Thank you, and good morning. On the call with me today are Marty Lyons, our Chairman, President, and Chief Executive Officer, and Lenny Singh, our Executive Vice President and Chief Financial Officer, as well as other members of the Ameren management team, including Michael Moehn, Group President of Ameren Utilities.

This call contains time-sensitive data that is accurate only as of the date of today's live broadcast, and redistribution of this broadcast is prohibited. We have posted a presentation on the amereninvestors.com homepage that will be referenced by our speakers.

As noted on page 2 of the presentation, comments made during this conference call may contain statements about future expectations, plans, projections, financial performance, and similar matters, which are commonly referred to as forward-looking statements. Please refer to the Forward-Looking Statements section in the news release we issued yesterday, as well as our SEC filings for more information about the various factors that could cause actual results to differ materially from those anticipated.

Now here's Marty.

Thanks, Andrew. Good morning, everyone, and thank you for joining us.

Beginning on page 4, here we highlight some of the key updates we will cover today. We will walk through our 2025 financial results, recap key accomplishments, and discuss how we are well-positioned for 2026 and the years ahead.

Specifically, we delivered 2025 adjusted earnings of $5.03 per share, which represents 8.6% growth over adjusted 2024 results. We affirmed our 2026 earnings per share guidance range of $5.25 to $5.45.

I'm also pleased to report that this week, we signed 2.2 GW of large load electric service agreements in Missouri. We continue to take meaningful steps towards supporting significant economic development opportunities emerging across our service territory, while also continuing to provide strong value for all our customers and our communities.

I'm proud of not only the strong operational and financial results we delivered as an Ameren team, but also our strategic plans and accomplishments that we expect will lead to competitive long-term returns for our shareholders in the years ahead. Today, we issued 6% to 8% earnings per share growth guidance for the period 2026 to 2030, and we continue to expect year-over-year results near the upper end of that range.

Turning now to page 5. As always, at the center of everything we do is creating value for the 2.5 million electric and 900,000 natural gas customers that we have the privilege to serve.

Our three-pillar strategy, investing in rate-regulated infrastructure, advocating for constructive regulatory and legislative frameworks, and optimizing our business, continue to guide our work for customers, communities, and shareholders. This year, the Ameren team accomplished all of the key strategic objectives we outlined a year ago, shown on page 6.

This included investment of more than $4 billion in electric, natural gas, and transmission infrastructure. We installed nearly 26,000 electric distribution poles, 283 miles of upgraded transmission and distribution lines and underground cable, 750 smart switches, and 31 new or upgraded substations.

We also made significant progress on the development of new generation resources. On the regulatory front, we received constructive orders in both Missouri and Illinois electric and natural gas rate reviews.

Legislatively, the enactment of Missouri Senate Bill 4 provides support for economic development and investment in reliable energy for years to come. To further advance economic development and ongoing reliability, we updated our Ameren Missouri preferred resource plan last February and immediately began executing on the accelerated components.

Speaking of economic development, in 2025, we worked with stakeholders across Missouri and Illinois to support more than 70 projects that are expected to bring an estimated $3.6 billion of capital investment and approximately 3,700 jobs to our service territory from new or expanding businesses, fueling regional economic growth for years to come. These businesses represent the diverse set of industries operating across our states, including healthcare, manufacturing, distribution, warehousing, alternative energy, and food production.

We also worked closely with stakeholders to design and obtain approval of a new rate structure for large load customers to support fair cost allocation and reliable service as customer energy needs evolve. I'm proud of our team's performance in 2025.

Collectively, we focused on safely providing electric and gas service to our customers, battling through challenging weather events, building more reliable and resilient infrastructure, and maintaining disciplined cost management. As a result of strong execution of the company strategy and solid operating performance, we delivered 2025 adjusted earnings of $5.03 per share, up 8.6% from 2024 adjusted earnings of $4.63 per share.

Turning to page 7. Here we highlight the value we delivered for our customers and communities.

In 2025, severe weather events tested our system as we experienced approximately 30% more storms than average over the past 10 years. The severe storms and tornadoes, as well as extreme temperatures experienced in our territory, highlighted the value of our investments, which are designed to bolster reliability and resiliency, and the value of our team members, who braved these challenging conditions to safely restore service when our customers needed us most.

In the face of this elevated storm activity, our system and teams performed exceptionally well. Reliability and resiliency remained strong, benchmarking in the first quartile for SAIFI performance, and second quartile for SAIDI performance.

In 2025, our investments to strengthen the grid prevented more than 56 million minutes of potential customer outages across Missouri and Illinois, more than double the prevented outage minutes from last year. The investments to strengthen the reliability of our system are also the foundation for economic growth and strong customer satisfaction.

Notably, a recent economic impact study shows our operations in Missouri and Illinois generate more than $20 billion in annual economic activity, in addition to other benefits to the communities where we live and work. At the same time, we continue improving the day-to-day experience for customers.

By leveraging technology and streamlining service processes, we've given customers more control and transparency with regard to energy use and billing and a quicker path to assistance, reducing our average call handle time by 21% and total call volume by 12% since 2023. These improvements are resonating with customers, who have rated their satisfaction at approximately 4.6 out of 5 stars on average after interacting with us across all our service channels, including call center, website transactions, and field service.

Moving to page 8. We recognize that our critical infrastructure projects represent significant investments, which is why we prioritize the projects that are most beneficial for customers and maintain a sharp focus on keeping rates as low as possible.

Through disciplined cost management, we have been able to keep our Ameren-supplied residential rates in Missouri and Illinois on average below both national and Midwest averages. Importantly, the percentage of the average customer's income spent on electricity has remained stable, generally tracking the rate of inflation over the last decade, even as we've made substantial investments in critical infrastructure.

Ameren invests hundreds of millions of dollars each year to support our customers and communities through energy efficiency programs, demand response initiatives, and substantial energy assistance funding. In addition to funding Ameren-developed programs, we also partner with a wide range of organizations to connect customers with available federal, state, and local assistance.

Turning to page 9. Disciplined execution of our strategy has delivered strong and consistent results over time.

Weather-normalized adjusted earnings per share have risen at an approximate 7.4% compound annual growth rate since we divested our merchant business in 2013, while annual dividends per share have increased 78% through 2025. This performance has resulted in a total shareholder return of greater than 300% over the same period, significantly outperforming utility index averages.

As we look ahead, we believe execution of that same strategy, putting customers and community value at the center, will continue to drive strong returns. Moving to page 10.

We turn our focus to our 2026 key strategic objectives, which continue to be focused on resource adequacy, reliability, affordability, and supporting local economic growth. This year, we plan to invest approximately $5.5 billion in electric, natural gas, and transmission infrastructure to bolster the safety, security, reliability, and responsiveness of the energy grid.

As we execute our generation plan over the coming years, we will continue to file CCN requests for new generation resources, and we expect to file our triennial Missouri Integrated Resource Plan by late September, which will outline updated generation plans for the next 20 years. Further, last month we filed the required Ameren Illinois Integrated Grid Plan, detailing electric investments needed for 2028 through 2031, and we are seeking ICC approval of the plan by the end of this year.

We continue to evaluate regionally beneficial transmission investment opportunities in MISO. We submitted bids for two Tranche 2.1 competitive projects last month and are evaluating two other bidding opportunities.

As always, while we work to accomplish the key objectives highlighted on this page, we remain focused on operating as efficiently and effectively as possible, with a goal to hold O&M growth below the rate of inflation and as low as prudently possible over our five-year plan. We have a number of initiatives underway to continuously improve and optimize our performance.

On page 11, we outline how the execution of our strategy is expected to drive a strong total shareholder return over the next five years. Today, we are rolling forward our five-year investment plan, and as you can see, we expect to grow our rate base at a 10.6% compound annual rate from 2025 through 2030.

This strong expected rate base growth will be driven by $31.8 billion of planned infrastructure investment, a 21% increase in our five-year capital plan compared to the plan laid out last February, with the increase primarily due to robust expected generation investment needed to serve anticipated load growth and support system reliability. We continue to expect 2026 earnings to be in a range of $5.25 per share to $5.45 per share.

The midpoint of this range represents 8.1% earnings per share growth compared to our original 2025 earnings guidance midpoint. Building on our proven strategy and track record of strong earnings growth, we continue to expect to deliver 6% to 8% compound annual earnings per share growth from 2026 through 2030, using the midpoint of our 2026 guidance of $5.35 per share as the base.

More specifically, we expect consistent earnings growth near the upper end of this range in 2027 through 2030. In addition, last week, Ameren's Board of Directors approved a quarterly dividend increase of 5.6%, equating to an annualized dividend rate of $3.00 per share.

This represents our 13th consecutive year of increasing our dividend. We continue to expect dividend growth in line with our long-term EPS growth guidance, and we expect our dividend payout ratio, which today is approximately 56%, to be maintained within a range of 50% to 60%.

Combined, our earnings and dividend growth expectations support our strong long-term total shareholder return proposition. On page 12, we provide an update on the Ameren Missouri large load rate structure, which the Missouri PSC approved last November.

This rate structure is in accordance with Missouri state law, which requires data centers to pay for costs to connect them to our system and for them to pay their share of ongoing cost of service. Under the large load rate structure, customers requesting 75 MW or more will pay a base rate, which at this time is approximately 6.2 cents per kilowatt-hour, and agree to additional terms and conditions under an ESA.

The additional terms will include a service commitment of 12 years after ramp, a minimum demand charge of 80% of contracted capacity, termination provisions, and collateral requirements, all designed to protect existing customers. In addition, new customer programs will allow qualifying customers to elect to advance their clean energy goals by supporting the carbon-free energy resource of their choice through incremental payments, which would be used to help offset costs of service for other customers.

Turning to page 13, I'll provide an update on the large load data center opportunities in our service territory. In the coming years, these projects are expected to bring in jobs, tax revenues, and investment, and to drive long-term economic growth.

Just this week, Ameren Missouri executed ESAs with large load customers that cumulatively represent 2.2 GW of new demand to be served in the future. Executing these ESAs is an important milestone.

Of course, there are a number of other project milestones still to be achieved, including customer project announcements, groundbreaking, and construction. Still, these agreements are an exciting development.

Our five-year financial plan laid out today assumes 6.2% compound annual sales growth from 2026 through 2030, which includes a base assumption of 1.2 GW of new load growth by 2030, consistent with our preferred resource plan and is depicted by the blue line on the chart on the right-hand side of this page. The 2.2 GW of executed ESAs represent upside to our sales and earnings forecasts.

Developers continue to evaluate Missouri and Illinois for additional future large load projects. In Missouri, this pipeline includes projects with transmission interconnection construction agreements representing a total of 3.4 GW of potential new demand, inclusive of projects associated with the executed ESAs.

In downstate Illinois, this pipeline includes projects with construction agreements representing a total of 850 MW of new demand. We have now received approximately $46 million in non-refundable payments from developers in Missouri and Illinois to cover the cost of transmission upgrades related to these construction agreements.

These payments reflect developers' confidence in and commitment to their projects. Turning to page 14 for an update on our generation build-out.

The integrated resource plan filed last February called for development of 5.3 GW of new generation resources between 2025 and 2030. We've made strong progress on development of these resources over the last year, with nearly 2.7 GW of new generation in progress.

In December, we placed Vandalia Energy Center, a 50 MW solar facility, in service, and the Bowling Green and Split Rail Solar Energy Centers, totaling 350 MW, began final testing in January. Further, as part of strengthening our existing fleet, dual-fuel conversion work is expected to be completed by the end of the year at our Audrain Energy Center to add 700 MW of capacity on the coldest winter days when gas is otherwise unavailable.

We continue to advance our new natural gas generation projects as well. Yesterday, the Missouri PSC approved the certificate of convenience and necessity for the 800 MW Big Hollow Natural Gas Energy Center and accompanying 400 MW battery storage facility, both scheduled to be in service in 2028.

Proactive strategic supply chain work for all of our planned generation resources continues. We have procured long lead-time components, such as turbines and transformers, for our planned near-term energy centers, and we have executed gas supply contracts and awarded labor contracts for both simple cycle natural gas facilities.

We continue to actively plan for the construction of a 2.1 GW combined cycle facility included in our IRP, having secured production slots for the three necessary turbines. We anticipate filing our CCN request with the commission later this year for this combined cycle facility, which we expect to be placed in service in 2031.

These efforts keep us on track to maintain a balanced energy mix to meet growing demand affordably and reliably, targeting approximately 70% generation from on-demand resources and 30% from intermittent resources by 2040. Moving now to page 15 for a transmission update.

As we look ahead, there's a significant transmission investment needed to support new large load customers as well as energy resources to supply this new demand reliably. In addition, we remain focused on executing our assigned Tranche 1 and 2.1 long-range transmission projects and developing strong proposals for Tranche 2.1 competitive projects.

In January, we submitted joint bids for two Illinois projects, and we expect MISO to select the developers for the projects this summer. Bids for two additional MISO projects are due mid-2026, and we are evaluating those opportunities.

Recall that we do not include competitive projects in our capital plan or 10-year pipeline until projects are awarded. Now turning to page 16 for an update on investment opportunities in our service territory over the next decade.

Our pipeline continues to grow, standing today at more than $70 billion. These investments will strengthen the safety, reliability, and resiliency of the energy grid, powering the quality of life for families and businesses and supporting thousands of jobs and driving economic growth across our communities.

Moving to page 17 to sum up our value proposition. We're confident that the execution of our strategy in 2026 and beyond will continue to deliver superior value to our customers and shareholders.

Solid operating performance and prudent infrastructure investment, along with a strong balance sheet and strong credit ratings, supports safe, cost-efficient, and reliable service for our customers. Robust infrastructure investment is needed in each of our business segments to ensure safe, reliable service and to meet the demands associated with exciting economic development opportunities.

These infrastructure investments are anticipated to drive compound annual rate base growth of 10.6%, which along with sales growth, provides the foundation for our 6% to 8% compound annual earnings growth expectations. Continuing our long track record of delivering strong earnings growth, coupled with an attractive and growing dividend, will result in a compelling total return story for those seeking a high-quality utility investment opportunity.

I'm confident in our team's ability to effectively execute our investment plans and other elements of our strategy across all four of our business segments. Again, thank you all for joining us today.

I would now like to welcome our recently appointed Chief Financial Officer, Lenny Singh.

Thanks, Marty. I'm glad to be here with you today.

I'll begin on page 19 of our presentation with our 2025 earnings results. Yesterday, we reported 2025 adjusted earnings of $5.03 per share compared to earnings of $4.63 per share in 2024.

Our 2025 adjusted earnings exclude certain tax benefits at three of our business segments: Ameren Transmission, Ameren Illinois Natural Gas, and Ameren Illinois Electric Distribution. These tax benefits were recorded in response to IRS guidance issued to another taxpayer and associated regulatory orders issued by FERC and the Illinois Commerce Commission regarding treatment of net operating loss carryforwards.

Pursuant to this guidance and these orders, we decreased income tax expense by a total of $86 million in 2025, resulting in a 32 cents per share benefit. On page 20, we summarize key drivers impacting adjusted earnings at each segment.

As Marty outlined, we achieved strong earnings growth supported by strategic infrastructure investments and robust retail sales at Ameren Missouri. Weather-normalized sales at Missouri grew 1% overall, with a 0.5% and 1.5% growth for our residential and commercial classes, respectively.

We also experienced favorable weather across our service territory. At the same time, we funded incremental operations and maintenance activities in Missouri to improve grid and energy center reliability for the benefits of our customers.

Of course, disciplined cost management remains core to our way of doing business. Process improvements across both states help us start jobs sooner and complete work faster, delivering tangible benefits for customers.

For instance, in the past two years, we achieved $20 million in recurring O&M savings from energy delivery process improvements, including enhanced field work scheduling that, where implemented, has improved productivity by about 25%. Looking ahead, continued efforts to simplify and standardize processes are expected to drive efficiency, improve customer experience, and help keep rates as low as possible.

With that, let's move to page 21 for a brief update on the constructive orders in both of our Illinois rate reviews in late 2025. In November, the Illinois Commerce Commission approved a $79 million annual base rate increase for our natural gas distribution segment, which reflected a higher return on equity of 9.6% and a 50% equity ratio.

New rates were effective in December. In December, the ICC also approved a $48 million reconciliation adjustment to the 2024 revenue requirement that was approved as part of the multi-year rate plan, with new rates effective in January of 2026.

This annual adjustment aligns customer rates with actual costs. Both orders were largely consistent with the administrative law judges' recommendations.

Finally, in January, Ameren Illinois filed its required multi-year grid plan for 2028 through 2031 with the ICC, which outlines continued infrastructure investments needed for reliable, safe energy in downstate Illinois. We would expect an order from the ICC on the proposed grid plan later this year.

Turning to page 22, we look to our company-wide capital plan for the next five years. As Marty highlighted, we see robust investment opportunities ahead.

The plan we are releasing today calls for $31.8 billion in capital expenditures from 2026 through 2030, an increase of more than 20% compared to an investment plan issued last year. The increase in our capital plan primarily reflects the roll forward of our plan from 2029 to 2030 and the firming up of cost estimates and project timing.

The investments themselves primarily reflect critical upgrades to strengthen and maintain an aging grid across all jurisdictions, significant new generation investments at Ameren Missouri, and expanded transmission capabilities to support resource adequacy across the region. We expect this investment to drive 10.6% compound annual rate base growth, which is outlined by business segment on this page.

For more detail on the electric investment underlying our capital plan, you may reference the Ameren Missouri Smart Energy Plan just filed with the Missouri PSC, as well as the multi-year grid plan filed recently with the Illinois Commerce Commission. Turning to page 23.

Here we outline the expected funding sources for investments noted on the prior page. Our balance sheet is strong, and we remain committed to funding our investment plan in a way that supports strong investment grade ratings and long-term financial strength.

Our primary source of funding will continue to be cash from operations, which we expect to increase as sales grow and rates are updated. Remaining funding needs will be financed in a balanced manner consistent with our past practices.

We expect to issue approximately $4 billion of equity from 2026 through 2030. We've fulfilled our 2026 equity needs with $600 million of forward sales agreement that we expect to settle near the end of the year.

We expect above-average equity issuance in 2027 and 2028, aligned with the timing of our new generation investments. The amount and timing of our equity needs will ultimately be a function of the timing of cash flows, including cash flows from data center sales, timing and amount of which we expect to have further clarity on over the course of this year.

A portion of our equity needs could be satisfied through issuance of hybrid debt securities at the parent company, which receive 50% equity credit from Moody's and S&P. We expect to continue to issue long-term debt to fund remaining cash requirements.

To fund maturing obligations and a portion of the $5.5 billion of planned investment, we expect debt issuances totaling approximately $2.85 billion in 2026. Expected timing of these issuances is shown on this page.

Moving to page 24 of our presentation for our 2026 earnings guidance. Today, we're affirming our 2026 diluted earnings per share guidance range of $5.25 per share to $5.45 per share, the midpoint of which represents approximately 8.1% growth compared to the midpoint of our 2025 original EPS guidance range.

The earnings drivers are summarized on this page and remain largely consistent with those discussed on our third quarter earnings call. Through disciplined cost management, we will target limiting consolidated O&M expenses to less than the rate of inflation over the five-year plan.

Finally, turning to page 25. I'm encouraged by the opportunities we have at Ameren to make lasting impact in our communities and shape the energy future for our customers.

This is an exciting time in industry, one that I could never have fully imagined when I started my career over 30 years ago. We remain confident in and excited about our long-term strategy, one that we believe will continue to consistently deliver for shareholders.

Our investment positions us to strengthen reliability for all customers and attract and support economic growth in our communities. Our disciplined cost management and strong customer growth pipeline position us to do so while keeping customer rates as low as possible.

We expect that our strong earnings per share growth paired with our attractive dividend will provide a compelling total shareholder return that will compare favorably with the growth of our peers. That concludes our prepared remarks.

We now invite your questions.

Hey, good morning. Can you guys hear me okay?

Yes, Julian, good morning.

Hey, love that it works. Excellent.

Hey, nicely done all around. I got to hand it to you guys.

Just a couple of questions real quickly. First off, on the 2.2 gigs of executed ESAs, any caveats on why not to include it here?

Obviously it's relatively recent. Then separately, can you talk a little bit about the commentary about being at the upper end of the 6 to 8?

Just how does that reconcile with the 2.2? How do you think about, for instance, CapEx reconciling with that, and how that would position you here?

I'll leave it there.

That's fine, Julian. This is Marty obviously, I'll try to answer those questions.

Look, we're off to an exciting start to 2026, February in particular. It's been this month that we've been able to sign these 2.2 GW of ESAs, and as we talked about on the call as well, just this week, the Public Service Commission in Missouri approved our Big Hollow 800 MW simple cycle gas plant, as well as some battery energy storage of 400 MW.

It's been an exciting month and a great start to the year. As we think about our guidance and the sales growth looking ahead, as what's been baked into our guidance over the past year has really been about 1.2 GW of new demand by 2030, and as we talked about in our IRP last year, up to about a gig and a half by 2032.

For purposes of guidance, that 1.2 GW by 2030 is certainly relevant. That of course was sort of the baseline that was in our preferred resource plan that we filed with the commission this past year and is shown on page 13 of the slide deck we posted today.

Importantly, that 1.2 gigs was in the guidance we provided, that 6% to 8%, and as we guided last year and we continue to guide, we really expect to be able to deliver near the upper end of that range over the five-year period. As you look at this 2.2 GW of ESAs, that certainly represents upside to the sales growth that has been embedded in that 6% to 8% guidance and in our assertion that we expect to deliver near the upper end of that range.

It does represent upside. Now, as you mentioned, we just got these ESAs signed here in February, and there's a lot of milestones ahead with respect to the development of those data centers associated with those ESAs, things like actual customer announcements, project announcements, groundbreakings, the construction of those data centers.

Again, I would say that the ESAs that we signed and the 2.2 GW certainly gives us greater confidence with respect to our ability to deliver over this time period towards that upper end of that 6% to 8%. I would say, depending upon the ramp rates, gives us the potential to even achieve above that.

We're very excited about it. It's been a great start to the year.

Hopefully, that answers your questions.

Absolutely. Thank you very much.

I appreciate that. Then just if I can quickly follow up, you made reference here to hybrid securities real quickly.

How do you think about that as being part of the plan? Clearly it is.

How do you think about that strategically here, and is that accretive to the plan when you talk about being nearly the upper end of 6 to 8? Is that an incremental source of latitude here just to come back to what's in versus out of the plan?

I think as you think about utilization of those securities versus straight equity, it might be slightly accretive in the short term. I think over time, we'd have to evaluate whether it is or isn't from that standpoint.

Obviously, there's the interest cost associated with those securities. It may be more of a neutral over time, but something that we're going to evaluate as we think about the financing plans we have ahead.

Obviously, one of the things that we've really utilized over time are these ATM issuances to fulfill our equity needs. I think we'll continue to lean on that heavily, that kind of a approach as we think about our financing plans, but always want to keep our options open.

Awesome, guys. All right, I'll leave it there.

Thank you so much.

Good morning. It's actually Andrew Kadavian on for Shar.

Thanks for taking my questions.

Morning, Andrew.

With your rate base CAGR at 10.6% and your EPS CAGR at 6% to 8%, there's a healthy amount of lag. How much of that is financing versus how much is structural, and how much can you narrow the lag in time and put upward pressure on the 6% to 8%?

I'm just trying to follow you. Maybe repeat that question for us.

There's a little bit of lag between your rate base growth and your earnings growth, and I just wanted to know how that breaks down between financing and maybe other structural issues, and then is there the opportunity to narrow that lag?

No, I've got you. Look, I think if you look at our rate base growth of about 10.6%, and you think about the amount of equity that we plan to issue, and think about the dilution from that, that's the primary difference between the 10.6% rate base CAGR and where we plan to deliver from an EPS perspective, which, as I just said a moment ago, is consistently towards the upper end of that 6% to 8% range.

I think the other thing to think about over this time period is as these sales come better into focus from the hyperscalers that we're working with in these ESAs, that too can help to reduce any differential that we have between allowed ROEs and earned ROEs that also can help from an earnings perspective. Those are some of the big drivers that come to mind.

Then I would just say we're obviously a fully rate-regulated business, and as you well know, there can be lag as you think about over time during the periods between rate reviews. Those are just some of the things to think about in terms of the earnings, the earnings growth, the earned ROEs, etc.

Thank you, very helpful. Switching gears a little, we've seen some data center developers cancel projects despite having signed ESAs in place in other states.

Are there any concerns on your end about the potential for cancellations with your ESAs, and could you give us a little color on when the large load take-or-pay provisions in the ESA become binding for the customer?

All really good questions. With respect to these ESAs, the counterparties and the terms of these and the ramp rates are all highly confidential, can't get into any of that.

I wouldn't say that we have any concerns with respect to these ESAs or the projects coming to fruition. That said, I mentioned there's significant milestones ahead in terms of project announcements, the groundbreaking, the construction.

Certainly recognize that those uncertainties as we look ahead. Again, our 6% to 8% EPS growth guidance, our expectation of delivering near the upper end, again, was really based on about 1.2 GW of sales growth between now and 2030.

The ESAs we've signed represents upside. I think again speaks to the conservatism that we have in our overall guidance range, given again some of the uncertainties ahead.

We certainly don't have any concerns as we sit here today.

This is Michael. I agree with everything that Marty is saying.

I think beyond that, there are a number of provisions, obviously, in the tariff itself, in the ESA, that are protective to customers, in terms of termination provisions, minimum monthly payments, security requirements, etc. A number of steps have gone to great lengths here to make sure that we're protecting customers at the end of the day as well, in case that would happen.

Those are great points, Michael. While we can't speak to the specifics of individual ESAs, you can see some of that outlined on slide 12 that, as Michael mentioned, are all part of our large load tariff design.

Great, thanks. I'll leave it there.

Hey, good morning. Thank you so much for taking my questions today.

Hey, good to have you.

Thanks. Looking at your infrastructure investment pipeline, are there timing considerations to some of the future opportunities there, thinking about how much might fall within the five-year plan period, or how much visibility you have beyond 2030?

Are you really getting to the CapEx and how we see that playing out? At a high level, we talked about over the 10-year plan, really about $70 billion of investment opportunities.

We laid that out in our slide. Then during the five-year period, expecting $31.8 billion of infrastructure investments and largely being driven by generation investments in Missouri as we think about transitioning our fleet over time.

That may not be specifically answering your question if you want to dive a little deeper.

I guess sort of asking there maybe how to think about the cusp between the five-year plan of 2030 and beyond, are we seeing continued smooth investment there or are you thinking about filling more opportunities in?

I think, look, we try to smooth things out over time. I think it's something that's certainly good for customers as you think about bringing those investments into rate base over time and making a stable investment profile overall.

At times it'll be a bit lumpy, though, especially as you think about some of the infrastructure investments we have with respect to generation resources. They can certainly be more significant investments and create some lumpiness in the investment profile.

A couple things we've got coming up, as you can see in our slides, we've got some significant investments in simple cycle gas-fired generation that are coming into service in '27 and 2028. Then if you look at our integrated resource plan, we have a pretty significant investment in combined cycle facility, 2,100 MW, that we plan to bring into service in the 2031 time frame.

There's certainly some lumpiness there. The other thing I'd say just to watch for, didn't emphasize it necessarily on this call, but did highlight it, which is that later this year, we do expect to make our triennial integrated resource plan filing in Missouri.

In that plan, we'll certainly be looking at any opportunities to accelerate generation investments, specifically maybe looking at things like batteries, perhaps renewables. As you move into that 2030 to 2040 time frame, also looking at the need and potential additional investments in dispatchable generation facilities.

I don't want to front run that process. It's a comprehensive update where we'll look comprehensively at sales, generation options, costs, we'll get stakeholder input, but again, that'll be a meaningful filing we'll have later this year.

The other thing I'd maybe point you to is today, we also in Missouri announced our updated Smart Energy Plan. If you look into the details of that filing, you can kind of see some of the year-by-year investments that are planned in Missouri.

Similarly, if you look over in Illinois, earlier this year, we made our updated grid investment plan filing. In there, too, you can see some of the planned investments on a year-by-year basis.

Those are a couple of resources you can look to that are out there publicly.

Great. Thank you very much.

Hi, good morning.

Morning, Bill.

Just a couple quick questions on the theme of affordability, can you just maybe outline how you guys view this updated plan in terms of customer bill impact, I guess particularly in Missouri, and whether or not the benefit of the ESAs would help to defray some of that impact?

Bill, affordability is certainly a key concern of ours on an ongoing basis across both of our jurisdictions, in Missouri and Illinois. As really focusing on disciplined cost control has been a long-time focus of this company.

In fact, as you look back even over the past 5 years, I think our O&M CAGR was something like 2.8% at the same time that consumer prices went up about 4.6%. We've got a history of really looking to continuous improvement at the company to really take cost out, to produce productivity enhancements, and optimize.

That work is never done. Certainly, there's always the benefit of new technologies, new ways of doing things, and we're continuing to keep a sharp focus on continuous improvement, process improvement.

We call them transformation activities internally, and we've got a number of efforts going on right now that, again, we expect to be able to continue to bend that cost curve. As we said on the call, really look to keep O&M costs as low as prudently possible and really deliver under that rate of inflation.

I say prudently because there's times we're going to want to invest back in the system. We've done that with things like tree trimming, investments in our power plants, things that really keep our resources reliable and produce good reliability for our customers.

We're going to keep a good focus on all of those things. As we think about this incremental sales opportunity we have, a key focus of Senate Bill 4 in Missouri last year was really to require that at the end of the day, we design a tariff that really is focused on making sure that these new data centers are paying for the cost to connect them to the system and paying their fair share for the cost to serve them, really providing reasonable assurance that there's no burden being borne by the rest of our customers.

That was a focus of the legislature and certainly a focus of the Missouri Commission as they approved the tariff that we'll be utilizing to serve these customers. It was a focus of ours as we went through the negotiation of the ESAs that we announced earlier today.

I think it'll be a continuing focus as we go through our rate review proceedings in the future. Again, the goal is for them to pay their fair share, the costs of providing them service and, at a minimum, to not have a burden fall on the rest of our customers.

We're certainly hopeful that over time as these sales increase, that there would actually be benefits for the remainder of our customers. Again, affordability has been and will continue to be a big focus for us.

Okay. That's very helpful.

Then just a point of clarification, that the 3.4 GW of construction agreements, I guess that's inclusive of the 2.2 ESAs, right? Does that imply that there's about

1.2

GW of sort of advanced negotiations around additional large load customers?

Some are advanced, some aren't. I would just say that you're correct, by the way, the 3.4 is inclusive of the 2.2, and they're in various stages of development.

Okay. Then just to an earlier question, about rolling in the benefits of the ESAs, is that something you would look to do on a future quarterly call or would that need to wait until sort of your next full reset, maybe on Q3?

Look, I think we'll monitor over time. I mentioned some of the milestones ahead with respect to the development of these data centers and getting more clarity in terms of a sales forecast.

I also mentioned other drivers that might be out there, for example, of an update to the integrated resource plan later this year in Missouri. I think there'll be a number of things that will come into greater focus over the course of the year.

I wouldn't rule out an update as part of a quarterly conference call. Obviously, things are moving at a faster pace than they historically have, and we'll need to think about being more nimble as well in terms of the guidance we provide.

All right. Great.

Thanks very much.

Hey, good morning. Thanks for taking the questions.

Maybe one just on Missouri, know we're still pretty early in the legislative session there, but I think there's been some bills introduced around data centers and other generations, just curious if you have any early thoughts on potential impact there or if there's any other legislation that you've been watching?

Hey, Carly, it's Michael. There are a number of bills floating around.

There's a couple of bills related to solar. We continue to engage with stakeholders, sponsors around that.

It's early innings. I think people are open to discussion.

Again, with all resources, there's always certain concerns. My sense is that we can find a path forward on this, maybe it's related to some solar setbacks or some changes in local taxing authority.

Look, solar is an important resource, combined with everything else that we're doing from a natural gas and nuclear or coal perspective. As we just indicated, Marty just went through eloquently, we need all of this generation.

Engage with the stakeholders around this, and hopefully we can land in a good spot. Beyond that, not a lot of legislation floating around.

We had some success, obviously, last year with Senate Bill 4. The focus really has been on the implementation of that Senate bill.

There are a number of provisions in there around forward test years for water and gas utilities. Those rulemakings are active, and we're participating in that process.

That's important. We get that right, I think that could be a framework for us going forward on the electric side.

Beyond that, we'll just continue to evaluate the session.

Got it. Great.

Thank you for that. Then just a clarifying question as you think about the financing path.

Any sense how much of the equity you could look to satisfy with the hybrids, and then outside of that, is the ATM still the sort of preferred method of issuance?

Hey, good morning, Carly. Thanks for the question.

Or Sophie? Carly.

Thanks for the question. As we said in the plan, we have not specified what amounts are going to be using.

The plan, if you think back at the $4 billion over the five years, it's on average $800 million a year. Remember 2026 was completed with forward sales agreement.

We have had success with ATMs over the year, and we'll continue to leverage that throughout the plan. Hybrids are part of the solution, and we'll continue to make determinations as we progress throughout the year.

Great. Thank you so much for the color.

Hi, good morning. Thank you for taking my questions.

I was wondering how you guys see your role in, I guess, educating the communities, particularly in Missouri, right, on the benefits of having data center under this special tariff, and whether it's actually any benefits to them, because what we see is a lot of pushback on the track because of the media coverage that the data centers receive in a lot of communities without maybe understanding that it might be a benefit to them begin to oppose these developments. My question is, do you see yourself as having a role in actively educating these communities to prevent those outcomes?

I think we have a role specifically with respect to clarifying the impacts on reliability and affordability of energy services. I think with respect to the broader benefits to the community in terms of jobs, economic development, impacts on other aspects, I think, again, it would be up to really the data centers, developers, the hyperscalers to provide clarity with respect to broader impacts of their operations.

We think it's, again, important though for us to be there and be engaged and to be able to speak to the legislation that's been put in place, the terms and conditions of our tariffs, the ESAs that we're signing, also important, the generation resources that we have available, the generation resources that we're building, and the fact that we do believe we can serve these additional customers reliably. As I said earlier in my remarks, provide service to them in a way that they will be paying for the cost to connect them to the system, and they will be paying for the cost to serve them and the reasonable assurance that can be provided to the rest of our customers that they will not be negatively impacted by the service provided to these customers.

I do think we have a role in speaking to that.

All right. Thank you.

Then maybe on Illinois a little bit, I guess Illinois has been kind of not on the forefront of your investment plan lately. Can you talk a little bit about the regulatory climate in that state, how it's been evolving, and is there potential for upside from the multi-year grid plan or some other pending regulatory proceedings in Illinois?

Sophie, look, Illinois does remain, obviously an important part of our business. I would say we do continue to invest significantly in Illinois, as you see in our five-year plan, about $3.6 billion in electric distribution.

We've got $1.9 billion going into Illinois Natural Gas. They're growing at a somewhat of a slower growth rate than we're seeing with respect to our transmission operations and Missouri operations, but continues to be a significant place for investment.

I think if you look at the regulatory environment over there, I would tell you I feel like it's stabilizing and in some cases, improving. If you look at this past year end, and you can see some of this on slide I think 21 that we provided, but the commission approved the reconciliation for our last multi-year rate plan in December.

In November, we got an order in our gas case that we had pending, and what you saw there is both an increase in average rate base going from $2.85 billion to $3.2 billion, and you saw an ROE move from 9.44% up to 9.6%. I think it's a place that I know there were concerns over the past couple years, and I'm not saying those concerns have completely dissipated in the investment community, but I think we've seen a stabilization and I'd say constructiveness with respect to the recent decisions.

We've got this multi-year grid plan filing that's out there. We just made that in January.

In that filing, we look to listen to feedback we've gotten from commissioners and other stakeholders in the past. We look to really support the investments that we're making there.

We think they're the right investments to make for our customers, and we'll look to engage with stakeholders over the course of this year and expect an ICC decision in December.

Hey, Sophie, it's Michael. I agree with everything that Marty said there.

In addition to that, I think the other thing that came out of this recent legislation, this CEJA legislation that was filed was this construct of an IRP for the state of Illinois. I think that really is a very good, constructive step forward to give a clearer picture of the resource adequacy issues in both PJM and MISO, hopefully within a framework to begin to deal with this from a long-term reliability perspective.

We look forward to engaging in that, and I think it does continue to add to Marty's comments around the stability of the state.

Great. Thank you.

Appreciate the comments.

Again, thank you all for joining us today. I think you can tell we're off to an exciting start here in 2026 as a company.

I want to once again thank the entire Ameren team for all of their hard work serving our customers, serving our communities, and delivering the results that we've been able to deliver. With that, for all of you that joined us today, please be safe, and we look forward to seeing many of you as we get out on the road in the months ahead.

Thank you.