Good morning, everyone, and welcome to the CMS Energy 2024 first quarter results. The earnings news release issued earlier today and the presentation used in this webcast are available on 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 the star followed by 0. Just a reminder, there will be a rebroadcast of this conference call today beginning at 12:00 P.M. Eastern time, running through May 2nd. 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 Shore, Treasurer and Vice President of Investor Relations. Thank you, Drew. Good morning, everyone, and thank you for joining us today. With me are Garrick Rochow, President and Chief Executive Officer, and Rejji 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. Reconciliations of these measures to the most directly comparable GAAP measures are included in the appendix and posted on our website. Now I'll turn the call over to Garrick. Thank you, Jason, and thank you, everyone, for joining us today. CMS Energy: 21 years of consistent industry-leading results. What sets us apart is our performance, and it starts with our investment thesis. It is how we prioritize and focus our work to deliver the service our customers deserve and the financial outcomes you expect. As we look ahead, we see ample investment opportunity over the long term as we lead the clean energy transformation and deliver the critical work needed to improve the reliability and resiliency of our electric and gas systems. This important work is supported by legislation and a constructive regulatory environment which provides confidence in making required investments to strengthen our system and prepare for a clean energy future. We plan ahead through our Electric Reliability Roadmap, Natural Gas Delivery Plan, and our upcoming Renewable Energy Plan, which all provide visibility and transparency on the work we'll deliver to keep our systems safe, sound, and clean. At CMS Energy, we work both sides of the equation. We make important investments in our systems, and we work to keep bills affordable. Our CE Way Lean Operating System helps us improve our performance, increase productivity, and take costs out of the business. We are hard at work to grow Michigan through economic development, ensuring Michigan thrives well into the future. These efforts are important and help us keep customers' bills affordable. At CMS Energy, we make our investment thesis work year after year, and it continues to set us apart in the industry, delivering results for all our stakeholders. Today, I'm going to share three focus areas that have me excited about our future and give us confidence in our outlook. First, our electric distribution system. As our world becomes more dependent on electricity for business growth, technology advancements, devices, and vehicles, our system needs to be stronger, smarter, and more resilient for our customers. But our vast electric distribution system is aging and needs to be modernized and strengthened for increasingly severe weather. Over the past five years, we have seen some of the highest wind speeds on record in more frequent storm activity. We have responded to this need through our Electric Reliability Roadmap. Currently, a five-year, $7 billion plan to improve performance and harden our system for the future. The plan utilizes best practices from across the industry, including designing the system with stronger poles, undergrounding, sectionalizing, and further automation. Given the size of our distribution system—90,000 miles of line, nearly 1,200 substations, and a historically lower investment per mile compared to peers—we see a long runway of needed investment. We've incorporated roughly $1.5 billion of the incremental $3 billion you see on slide 4 into our current capital plan, and you'll start to see this investment show up in our next electric rate case, which we'll file in the second quarter. These important investments will mean fewer and shorter outages for our customers, and we are already seeing meaningful improvements from the investments made over the last few years. The second focus area I want to share is our continued leadership of the transformation to clean energy in the industry. In the past, I have shared our approved plans to eliminate coal in 2025, reduce carbon, grow energy efficiency, and build out renewables in pursuit of our net-zero targets and cleaner air for our customers and our planet. In late 2023, much of our clean energy targets were bolstered by Michigan's new clean energy law. This law is unique in the industry and is good for all stakeholders. It provides us with the opportunity to further reduce our carbon footprint while maintaining resource adequacy, affordable customer bills, and delivering for our investors. On the right side of the slide, you'll see the opportunities ahead as we prepare to meet Michigan's new clean energy law. It supports an accelerated plan with a decarbonization of our system, with an enhanced financial compensation mechanism which provides a roughly 9% return on clean power purchase agreements. In addition, there's an increased incentive on energy efficiency as we target 60% renewables by 2035 and 100% clean energy by 2040. It gives us important flexibility as we think through how to best meet our customers' needs with renewables across the broad MISO footprint. This mechanism and the flexibility in the law helps us balance customer affordability as we work through this transition. For our customers, all this means stronger, more resilient, and cleaner energy. For our investors, an exciting and robust investment runway well into the future. Now, let's work the other side of this investment equation. The third focus area that I want to share today is how we are helping Michigan grow and thrive, which is good for our company and our customers. Growth across our service territory is good for Michigan. It helps keep bills affordable for our customers and provides headroom for the investments I just referenced. I couldn't be more excited about the growth we are seeing in our state. Michigan has a strong fiber network, access to fresh water, temperate climate, energy-ready sites, and attractive energy rates. In February, we secured a contract with a large data center in the heart of our service territory. A majority of the 230 MW of new load is expected to be online by 2026. This is nice load growth. I'm even more excited about the manufacturing load growth we are seeing in Michigan, which is a differentiator for us. Our statewide leadership of projects such as Gotion, Hemlock Semiconductor, Ford, and many others continues to drive new and expanding load in our service territory. These projects bring significant jobs: supply chains, commercial growth, housing starts, and broad Michigan investment. The ancillary benefits of manufacturing growth are good for all customers and bolster our confidence in our plan for 2024 and beyond. Our customers thrive when Michigan thrives. I'm proud of the diversity and quality of new load our leadership is working to bring to the state. Now, let's get into the numbers. In the first quarter, we reported adjusted earnings per share of $0.97. Although we experienced a warmer than normal winter, the healthy set of countermeasures we deployed in 2023, as well as our active use of the CE Way, continued to benefit us in 2024. 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 $3.29-$3.35 per share, with continued confidence toward the high end. Longer term, we continue to guide toward the high end of our adjusted EPS growth range of 6%-8%, which implies and includes 7%-8%. With that, I'll hand the call over to Rejji. Thank you, Garrick, and good morning, everyone. On slide 7, you'll see our standard waterfall chart, which illustrates the key drivers impacting our financial performance for the quarter and our year-to-go expectations. For clarification purposes, all of the variance analyses herein are in comparison to 2023, both on a first quarter and nine months-to-go basis. In summary, through the first quarter of 2024, we delivered adjusted net income of $288 million or $0.97 per share, which compares favorably to the comparable period in 2023, largely due to higher weather normalized sales and lower service restoration costs at the utility, partially offset by mild weather. To elaborate on the impact of weather, we experienced another warm winter in Michigan during the first quarter, which had the second lowest number of heating degree days in the past 25 years. The warm winter weather resulted in $0.06 per share of negative variance, which appears modest on the surface given the historically low number of heating degree days. However, it's important to note that last year's winter was also quite warm. Rate relief, net of investment-related expenses, resulted in $0.05 per share of positive variance due to constructive outcomes achieved in our most recent electric rate case and last year's gas rate case settlement, coupled with residual benefits from our 2023 electric rate case settlement approved last January. From a cost performance perspective, our financials in the first quarter of 2024 were positively impacted by lower operating and maintenance, or O&M, expenses, primarily attributable to lower service restoration costs than we experienced last year. Also, as Garrick noted, we continue to see benefits from select cost reduction initiatives implemented in 2023, which have offset modest inflationary trends we've experienced in various cost categories, such as wages, as planned. And we anticipate this trend to continue over the remainder of the year. In our catch-all category, represented by the final bucket in the actual section of the chart, you'll notice a healthy pickup of $0.19 per share, largely driven by weather normalized sales, which contributed almost half of said positive variance, particularly in our residential and commercial customer classes. It's worth noting that the leap year impacts comparability with 2023 for weather normalized sales. But even absent the effects of the leap year, our residential weather normalized sales were up about 0.5%, and our commercial customer class was up almost 2.5% versus the prior year, which highlights the continued solid performance of our higher margin customer classes. Looking ahead, we plan for normal weather, as always, which equates to $0.22 per share of positive variance for the remaining nine months of the year, given the mild temperatures experienced for virtually all of 2023. For a regulatory perspective, we're assuming $0.18 per share of positive variance, which is largely driven by the constructive electric rate order received from the Commission in early March. We're also assuming a supportive outcome in our pending gas rate case. On the cost side, we anticipate lower overall O&M expense at the utility, driven by the usual cost performance fueled by the CE Way and last year's voluntary separation program, among other 2023 cost reduction initiatives that continue to bear fruit. We also assume lower service restoration costs, given last year's record level of storm activity in our service territory. In aggregate, we expect these items to drive $0.09 per share of positive variance for the remaining nine months of the year. Lastly, in the penultimate bar on the right-hand side, you'll note a significant negative variance, which largely consists of the absence of select one-time countermeasures from last year and the usual conservative assumptions around weather normalized sales and non-utility performance, among other items. In aggregate, these assumptions equate to $0.52-$0.58 per share of negative variance. Slide 8 offers the latest updates on our regulatory forward calendar. As you'll note in the top section, we plan to file our Renewable Energy Plan, or REP, by mid-November, which will highlight our strategy for complying with the various renewable energy targets associated with Michigan's new clean energy law. We are excited by the prospects of the new law, which will support our net-zero carbon by 2040 goal, and look forward to socializing our filing with key stakeholders in the coming months. Once filed, the Commission will have 300 days to issue an order, which will likely be in the third quarter of 2025. Therefore, as mentioned during our fourth quarter call, you should expect that the five-year plan that will roll out in the first quarter of 2026 will incorporate a greater portion of the financial impacts of the REP. Moving on to our general rate case filings, you can expect our next electric rate case to be filed in late May to early June timeframe. This filing will incorporate some of the initial spend we have outlined in our five-year Electric Reliability Roadmap that Garrick touched on earlier. Given the 10-month stipulated period for rate cases in Michigan, we would expect to receive an order from the Commission in the first quarter of 2025 and thus the related financial impacts. Lastly, we anticipate an order in our pending gas rate case by mid-October, absent a settlement. While we don't always include a balance sheet update in our formal presentation, it is worth noting that Moody's and Fitch reaffirmed our credit ratings in March and April, respectively, as noted at the bottom of the table on slide 9. Longer term, we continue to target solid investment-grade credit ratings and will continue to manage our key credit metrics accordingly as we balance the needs of the business. With that, I'll hand it back to Garrick for his final remarks before the Q&A session. Thank you, Rejji. Our simple investment thesis is how we run our business and provides us with the confidence for a strong outlook this year and beyond: 21 years of consistent industry-leading financial performance, 21 proof points, regardless of conditions, no excuses, just results. With that, Drew, please open the lines for Q&A. Thank you very much, Garrick. 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 the digit 1 on your touch-tone telephone. If you're using a speaker function, please make sure you pick up your headset. We'll proceed in the order 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 by pressing the star key followed by the digit 2 on your touch-tone telephone. Our first question today comes from Shahriar Pourreza from Guggenheim Partners. Your line is now open. Please go ahead. Hey, guys. Good morning. Hey, good morning, Shah. Good morning, morning. I guess, firstly, just given you have an upcoming electric case, how are you thinking about any kind of incremental construct improvements there? Would you kind of seek an expanded IRM framework? And do you need to address any kind of the rate design issues with CNI rates, especially as you're trying to accommodate new load like data center growth, especially as you're trying to kind of balance that customer rate impact? Shah, you want me to get into rate design? You guys are all going to fall asleep on this call if I go into rate design. So let me start out with that. Let me start out with the fundamentals of this electric case, because I think this is really important. You've heard me time and time again, whether it's investor meetings or in our calls, on the importance of improving reliability. We've seen higher wind speeds, more frequent storm activity, and this is our focus as a company: how do we improve reliability and the longer-term resiliency of our electric system? You can also hear that from the commissioners. They're very clear about that expectation. And so I would say there's really good alignment there. And this reliability roadmap does just that. It's aimed at those important capital improvements. There's some O&M work associated with that as well. These are best practices in the industry, which we're deploying across our system, and are going to reveal meaningful benefit for our customers. In addition to that, we're focused on the affordability piece. This is the fundamentals of this: great to invest the capital, but you also have to be focused on the affordability piece for our customers. And so it's driving down unit costs through the CE Way. It's other cost offsets. There's a whole range of things we're doing to make sure this next electric rate case delivers for our customers in terms of improved reliability and offsetting from a cost perspective. So that's the fundamentals of the case. And so we're going to look at different mechanisms in that case. As I've shared before, I would anticipate that we, again, take advantage of our infrastructure recovery mechanism that was supported in the last case. We'll look at a storm recovery mechanism. We've utilized that in previous cases. We'll continue to look at that optionality and what that could look like in this case. But again, longer term, we'll file this end of May, first part of June. I feel confident about what we're putting together based on the important merits of the case that are going to improve reliability, well balance the important components of affordability. Now, your question on rate design, there's a lot in rate design. I really will put you to sleep if I go there. We're going to make sure, as the state expands and we have this important load growth, that both the energy and capacity components, that cost of service mechanism, is appropriately allocated to where those costs are. That's what we've done historically. That's what the Commission supported. We'll look at that, certainly, within the context of this case. But it's really smaller in the grand scheme of the important work of this case. Got it. Perfect. And then lastly, as we're thinking about the energy law construct and you went right, I guess, what are some of the first changes you can implement, especially as we're thinking about the upcoming IRP update? Would you lean more on sort of that FCM construct? And is any of this kind of embedded in your longer-range growth guidance? Thanks. It's still early days on some of this modeling. So we'll file our REP, our Renewable Energy Plan, November 15th. And as I've shared historically here, previous year, there's a broad spectrum of ownership versus PPAs. The PPAs, obviously, have the opportunity for the Financial Compensation Mechanism, or if you're going to build everything and own everything, obviously, you have the opportunity to earn your ROE. So there's a broad spectrum. You can do either end. Those are the bookends. I think it's somewhere in the mix, and there's a lot of variables we need to consider that we're modeling out right now. And that's why we're not prepared to share what that looks like. But let me hand it over to Rejji. I know he has some additional thoughts on this. Shah, good morning. Thanks for the question. All I would add to Garrick's comments is that in our current five-year plan, what we've incorporated is just a modest amount of PPAs with the financial compensation mechanism. That's solely because of the fact that any PPA put in place after June of this year would be subject to the new FCM, which is around 9% versus the prior of about 5.5%. So we have a portion of that, albeit a small portion, incorporated into this five-year plan. We've also incorporated the enhanced economic incentives associated with energy efficiency. So that's flowing through our plan as well. Remember, historically, we've, on the electric side, been reducing load about 2% year-over-year. Before the new energy law, we'd get a 20% incentive on top of that spend. That's now 22.5%. So that's also a source of financial upside embedded into this plan. But to Garrick's earlier comments, the much more expansive opportunities, whether it's scaling contracts or the ownership opportunities or, more specifically, the rate-based opportunities, those are not incorporated into our five-year plan and really won't be until 2026. Okay. Perfect. Thank you, guys. Appreciating Garrick. For the record, your rate design answer was not boring at all. Thanks, guys. Our next question comes from Nick Campanella from Barclays. Your line is now open. Please proceed. Hey, good morning, guys. Hey, good morning, everyone. Thanks for taking the morning. I guess, just thinking about the other upside opportunities, could you maybe give us an update on your conversations around DIG and the recontracting opportunity there and how those discussions have been progressing? Is this something that we can maybe see an update on by year-end, or is it more a 2025, 2026 item? Maybe just talk about timing there. Thanks. Yeah, good morning, Nick. This is Rejji, and I appreciate the question. Yeah, as we talked about on our fourth quarter call, we still have about 30%-35% open margin in the outer years of our plan, really starting in sort of 2026 or second half of 2026 going through 2028. We certainly are seeing attractive reverse inquiry for that open margin on the capacity side. We're sold through on the energy side through 2028 or through the duration of this five-year plan, but there still are opportunities on the capacity side. And we'll be thoughtful. We never are too aggressive in selling down that open margin. We like to have a little bit of optionality, particularly with a really attractive technical that we continue to see in Zone 7 with the tightening of supply and upward pressure on demand. We'll provide an update in our next five-year plan, as we always do. I expect that we'll be selling down a portion of that open margin radically over the coming months and quarters, but should still have probably a little open margin as we provide a new five-year plan in the first quarter next year. Is that helpful? That is helpful. I appreciate that. And I guess, thinking about the rate case cadence and outcomes, on the electric side, the last case, you kind of pursued a fully litigated outcome. But on the gas side, you just received staff testimony. And I think, Rejji, I heard you say you get an order in fourth quarter absent a settlement. So just what's your reaction to staff's starting point here, and what are your thoughts on being able to settle the gas case? I'd go back, Nick, to the fundamentals of that case, aiming for a safe natural gas system, continuing to reduce methane across that, and deliver affordable natural gas to our customers. And so again, the imbalance, that equation of making the investments in the natural gas system, also just like we're doing the electric business, aiming for an improved affordability across the gas system through unit costs, through cost out using the CE Way and the like. So those fundamentals are true. Staff position, I would categorize as constructive, a constructive starting point. And so we'll look. Once we have that position, we're going to look for the opportunity for settlement. We've been able to work with a number of the intervenors in the past and have a good track record there. But also hear this: I'm confident in the testimony and the merits of the case. If we need to go to the full distance, we will and get a constructive outcome both for our customers and stakeholders. All right. Thanks so much. Have a great day. You too, Nick. Our next question comes from Jeremy Tonet from J.P. Morgan. Your line is now open. Please go ahead. Hi, good morning. Good morning, Jeremy. Thanks. I just want to dive in, I guess, to the sales outlook. Came in a bit better than expected, I guess, for the first quarter and for the balance of the year. Looks like that's trending better than expected. Just wondering, by customer class, if you could dive in a bit more on the drivers that you're seeing within each class that is leading to this uptick. Yeah, Jeremy, this is Rejji. Appreciate the question. So yeah, we were pleased with the first quarter performance of non-weather sales. We provide good color on that in our Earnings Digest, which you probably saw. But going through the customer classes, we saw a residential up just under 1.5% versus Q1 of 2023. So on the surface, that looks quite good. But it's important to note that the leap day in the quarter, because it's a leap year, drove about two-thirds of that. But still, even absent the leap day, as I mentioned in my prepared remarks, still up about 0.5%. I still think we continue to see continued upside of the return to work or return to facilities trend, where I think we had pretty conservative assumptions about return to facilities. We are seeing a stickiness to folks having or corporations retaining what I would describe as a hybrid workforce. And so that is still, I think, delivering some surprise to the upside. And it is a higher margin customer class, as you know. On the commercial side, really quite pleased with what we've seen. And so the number was just under 3.5% increase versus Q1 of 2023. And the leap year only affected about a third of that. So pro forma for the leap year, we were still just under 2.5%. So very pleased with that. And our speculation, we've seen some of the subsectors within commercial that have performed pretty well: agriculture, mining, up about 6.5%. We also saw entertainment up about 3%. And so we've seen some of the subsectors perform pretty well. But we also think, because folks are actually going to the office at least three days a week, that does create foot traffic in communities, and folks are going to cafés and things of that nature. So that's also part of it as well. But that's a bit more speculative. But that's our sense. And then within industrial, if you exclude one low-margin large customer, we're at just over sorry, just slightly up, let's say, about 20-25 basis points. And the leap year did have a big impact on that class. And so pro forma for the leap year, you're down about 1%. I will always caveat two things whenever we talk about weather normalized sales. One, remember, those numbers include the fact that we're reducing our load by 2% each year in electric due to energy efficiency. So all these numbers should be, on a gross basis, up 2%. And so you should provide that color to these industrial numbers. The other thing I always caveat is that weather normalization math, as good as our team is, as hard as they work to get it right, is a very imperfect science. And so it is very difficult to get these numbers exactly right. But what I would say in terms of industrial, that we feel very good, as Garrick noted in his prepared remarks, about the economic outlook and just have a robust pipeline and a very diversified pipeline of industrial opportunities, which really aren't reflected in our numbers at this point and won't be until the outer years of our plan. And we'll be disappointed if that opportunity doesn't continue to bear fruit for the next several years. That's the color I can offer across each customer class, but certainly happy to take any follow-ups as needed. That's very helpful. Thank you for that. Maybe just pivoting a bit here, it seems on the slides as they lay out, there's a bit of cushion to hitting the guidance 2024. So just wondering, I guess, how you feel confidence level guidance 2024 at this point. Does it put you in a position to start thinking about 2025? Just want to get a sense for how that stands. Yeah. Well, I would say, Jeremy, early days. Obviously, we're delighted that 2024 is not 2023 in that we don't have a big storm as well as mild weather to start off the year, which we obviously saw last year. But to be clear, we still saw negative variance in terms of weather, top-line-related weather. And so there's still some work to do. And so we are countermeasuring and, again, very confident in the outlook. But it's a little early before we start thinking about de-risking 2025 and beyond. Got it. Fair enough. I'll leave it there. Thank you. Thank you. Our next question comes from David Arcaro from Morgan Stanley. Your line is now open. Please go ahead. Oh, great. Good morning. Thanks so much. Good morning, David. I was wondering what you're seeing in terms of maybe data center demand in the pipeline, any uptick in further requests to connect beyond the big kind of megawatt addition that you called out, and wondering if that customer class, I guess, would potentially be involved in the voluntary renewables plan, any upside potential there. Thanks for your question, David. A couple of things on this. I typically don't like to talk about the pipeline just because it's pretty speculative on that. And many of these data center companies are testing the waters in a variety of different utilities. And so we typically talk in terms of contracts. And when we talk about economic development, whether it's manufacturing or data centers, it's secure contracts, which we, again, feel really good about. Let me reflect a little bit on this project, and then I'll talk I will highlight the pipeline. I will get to your answer. This particular project, this data center expansion that we mentioned in the prepared remarks, is 230 MW, online by 2025, majority of the load in place by 2026. And so that does speak to our ability and capabilities to be able to deliver for these customers. Then you see Michigan. And I said this in some of my remarks: temperate climate, which is great for the heating and cooling load of a data center, a lot of fresh water, and then energy-ready sites, attractive energy rates, good fiber network. All that comes together to make Michigan really attractive. I will say, within the state of Michigan, there is a sales and use tax that exists. There's roughly a dozen states that have this sales and use tax in place, about 6%. There are bills that are being considered in the House and Senate. It's passed the House in a bipartisan way. It's moved over to the Senate for consideration. We think that's going to move forward, that exemption, probably in the June, July timeframe at the end of this session before they go on summer break. That will open up Michigan a bit more for that pipeline. There are companies that are exploring Michigan right now, large data center providers, names that you would recognize. But again, a little bit they're testing the water in a lot of different locations. And so we'll see how Michigan progresses. We're certainly an attractive place to do business, and we'll look to attract that load growth appropriately. But as I stated in my previous remarks, we want to make sure there's a good balance that they're picking up the cost associated with that load as well, both from an energy and capacity perspective. So that's all the things we're working to balance, David. Hopefully, that provides some light to your question. Let me know if I didn't strike the right balance there. It does. That's helpful, yeah. And are you thinking there could be upside to your long-term load growth expectations, or is it still early? We have between the manufacturing load that's contracted and the data center load that's contracted. As Rejji said, it's a nice piece of low growth that we factored in not only the later years, this five-year plan, but future five-year plans. We're excited about what that means. There's a strong pipeline, both from a manufacturing perspective and, to a degree, the data center perspective as well. I'd be disappointed if some of those projects in the pipeline didn't materialize. Okay. Great. Thanks. That's helpful. Kind of separate topic, I was wondering your latest expectations for the performance-based rates process in terms of timing and where that outcome might be headed? That's progressed in a constructive way. We had close to 10 or 12 metrics that were originally proposed. It's narrowed to 4 metrics that are benchmarkable, and there's good standards. And so again, that constructive process plays out. There's more work to do from our perspective, and we filed comments in the February, March timeframe. We're expecting a report from the Michigan Public Service Commission staff in May. And so we'll see the next round of thinking. I would suggest it's a couple electric rate cases away, not this case, perhaps the next case before we see implementation. But again, this is an evolving process with the Public Service Commission. Okay. Great. Thanks for all the color. Yeah. Thank you, David. Our next question today comes from Michael Sullivan from Wolfe. Your line is now open. Please proceed. Hey. Good morning. Hey. Good morning, Michael. Hey, Garrick. Yeah, just sticking with the data center conversation, it sounds like you're kind of optimistic on this legislation. And if that does pass and start to bring more interest to the state, what do you think about the potential for DIG being used in its entirety as a behind-the-meter solution for a larger-type data center buildout? I know there's been a lot of focus on that on the nuclear side of things elsewhere, but people talking about gas as well. So just curious your thoughts there. Similar to Rejji's comments, from an energy perspective, energy tolls, and the capacity of the bilateral contracts, much of DIG has been spoken for at a really attractive position that either meets our expectations or is above our expectations. And so there's really, unless you're beyond 2028, maybe even the 2030s decade, DIG is really not available because it's already been secured and with, again, attractive energy tolls and bilateral contracts for capacity. Okay. Fair enough. Makes sense. Then just on your upcoming electric case filing here, just to set expectations, I know one of your peers in the state recently filed and got a pretty quick response from the AG. Are you anticipating something similar with yours? Should we just be prepped for that? It is. We got primaries in August, and that means early absentee ballots start in June. And so it's political season already in Michigan. And so I would anticipate that. Look, the Attorney General participates in all our cases. That's been a historical practice. Sometimes those are more public than other times. We stand, as I shared earlier, by the merits of the case, both in our gas case that's underway right now and this electric rate case. The team just went through a walkthrough this week, and I couldn't be more proud of the work the team's putting together on it. As I shared earlier in my questions or responses to questions, we're focused on reliability. That's going to improve for our customers. That is absolutely the right thing to do, well aligned with the Public Service Commission. We're working hard to create affordability, and we're good at that through the CE Way, through reducing power supply costs, through unit costs, from execution to capital. When you get that mix right, that equation right, it makes it you get good outcomes. So I'm excited about this case. It's certainly going to be a step up in capital. There's going to be some O&M work too that's focused on reliability. But there's also some offsets that are really exciting that make us get me excited, as you can tell by the tone of my voice, about what we're filing and what we're putting together because it's going to be good for customers, and it's going to be good for all stakeholders. All right. Yeah. You sound pretty pumped. Sounds good. Thank you. Our final question comes from Andrew Weisel from Scotiabank. Your line is now open. Please go ahead. Hey. Good morning, everybody. Hey. Good morning, Andrew. How are you today? Just a couple of follow-ups on the rate case here. Good, thanks. Just a couple of follow-ups on the rates. So first, I think you just alluded to this for the electric side. You're going to have more capital and more O&M. Just from a headline perspective, should we expect a larger revenue increase request than what we've seen in past filings in terms of percent increase to customer bills? Yes. The short answer is yes. But again, important work from a capital investment perspective on reliability, and we've done a lot to offset some of the O&M cost components of this to strike that right balance. And that's what I mean by the important fundamentals or merits of the case. Okay. Very good. And then procedurally on the gas side, I know this case is unique in that there's no ALJ. Does that change the timeline at all or the potential for settlement? You talked a bit about settlement, but the lack of ALJ, does that factor in at all? No. The team's excited about the opportunity to get to the table now that we have staff's position, now that we know where intervenors are at to talk settlement. As I shared, we've been able to navigate that with success in the past with all intervenors, all stakeholders. We'll look to do that. I also hear my confidence in the merits of the case that if we need to go the full distance, we will. I know that will get a good outcome for our customers and for stakeholders. All right. Sounds good. Appreciate all the updates today. Yeah. Thank you, Andrew. That concludes the Q&A portion of today's call. I'll now hand back over to Garrick. Thanks, Drew. I'd like to thank you for joining us today. I look forward to seeing you on the road soon. Take care and stay safe. That concludes today's call. Thank you for your.