Thank you, Liz, and good morning, everyone. Welcome to Evergy's fourth-quarter 2025 earnings conference call.

Our webcast slides and supplemental financial information are available on our Investor Relations website at investors.evergy.com. Today's discussion will include forward-looking information.

Slide 2 and the disclosures in our SEC filings contain a list of some of the factors that could cause future results to differ materially from our expectations. They also include additional information on our non-GAAP financial measures.

Joining us on today's call are David Campbell, Chairman and Chief Executive Officer, and Bryan Buckler, Executive Vice President and Chief Financial Officer. David will cover our 2025 highlights and recent economic development activities.

Bryan will cover our full-year results, electric load growth potential, and our financial outlook. Other members of management are with us and will be available during the Q&A portion of the call.

I will now turn the call over to David.

Thanks, Pete, and good morning, everyone. I'll begin on slide 5 by first thanking our employees who worked tirelessly throughout the year to advance our strategic objectives of affordability, reliability, and sustainability.

The team's hard work and execution laid the foundation for the transformative growth opportunity before us. Today, we are raising our long-term adjusted EPS growth target to 6% to 8% plus through 2030 off of our 2026 guidance midpoint of $4.24 per share.

We expect EPS growth to exceed 8% annually beginning in 2028 and through 2030. Our updated growth outlook is bolstered by the recent execution of electric service agreements for four data center projects that I will discuss shortly.

With respect to 2025, we executed on our capital investment plan to improve reliability and resiliency, investing $2.8 billion in infrastructure to modernize our grid and replace aging equipment. Our financial results in 2025 were negatively impacted by weather and weak industrial demand throughout the year.

Despite meaningful results in cost and mitigation actions, we were unable to fully offset these impacts. While the negative drivers were outside of our control, we fully understand that consistent financial performance is a hallmark of long-term value creation.

We have confidence in our updated financial outlook, which has been tested against a range of outcomes, and we are committed to delivering against our objective of sound financial execution. Brian will discuss earnings drivers in more detail later in his remarks.

In 2025, we made significant progress in advancing economic development opportunities, growing our pipeline to over 15 gigawatts. A major milestone involved approval of new large load power service tariffs, the LLPS, in both Kansas and Missouri last November.

These tariffs establish a framework under which new large customers will pay a premium demand rate to locate in our service territories while adequately paying their fair share of existing and new system costs. This, in turn, will drive affordability benefits for existing customers and support economic growth in Kansas and Missouri.

In Missouri, the passage of Senate Bill 4 in 2025 marked another successful legislative outcome that signaled strong support for infrastructure investment and growth. Among other features, SB 4 includes provisions that enhance our ability to invest in and timely recover costs associated with new natural gas generation while also extending the PISA sunset provision to 2035.

SB 4 reflected the support and combined efforts of the Missouri Public Service Commission, legislative leadership, the governor's office, commission staff, and many other key stakeholders, and we appreciate their leadership and collaboration. In Kansas, we were pleased to reach a unanimous settlement agreement in our Kansas Central rate review.

The settlement provided a balanced outcome for our customers and communities and reflects broad alignment around our infrastructure investments while ensuring we continue to provide reliable and affordable electric service. We also received approvals from the KCC and MPSC to construct three new natural gas facilities and three solar farms, totaling nearly 2,200 megawatts.

These projects further advance our all-of-the-above generation strategy to support rising customer demand. Safety is at the core of everything we do, and I'd like to thank our generation, transmission, and distribution teams for their commitment to safety and the significant reduction in the injury rate last year.

Reliability performance also improved as we achieved the strongest results in the company's history for SAIDI, with reductions in both average outage duration and frequency. Our infrastructure investments and the hard work of our operations teams continue to drive benefits and enable us to deliver affordable and reliable power to customers, no matter the conditions of the weather.

In November, we raised our dividend 4% to an annualized $2.78. As our dividend continues to grow, we expect the payout ratio to decline over time to a revised target of 50% to 60%.

As Brian will discuss, this target is part of our financing plan as we enter a period of elevated growth and investment and is similar to the approach of many peer utilities. Moving to slide 6, I'm very pleased to announce new electric service agreements for four major data center projects.

This includes two new data centers and significant expansions of two existing projects. In aggregate, these four projects represent 1.9 gigawatts of steady-state peak demand.

Taken together, these projects alone amount to nearly 20% increase in our total peak system demand and an even higher level of usage growth, given high expected load factors. As these customers ramp up, we'll be able to deliver affordability benefits for our customers and communities through the strong LLPS tariffs.

Of course, these facilities will take time to construct and reach their maximum megawatts. We've included 1,300 megawatts in our retail load growth forecast in 2030, with the remainder ramping up after that year.

This outlook reflects our expected case, which is informed by the specific load ramps as outlined as part of each customer ESA. Finally, we're making strong progress with several additional large customers and expect at least one more executed ESA in 2026.

This upside is not captured in either the financial outlook or sales forecast we're sharing with you today. These commitments solidify Missouri and Kansas as premier destinations for data center customers and are the product of strong partnerships with world-class customers in Google, Meta, and Beale, who we'd like to thank for their investments in Kansas and Missouri.

As customers complete construction, they are responsible to pay their fair share of costs incurred to serve them, including the LLPS premium pricing. As an additional protection, if their actual usage falls short of annual expectations, they are subject to minimum bill provisions, which provides strong visibility to our 6% to 8% plus EPS growth outlook and the affordability benefits we can expect to provide our current customers.

Slide 7 summarizes the progress we've made in converting our Tier 1 large customer pipeline to signed agreements. Starting in the top row, the 2.4 gigawatt includes the four ESAs announced today and the larger customers that have already commenced operations.

This Tier 1 demand enables a transformative growth opportunity for Evergy, supporting our expected retail load growth of 6% annually through 2030, well above the historical 0.5% to 1%. Moving to the section shaded in green, we remain in advanced discussions with multiple customers whose load represents a 2.0 to 3.5 gigawatt opportunity.

We expect to execute at least one more large customer ESA in 2026 from this group. In aggregate, these potential customers have executed various service agreements, posted financial commitments, and otherwise demonstrated their significant interest in locating in our service areas.

The remainder of our pipeline, totaling over 10 additional gigawatts, highlights the robust activity and sustained interest in our region. The opportunity to serve this load will require creative solutions, and the ongoing dialogue also underscores the readiness of customers to step in should others exit the queue.

The announcements we've made today serve as clear proof of concept that Evergy is well positioned to capitalize on this historic opportunity, reflecting the geographic advantages of our region, supportive business and energy policies, and a shared approach amongst our many stakeholders to capitalize on economic growth. On slide 8, we summarize key customer and shareholder protections as provided by our LLPS tariffs.

Early last year, we set out on a cross-functional effort to address a key opportunity and challenge: How can Evergy serve new large loads while supporting affordability for existing customers and fairly addressing cost allocation related to new infrastructure investment to serve these large loads? The follow-up work culminated in the approval of settlement agreements in both Kansas and Missouri on a tariff that addresses this challenge.

It reflects significant collaboration with commission staffs, consumer advocates, industrial groups, the Data Center Coalition, Google, Meta, and others, and ultimately garnered strong support as reflected by the approvals of both the Missouri and Kansas commissions. As outlined in the tariff, new large customers are committed to minimum term lengths and minimum monthly bills regardless of usage shortfalls that cover no less than 80% of their contracted capacity at a premium demand rate.

Additionally, customers must meet creditworthiness standards and collateral requirements. Termination fees are required should a customer decide to cancel a project or leave early, and these fees would cover the remaining minimum monthly bills for the term of the contract.

All told, these tariffs established the framework through which new large customers will pay their fair share for capital investment while bringing massive new projects to Kansas and Missouri. Slide 9 is illustrative and expands upon how the provisions of the LLPS tariffs will work in practice and, critically, mitigate impacts on existing customers.

Customers taking service under the LLPS tariff will pay a premium demand rate 15% to 20% higher than the rate for existing industrial customers, as well as all the direct costs to serve them. This premium and the revenues driven by the customers' high load factors will generate significant benefits for existing residential, commercial, and industrial customers.

As laid out in the flowchart, our future rate requests will be reduced by the revenues generated from LLPS customers. As the higher load from these customers is factored into our requests, system costs are then spread over a higher base, which in turn puts downward pressure on future rate requests.

This is a critical aspect of our affordability proposition, as over time we will be investing at higher levels to serve growing demand. Our existing customers will share in all the benefits of a modernized grid and new best-in-class generation technology without encountering the same level of costs they otherwise would have faced without large new customers.

In short, we have a unique opportunity to upgrade the grid and replace aging infrastructure much more affordably than we could without this robust level of load growth. Moving to slide 10, we highlight a few of the expected benefits of data centers.

It's important to recognize that these projects deliver substantial, long-lasting value to the communities we serve. Beyond the benefits and protections of the LLPS tariffs, these projects generate tax revenues, typically far in excess of the local services needed to serve them.

These tax revenues in turn support local budgets for education, infrastructure, parks, and other community services. Data centers also strengthen the economic ecosystem, given the growing importance of automation and low latency.

These attributes will likely feature more and more prominently in sectors such as healthcare, finance, transportation, logistics, and advanced manufacturing. By enabling leading applications in these industries, data centers will help to attract and support high-quality job creation.

These data center projects also represent multibillion-dollar capital investments, with construction job growth often sustained by ongoing equipment upgrades. They drive the need for new and updated fiber-optic infrastructure, which can then create a virtuous cycle for additional data-focused industries.

In summary, data centers are major investments that can also serve as powerful engines for economic development. They support affordability, generate long-term tax revenue, expand industries, support job creation, and catalyze infrastructure investment.

This is the kind of growth that strengthens communities for decades, and we are proud to do our part. On slide 11, we highlight the major gains in regional rate competitiveness our company has achieved since 2017.

This success directly supports the growth opportunities that we're discussing today. Since 2017, our rate trajectory has remained well below regional peers and far below inflation.

The cumulative change in Evergy's all-in rates over that time is approximately 4.9%, compared to a regional peer average of 19% and inflation of 29%. Holding rate increases to a 0.5% annual rate reflects the scale benefits and cost savings from the merger that created Evergy: promises we made and promises we kept.

As we enter a new era of economic development, we'll maintain our relentless focus on cost discipline, affordability, and the competitiveness of our states. Slide 12 lays out our updated capital forecast.

Our rolling five-year investment plan totals approximately $21.6 billion from 2026 to 2030, equal to a $4.1 billion increase over the prior plan. The increase includes over $3 billion of new generation investment to support growing customer demand and meet higher generation reserve margin requirements in the Southwest Power Pool.

Our five-year investment program is expected to result in 11.5% annualized rate base growth through 2030, which compares to our prior forecast of 8.5%. We'll take a flexible approach to financing our capital plan, utilizing a prudent mix of debt and equity, with optionality around timing and execution, as Bryan will describe.

I'll conclude my remarks with slide 13, which highlights the core tenets of our strategy. I'll focus specifically on affordability.

Keeping rates competitive and affordable has been a strategic priority since our company's formation in 2018. Evergy stands out as one of the best utilities in the country in managing customer rates and keeping rate increases well below inflation.

We will continue to prioritize affordability in our long-term plan. While capital investments are higher than historical levels, too is load growth, which will allow us to spread fixed system costs over significantly higher kilowatt-hour sales.

We expect to see customer rate increases over the next several years being in line with or below inflation for the significant majority of our residential customers. Missouri West is our smallest utility today, with the lowest rates in our system and some of the lowest rates in the nation, partly because the utility is in need of infrastructure investment, in particular new dispatchable baseload generation.

As a result, as new generation plants come online to serve that jurisdiction, customers may see rate increases above inflation over the next five years. However, these investments will help to reduce the rate volatility that Missouri West customers have experienced as a result of utilizing more market-provided energy.

In addition, as the full benefits from large load customers are realized, we are confident that we can manage residential rates to a level consistent with inflation, and Missouri West customers will benefit for decades to come. By prioritizing affordability, we contribute to the robust economic development pipeline ahead of us and support the substantial economic potential within our states.

As outlined in our capital plan, we will continue to invest in grid modernization to ensure reliability, as well as grid resiliency, strong customer service, and generation availability. Our primary sustainability goal is to execute a cost-effective, all-of-the-above generation strategy, as reflected by our planned investments in natural gas, storage, and solar to support our Kansas and Missouri customers.

We look forward to continuing to advance a balanced mix of resources over the coming years to support growth and prosperity in our states. With that, I will turn the call over to Bryan.

Thank you, David. Thank you, Pete, and good morning, everyone.

Let's begin on slide 15 with a look back at our financial results. For the full year 2025, Evergy delivered adjusted earnings of $894 million, or $3.83 per share, compared to $878 million, or $3.81 per share, for the same period last year.

As shown on the slide from left to right, the year-over-year drivers are as follows. First, 0.3% growth in weather-normalized demand, primarily driven by the commercial class, resulted in an increase of 4 cents per share in margin.

These results were weaker than projected for both residential and industrial, including in the fourth quarter, which led to our final 2025 adjusted EPS results falling short of the guidance we provided on our third-quarter call. Regarding residential and industrial load, early indications in 2026 are strong in comparison to 2025, and we expect to return to normal residential load growth in 2026.

Secondly, recovery of and return on regulated investments, driven by new retail rates and FERC-regulated infrastructure investments, contributed 56 cents to EPS in 2025 as compared to 2024. Unfavorable variances for the year included higher operation and maintenance costs and depreciation and interest expense due to increased infrastructure investments, which drove a 43 cents decrease in EPS.

Other items had a negative 10 cents impact for the year. Finally, dilution from our convertible notes led to a 5 cents decrease for 2025.

Let's move to slide 16 to lay out how we expect to deliver on our 2026 EPS guidance midpoint of $4.24. Again, starting on the left side and beginning with 2025 adjusted EPS of $3.83, we've modeled a reversion to normal weather in 2026, which would add approximately 13 cents per share.

Next, we expect a 26 cents increase from demand growth in 2026, which reflects a forecasted 3% to 4% increase in weather-normalized retail sales. This exceptional level of load growth is driven primarily by the continued ramp of the Panasonic advanced manufacturing facility, as well as the ramp-up of the data center customers with signed ESAs in our Metro and Missouri West jurisdictions.

Next, updated recovery of costs and return on our regulated investments are expected to contribute 35 cents of EPS for the year, primarily related to new rates at Kansas Central that went into effect in the fourth quarter 2025, as well as the recovery of FERC-regulated infrastructure investments. Offsetting these positive drivers is an increase in O&M, as well as the combined impact of higher depreciation and interest expense, net of AFUDC earnings and PISA deferrals, which is expected to drive a 20 cents unfavorable impact.

Lastly, we assume 8 cents of drag related to dilution from convertible notes and expected common stock equity issuances, as further described in a moment. We have high confidence in this 2026 guidance, and it is bolstered by the execution of electric service agreements that we've announced today.

Moving to slide 17, we highlight our large load demand growth profile and our financial plan. Over the past two years, we've been hard at work to advance competitive frameworks for capital investment in Kansas and Missouri that would enable our ability to invest for growth in a way that promotes economic prosperity for our customers and communities, while solidifying our region as a premier destination for advanced manufacturing and data center customers.

The passage of the LLPS tariffs, our operational team's execution on transmission and generation capacity planning, as well as strong collaboration with customers and local stakeholders on legislative efforts, have all culminated in what we believe is one of the most compelling growth stories in the sector. As indicated on the chart, the large load customer ramps are already underway and will continue building through 2030 and beyond, supporting our retail load growth CAGR of approximately 6% through 2030.

This tells a powerful story of growth, anchored by long-term contracts and clear parameters on monthly billings, providing significant visibility into our earnings growth and cash flow streams. We are able to share this level of detail with you because our teams are no longer just talking about a pipeline.

Now they are also talking about the successful inking of actual electric service agreements with the very high quality customers David described earlier. To drive home this point further, the execution of these ESAs was the milestone needed to solidify Evergy's growth trajectory as a company, as these were the final binding agreements to be signed between Evergy and these customers.

The numbers on slide 17 that you see reflect our planning assumptions around the capacity demand that will drive revenue during our planning period, growing from 350 to 400 megawatts of served capacity by year-end 2026 to up to approximately 1,700 megawatts of served capacity by 2030. As a reminder, this plan reflects the contributions from customers under signed ESAs for four major projects.

Furthermore, we are making strong progress with several additional large customers and expect at least one more executed ESA in 2026, whose load would represent upside to the back end of this forecast. As David described, we'll continue working in a measured fashion through our 10 gigawatt-plus balanced pipeline to build on the success we're sharing with you today.

Slide 18 converts that megawatt capacity usage you see on slide 17, along with our broader customer base, which is also expected to grow, into a view of the strong load growth profile we see ahead. In particular, it highlights generally accelerating annual load growth from 3% to 4% in 2026 to an average annual rate of 7% per year from 2027 through 2030.

It also highlights the growth we're seeing across our entire system, growth that will ultimately drive affordability benefits for our customers in every jurisdiction. We believe the ranges on this page will assist analysts and investors in the modeling of our 6% load growth CAGR over the next five years across jurisdictions, and importantly reflects the positive momentum we expect to build in our financial results throughout the five-year planning period.

On slide 19, I will briefly highlight our five-year investment plan. As David referenced earlier, our $21.6 billion capital investment plan represents a $4.1 billion, or 24%, increase compared to the prior five-year plan.

A key feature is higher generation investment, which captures approximately $3.4 billion of the total increase and largely consists of new natural gas power plant investment needed to serve growing demand and to meet SPP reserve margin requirements. The T&D portion of our plan emphasizes strengthening system reliability through grid modernization efforts, including replacing assets that are at or near the end of their useful lives.

Deploying these critical infrastructure investments to the benefit of our grid operations and for our customers and communities is expected to result in a rate base CAGR of 11.5%. Let's now turn to our updated financing plan on slide 20.

As mentioned on slide 19, our projected capital investments over the five years through 2030 now stands at $21.6 billion. We'll utilize a prudent mix of debt, equity, and hybrid securities to finance our capital investments, targeting an FFO-to-debt ratio of approximately 14% through the forecast period, with strong annual growth in FFO that will provide the potential for even stronger metrics toward the end of the five-year plan.

Moving from left to right, we expect $13.5 billion of cash flow from operations. Our $3.6 billion dividend assumption reflects our expectations of growing the dividend throughout the period, while targeting a 50% to 60% payout ratio.

Recently, our dividend payout ratio has been in the 65% to 70% area, and we plan to grow the dividend annually at a rate below our EPS growth projection of 6% to 8% plus. We expect to achieve the 50% to 60% ratio in the latter half of the plan.

Retaining more of our earnings and equity in the business allows us to efficiently fund our capital investments and keep the level of common equity issuances at lower levels than would otherwise be needed. Next, we forecast $8.4 billion of incremental debt and hybrid securities, net of upcoming maturities.

Our plan incorporates $1 billion of equity credit from hybrids, which may assist you in your modeling. Finally, our expected common equity need across 2026 to 2030 is forecasted to be a total of approximately $3.3 billion, and now incorporates the benefits of operating cash flow that comes from customers taking service under the LLPS tariff, as well as our revised nuclear PTC assumptions.

Of note, we currently assume no equity issuances in our plan in 2030, as the cash flow generation of our business improves and improves. This results in an annual need of $700 million to $900 million from 2026 to 2029.

Of course, we'll continue to evaluate the appropriate level of equity funding, particularly as upside capital opportunities make their way into our plan. Now, let's close on slide 21.

It's a recap of our growth outlook summary for the next five years. First, with the successful execution of electric service agreements with large load customers, we expect strong load growth through 2030 and beyond, as the initial 1,700 megawatts will support a 6% consolidated retail load growth CAGR through 2030.

This provides us with a visible runway of predictable earnings and cash flow growth into the next decade. As a reminder, this forecast includes load from four projects under ESAs and other non-LLPS large customers already announced.

We're making strong progress with multiple additional large customers and expect at least one more executed ESA in 2026 that is not yet captured in our financial plan today. We continue to believe Evergy has one of the most compelling customer growth opportunities in the industry that could drive robust growth not just in our five-year forecast, but well into the next decade, resulting in sustainable growth and affordability benefits for customers and communities and a great long-term outlook for all of our employees.

Next, I'll reiterate our capital investment and rate base growth outlook. The foundational earnings power of the company will be fortified by our $21.6 billion capital investment program.

Our higher levels of infrastructure investment are in large part related to supporting economic development in Kansas and Missouri and will drive grid modernization and the addition of incremental generation capacity to support our growing customer demand and SPP reserve margin requirements. Our capital plan is expected to drive an 11.5% rate base growth through 2030, fortifying our earnings foundation.

Our projections of regulatory lag and financing costs convert this 11.5% rate base growth to an earnings growth projection exceeding 8% annually beginning in 2028. We plan to file rate cases on a timeframe corresponding to the in-service dates of new generation projects to ensure the financial strength of our utilities while incorporating the affordability benefits of large loads.

It is critical that we deliver on our affordability and reliability objectives for the benefit of our customers. As our capital investment plan grows, we will utilize a prudent mix of debt and equity financing to support our strong investment-grade credit rating and FFO-to-debt target of 14%.

We will take a flexible approach and evaluate all available financing options, including the use of hybrid debt securities that receive equity credit to meet our financing needs. We anticipate approximately $700 million to $900 million of equity annually from 2026 through 2029, and currently assume no equity needs in 2030 due to improving cash flows from operations.

That being said, upside capital opportunities do exist, and we'll continue to evaluate the appropriate level of equity funding. All together, this plan lays the foundation for a transformative growth phase ahead, as we expect annual adjusted growth of 6% to 8% plus through 2030 off of our 2026 midpoint guidance of $4.24 per share.

As an additional note for the analyst community, we currently expect 2027 EPS growth in the lower half of our 6% to 8% range, before accelerating to a level in excess of 8% beginning in 2028. I speak for the entire leadership team in saying that we are excited about the future at Evergy, and all of our employees are deeply committed to successfully executing our business plan and delivering results for our customers, communities, employees, and shareholders.

With that, we will open up the call for your questions.

Hey, David and Bryan, thanks very much for taking my questions this morning.

Good morning.

Good morning, Steve.

Good morning. Just had a couple.

It's a great update, and thank you very much for giving all the color on the added ESAs. Just the one thing that stuck out to me was on the equity issuances in 2030 that you have no planned equity issuances beyond '29.

Can you just talk a little bit about what that means for steady-state equity needs for the company? Obviously, there's upside capital that we can talk about, but just to the extent we roll forward a year, what do equity needs look like in '31 and '32?

It's a great question, Steve. It's a plan that we're really excited about, and our metrics really are fortified by the ESAs you mentioned to have that level of predictability in your future revenue outlook.

It really just strengthens our profile as a company. When we look at CapEx, $21.6 billion that's currently in our five-year plan, this is definitely an elevated level of CapEx compared to what we've had in the past.

As David mentioned, we also have an elevated level of load growth. In this big construction phase these next few years, we certainly have an equity need like many of our peers, and we're excited to be able to issue that kind of growth equity.

Just as we see it today, no need for equity in 2030 because our FFO just greatly improves each year. Kind of is illustrated quite well by that slide 17, where you can see that the megawatts grow each year of capacity served.

There's a potential we win more ESAs. I think we have a high confidence in that, and what comes with a growing company like that is often more capital.

We'll have to reevaluate 2030 as more capital opportunities come into play. David and I were just talking yesterday, when you get into the early 2030s and when we finish our full infrastructure build-out, you're going to have some tremendous FFO in the plan, and really will make an even stronger balance sheet.

To build on that, I think we expect at least one more ESA to sign this year. That's not in our plan currently, that's not in our sales outlook over the earnings outlook we described.

There'll be capital to serve those customers. Now, we'll be in an environment where we've got strong FFO-to-debt levels, but we do expect incremental upside capital investment opportunities, and with that will come a financing strategy alongside it.

We won't get ahead of what that update will be when we have those additional ESAs, but we're really excited that it will be an upside potential for our customers and communities and for the company.

That's very helpful. Just, again, not to front-run the update, I guess, but can you just give a little bit of flavor of the 2.0 to 3.5 peak gigawatt potential for advanced discussions where you expect one more ESA?

How many customers does that represent, or how many sites, just so that we can maybe get in some type of idea of what an additional ESA could potentially mean for you guys?

Sure. I would describe it as we want to be purposeful in saying we do expect at least one more executed ESA in 2026.

Each one of those words, at least, and one more, are purposeful. We've worked hard to identify potential transmission distribution solutions, capacity opportunities.

We feel like we're really tracking well for at least one more this year. You have a sense for the potential size of these customers from the first four ESAs that we've signed.

We're talking about additional sizable opportunities in that category, and we haven't yet included in our plan. The team's working hard, and our confidence is based not only on our assessment of the capacity on the transmission generation side, but also the status of our discussions and where those customers stand with respect to lining up land, permits, and advancing commitments to us.

We're optimistic we'll be there. I think it's fair to say that the bulk of the impact from additional ESAs will come after 2030, but there's some additional potential before then, bulk of the impact after in 2030 and beyond.

What we like about that, of course, is the ESAs we've announced today are transformative for our company in our service territory. The additional ESAs will help to sustain and extend and expand that opportunity well into that next decade.

We're really excited about the pipeline, and we're committed to executing on that, and really do expect at least one more sizable large customer ESA executed this year.

Great. Thanks very much, guys.

Appreciate the time.

Thanks, Steve.

Thanks, Steve.

Hi. Good morning, team.

Good morning, Paul.

Good morning.

Thanks for all the disclosures. Much to ask, but I'll keep it concise.

Thank you for the commentary on what '27 looks like as well. Is it fair to think you're targeting an 8% plus CAGR as well?

I know it accelerates in the back half, but should we think about it better than 8% as we look 2026 to 2030 as well?

I think, Paul, we've tried to be pretty explicit in how we've described it, I won't change how we've described it, but kind of reiterate. Let me just walk through it again.

The overall formulation, 6% to 8% plus. As Bryan described, '26, '27 in the bottom half of the 6% to 8% range, but that we expect to accelerate to exceed 8% annually beginning in 2028 and then through the 2030 timeframe.

I think that gives you a sense for how we see that earnings power and how it evolves over that time period. The overall rate base growth is in the 11.5% range annually.

As we think about the gap between rate base growth and earnings growth, historical guidance we provided, it was about 8.5% rate base growth, and we were in the top half of the 4% to 6% range, it was about 300 basis points. We expect that to be in the range of a 250 basis point gap over time.

There's lag that comes from issuing equity and regulatory lag as you in a heavy investment mode, but that's what we're looking at over time is sort of that range of 250 basis point gap between rate base growth and earnings growth. The formulation, we tried to be explicit in that 6% to 8% plus, what you see in '26, '27, and then where we expect to accelerate to in 2028 and beyond.

Okay. I understand that part.

Then just on the credit metric discussion, apologies if it was clear to others, but the 14%, is that an average that you're targeting over time? Because I know you emphasize things get stronger in the back end.

Just any kind of color on the shaping or just how to think about the 14%, if that's kind of a trough or an average? That'd be helpful.

Thanks.

Yeah. Hey, Paul.

Think of it as an average. It's pretty consistent throughout the five-year plan.

We do see it getting a bit stronger in the year four and five of the plan. There's just such a heavy construction phase, '26 through '29, and doesn't really abate that much in 2030, but the level of FFO certainly is just building on itself each year and getting stronger and stronger.

What I would just point out is just our cash flow projections, we believe are some of the most predictable in the industry. They're fortified with these electric service agreements with top-quality counterparties underwritten by that strength of the LLPS tariffs in Kansas and Missouri, including the minimum monthly bill provisions that escalate over time in conjunction with that rising capacity levels, which are actually spelled out in those ESAs that we're mentioning.

You put all that together and it's a really strong, consistent plan throughout the five-year period with consistently strong EPS growth and very solid metrics throughout.

Okay. Thanks a lot, team.

Thank you, Paul.

Thanks, Paul.

Good morning. Actually, it's Andrew Kadavian on for Shah.

Thanks for taking my questions. Good

morning, Andrew. Good

morning.

On the ESAs, how prescriptive is the ramp rate? How much clarity do you get on how much load you'll be serving on a year-by-year basis?

Then when do the minimum monthly bills begin to kick in? Do they kick in during the ramp period or once the customer is fully ramped?

The ESAs, the great thing about these electric service agreements that we've signed is that they include a schedule, which includes an annual capacity levels that are specified by year, starting in the first year. They'll be charged the levels that they use, but if they don't meet the minimum levels, then they'll be charged at that 80% level based on the schedule of contracted capacity that's laid out in the ESAs.

It's a level of specificity and commitment that's laid out contractually with these counterparties. We're really excited to have reached agreements with Google for two of these, one new and one an expansion of a previously announced project, with Meta, also an expansion, and then with Beale Infrastructure, which is a Blue Owl company.

These ESAs include those ramps. They're specific.

They're megawatt by year, and the LLPS provisions on minimums and on requirements are tracked directly with that schedule.

Great. Thank you for that color.

Then just changing gears a little bit, you mentioned that weak industrial demand played a part in the results for this quarter. What gives you confidence that it'll turn around in 2026?

How much of your overall industrial load is represented by the Panasonic project?

Hey, Andrew, this is Bryan. Thanks for the question.

Industrial load in 2025 we're kind of fighting it all year long. January and February of 2025, we had massive snowstorms in Kansas City, and some of our largest businesses closed their doors for many days.

Then we had a large oil refinery that had an outage early in the year. Then industrial demand picked up with Panasonic, but ultimately, by the end of the year, fourth quarter, it was a disappointing level of industrial demand again.

With industrial demand, there's a price component to lower price if you hit a lower peak demand. That had kind of a double effect on our '25 earnings.

Now, we've embedded all this recent weakness in industrial load into our 2026 model already. Our forecasting team, we kind of did a gut check and said, "How comfortable are we with these load numbers in 2026?"

We did modify them down, and that's fully reflected in the $4.24 of guidance for EPS in 2026. We feel like we're in good shape there.

The January '26 books we just closed maybe 10 days ago, and those numbers came in really strong. We're pleased with our start to '26.

It's only 1 month, of course. Then lastly, I'll just say with Panasonic, they certainly started out '25 at a slower pace than we had hoped.

In recent months, they're drawing a considerable amount of load more and more each month. We certainly expect their load in '26 to be within range of our planning assumptions.

In a recent press release, Panasonic executive mentioned that they plan to start two new production lines at their Kansas facility this year and will ramp up to kind of 50% of total capacity early this year. I don't know that we've given explicit megawatt numbers for Panasonic, I can't really give you that kind of detail around its percentage of industrial load.

Understood. Thanks.

I'll leave it there.

Great. Thank you.

Thank you.

Hey. Good morning.

Good morning, Michael.

Hey, guys. I know there's moving pieces and it might be tough, but just in terms of sensitivities or rule of thumb, can you give us any sense of incremental load growth?

What does that do for CapEx and earnings? Then how much of incremental CapEx needs to be financed with equity?

Any help you can give us there?

Michael, just to clarify, you talking about additional CapEx and load growth beyond what we're describing today?

That's right. Yeah.

If you get another customer that ESA, what does that do to CapEx and earnings, and then how do you finance the associated CapEx?

Yeah. I'll put the financing question to Bryan in terms of if we had a billion of additional capital, what would the general rule of thumb be.

I'd say, Michael, every ESA is going to be dependent on what you ultimately reach for that customer. As I described, we expect at least one more ESA in 2026.

We think it will be in the general size range what's reflected in the four we've announced today, at least that large. As I also described, there's some upside in the 2030 timeframe, but the bulk of the impacts are in '30 and beyond, into the next decade.

I would really describe it, it certainly reinforces the plus, and it also helps to extend and fortify that growth trajectory into the 2030s. I won't get ahead of the specific announcements since those will all depend.

The great thing about these ESAs, and why we're able to provide the level of detail that we did on pages 17 and 18, is they do include specific schedules. They do include annual ramps in them.

We'll give that specificity when we announce a specific customer. Hope that makes sense.

Now, Bryan, how would you describe if we have incremental capital, what the general financing rules of thumb might be? Absolutely.

Michael, we've kind of historically cited 50/50 on debt/equity funding of incremental capital, which over the long term is a rule of thumb used by many in the industry.

I think that is fine for you to use as a rule of thumb still for us, being mindful, of course, that the addition of more ESA customers, like David mentioned, could still benefit the very back end of the plan, '29, 2030, think of it in a potential benefit there. The ramp rates of existing customers could also play a factor.

In addition, as we move into future years beyond 2030, these ESAs will reach their peak capacity levels in that early 2030s, maybe in the mid-2030s for the next round. These contracted cash flows will be correspondingly higher levels throughout that period of time, really the next 10 years.

Super powerful to our cash flows as we think ahead.

Irrespective, we do expect this CapEx plan to grow, and it would be accretive, and we'll be prudent with our mix of debt and equity and hybrids, because we want to continue to create incremental value not only for you, our investors, but also for the economic growth of our communities.

That's very helpful. Then this was kind of asked, but in terms of what you're embedding in terms of the ramp rates here, are you assuming the 80% minimum bill level or the full ramp, or is that basically what the range is between those two?

Michael, let me give you a sense for the general approach we've taken to these, and that is that we typically in the first couple of years of the ESA, we look to the 80% minimum level. Again, if the customer uses more, they'll be billed more.

The different constituents listening here that minimum bill does not mean if you use more electricity, you'll only be billed the minimum. That's what you'll be billed if you use less.

We typically, in the first two years, we model it in our plan at the 80% level. Then in the third year and beyond, we use more of an expected case, given what we've seen and what we expect from the customer.

It's more of an expected case. There's a range of upsides and downsides as you move out further in time, but the first couple of years across the ESAs, we typically are using that 80% level to be a little more on the conservative side.

Okay. That's very helpful.

I appreciate it.

You bet.

Thanks, Michael.

Thank you, Michael.

Thank you very much, and congratulations on a great quarter. I guess my first question is, can you tell us roughly what your industrial rate is in terms of dollars per megawatt-hour?

It varies by jurisdiction, Paul, and it's in a typical range. I don't know if, Chuck, you want to comment on what our typical industrial range is, again, with it varies by jurisdiction.

Paul, good morning. I'll let these guys jump in.

I'll just remind you that our LLPS rate is a premium, 15% to 20% premium on the demand charge on the rate

they're

about to give you.

Okay.

Go ahead, Chuck.

Our typical range is in the vicinity of 6 to 7 cents a kilowatt-hour. The $60 to $70 a megawatt-hour, if you want to use that metric.

Typically, we've cited it in cents, but, yeah, 6, 7 cents.

Perfect. Then if there's a cancellation, is that rate essentially sufficient to allow you to recoup all of the costs, or would there be any exposure in the event of an early cancellation?

The provisions of the LLPS are quite specific on what the results are of a cancellation. In effect, through the term of the agreement, the counterparty is responsible for the minimum bill.

That'll depend on what the total megawatts are of the contract. In general, that's a very strong protection if you think about size of these customers, because the rates from the LLPS, under the large load power service tariff, are demand rates that's 15% to 20% higher than the standard industrial rate, which as you just heard from Chuck Caisley, is the standard rate that's 6 to 7 cents.

You've got very good protections for your customers. Also, in that scenario, Paul, which is a great situation, as you will have a set of infrastructure, new infrastructure, you've built in place for existing customers, and you've effectively had a customers alongside who've funded a very large portion of it.

Again, the exact math would depend on the size of that customer and the specific ramp they have over time. These LLPS provisions are strong.

The customers with whom we've contracted, one of the hyperscaler customers put out a statement last week, their commitments around meeting their incremental costs are high. Their interest in being in our region and in having as much capacity as we're able to serve them is very high.

We feel great about the benefits that these contracts will offer for our existing customers and the protections that are embedded on the explicit terms of the LLPS.

Then for the contracts in late-stage negotiations, would that be a new customer, or would that be an expansion of an existing customer?

Could be either one.

Okay. Last question for me.

With respect to the ESAs, are the four signed contracts roughly equivalent in terms of megawatts, or should we assume an average of 300 megawatts per ESA?

We won't disclose the size by customers, but the total steady state is 1.9 gigawatts. Obviously the average of the four comes close to 500, but we haven't broken it out by individual customer, and that is confidential.

The total size we have described not only in aggregate, but how we expect that to feather in over each year, and that's laid out in our slide presentation.

Great. Thank you very much.

Thank you, Paul. Thanks, Paul.

Hey. Good morning, team.

Thanks for taking my questions, and appreciate the detail. I just wanted to jump on Paul Zimbardo's question earlier.

Just if you could help me out, where did you end the year on an FFO-to-debt basis? Then thoughts, and this maybe was the heart of Zimbardo's question, just as you're going into a very significant CapEx cycle, thoughts of maybe adding a cushion to your downgrade threshold?

Hey, Anthony, good morning. Our FFO to debt 2025 was right around that 14% area as well.

That was despite the weakness we had with weather and that late industrial demand weakness. We talked a lot about the 14% FFO-to-debt target, and this will be a little bit repetitive to what I said to Paul.

We really do expect this growth in cash flows from operations each year throughout the five-year plan to be quite robust. With the CapEx plan at the level it is, too, we have inserted planned common equity issuances of $3.3 billion.

This is a robust equity issuance plan and one that we believe will be appreciated by the rating agencies. We're also moderating our level of annual dividend increases, allowing us to retain higher levels of earnings within equity each year.

These are two very meaningful steps that our board supports to the benefit of our balance sheet. Keeping a strong balance sheet and our credit ratings is really important to us.

As I pointed out earlier, we believe we absolutely have some of the most predictable cash flow projections in the industry because they are fortified by those ESAs with top-quality counterparties with that strong LLPS tariff protection and inclusive of monthly minimum bills that David mentioned. Those escalate over time, the ESA agreements are very specific each year what those minimum bills will be based on.

It's an expanding capacity level each year in the five-year ramps and then a 12-year contract at steady-state peak after that. Just we're in a little better position than I think many peers, Anthony, in the sense that our revenue stream is just fortified by those ESAs and more predictable than they've ever been, with just tremendous counterparties.

That went into our thinking, too, when we targeted that level of 14%.

Just apologies, is that a change from the third quarter, your FFO-to-debt target?

Yeah. Moody's lowered our downgrade threshold a year ago from 15% to 14% after our February call.

This is our first comprehensive update that we've given since last February.

Great. Thanks so much.

Appreciate the time.

Thank you.

Good morning. Is Evergy seeking DOE energy dominance financing capital for its transmission plan, or any color you could share around maybe alternative subsidized forms of capital outside of capital markets?

As of today, the plan that we announced today is through the traditional financing mechanisms that are available to the utility, and will be as Bryan described, we'll have a prudent mix of debt and equity with some optionality around how we move things forward, but with a real commitment to a strong balance sheet. For that next tier in our pipeline, we're absolutely open to and will be considering different paths.

That could be in the form of some of the creative ideas that are coming out of Washington now, and pursuing that. It could be participating more directly with large customers.

The LLPS tariff actually has embedded within it if customers bring their own capacity solutions. It's explicitly contemplated if they are amenable to demand response that could reduce their capacity requirements.

That's also an embedded feature in the LLPS. Both those factors could positively impact the rate.

I think, particularly getting into that next tier beyond the first two categories we list on slide 7, that next 10 gigawatts, creative approaches are going to be important. We're committed to exploring those, and I think a range of different options will be there.

I think the size and scale of the opportunity before our country, as well as our company, is such that it warrants exploring those opportunities. What I would emphasize is just with the announcements we've made today, it's a transformative growth opportunity for our company, backed up by ESAs with large customers, great customers who we really appreciate their commitment to our region, Google, Meta, and Beale.

We're excited that we think we can sign at least one more this year, and keep moving beyond that. As we go further and further, I think those kind of creative options are absolutely things that we'll be open to and will continue to explore.

Then a follow-up on that. Does that imply that you looked at the kayak structure for the existing deals, but passed on it and maybe would reconsider that on future deals, or am I reading too much into that?

Could you expand on your question a little bit? You have acronyms that are different from the ones I'm typically used to, but go ahead.

I want to make sure I answer your specific question.

Just in terms of having some of the customers prepay for some of the associated capital in advance as a kayak structure, but just in terms of just that concept.

Got it. The LLPS tariff does not go down that route, but it certainly is, as I mentioned, that for additional potential opportunities and down the road, either that kind of set up or customers bringing potentially their own generation solutions that are either brought directly or contracted for.

Those kind of approaches are absolutely things we're open to and the tariff explicitly contemplates. That could be a direct in SPP, and we're part of the process there is looking at different ways for large loads to bring their own generation, a different products that they've advanced and we'll be advancing with FERC.

It could range from customers bringing their own generation to bringing their own capacity they've contracted, and thereby reducing the LLPS rate. Those are all different mechanisms we could use.

What we've announced today is under the structure of the LLPS, and supported by generation that we're bringing, but some of our current customers, and if you look in past announcements, are contracting with potential resources. If they bring those, then those will be things that they will contract for and will be an offset for the rate.

Great. Thanks for taking my question.

Thank you very much.

Thank you, Liz. I want to thank everyone for participating in the call today.

Want to thank our customers for their commitment to our region. With that, have a great day.

That concludes our call.