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Rejji Hayes

Thank you, Garrick, and good morning, everyone. On Slide 8, you'll see our standard waterfall chart, which illustrates the drivers impacting our financial performance for the quarter and our expectations. For clarification purposes, all of the variance analysis herein are in comparison to 2024, both on a first quarter and nine months to-go basis.
In summary, through the first quarter of 2025, we delivered adjusted net income of $304 million or $1.02 per share, which compares favorably to the comparable period into [4], largely due to the absence of the mild weather experienced in Q1 of 2024, coupled with higher rate net of investments. These sources of positive variance were partially offset by higher O&M costs at the utility driven by the continued execution of our electric reliability road map and the time of select items at NorthStar, like our planned outage at the industrial generation facility or DIG, among other factors.
To elaborate on the impact of weather, we experienced a relatively normal winter in Michigan in the first quarter for the first time in a couple of years. As such, we saw $0.26 per share of favorable variance, which largely reflects the mild weather experienced in the first quarter of 2024. Rate relief net of investment-related expenses resulted in $0.07 per share a positive variance due to constructive outcomes achieved in last year's electric and gas rate orders in addition to the benefits of ongoing renewable projects.
Moving on to cost trends. As noted, in accordance with our electric reliability road map, we continue to increase the size of our vegetation management program as we glide path to a 7-year trim cycle across our low-voltage electric distribution system. The associated financial impact was the key driver of the $0.05 per share of negative variance versus the comparable period in 2024. In our touch all category by the final bucket in the actual section of the chart, you'll note a negative variance of $0.23 per share, largely driven by a strong 2024 comp at NorthStar due to normalized operations at DIG and the timing of tax benefits from renewable projects.
Other notable drivers category include the impact of parent financing activities in the quarter and select onetime reversals from last year. Looking ahead, we plan for normal weather, as always, which equates to $0.12 per share of positive variance for the remaining nine months of the year, primarily due to the absence of the mild temperatures experienced in the fourth quarter of 2024.
From a regulatory perspective, we're assuming $0.16 per share of positive variance, which is largely driven by the constructive electric rate order received from the commission in March, ongoing benefits of renewable projects at the utility and the assumption of a supportive outcome in our pending gas rate case.
On the cost side, we anticipate higher overall O&M expense at the utility for the remainder of the year, largely driven by the expectation of increased service restoration costs attributable to the large weather system that impacted our service territory in late March, extending into early April that Garrick mentioned. It's worth noting that this storm was the costliest in our company's history at roughly $100 million of operating and maintenance or O&M expense, for our preliminary estimates.
As you would expect, we're already busy at work identifying and implementing countermeasures such as limiting hiring, reducing our use of consultants and contractors and eliminating other discretionary spending among other potential assets. And of course, we expect increased productivity from the CE Way, which our workforce has delivered every year since we instituted the Lean operating system roughly a decade ago.
It is also worth noting that we have sought a deferred accounting order for the financial impacts of the storm given its historic nature, which we filed earlier this week. The recalibration of our service restoration expense for the remainder of the year, net of anticipated savings from the aforementioned countermeasures will drive an estimated net impact of $0.04 per share of negative variance for the remaining nine months of the year.
Lastly, in the ultimate bar on the right-hand side, you'll see an estimated range of $0.03 to $0.09 per share of negative variance which incorporates further risk mitigation to the financial headwinds encountered in the first quarter and provides additional contingency should we need it, namely in the form of opportunistic financing activities.
Before moving on, I'll just note that our track record of delivering on our financial objectives over the last two decades, irrespective of the circumstances speaks for itself. That said, we'll always do the waring so you don't have to. And we remain confident in our ability to deliver our financial and operational objectives this year to the benefit of all stakeholders.
Moving on to credit quality. It is worth noting that Fitch reaffirmed our credit ratings in March as noted at the bottom of the table on Slide 9, and we are currently working through the review process with Moody's. Longer term, we continue to target solid investment-grade credit ratings and will manage our key credit metrics accordingly as we balance the needs of the business.
Slide 10 offers an update to our funding needs in 2025 with the utility and the parent. During the quarter, we issued $1 billion of junior subordinated notes for hybrids with a 6.5% coupon its parent, which I'll note was identical to rates achieved by some of our much larger peers and had the tightest credit spread achieved for a hybrid and reset which speaks to our credit quality and a strong receptivity to our paper in the market. As you'll note in the table on the left-hand side of the page, the hybrid issuance address a good portion of our financing needs at the path for the year while offering significant financial flexibility on our remaining needs.
We'll look to complete the balance of our financing plan at the parent and utility over the remaining months of the year with a keen focus on maintaining our consolidated credit metrics around the mid-teens area from a funds from operations to total debt perspective. As always, we'll remain opportunistic and look to capitalize on market conditions.
And with that, I'll hand it back to Garrick for his final remarks before the Q&A session.

Garrick Rochow

Thanks, Rejji. As the landscape continues to evolve, I want to remind everyone about our long history of delivering under all scenarios for all our stakeholders. Remember, our business is preparedness and response through uncertainty, recession, bad weather doesn't matter. We've seen it before, and we've navigated the waters. Bottom line, we deliver.
Our track record speaks for itself. We focus on what is necessary to deliver for our customers and investors, and we remain confident in our outlook for 2025 and beyond.
With that, Harry, please open the lines for Q&A.

Question and Answer Session

Operator

(Operator Instructions) Durgesh Chopra, Evercore ISI.

Durgesh Chopra

I appreciate all the commentary around tariffs and IRA. I just -- one question was focusing on NorthStar. Maybe just -- can you remind us what percentage of capital? I appreciate it's small or of capital is going towards solar, storage. And then just given the IOA discussion and repeal risk, do you kind of reprioritize that capital, potentially maybe switch that with higher regulated capital?
Your comments around safe harboring, do those apply to NorthStar as well as you try to kind of secure those tax resets into the future?

Garrick Rochow

Thanks for your question, Durgesh. Great question. Again, contacts is really important here in the context of NorthStar. So we're talking about 5% of the EPS mix here. So remember, the big driver here is DIG, our Dearborn Industrial generation.
That's the big story in the energy and capacity markets. And so when it comes down to the amount of capital that we're spending on renewables, it's small. Rejji will have the numbers here in a bit, but there's nothing on storage, 0 on storage. And so it's all really renewables and those are, again, projects that are well laid out for the future.
Now how we derisk those projects? One, we have contracts in place that allow for escalators, that's an important piece. But we've done a lot of great work in terms of securing -- I've got panel security through 2030. There are a variety of vendors through contracts, some are already on site, able to navigate any implications from a tariff perspective. And then I'm out in 2028 from a safe harbor provision and the main power transformers.
And so we feel good about the runway there of projects, renewable projects that we've done to derisk that. But as you know, on your question alluded to, there's tons of flexibility. We have plenty of opportunities to utility itself. And so those are decisions we make on a time by a year-by-year basis on where the needs are for the company and are best suited. But again, feel good about NorthStar's ability to deliver, not just in the year, but also from a long-term perspective.

Rejji Hayes

Yes, Durgesh, I'll just build on Garrick's comments there. We certainly feel good about NorthStar's prospects going forward and have done a lot to derisk renewable projects on both the utility side and the NorthStar side and have done some things in supply chain that further fortify our position going forward. From a capital perspective, we're planning, and this is that we filed last quarter. About gross investments a little over $2.5 billion. I say gross because we have planned to res capital largely a NorthStar through the sell-down of common equity as providing a lot of liquidity to fund their projects.
And so the equity infusions from the parent are relate light probably about 20% of that or so or $0.5 billion. So gross capital investments of about $2.5 billion to support commercial renewable projects over the next five years. And the reality is if we do see some repeal of the IRA, we will just increase the bar or raise the expected hurdle rate for those renewable project NorthStar. And so if we saw the economics of those projects being less attractive, we would certainly allocate more capital to utility. As you know, capital is not an issue at the utility.
There's plenty of opportunity. Our current 5-year plan at $20 billion of capital investments at utility has another $20 billion or so on the outside looking in. And I think that, that's the low end. Capital investment opportunities outside of the plan. So a lot of flexibility to allocate capital to the utility versus NorthStar, again, if we see the economics of those projects start to soften over time.
So really good flexibility going forward and no concerns with the outlook there. Is that helpful?

Durgesh Chopra

Very helpful. A lot of flexibility there sounds like. And then just quickly, Rejji, the deferred accounting order on the storm cost, have you guys done that before? Sorry, I should know, but I don't. Maybe just remind us if you have done that before?
And if not, like what are sort of the procedural steps here? Is there a time line that the commission is kind of sort of rule this on by? Or is this just a one-off type of went and there's no set procedural schedule here?

Garrick Rochow

And maybe I'll just take your question and do a little bit of your picture on it, and then we can go down in this process from a storm perspective. As Rejji talked about in his prepared remarks, there is a number of levers and opportunities, everything from the CE Way to technology to what Rejji shared in his prepared remarks and on how to deliver the year.
And for both the customers and really investors and really all stakeholders, that's the tools in the dual box. And what we're doing with this particular storm this, what I would say, is a historic storm and really extreme weather, as I characterized in my remarks, leveraging the Liberty audit. If you go in the Liberty audit, that's the distribution on it, it specifically calls out best practices with jurisdictions and utilities is to have a mechanism for extreme weather.
And that's the -- and that will be the first time we filed that with the commission in this kind of framework. We've had constructive conversations both with staff and the commissioners. And so again, it's an ex part day filing, the time line has not been established at this point. But -- gas I'm going to go off a little of little off the record here. Like I'm going to hold for on a farm.
And so I don't count my chickens before they hatch. And so -- and that's a true thing from a farmer perspective. But understand this, like we're not counting on that. It's important. We think it's needed in Michigan.
Again, constructive conversations, but we have a lot of it to be able to deliver the year.

Rejji Hayes

Durgesh, all I would add, and I wish I had -- I wish I had a farming an analogy as well, but I do not just a couple of things to Garrick's good comments. And so you asked, I think specifically about the timing of approval because it's filing I think that will be at the commission's discretion. Obviously, we're -- our expectations are tempered, but we would love to see just a fairly quick resolution to the matter. So we just at least know what the outcome is in a timely fashion. And in terms of our history around this, we have sought mechanisms in the context of rate cases.
I can't recall the last time we saw an accounting order like this outside of a rate case, maybe once in the past in my eight years fairly atypical. But we think given the historically it's justified, and I believe we've made a strong case in the filing as to why we should get support here. So I just wanted to address those two direct questions,

Operator

Shar Pourreza, Guggenheim Partners.

Shar Pourreza

How are you thinking about the execution of the financing plan, just given that optical of equity needs is resolved through the hybrid? Is that -- is there kind of more execution to come in '25? Or is there an efficient financing that unlocks like a CapEx pull forward or any other opportunity in the near term?

Rejji Hayes

Constantine, this is Rejji. I appreciate the question. Yes, per my prepared remarks, we still have a bit of left in the plan for the year. And so at the parent, just going back to our original guidance, we said we had about $1.8 billion to do. So $1.3 billion of what I'll just say nonequity financing and our working assumption with senior debt assumption -- senior debt financings and then up to $500 million of equity.
Obviously, the hybrid transaction that you noted, really took care of a good portion of those needs. And so with the equity credit ascribed to hybrids, that creates a lot of financial flexibility. And so -- we still have about $700 million or so left for the remainder of the year. We're keeping all options on the table. We've seen really attractive execution across a variety of securities offered in the first quarter from some of our peers.
And so we're keeping all options on the table, but I have quite a bit of flexibility. And at the opco just to round it out, we've got $1.1 billion left. And I think the working assumption for those financings will be first mortgage bonds. And so -- as always, we'll look at which securities are most attractively at both the parent and the opco, and we'll be opportunistic as we always affect the pull-aheads for capital. We've got $3.7 billion in the utility per our plan this year.
And so we're focused on executing on that. And so we'll see rest of the year has in store So we're acutely focused on the current plan for this year and really haven't thought about pull-aheads in any respect, if that was the spirit of the second part of your question.

Shar Pourreza

Yes. Understood. Understood. And maybe a higher-level question on -- in terms of your energy supply needs. How are those evolving, especially as you get feedback to the R&D process?
Is there more dispatch generation needs that you see kind of going into the next IRP cycle? And do you think that there's a better case for kind of like a big buy-in into the opco?

Garrick Rochow

A portion of our energy supply needs are spelled out in the renewable energy plan, and that addresses some of the energy needs and the compliance with the '23 energy law. And so as we've seeing the need to get to the 50% and 60% renewable targets as well as because of the 3% low growth that is in our 5-year -- you can see and have insight into those both renewable needs as well as storage needs in the future.
The broader need for capacity and to continue to deliver to the low growth in the pipeline within the state will come together in the integrated resource plan, we'll file that in 2026. It will evaluate and look at natural gas plants, the existing natural gas plants we have in the state, the longevity of those plants, considerations for carbon capture and sequestration technology. And so that modeling work still underway, as you might imagine, for a 2026 filing and will be also based on the renewable energy. As you're growing the state and you have this pipeline, there will be additional needs in the future for supply assets.

Shar Pourreza

Okay. Understood. Got just a question around storms again. As you're kind of noting the impact of the offsets in the quarter, do you anticipate those to be recurring? Or would those potentially unwind with that potential deferral filing?

Rejji Hayes

Yes. So I would say, Constantine, similar to prior years when we saw a significant financial headwinds. We'll look at all opportunities that cost the cost structure. I'd say it's premature to think about what's recurring and what isn't. But what I have been encouraged to see really for my prepared remarks over the last 10 years is every year, we establish a target for how much productivity and cost savings, whether that's hard cost savings or avoided costs associated with the CE Way.
And every year, we exceed that target pretty significantly. And by definition, the savings generated by the CE Way are our recurring savings. And so I'll give you an example, last year, we had a target for the CE Way of around $50 or so million. We delivered $110 million of savings, and those are obviously recurring. And so I would say we've exceeded expectations year-end -- on what we expect to achieve from a private perspective.
But we'll also look at one-timers. I mentioned, we'll look at sort of financing activity, so we may start to take a look at liability management as we had in the past, and we'll also look at other potential cost deferrals, which would not be recurring of all of the above, like we've done in prior years.

Garrick Rochow

Let me just take a moment to just elaborate on this toolbox of opportunities, and Rejji characterized it well. It starts with conservative planning, right? That is part of our mindset, that's part of our approach. We're not redlining the engineer. This is just how we think about different scenarios.
That's like point one. Rejji emphasized the CE Way. There's so much opportunity in the CE Way that our coworkers deliver on. And you take and improve a process, you take waste out, who workers feel better, customers feel better and you cost file.
The other one that we've been really highlighting, too, is in the space of technology. The IT team calls it app realization, and I make fun of them when they talk about it because I like what the hell is that? But -- and the reality is it looking about all our software, all our hardware and how are we leveraging to get additional benefit out of it, where there's real savings there as well. And then you apply AI in some places, and we get better predictions and that takes cost out as well. And then there was all the things that Rejji mentioned in his prepared remarks.
And so again, I feel confident in just the ability to leverage these and a portion of them, a good portion will be sustaining. And as Rejji indicated, some will be onetime.

Operator

Jeremy Tonet, JPMorgan.

Jeremy Tonet

I just want to pick out with the gas case -- just wanted to pick up with the gas case. And given what's come out so far, the appetite for settlement or just -- any other thoughts at this point? I know you said you'd be happy going either way, but just wondered any incremental color you could provide?

Garrick Rochow

I'm going to even pull it back a little bit. And just with these words, I am very pleased with our track record of delivering constructive outcomes in Michigan. There's all kinds of data points, four gas settlements doesn't matter, electric or gas. We just need to deliver time and time again. And in the Q4 call, what I shared was throated constructive, we'd see a constructive electric.
And how did I know that? One, is the quality and the visibility we put in this case, the constructive legislation we have. And it's not perfect, as I shared, but we continue to work on improving that. And then if you look at the staff, the MPSC staff are professionals. When you have a good staff position or a constructive SaaS position, you get good outcomes.
And that's what we did. And that's another data point with this electric rate case. And I'm excited about this gas case as well. It is down the fairway or straightforward. We're replacing gas pipe.
We're making the system safer, like that's important from a gas business perspective. We're ensuring capacity to deliver to customers and growth in the gas business. And when you do all that right, you also reduce carbon emissions. It's a trifecta, right? It's a great face the team has built straightforward.
And so I'm excited about SaaS's position. It is a complete starting position within the gas case. And we go through the process, we'll go through rebundle as we always do. ROEs, we're going to push on those. This is like if I look at the external environment.
Risk has not declined, right? And so we'll push on the ROEs and rebuttal. That will be an important piece for us to lean into. But as I said always, I'm open to settlement. There's a variety of different points of view and different intervenors on that.
We'll work through that process. If we see that, I would imagine it would be before the that's expected in August time frame. But here my confidence in our ability to go the full distance to and just continue the track record of constructive outcomes in Michigan.

Jeremy Tonet

Got it. No, that makes sense. I just want to pivot to a smaller point, if I could, deferral -- that's baked into the guide right now. I just want to be clear on the treatment there.

Rejji Hayes

Jeremy, this is Rejji. We have not presupposed approval of the deferred accounting order. Like I said, I think we made a very compelling case given the historic nature of the storm and our efforts to restore customers as quickly as possible, both inside our service territory now. And so we think we've made a compelling case. But as you know, given our conservative nature, we have not presupposed approval of that.

Jeremy Tonet

Okay. Got it. That's very helpful. And just a last one, if I could. As it relates to ITC's unregulated part of the business, what's the magnitude of earnings exposure in your plan here?
And really, if you could outline a bit more how tax equity impacts this? And any other relevant considerations and how potential tariff risk at the project level could influence growth here? I know you touched on it a bit before, but I just wonder if you can flesh out those points a bit.

Rejji Hayes

Yes, Jeremy, I'll take this as well. This is Rejji. So I would say in the context of 2025 guidance, in our original guidance, we guided [$1 to $0.22] given the planned large -- which historically really going forward is the flag shippings contributor to NorthStar. We are anticipating more contribution from commercial renewables projects, and we have two solar projects that are well on their way of delivering constructive outcomes later this year.
And so I would say the exposure from a renewable this year is a little bigger than other years. And so of that $0.18 to $0.22. I assume about three-fourth of that is delivered by residual benefits from ongoing asset a little bit of NorthStar but primarily from two solar projects we have underway. As we look at the outer years of the plan, still an issue of solid renewable development over the course of the plan. But again, you should always assume that DIG will be the primary contributor of earnings to NorthStar over the course of the next five years.
Let me pause there to see if there are any questions on that.

Jeremy Tonet

No, that's helpful. I'll leave it there.

Operator

The next question today will be from the line of Nicholas Campanella with Barclays. Apologies, we're not receiving audio from Nicholas' line there. So we're moving on to the next question being from the line of Julien Smith with Jefferies.

Julien Dumoulin-Smith

I hope I get a candid response from Garrick as earlier here. Just with -- I think we're developing a new pattern. Just on economic development, I'd just love to understand how you guys are thinking about them. I heard the comments on the call with respect to data center activity and ongoing development year-to-date subsequent to the legislation. But in parallel, I also note the Goshen developments from the county board here, how are you thinking about what's included in the 900 megawatts of demand in the current plan?
Are there puts in that? Or is it still kind of static pending some more formal updates here? Just to understand how you think about both the positives and the negative that are accumulated year-to-date.

Garrick Rochow

Yes. And so that 2% to 3% that makes up that 900 megawatts, that's a conservative approach, and you know that about how we plan. And so there is an economic development is that even in the best of times, there's some slowdowns in some projects and some speed up in some projects. What's great about that 2% to 3% is we have like line of sight into that work. We're constructing the substation.
In many cases, we can see them building their facilities in the long term and they have for that. And so that's exciting. That gives us confidence in that 2% to 3% low growth. And there's always little puts and takes. And as we -- as I shared, one of the data centers that we're constructing right now is actually accelerating their low growth and their ramp up, which is a positive and the same with the large manufacturing.
And so to the degree there's a pause with Goshen, there's also some acceleration with some as well. And so that's all kind of in that mix to -- now if we go to the 9 gigawatts, as I shared in my prepared remarks, but let me offer a little more clarity, there's a lineup of data centers there of 65%. Some of them are moving faster and jumping the line and moving to the front of the line in the progress. And so that gives us a lot of confidence that those will materialize. But the next logical step in that process is get this tariff complete with the commission.
Again, I'm optimistic that settlement is an option there to be able to move those forward and for those data centers to take the next logical step. Does that help?

Julien Dumoulin-Smith

Yes. No, absolutely. Actually, just to clarify that last piece since you bring it up, just with the tariff you alluded to potential settlement, certainly a possibility in other states as well. Could that be paired up with a more formal commercial arrangement? Is that because you get the clarity on the tariff, would that be sort of the catalyst to announce any larger commitments here?

Garrick Rochow

Certainly, the data center projects and possibilities, I want to have clarity on that in the context of that. It's just from a special arrangement perspective, special contracts, we don't do those. That creates a lot of long-term risk for the company and for shareholders. And so this tariff, it really is the best option. And as you might imagine, when they have clarity on what that looks like, that will be the next logical step in moving some of those projects forward.

Operator

Michael Sullivan, Wolfe Research.

Michael Sullivan

Just wanted to ask quick on how you're thinking about the risk of transferability potentially going away. I think you've given us some numbers on what you embed there in your plan, but just what that scenario would look like if you were to lose the ability to transfer tax credits?

Garrick Rochow

Let me offer some high-level comments, and Rejji will get into some specific numbers. Again, many of the Republican jurisdictions areas have benefited from the IRA. But what I think is even more important is the conversation that I'm having part of the team's having, EI's having with a number of Republican congressmen in women. And that is support for these PTCs and ITCs as well as the tax monetization or transferability component of it. Because you see in these times, the importance of affordability and how that transfers directly to savings for our customers.
And that's been an important part of the conversation. So that's what gives us -- we'll see how legislation takes place and how it all evolves, but that gives us some certainty, I guess, optimism about the ability to maintain PTCs and ITCs in this transferability going forward. But Rejji to offer some additional comments on the dollars.

Rejji Hayes

Yes. So Michael, I appreciate the question and just to talk about potential offsets or countermeasures in the -- as I still see it in the unlikely event, we saw transferability go away. We would look at a variety of financing sources. And I think the good news in this environment and in prior environment is that the capital markets remain broad and deep. And so we would certainly look at more genius subordinated notes as a potential option.
Clearly, there's quite a bit of capacity in the market there. And based on our even recent issuance of $1 billion that I noted in my prepared remarks, we still have in this year alone with $3 billion of additional junior subordinated capacity, and that amount of capacity accretes over time as your book capitation grows through retained earnings. And so a lot of opportunities to potentially look at more junior subordinated notes. Obviously, we could look at doing additional equity as well. We feel very comfortable with the equity levels that we're issuing over the plan and still think we have capacity to do additional equity to fund this attractive growth opportunity we have at the utility.
And so incremental equity would also be a potential offset. And it's also important to note just the significant flexibility afforded to us through the energy law and the ability to earn on PPAs as we look to comply with the energy law and the significant renewable opportunities associated there with that creates a lot of balance sheet flexibility as well. And so as we look at subsequent 5-year plans, we may transfer or shift -- transfer is probably not the right word there, upon not intended. But we could look to potentially shift our spend mix from instead of investing and owning some of those renewable opportunities, we could potentially contract and own about a 9% FCM on those, which obviously, again, creates a lot of balance sheet capacity. And so those are all potential countermeasures in the event transferability went away.

Michael Sullivan

Helpful. And just to double check the $700 million number from the year-end call in terms of what's in the plan is still good?

Rejji Hayes

That's still the current plan, yes.

Operator

David Arcaro, Morgan Stanley.

David Arcaro

This is Alexman for Dave. So starting with the farm tracker, could you talk about the strategy going forward to get it approved? Is there any specific changes you want make to address the pushbacks?

Garrick Rochow

In reference, just for clarity for who might be listening on the call, in a number of the previous electric rate cases we proposed -- a storm tracker or storm recovery mechanism in those we've heated some of the comments from both staff as well as commissioners on sharing and sharing of that or those mechanisms. Unfortunately, we have not had success in that mechanism. But we continue to look at options to be able to offset some of the costs. Again, I'd go back to the Liberty audit, which, again, recommends best practices for jurisdictions and utilities and ultimately for the customer is to have a mechanism in place for extreme weather. The storm recovery mechanism, or tracker is one way to go about it.
Another way that we're obviously filing for here in filed for this week is just through this deferred accounting mechanism for, again, regulatory treatment of historic or extreme weather.

David Arcaro

Got it. And back to the data center demand in Michigan, did you see a big change in interest after the state approved the tax exemptions late last year?

Garrick Rochow

That is correct. Of our pipeline, it was primarily about 65% manufacturing prior to the signing of the sales and use tax and that flipped the actual pipeline grew to 9 gigawatts. And a majority of it, specifically about 65% of it is data centers as a result. And so we attribute to that to, in part, due to the sales and use tax exemption. But also, there are other RTOs that are -- have had some challenges.
And so MISO continues to be an RTO and frankly, we have a nice energy law that supports the ability to put on the supply needed and necessary for these important projects.

Operator

Travis Miller, Morningstar.

Travis Miller

On the electric rate case, I wonder if there were any lessons learned or aside from the headline numbers, anything in the case decision that you'd like to go back for or you hoped to get anything like that? You mentioned the storm tracker, but anything aside from that?

Garrick Rochow

There's always room for improvement in our cases. I want to be real clear. We've had a successful track record, but we're not perfect. There are a lot of opportunities for us to improve. We get the feedback from the from the staff.
We get the feedback from the commissioners and there's important work to do. One of the important pieces that -- or comments that was made by the commissioners, when they provide the order was the mix of capital and O&M. And recall that in that case, the Liberty auditor, the distribution audit kind of came midway through. And so we had a capital in there and the recommendations on tree trimming and vegetation management were not in there. And so you can imagine that in this next case that we'll have a greater degree and a greater amount of vegetation management, and we'll also match that with the important capital investments because it's both.
You have to deliver the reliability and long-term resiliency. And so I would expect to see filing our reliability road map, more capital investments. But also a much larger investment too in vegetation management to improve our reliability for our customers. And so that's an area of improvement. There was also from the bench, a small thing is following where the dollars went.
We got more granular in some of our bucketing so we could see the benefits of that work. And there were some feedback that you couldn't tick and tie as easily. So we're going to improve that as well and just make a key -- I'm in the weeds now, but it's just a key to be able to make that clear for intervenors as well as the staff and commissioners to file. So those are ways we're always looking to improve the process.

Rejji Hayes

Yes, Travis, I would add, this is Rejji. Aside from 10.25% ROE, which is on my personal wish list. The other subtlety or a smaller element of the filing that we did seek and unfortunately, didn't get support for. But over time, I do think it would be helpful as we did propose a wildfire risk mitigation plan. And though Michigan is not as susceptible to a lot of states to the -- to the west of us to wildfire.
We do think you cannot plan soon enough for wildfire risk mitigation. So we had $12 million of capital ascribed to it, $4 million of which was for strategic undergrounding. Covered conductors was another bit of a spend. And then what I would call strategic vegetation management. And so we do think over time, we'd like to start to put in place a program because, again, I don't think you can plan too soon for that.
And so that was the other item on the wish list that we'd like to get support for going forward.

Travis Miller

Okay. That's great. I think we all have 10.25% on the wish list. So the REP, when you get that September ruling, what's kind of the next step? Would there be any immediate, I guess, disclosures or changes potentially in the capital plan?
Or is that something that's going to evolve as you do perhaps RFPs or some other type of solicitations along the way? Anything that's going to happen in September or October after the decision?

Garrick Rochow

Well, it gives -- certainly gives us more clarity on the clean energy and the a portion of the investments that are in the 5-year plan, there could be additional investments in that. And that again flows into the integrated resource plan. And so you'll see that, that approval is important to build out the integrated resource plan. And so those are the couple of components that you will see. And of course, we'll have greater clarity and certainty around what those renewable energy supply assets are.

Operator

Gregg Orrill, UBS.

Gregg Orrill

Just the -- I wasn't quite sure I understood what the $0.04 impact in the balance of the year related to the storm accounting order was? Sorry if I missed that.

Rejji Hayes

Yes. I'm not sure, Gregg, this is Rejji, where you got the $0.04 impact. But just to walk through the details of the estimated -- and I say estimate because we're still doing all of the closing out of contracts and invoices from third parties you helped us. But as you'll see in the regulatory filing we submitted yesterday, the estimates for the storm was about $100 million, and so call that $0.25 per share of impact. And as you think about the waterfall I walked through for the bridge of financial performance over the course of the year, we are assuming a good portion of that storm impact will flow through that cost bucket or what we're calling specifically reliability storms, including productivity.
And so the $0.04 of negative variance that you see in a year ago, when you add that to the $0.05 of negative variance we saw in our year-to-date actuals, what you see is basically a $0.12 per share swing versus our original guidance. And that basically adds up to about $50 million pretax. And so we've baked into the assumption of additional service restoration expense productivity in the form of CE Way, the CE Way and all the other cost-out items I enumerated in my prepared remarks. And so we're assuming that we're going to have an increase for sure in service restoration expense, but we will also net those down with cost reductions. We've also assumed cost performance as well in that parent financing tax and other buckets.
And so if you look at the comparison of what we have in our current waterfall versus our original guide, you'll see about $0.11 per share or $45 million roughly pretax of improvement versus the original -- but and that's where you see the balance of cost takeout or support to fund the impact of that service restoration expense increase, and that's what gets us to our full year guidance. So it's flowing through the cost associated with the service restoration expense is flowing through that reliability storms, including productivity line item. And again, the countermeasures are flowing through both of those sort of latter two buckets in the waterfall. Let me pause there and see if you have any further questions, Gregg.

Operator

Andrew Weisel, Scotiabank.

Andrew Marc Weisel

Good luck settling the gas rate case. So if you make a five timers club, like Saturday Night Live, I think you get one of those cool black wearing the jacket.

Garrick Rochow

I look forward to wearing that jacket.

Andrew Marc Weisel

Just want to clarify, I think you kind of just answered this on the last question, but to clarify, are you all ready in cutting mode after that storm? Or are you just reminding us of your proven ability to do that?

Rejji Hayes

No, Andrew. We've been -- we've gotten the Focal very early in the first quarter. I'd say once we started to get visibility that a significant storm is underway. And also -- even earlier in the month, we started to see pretty mild temperatures in the month of March, and so we already started to get the FOX start identifying and implementing countermeasures really in the early part of March that are already well underway. And so this is beyond -- with an academic.
We're in invitation mode. And so still more work to be done, but we're already in implementation mode based on the visibility we got earlier in the month and then as the storm started to materialize. Let me pause there.

Andrew Marc Weisel

I guess my question is, should this deferral be approved which, of course, is a good situation, what would you do then? If you're already cutting costs, then you get the good news of getting this approved, what happens?

Rejji Hayes

Yes. So it certainly creates additional flexibility in the plan, what we like. And I'll remind you that the CE Way will be one of sort of the anchor countermeasures that will lean in and we see no downside in overachieving on our CE Way targets year in and year out because it just creates additional headroom going forward and rate reduction opportunities for customers going forward. And so -- there's no reason to dial back those efforts. We may take a harder look at some of the planned cost deferrals and some of the other measures, like I said, where we would limit hiring and some of the other sort of flex related items that are more onetimers.
And so it just gives us more flexibility to potentially turn back on those spigots in the event we get success there. But if we see opportunity to execute on recurring savings opportunities, we would obviously carry on with those. Does that make sense?

Andrew Marc Weisel

Yes, it does. Given the weather challenges, it's been a while since you were in invest mode as opposed to lean mode. But yes, that would be a good situation. Okay.

Garrick Rochow

One thing only.

Andrew Marc Weisel

I think I -- yes. Kind of like the 10.25%. My other question, I think I answered this at storm a few years ago. What breed would you give yourselves in terms of reliability from the storm? I know, obviously, it's been a focus and the Liberty audit came out last year, but how would you evaluate the performance for the storm?

Garrick Rochow

Much, much, much better. And I would point to customers and policymakers, real positive sentiment with both. We're not seeing -- what we saw in 2023 was just a lot of aftermath after the storm, and we've improved greatly through process, through investments, and we've got a lot of positive feedback. And so I don't want to be too bustle. And so I'm still kind of grade myself hard.
So let's say like a B -- I still think there's room for improvement, but it's a lot different fact pattern than we had back in '23.

Operator

Sophie Karp, KeyBanc.

Sophie Karp

Yes, most of my questions have been answered, but maybe I can just ask a higher-level question on the economy in Michigan. I guess the unemployment rate which was a little elevated for the state. What are you seeing from your customers, if any, in terms of what are they saying about the activity? Are they adjusting to the new really with the tariffs and everything else? Any color would be helpful.

Garrick Rochow

I still see a lot of positive indicators in Michigan. And part of it, I talked about in response to a question in my prepared remarks, particularly in the 2% to 3% growth. the fact that data centers are accelerating the fact that manufacturing customers are still moving forward with projects and we can see that construction and then in some cases, asking to expand or at least in one case, asking to expand our promising indicators. But if I go right down to today, right, and remember like when we follow the margin and it's in the residential commercial space, we still see solid performance there.
And if you look into like -- we do this. We look into like permits and housing starts. And if you look at that Grand Rapids Politan area, permits, housing starts for single family continue to increase, for multifamily and commercial continue to increase. And so those are positive indicators. The other one I look at is relocations is what we call it, or alterations.
Those are customer-requested work for changes at their home or their business. And so maybe they need a larger meter to be able to serve their low. Maybe they need the meters move because they're putting a dish their home or their business. That, of course, went up in the pandemic as people went home and invested in their homes. And that is still elevated.
That's still above pre-pandemic levels, which is another good -- about people investing in businesses, in their homes, particularly in the residential and commercial space. So that gives us a lot of confidence that the sales piece of resi and commercial continue to be and where the margin is to continue to be solid.
The other thing I'll point out is there's always pluses and minuses when you get in the industrial space. And I talked about that a little bit with Julian on the Goshen piece. But when I look at our mix and how diversified Michigan is, we surprised people with this number sometime, there are 4,000 businesses in Michigan in the aerospace and defense industry, 4,000 including now Saab in our service territory. And so in this federal administration, you can make a strong bag that defense spending is going to increase. And so that's a real positive for Michigan.
The other one I'd like to point to is that we're the second most diverse state from an agriculture perspective. And what we've seen over the last 10 to 15 years is more of that processing of food move closer to the fields, move closer to the farm. And as a result, there's a lot more processing and manufacturing of food, and that's growing in this environment. Like even in the worst scenario, even the worst here of a recession, people still need food bread, milk and those dairy products. And so a long-winded way of saying, we still see a lot of positive indicators in our service territory, which gives us a lot of confidence of Michigan and a forward look.

Operator

And that concludes our Q&A. So I'd now like to hand back to Mr. Garrick Rochow for closing remarks.

Garrick Rochow

Thanks, Harry. I'd like to thank you for joining us today. I look forward to seeing you at the upcoming AGA Financial Forum. Take care and stay safe.

Operator

That concludes today's conference. We thank everyone for your participation.