 500 kV system, and we have approvals pending in Texas and in Louisiana on transmission right now. So there is the possibility for significantly more. We have quite a bit coming through the MTEP process that's seeking MISO approval by the end of this year. Depending on the growth, there could be additional investment opportunities out there. So we are expecting continued significant transmission investment going forward.

I was wondering, let's see, you might have said before, but I may have missed it. What's the time frame for the 4.5 gigawatts of the power equipment that you secured? And I guess I was wondering, is this a stepping stone? Are you still actively working to secure additional power equipment in a similar way?

The timing for the extra 6 units would support commercial operations in 2031 and 2032. We're using our standard design of 750 megawatts, which totals a little over 4 gigawatts. That's the plan. I can't remember the last part of your question, David, remind me.

Yes. Curious if this is a stepping stone. Are you still actively in discussions and working to increase your access to gas turbine supply beyond that 4.5.

Right now, it matches what we see as our customer needs. If there continues to be growth, then we may continue to go into the market and seek additional turbine access. But I think that's where I would put it right now. It's meeting our expectations of potential growth that we see in the near term. We're also looking at a number of other things. We continue to monitor new nuclear and look into that and talk to our customers about that. We are also looking at a number of upgrades on our system to provide incremental supply. Several things are out there that could still drive incremental generation capacity even beyond just gas turbines. Thank you for that question. We're excited to see some investment happening. The industry really needs to manage construction risk effectively. We commend the efforts that Brookfield, Westinghouse, and Cameco are making with the Federal government to address this. There are still many details to be clarified, and we look forward to discussing their initiatives further. We're pleased to see progress and the potential it has to advance the industry. Additionally, there is significant interest from our stakeholders in introducing new nuclear energy in Texas, Louisiana, Mississippi, and Arkansas. Each of these states has commissions or task forces exploring this, and we are actively involved in all of them. We continue to investigate these opportunities.

So I was just wondering, we've all read about the Manhattan-sized data center in your Louisiana service territory from Meta. So how much of that is currently covered by ESAs and reflected in your pipeline?

Right now, the only thing that we have in our outlook is the signed ESA that we previously announced about a year ago almost now. That project has been publicly said by Meta to be 2 gigawatts of compute. Any beyond that is not currently reflected in our outlooks. We wouldn't comment on any specifics of the size or timing of any project, just like for that potential opportunity, even though we know that they've been posting about it. But we wouldn't comment on it consistent with our ongoing policy for not commenting on specific customer opportunities.

A couple of questions for me. On the regulatory front, given all of the demand from large customers and all the trends that we know about, do you envision that you will need something more beyond your regular formula rate plan proceedings to accommodate that growth and recovery, of course?

Yes, it varies by jurisdiction. Thank you for that clarification. In Mississippi, there is a law that supports significant economic development projects by allowing them to proceed with a presumption of the certificate of convenience and necessity. However, we still need to obtain regulatory approval for formula rate plans and similar matters in Mississippi. The commission is still involved, but we can advance projects there. Louisiana and Arkansas have also made progress. Kentucky recently enacted the Generating Arkansas Jobs Act, which provides an expedited process. We are continuing our efforts in Arkansas, and we anticipate similar progress in Louisiana. We plan to utilize the same procedures in Louisiana, Arkansas, and Mississippi for large economic development projects.

Got it. Got it. And then my other question was the 12-gigawatt pipeline. Could you help us and break it down by, I guess, the stage it's in, like how much of that is in the ESA stage versus the slightly earlier maybe in the process?

Sophie, it's Kimberly. I would not think of that as signed ESAs. That is opportunity in the pipeline. It's in various stages, but not all the way to the end. As Drew mentioned earlier, we don't include in our forecast until we get to certainty around the signed ESA. So that would not be in that 7 to 12 gigawatts that we gave.

I had a clarifying question following up on David's a little bit. Could you explain the comment on the 8 gigawatts for additional growth from the power commitments above the plan? Because I recall it was 7 gigawatts from the second quarter call, and I know you said you added 4.5 gigawatts. But does that mean you execute against some of that incremental opportunity? I was just a little confused on that piece, if you could clarify.

Sure, Paul. I would think about in the second quarter call, we said 15 gigawatts, 8 was in the forecast through '28, and 7 was for growth. We now have 19.5 gigawatts compared to that 15, and 8 is for growth. So that delta is what I was referencing earlier around it's either in the forecast or it's in the forecast, but the capital closes outside the period.

Yes, I think we would expect that there would be additional renewables associated with large hyperscaler deployment. We've certainly seen that with each of our announcements thus far. AWS had, I think, 600 megawatts of solar associated with Google similarly.

I think one, just maybe a follow-up. On the 4.5 gigawatts, I guess, of the additional power equipment, is that incremental to what's on Slide 14 of, I guess, you have 7 CCGTs listed that is incremental to that?

Yes, the 4.5 would be additional to what is shown on that page. There are other projects included in our total of 19 gigawatts that are not listed there, but the 4.5 would be an addition to what's already presented.

Great. I think you mentioned in your prepared remarks about the availability of EPC. It appears there are no issues in obtaining craft labor contracts for constructing all the generation facilities. If you could provide any insights on this, especially since we've observed other large projects facing challenges with their size. However, it seems there are no labor issues. I would appreciate any additional information you could share on this topic.

I would say that there are real challenges with labor. It's not easy to get the labor lined up. There is a real need for skilled craft of all types, and that hasn't changed. The result has been that there are increasing costs associated with these combined cycle projects. It's very real. Our projects aren't immune to that, but we're working through it with the EPCs.

If I can first piggyback on Angie's question about the massive data center build-outs. I don't need or expect you to comment specifically on Meta's Hyperion project, but how are you thinking about the potential for some of these data centers to build on-site power generation themselves? Have you been talking to them about their interest in self-generating versus buying power from your utilities? I know your CapEx and earnings outlooks are based on real signed contracts, but how are you thinking about that going forward?

To manage transmission costs, we are constructing generation facilities close to where our customers are located. While this may not be on-site or behind the meter, it is very nearby. An example of this is the Meta project. From a physical grid perspective, there isn't much difference. These customers have the ability to generate their own power but prefer to invest their capital elsewhere. This is evident in Meta's recent financing of their facility, where they are leasing it back in North Louisiana. They have capital needs and would rather not invest in generating stations. We are competitively positioned to support their growth by building our plants nearby, achieving similar benefits, and ensuring capital is deployed on our books instead of their balance sheet. I can't provide an update today as the team is still working on the case, and I don't want to get ahead of them. However, in Arkansas, over time, you will see similar benefits to those in other areas, where the advantages from a large new customer will assist existing customers. We expect to detail this in the upcoming rate case. Additionally, we are currently engaged in discussions about the existing processes concerning the formula and the special rate contract we submitted in Arkansas for Google.

Just maybe trying to tie around this 4.5 gigawatts of incremental. I was just wondering if you could maybe tie that with the comments made a little bit earlier on the ERAS queue as well. Is that 4.5 gigawatts, does that tie to those extra incremental, I feel like 4 projects in the queue? More broadly, if the ERAS process right now is working as intended and seemingly should be able to help for the forward needs?

Yes, the 4.5 gigawatts, those extra 6 turbines are not yet represented in the ERAS queue. The things that are in the ERAS queue would be much more near term than those. Those projects that we have in the ERAS queue would be coming in much earlier than that. So hopefully, that answers your question.

Drew and Kimberly, just kind of again on some of this discussion around the dispatchable generation. Can you talk a little bit more about the alternative financing agreements that you guys are using? Can I extrapolate what that is, the sizing of that, if you've gone from 8 gigawatts that I think was committed in 2Q to now the implied 11 gigawatts in Q3? Does that 3 gigawatt increase basically what's being alternatively financed and falls outside of the plan? Just can you give a flavor of the timing around that and the magnitude? Because it seems like that would be a $6 billion to $7.5 billion of spend that could come in 30 or 31, which would look like it would drive an outsized amount of growth.

Steve, it's Kimberly. I wouldn't think of it as a direct correlation between that alternate financing and the 3 gigawatts that you referenced. First, we added an extra year, so you rolled forward to 2029. You can see the run rate of that is consistent with where we've been in each of the prior years before that. That's your biggest piece. There is some alternate financing. We talked about that actually in our Legend filing in Texas as a way to help with the overall cost, but also time that closing with when that asset goes into service and throws off cash. We haven't sized that. We'll have a little more visibility into that at EEI. I think your numbers are a bit outsized relative to what you have here, and I'd think more about the 2029 addition.

Sorry, Steve, just to add to that, all of these projects that we are bringing on that we've contracted for with these turbines, we expect to achieve commercial operations by 2032. They're all coming pretty fast. You could see a number of them on that Page 14 that we were referencing earlier. A whole bunch more are coming in the next few years, beyond that, if everything comes together on the schedule that we've laid out with the turbine orders. Quite a bit of capital is just over the horizon from 2029 to support that potential build-out.

Thank you, Greg, and thanks to everyone for participating this morning. Our quarterly report on Form 10-Q is due to the SEC on November 10 and provides more details and disclosures about our financial statements. Events that occur prior to the date of our 10-Q 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 web page 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.

Thanks, everyone. Again, this concludes today's conference call. You may now disconnect.