CMS Energy Corporation

Good morning, everyone, and welcome to the CMS Energy 2025 Second Quarter Results. The earnings news release issued earlier today and the presentation used in this webcast are available on the CMS Energy's website in the Investor Relations section. This call is being recorded. After the presentation, we will conduct a question and answer session. Instructions will be provided at that time. If at any time during the conference you need to reach an operator, please press start followed by zero. Just a reminder that there will be a rebroadcast of this conference call today, beginning at 12 p.m. Eastern Time, running through August 7th. This presentation is also being webcast and is available on CMS Energy's website in the Investor Relations section. At this time, I would like to turn the call over to Mr. Jason Shaw, Treasurer and Vice President of Investor Relations.

Thank you, Seb. Good morning, everyone, and thank you for joining us today. With me are Kerrick Rochelle, President and Chief Executive Officer, and Reggie Hayes, Executive Vice President and Chief Financial Officer. This presentation contains forward-looking statements, which are subject to risks and uncertainties. Please refer to our SEC filings for more information regarding the risks and other factors that could cause our actual results to differ materially. This presentation also includes non-GAAP measures. Reconciliation of these measures to the most directly comparable GAAP measures are included in the appendix and posted on our website. And now I'll turn the call over to Gerrick.

Thank you, Jason, and thank you, everyone, for joining us today. Our investment thesis, robust and solid, continuing our track record of industry-leading results. You know this, and you've seen the results it delivers. As I've said before, Michigan is open for business. Today, I'm pleased to announce we have reached an agreement with a new data center, which is expected to add up to one gigawatt of load. This load is incremental to our plan and part of the nine gigawatt pipeline that we have been working to locate in our service area. We expect this load, early ramp, to start to show up in the latter portion of the five-year plan. We continue to see positive momentum with data centers within the nine gigawatt pipeline and expect additional progress once we finalize the data center tariff. In addition to low growth from data centers, Michigan is on the move. Grand Rapids, the heart of our electric service territory, was recently ranked the number one city on the rise in the U.S. by LinkedIn, highlighting their diverse industries from tech, insurance, manufacturing, and healthcare. This area is growing nicely, bringing jobs and people to the state. And once again, CNBC ranked Michigan as the top 10 best state for doing business. And we are seeing it. As I shared in Q1, we continue to see strong housing starts, alterations, as well as upgrades and relocations, all signs of positive growth among residential, and commercial customers. All this drives our long-term annual sales growth estimates of 2 to 3 percent. And remember, this is before this new data center is fully online. We're excited about and committed to Michigan's future prosperity. We are prepared and ready to serve its growing energy needs. On this next slide, I want to connect a few dots, which highlight the investment opportunities we see above and beyond our five-year plan. And specifically, I want to share some early insight into our upcoming integrated resource plan filing. Let me start here. A long runway of customer investments is great, but isn't sustainable if your customers cannot afford them. So I like starting with customer affordability. What we know to be true is that growing demand, like I shared on the previous slide, enables longer-term cost savings for our customers. As our load grows, we can expect or we can spread fixed costs over a larger customer base. A win for all. Add to it our ability to realize savings through the CE way, episodic cost-saving opportunities, and our energy waste reduction program. We have multiple ways to keep bills affordable for our customers. It is our strong focus on these cost-saving opportunities that keep bills affordable, both gas and electric, and allow us to make needed customer investments. And there are many customer investment opportunities, greater than $25 billion, above and beyond our five-year plan. Now, we've talked previously about the investments needed in our electric grid, which drive resiliency and reliability for our customers through our electric reliability roadmap. In addition, we have important investments clearly articulated in our renewable energy plan, or REP, to meet Michigan's clean energy law. And today, I want to highlight our integrated resource plan, or IRP, which we'll file in mid-2026. We are still preparing for this filing, but getting a clearer picture on what will be required for the future. As I mentioned, we are building renewables required by the law and included in the REP, which provide energy but limited capacity. Our IRP will primarily address capacity. When we model a 2% to 3% sales growth that we are realizing, the need to replace plants, existing capacity that will retire over the next five to seven years, and the need to replace a large PPA that will expire in 2030, the model points to additional storage and gas capacity. We anticipate needing to build more storage than the amount required by the 2023 energy law. We currently see this as a mix of owned and PPAs with the financial compensation mechanism. And of course, we'll take advantage of supportive tax credits for storage. We also anticipate new gas capacity at multiple locations, and we are well into the planning and preparations to realize this need. Our first cut looks like an additional $5 billion of opportunity outside the five-year plan. But understand that this is an early number and could be higher. We'll continue to keep you updated as the preparation continues prior to this filing of this important IRP. As I've shared before, CMS has a long history of working effectively with all administrations, and I continue to be proud of our agility as the federal environment continues to evolve. Let's start with the One Big Beautiful Bill Act and how it impacts the utility. As we understand the provisions today, our renewable projects within the five-year financial plan are well positioned to meet timelines and requirements to receive full production and investment tax credits, as well as transferability through 2029. These de-risk $4.5 billion of capital, the renewable portion of the five-year plan, at the utility. It also ensures full transferability of the tax credits, which Reggie will summarize in a moment. This puts us well on track for the 2030 renewable requirement in Michigan's energy law in a way that maintains affordability for our customers. And recall that to the degree we see affordability concerns post-2029, we have options within the law to mitigate costs, including -of-state PPAs, where capacity factors may be higher, or an extension to the compliance period. At a minimum, we're seeing cost savings on self-build projects through good, lean engineering, the CE way, to further take costs out for our customers. Now, let me address North Star. Again, this business makes up approximately 5% of the earnings mix, so it is small, with the majority of the growth at Dearborn Industrial Generation, or DIG, with energy and capacity sales. The renewables portion of the business is very small. We typically complete one to two solar projects a year, with utility-like returns are better. At North Star, our renewable projects are safe harbor through 2027, with some options in 2028. Many of these projects are already contracted with off-takers, materials secured, and a solid plan to execute, including strong contractual language. As we move forward, we'll continue to evaluate the needs for capital across the business, as we always do. We'll be mindful of the return on those investments. In light of the passage of the One Big Beautiful Bill in subsequent executive order, we're using a sharp pencil in the five-year planning process, which is well underway. This includes growing value at DIG and re-contracting both energy and capacity, as both markets continue to be strong, and the ability and willingness to shift capital to utility investments that benefit our customers. Shifting to the Federal Power Act 90-day emergency order, in May, we were ordered by the Department of Energy, or DOE, to continue to operate our J.H. Campbell Coal Facility. We are complying with that order and dispatching into MISO. We are also currently reviewing our maintenance and investment plans for the facility, should we see a push for longer-term use. Keep in mind, the DOE's order provides for cost recovery. We have filed a request with FERC for recovery from all MISO North and Central customers who are served and benefit from this supply resource. We expect a positive outcome from this proceeding that will be good for all stakeholders. Finally, our minimal exposure to the auto industry, diverse supply chain, and continued focus on moving to U.S.-based suppliers further limits potential tariff impacts. Recall, much of the exposure is related to capital equipment, which means any impact would be spread over the life of the asset, with minimal impact to earnings and customer rates. To date, we've only experienced about $250,000 in increases. Again, I appreciate the team's efforts on multiple fronts to continue to position CMS Energy for success in what is a dynamic federal environment. I want to take a moment to highlight Michigan's constructive regulatory environment. Last month, the Commission approved the first-ever storm referral at the utility, a new precedent for Michigan. It speaks to our performance during the March and April ice storms and the constructive nature of this commission. While this is a unique aspect in the utility sector, it was noted as a best practice by Liberty Consulting in the third-party distribution audit and was approved by the Commission in a timely fashion. This is a great step to strengthen an strong regulatory environment in the state. We continue to be supportive of the Liberty audit of our distribution system. It was commissioned by the MPSC, and the results point directly to the important investment needed to improve reliability for our customers and bolsters the game plan we laid out in our reliability roadmap. We will continue to weave the audit findings into future rate cases. Now jumping to the rate cases, on the electric side, our current rate case filing is larger than what you've seen from us in the past at a $460 million revenue increase and is well aligned to significantly improve reliability for our customers through additional capital investments and O&M, including vegetation management. To frame this case from an affordability perspective, if we were to achieve 100% of the rate case ask, our residential electric bills will continue to be below the national average. In our gas case, we saw a very constructive recommendation from the staff supporting approximately 80% of our revised ask and about 95% of our capital. And while we're always open to settlement, we're confident in the investments we need to make in the quality of our case and comfortable going the distance to a fully adjudicated order. For our longer term filings, we expect an order in our renewable energy plan, or REP, by mid-September. Our REP will further define our renewable investments and feeds into our integrated resource plan that we'll file in mid-2026. We are making important investments for our customers in the future of our growing state, and we continue to see constructive outcomes time and time again. Finally, I'd like to take a moment to welcome our new commissioner, Shaquille Myers, who was appointed earlier this month by the governor. Commissioner Myers has an impressive background. She was a member of the governor's senior leadership team and previously led speaker of the house, Joe Tate's office, as his chief of staff. She understands the importance of economic development to bring good paying jobs to Michigan and played an instrumental role in the development of the 2023 energy law. We look forward to working with Commissioner Myers and the rest of the commission and staff as we have in the past to reach constructive regulatory outcomes. Okay. Now, onto the financials for the quarter. We are in a strong position heading into the second half of the year. For the first half, we reported adjusted earnings per share of $1.73, well ahead of our budget and where we had planned to be according to our full year guidance. The team has delivered strong performance, particularly in Q2, on all fronts, regulatory, operations, and financial. Therefore, we remain confident in this year's guidance and long-term outlook and are reaffirming all our financial objectives. Our full year guidance remains at $3.54 to $3.60 per share with continued confidence toward the high end. Longer term, we continue guide toward the high end our adjusted EPS growth range of 6 to 8%. With that, I'll hand the call over to Reggie.

Thank you, Garrick, and good morning, everyone. On slide 9, you'll see our standard waterfall chart, which illustrates the key drivers impacting our financial performance for the first six months of 2025 and our year to go expectations. For clarification purposes, all of the variance analyses herein are in comparison to 2024, both on a year to date and a year to go basis. In summary, through the first half of 2025, we delivered adjusted net income of $518 million, or $1.73 per share, which compares favorably to the same period in 2024, largely due to the absence of unfavorable weather from the prior year and continued constructive regulatory outcomes. To elaborate on the top line impact of weather, favorable weather in the second quarter, largely in the month of June, coupled with a relatively normal winter in Q1, provided an aggregate benefit of $0.32 per share of positive variance. And it's worth noting that the weather outlook in our service territory remains quite good for the balance of the summer. Rate relief, net of investment related expenses resulted in $0.09 per share of positive variance due to constructive outcomes achieved in our electric rate order earlier in the year and our gas rate case settlement in the second half of 2024. Moving on to cost trends, you'll notice in the third bar on the left-hand side of the chart, $0.04 per share of negative variance versus a comparable period in 2024, due in large part to increased vegetation management in accordance with our electric reliability roadmap. What's less visible in that bar on the right-hand side of the chart is the favorable impact of the aforementioned service restoration expense deferral granted by the commission in June, which enabled us to establish a regulatory asset on the balance sheet for the substantial costs incurred during the March-April storm. This timely and supportive action by the commission is not only a testament to the historic nature of the storm and our strong restoration efforts, but it's also worth repeating the constructive nature of the Michigan regulatory environment. Rounding out the first six months of the year, you'll note a negative variance of $0.27 per share highlighted in the catch-all bucket in the middle of the chart. The primary drivers of the negative variance were related to the planned outage of our Dearborn Industrial Facility, which I'm pleased to report is fully operational and expected to deliver normalized earnings for the remainder of In addition, we anticipate back-end weighted tax benefits from select renewable projects at Northstar. Other notable drivers in this category include the impact of parent financing activities thus far in 2025 and slightly lower electric and gas non-weather sales volumes. Looking ahead, as always, we plan for normal weather, which equates to $0.11 per share, a positive variance of the remainder of the year, given the absence of the mild temperatures experienced in the fourth quarter of 2024. From a regulatory perspective, we're assuming $0.18 per share of positive variance, which is largely driven by the aforementioned electric rate order received from the commission earlier this year and the expectation of a constructive outcome in our pending gas rate case. Closing out the glide path for the remainder of the year, as noted during our Q1 call, we anticipate lower O&M expense at the utility driven by the usual cost performance fueled by the CEA, which we're estimating at $0.01 per share of positive variance. Lastly, in the penultimate bar on the right-hand side of the chart, you'll note an estimated range of $0.14 to $0.20 per share of negative variance, which largely consists of the absence of select one-time countermeasures from 2024 and the usual conservative assumptions around weather normalized sales and parent financings, among other items. Given our strong -to-date performance, particularly in the second quarter, we remain confident in our ability to deliver and our full-year financial objectives to the benefit of all stakeholders. Moving on to credit quality, it is worth noting that Moody's reaffirmed our credit ratings in May, as noted at the bottom of the table on slide 10, and we are currently working through the review process with S&P. Longer term, we'll continue to target solid investment grade credit ratings and we'll manage our key credit metrics accordingly as we balance the needs of the business. Slide 11 offers an update to our funding needs in 2025 at the utility and at the parent. With two quarters under our belt in 2025, I'm pleased to report that we have completed the vast majority of our financing plans for the year. And as you'd expect, we're busy evaluating alternatives for our remaining funding needs at the parent. To that end, it's worth noting that we have executed 40 equity contracts of approximately $350 million, thus de-risking roughly 70% of our planned equity needs for the year. Lastly, we continue to see strong appetite in the bilateral market for tax credit transfers and are on track to complete our planned monetizations for the year. Longer term, we'll continue to utilize this funding vehicle as a source of liquidity while available. To that end, as Gehrig noted, based on the expected in-service dates of our renewable project pipeline, as well as the construction status on projects in the outer years of our plan, we are well positioned to execute on approximately $700 million of tax credit transfers in our five year plan. As I've said before, our approach to our financing plan is similar to how we run the business. We plan conservatively and capitalize on opportunities as they arise. This approach has been tried and true year in and year out and has enabled us to deliver on our operational and financial objectives, irrespective of the circumstances, to the benefit of our customers and investors. And this year is no different. And with that, I'll hand it back to Gehrig for his final remarks before the Q&A session.

Thanks, Reggie. We've had a great quarter and we are well positioned to deliver on the full year. What I'm even more excited about is how this team continues to deliver great outcomes for our customers and investors. The data center agreement is a big win and reflects progress in our growth, as well as the opportunity to invest in new renewable and thermal resources. It is an exciting time in this industry and CMS energy is well positioned. With that, Seb, please open the lines for Q&A.

Thank you very much, Gehrig. The question and answer session will be conducted electronically. If you would like to ask a question, please do so by pressing the star key followed by number one on your touchtone telephone. If you're using a speaker function, please make sure you pick up your headset. We'll proceed in the order that you signal us and we'll take as many questions as time permits. If you do find that your question has been answered, you may remove yourself from the queue by pressing star followed by number two on your touchtone telephone. We'll pause for just a second while we register the questions. Our first question is from Julian Demolin-Smith at Jefferies. Please go ahead.

Hey, good morning, team. Thank you very much and nice progress again. Good morning, team. Hey, Julian. Good morning. I'm looking forward to the next video, Julian. I was going to say I'm looking forward to the next video, Julian. You better believe it. We got to wear another rally cap. With that said, speaking of rally, how about this gigawatt that you announced this morning? I just would love to get a little bit more details here. I mean, how do you think about the ramp and the load? You said it's towards the end of your outlook. Can you elaborate a little bit more specifically? And then also, can you elaborate a little bit more about how this fits into your resource mix? I know that this is somewhat dynamic itself, but can you elaborate at least preliminarily on how you're thinking about it? And when you say it's ramping up in the back half of the plan, like when do you get to that gigawatt? I mean, is it just a few hundred megawatts towards the back of the plan? Just give us a little bit more if you can and I appreciate it.

We're excited about the opportunity here. Teams did a nice job of converting part of this 9 gigawatt pipeline. So we have agreement in place and the counterparty has put a significant amount of money or capital into this agreement. And that is really to secure materials and equipment and be able to do final design work. And so again, nice progress from that perspective. From a ramp perspective, those conversations continue with the counterparty and specifically it's in 29 or 30. And then we're also looking at that ramp rate. And so that's kind of the framing. So that's what we'll see early ramp, early megawatts show up in that 2029 or 2030 timeframe. And then how fast is still being determined in the discussions with the counterparty. So that gives you a little flavor of that. Now you talked about the resource mix and just to give you a little context of how we're thinking about this. I love the fact that that ramp is in that 29, 30 into the next decade. That gives us a ton of flexibility from a resource perspective. And so remember, I'm a little long from a capacity perspective. It's a good starting point. I'm still building capacity today, even though I'm long on building capacity, because I have a renewable energy law. So I'm building renewables. Now those have limited capacity, but I'm also building storage. Like already underway. We're doing that as well as well. A few, a few PPAs on storage as well with an STM. And then hopefully you heard in my comments, this willingness and preparations to build out gas capacity. Now what I talked about was specifically the two to 3% low growth. So this would be incremental to plan, but hopefully here's some flexibility to build out gas. And I would just say we're well into the preparation phases for, for gas capacity build out. So that's how we'll, that's kind of the mix of the supply resources that will, that will serve, serve this customer.

Awesome. And if I can just follow up quickly here, that nine gigawatt number on the pipeline side, how are you seeing that evolve here? I mean, I think it's, it's flat quarter to quarter. And again, I suppose that's in this, in this modern day and age, I'm curious on how you're seeing it evolve and specifically to think that to what you were to see any of it materialized, would it be kind of tail end of the period or beyond at this point, just given what you're seeing on ramp rights for other customer contracts?

That nine gigawatt pipeline continues to fill is what I put it. It's, it's conservative. If you look at some of our other public documents, you would see a larger pipeline. We feel confident in the nine. And I've talked about that being a gradient. There are some customers within that pipeline where we continue to exchange terms and conditions and red lines. And, and one of the next stage gates specifically is this data center tariff. And so I would expect that additional customers could convert once we have that data center tariff in place. And so we can see, continue to see good progress with that pipeline. I'll also make a note. We haven't talked much. We've been talking a lot about data centers. There's a good manufacturing base in there as well. There's, there's over 200 customers, 200 customers that are non data centers that are a part of that, you know, overall large growth potential. And so again, things in Michigan look strong and look good for the future.

Awesome guys. See you soon. All right. Yep.

Thank you. Our next question is from Nicholas Campanella from Barclays. Please go ahead.

Hey, morning. Thanks for the time. Morning. Hey, I just wanted to, I wanted to pick up where you left off there and just be a little bit more clear on how the, the one gigawatts of new data center customer interacts with the 5 billion of CapEx upside in the IRP. Is it just like, is there, is there like a tipping point where if you do like another gigawatt and you go back and revise that 5 billion number and just where is the point in which you, you look at a higher than two to three percent long-term sales outlook, if that makes sense?

Yeah. Let me broaden your question a bit as well. So when I think we'll, we'll of course do another capital update and the Q4 call, and there are several things that I see about that. We'll update the grid numbers, the reliability, resiliency piece, and the economic development projects will fall into that. So you'll see that grow. We'll have the REP. It'll be approved by that time. And so you'll see the renewables and that'll be a big piece of that five-year plan as well. And here's the thing about that renewables piece that I want to point out is that what we're seeing with the passage of the, of the big, beautiful bill act is that there are more developers that are pulling projects forward and that gives an opportunity to build transfer arrangements. It allows us to do maybe some PPAs and some with a financial compensation mechanism. And so that might grow a little bit, particularly in the near term for the utility. And then there are going to be some dollars for this IRP. Now we've got to balance that, right? Because we're going to file an IRP in 2026, takes 10 months to get a rate case approval. That puts it in 2027, but we're going to have to run some things in parallel in that, because to be able to build out the capacity we need for the future, we're going to have to move in that direction. So you'll see some of that sprinkled into the, into the plan going forward. Now to get to your question, that $5 billion plus is really what we need to the, to deliver today with the two to 3% sales growth was realizing the retirement of some plants or placement of a large PPA. This gigawatt is incremental. So we'd have to adjust that number up. And so again, let us play that out in the Q4 call as well as in other filings and you'll see that get woven into future capital plans.

Excellent. Excellent. Okay. That's, that's very clear. And then just, how do you feel about the gas case at this point and the, the ability to potentially settle that? You know, I know that we've been looking at a little bit more kind of litigated full distance outcomes on the electric side, the ones that just take your temperature on the gas.

Thanks. We're in a great, great spot right now. When I say great spot, 80% of the revised task, 95% of our capital is improved. That's a great case from a quality perspective. It's the right investments to make in the state. And we continue to be open to settlement. August, we should have a PFD on it. But you can hear, hear me out here. We're in a good spot. And so I'm comfortable going to a fully adjudicated order.

Great. And then if I could squeeze one more in, just really appreciate the financing update, Reggie. Seems like you're executing 25 as planned. Just how are you kind of thinking about 26 and whether there's an opportunity to kind of de-risk the equity in 26? And is that something that you'd be open to?

Yeah, I appreciate the question, Nick. The quick answer is that as we look at the second half funding needs we have for 2025, we will also take into account funding needs we have in the front half of 2026. And if there are opportunities to pull ahead some of those financing needs in an efficient transaction this year, we may look to do that. So we're keeping all options on the table as you'd expect. And the funding environment remains quite good. So again, we're going to keep as much flexibility as possible.

Okay, thanks so much.

Thank you. At this time, there are no further questions in the queue. I'll hand back to Mr. Eric Rochelle for any closing remarks.

Thanks. I'd like to thank you for joining us today. I look forward to seeing you on the road. Take care and stay safe.

This concludes today's CMS Energy Q2 2025 call. Thank you all very much for joining.