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DATE
Thursday, August 7, 2025 at 2 p.m. ET
CALL PARTICIPANTS
President and Chief Executive Officer — Nicole Kivisto
Vice President, Chief Financial Officer, and Treasurer — Jason Vollmer
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RISKS
Weather impacts, particularly warmer temperatures in Idaho, negatively affected second quarter volumes at the Natural Gas Distribution segment, with Jason Vollmer noting, "we talk about roughly $1 million of impact just related to weather in Q2 2025 alone."
Total company earnings from continuing operations (GAAP, excluding Everest) declined to $14.1 million, or $0.07 per share, from $20.2 million, or $0.10 per share, in the prior year period, reflecting both operational and cost pressures.
Earnings at the Electric Utility dropped to $10.4 million from $15.5 million in Q2 2024, mainly due to higher payroll-related costs and a planned outage at the Coyote generating station.
Earnings at the Pipeline segment decreased to $15.4 million from a record $17.3 million in Q2 2024, with management attributing the decline to higher operation and maintenance expenses and the absence of a prior-year settlement benefit of $1.5 million net of tax.
TAKEAWAYS
Income from Continuing Operations-- $14.1 million, or $0.07 per share, from continuing operations, representing a decrease from $20.2 million, or $0.10 per share, in the prior year period.
Total Second Quarter Earnings-- $13.7 million, or $0.07 per share, down from $60.4 million, or $0.30 per share, in the prior year period.
Electric Utility Earnings-- $10.4 million, down from $15.5 million in the prior year period, as higher payroll and outage costs offset commercial volume increases and South Dakota rate relief.
Natural Gas Distribution Loss-- driven by increased costs and lower volumes from warm weather, partially offset by higher revenues from rate relief and transportation.
Pipeline Segment Earnings-- $15.4 million, versus $17.3 million in the prior year period; after adjusting for the $1.5 million net-of-tax customer settlement received in the prior year period, management described segment results as “very solid.”
Retail Customer Growth-- within the targeted annual growth rate range of 1% to 2%.
EPS Guidance Revision-- Management narrowed 2025 earnings per share guidance to $0.88 to $0.95 per share, from $0.88 to $0.98 per share, citing mid-year results and second quarter headwinds.
Five-Year Capital Investment-- $3.1 billion in planned capital investment over the next five years, with management anticipating 7%-8% compounded annual utility rate base growth during that period and 1%-2% targeted annual customer growth.
Long-Term EPS and Dividend Targets-- Anticipated long-term earnings per share growth rate of 6% to 8% annually, with a targeted annual dividend payout ratio of 60% to 70%.
Data Center Load Agreements-- 580 megawatts of data center load under signed electric service agreements at the electric utility as of Q2 2025. Of this, 180 megawatts is online as of Q2 2025, with 100 megawatts expected to come online late this year, 150 megawatts expected in 2026, and the remaining 150 megawatts in 2027.
Planned Rate Cases-- Electric segment filed in Wyoming and expects to file in Montana before year-end; natural gas segment filed in Idaho and reached settlements in Wyoming and Montana.
Transmission/Generation Strategy-- Current data center load will be met via a capital-light approach, with new generation and transmission investment considered for future incremental load if additional agreements are reached.
Minot Pipeline Expansion-- Project under construction, will add approximately 7 million cubic feet per day of capacity and is expected to be in service toward the end of this year and is planned to be in service by year-end.
Bakken East Pipeline-- Continues in customer dialogue phase; project scope, timeline, and commercial terms are under discussion, and the project is not currently included in the five-year capital forecast.
ATM Equity Program-- No equity needs anticipated in 2025, but a reestablishment of an ATM (At-the-Market) program is expected to support longer-term capital plans.
SUMMARY
Management directly attributed the narrowing of 2025 earnings per share guidance to weather impacts and increased operating costs, particularly affecting regulated utility segments.MDU Resources Group(MDU -6.66%) maintains its five-year capital and growth outlook, with $3.1 billion of investments planned over the next five years and long-term commitments to dividend and EPS growth targets. Customer growth at the utility business and data center load expansion reinforce management’s recurrent emphasis on demand-driven investment opportunity and capital allocation strategy.
Management does not expect the same run rate of cost impacts that pressured first-half results to persist for the balance of the year, stating, "we don't expect that to be a similar run rate to what we see the balance of the year."
Pending regulatory outcomes include the North Dakota Public Service Commission’s hearing on the Badger Wind Farm stake, scheduled for September 9, and regulatory approval of rate cases and wildfire mitigation plans across multiple states.
MDU Resources Group will provide updated guidance on forward capital needs and equity requirements later in 2025, following appraisal of ATM program timing and market access.
Management conveyed that weather normalization mechanisms did not cover all geographical operations, leaving Idaho and Montana exposed to unmitigated weather risk during the quarter.
The pipeline segment’s future growth prospects hinge on securing customer commitments for projects like Bakken East, with timing of open seasons and state support remaining fluid.
INDUSTRY GLOSSARY
ATM (At-the-Market) Program: Facility allowing the company to issue stock directly into the open market over time, providing flexible access to equity capital as needed without a single large issuance.
Open Season: A defined period when a pipeline operator solicits binding or non-binding commitments from potential customers for capacity on a proposed or expanded pipeline project.
Full Conference Call Transcript
Nicole Kivisto: Thank you, Jason, and thank you, everyone, for joining us today and for your continued interest in MDU Resources Group. This morning, we reported income from continuing operations of $14.1 million or $0.07 per diluted share for 2025. Unfavorable weather at our Natural Gas Distribution segment and increased operating costs across our business did impact our second quarter results. Despite these challenges, we have had a solid start to the year. Continued strong customer demand at our pipeline segment and in our utility regulatory schedule provide opportunity as we move forward. In addition, our utility experienced retail customer growth of 1.4% when compared to this time last year, which is within our targeted annual growth rate of 1% to 2%.
This strong customer demand at our pipeline, along with the growth and infrastructure needs at our utility, provide robust investment opportunity across our entire regulated business model. I'm extremely proud of our employees whose dedication to our core strategy continues to drive our business to deliver solid performance and positions MDU Resources Group with compelling long-term growth prospects. At our electric segment, we filed a general rate case in Wyoming during the quarter and plan to file a general rate case in Montana later this year.
As mentioned last quarter, we filed an advance determination of prudence with the North Dakota Public Service Commission for our proposed acquisition of a 49% ownership interest in the Badger Wind Farm, which equates to 122.5 megawatts of the project's total 250 megawatts of generation capacity. The commission has scheduled this hearing for September 9. We also continue to refine our wildfire mitigation plans across our electric service territory in accordance with recent legislation. We will be filing those plans in North Dakota, Montana, and Wyoming later this year. On the data center front, we continue to see opportunities for both our electric utility and pipeline business.
Specifically, at our electric utility, we currently have 580 megawatts of data center load under signed electric service agreements. Of that total, 180 megawatts is currently online, with an additional 100 megawatts expected to come online late this year. Another 150 megawatts is expected in 2026 and the remaining 150 megawatts in 2027. Our current approach on the 580 megawatt load is a capital-light business model, which not only benefits our earnings and returns but also provides cost savings to our other retail customers. We continue to pursue additional discussions on incremental data center load, and should those discussions progress to signed agreements, we would consider investing capital into new generation and transmission assets to serve the increased load.
Jason Vollmer: For our natural gas segment, we filed a general rate case in Idaho during the quarter with a requested effective date of January 1, 2026. We also reached a settlement agreement in our Wyoming rate case with new rates effective August 1. In Montana, we filed a settlement agreement on April 3, which is pending commission approval. We are currently collecting interim rates in Montana pending the commission's final ruling. Our pipeline segment is executing well on our core strategy and delivering solid results, driven by strategic expansion and increased demand for transportation and storage services.
We remain committed to investing in future expansion projects to meet customer demand for services, including strong interest from industrial customers and power generation projects. We began construction on our Minot expansion project in May, which will add approximately 7 million cubic feet of natural gas capacity per day and is expected to be in service toward the end of this year. In regards to our proposed Bakken East Pipeline project, that could run approximately 350 miles from Western North Dakota to the eastern part of the state plus additional pipeline laterals, we continue to engage with all interested parties to further refine the project scope, timelines, and commercial terms.
This project would provide much-needed takeaway capacity to meet the forecasted natural gas production growth in the region and provide natural gas transportation service to industrial power generation and local distribution companies. The project is not currently in our five-year capital forecast and would be incremental should we determine to proceed. The binding open season for our Baker storage field enhancement and transportation expansion project concluded in May. We are reviewing results, and based on initial feedback, are evaluating a smaller project to align with customer interest received in the open season. In addition to these specific projects, the team also continues to several other growth projects that are in various stages of development.
With the weather and operating expense impacts we experienced in the second quarter, in our view midway through the year, we are narrowing our earnings per share guidance to a range of $0.88 to $0.95 per share, from our previous range of $0.88 to $0.98 per share. We remain confident in our ability to execute on our long-term growth strategy and believe our operational focus and financial discipline continue to position us well for delivering safe and reliable energy, customer value, and strong stockholder returns. As we look ahead, we are focused on our core strategy, emphasizing customers and communities, operational excellence, returns-focused, and employee-driven.
We believe we are well-positioned for growth into the future with an anticipated capital investment of $3.1 billion over the next five years, 7% to 8% compounded annual utility rate base growth, and customer growth of 1% to 2% annually. We also anticipate a long-term EPS growth rate of 6% to 8% while targeting a 60% to 70% annual dividend payout ratio. As always, MDU Resources Group is committed to operating with integrity and with a focus on safety. We remain dedicated to delivering value as a leading energy provider and employer of choice. I will now turn the call back over to Jason for the financial update. Jason?
Jason Vollmer: Thank you, Nicole. This morning, we announced second quarter earnings of $13.7 million or $0.07 per share compared to second quarter 2024 earnings of $60.4 million or $0.30 per share. Income from continuing operations, which excludes the impacts of Everest, which became a separate public company in October 2024, was $14.1 million for the second quarter or $0.07 per share compared to $20.2 million or $0.10 per share in 2024. Turning to our individual businesses, our Electric Utility reported second quarter earnings of $10.4 million compared to $15.5 million for the same period in 2024.
Higher payroll-related costs and costs related to a planned outage at our Coyote generating station drove the increase in operation and maintenance expense experienced during the quarter. These are partially offset by increased commercial sales volumes, largely from data center load, and rate relief in South Dakota. Our natural gas utility reported a seasonal loss of $7.4 million in the second quarter compared to a loss of $5 million in 2024. Increased operation maintenance expense primarily due to higher payroll-related costs and lower volumes due to warmer weather, largely in Idaho, drove the increased loss in the quarter. Partially offsetting the loss were higher retail sales revenues due to rate relief and higher transportation revenue.
The pipeline business posted second quarter earnings of $15.4 million compared to a record second quarter earnings of $17.3 million in the prior year. In 2024, the pipeline received proceeds from a customer settlement of $1.5 million net of tax. Backing that off of the total earnings for 2024, we view the second quarter at our pipeline segment as very solid. Higher operation and maintenance expense further drove the decrease in earnings. Partially offsetting the decrease was higher transportation revenue due to the Wapton expansion project and customer demand for short-term natural gas transportation contracts. Finally, MDU Resources Group continues to maintain a strong balance sheet and ample access to working capital to finance our operations throughout our peak seasons.
While we have no equity needs in 2025 based on our current capital plan, the $3.1 billion capital investment program over the next five years will require some access to the equity capital markets. As mentioned last quarter, we plan to reestablish an ATM program in the near future to meet those needs. We will update our forward-looking capital investment plan later this year and provide further guidance around the size and timing of future equity needs at that point. That summarizes the financial highlights for the second quarter. We appreciate your interest in and commitment to MDU Resources Group. We will now open the line to questions. Operator?
Sylvie: Thank you, sir. At this time, I would like to remind everyone, if you would like to ask a question, please press star and the number one on your telephone keypad. And if you would like to withdraw your question, please press star 2. And if using your speakerphone, please pick up your handset before entering your request. Thank you. And your first question will be from Ryan Levine at Citi. Please go ahead, Ryan.
Ryan Levine: Hi, everybody.
Nicole Kivisto: Hello, Ryan.
Ryan Levine: What impact does the lower storage project size have on the potential scale of the Bakken East pipe? And can you walk through the implications of the revised scale of the storage facility?
Nicole Kivisto: Yeah. Appreciate the follow-up on that, Ryan. Essentially, as we were providing an update there on the Baker storage enhancement and transportation project, I would see that as one data point. But as it relates to Bakken East, essentially, we'll talk a little bit about that and provide a little more color on where we're at with that project. But I wouldn't say that what happened with Baker Storage enhancement and the open season we did there has implications on Bakken East. In fact, if we continue with the Bakken East project, there may be incremental enhanced opportunities for us to expand storage opportunities on a go-forward basis. So essentially, the two projects are deemed really separate right now.
But to the extent we have enough customer commitment, on a go-forward basis to move forward with Bakken East, that could provide incremental opportunity from an expansion of our storage assets going forward. Maybe just stepping back for a minute, as I think about Bakken East and quite frankly, our storage assets in general, I really do like our strategic position. I've talked about this before in the Bakken, but we believe the Bakken play in North Dakota provides many opportunities with the growing production that we see coming out of the Bakken and the low cost of gas.
So as I think about WBI position, strategically located over that play, it certainly provides us strategic advantages as we think about positioning as it relates to the Bakken pipeline as well as potential storage opportunities going forward.
Ryan Levine: Great. And then one unrelated question. In terms of the revised EPS guidance range, given the drivers of the revision there, how does that impact your longer-term EPS outlook? Does that signal you're moving towards a certain end of the range or any color you could share on that?
Jason Vollmer: Yeah. Thanks, Ryan. This is Jason. I can jump in there. So yes, we did revise our range here. And I think really looking at where we're at in the middle part of the year, we had some impact as we noted in the release related to weather, particularly in Idaho for the second quarter. Warmer than normal temperatures drove some volume impacts there. But also, some higher operating expenses than maybe we originally had looked at there. As we look at the operating expense piece, that, of course, as we look forward into our guidance, how do we think about where we're to finish the year. You know, what goes through the operating expense there is a few items.
There are certainly some items that are, we'll call it pass-through in nature. So items that we would have seen some higher expense for related to conservation programs as an example on the regulated side, we get to recover in revenue. So it stands out as a larger expense. Items related to the transition services agreement for Everest, which we are billing them for, again, providing service, through that stands on expense, but also shows up in revenue. So those lines are really kind of a pass-through as we look on that side. However, we did see on a quarter-over-quarter basis, and again, we had planned for an outage at the Coyote Station.
But we're seeing, I think, just general inflationary costs across the board for various items such as insurance costs are going up, payroll-related costs we talked about. We've seen some increases there. And I think it's, as we navigate through the balance of the rest of the year, based on our forward look, we don't see those being as impactful as they probably are in the run rate that you see today, and certainly don't think that's a larger-term trend for us.
But we had to really step back and look at where we're at this point in the year and our guidance range right now would tell us that, you know, it's unlikely we would have hit that top end of that range based on that. So we felt comfortable moving that top end back. And feel it we have the range set at right now is very reasonable for the rest of the year.
Ryan Levine: Great. Thanks for taking my questions.
Sylvie: Once again, I would like to remind everyone, if you would like to ask a question, please press star then the number one on your telephone keypad. And if you would like to withdraw your question, press star 2 on your telephone keypad. If you're using a speakerphone, please pick up your handset before entering your request. And the next question will be from Julien Dumoulin-Smith at Jefferies. Please go ahead, Julien.
Brian Russo: Yeah. Hi. It's Brian Russo on for Julien.
Nicole Kivisto: Good afternoon.
Brian Russo: Good afternoon, Brian. Hey. Just to follow-up on the Bakken project. I think the next North Dakota Industrial Commission meeting is on August 21 maybe. What can we expect there regarding their decision or recommendation on, I think, some takeaway task over ten years? Would that alter the WBI Energy's development plans at all?
Nicole Kivisto: Yeah. So first, let me address the next meeting. You are spot on in terms of the timing of the next meeting of the North Dakota Industrial Commission. It appeared that they were leaning into potentially providing a decision at that meeting. However, we're not 100% certain on that. But in the public format, there was indication that they were going to try to get to conclusion by the August meeting. So more to follow in terms of whether that happens or not. Certainly, state support, as you commented on, would enhance the project and provide what we believe to be a bridge because as we work through these customer commitments that we are in conversations with.
There's varying degrees in terms of needs. So timing is one consideration, where we it's probably makes sense that, obviously, not all customers have the same timing in mind. And so as we think about the state's interest in this project, and what it will do for the state of North Dakota, certainly they've got interest. Right? We talked already about increasing production out of the Bakken. Gas to oil ratios continue to increase. They want takeaway capacity out of the Bakken. So they're very focused, the state is, on getting a project done. As it relates to WBI and our project specifically, we do believe a state decision does help in terms of providing some certainty for our customers.
But that being said, it isn't the only thing that we're focused on. Certainly, are very focused on what kind of customer commitments we can get and how we continue with the dialogue with our customers. As that dialogue progresses, we are hopeful then that would turn into a binding open season. So our next step would be a binding open season. All of this conversation will continue to transpire. We're hoping, over the next six plus months, just to give you some timeline in terms of timetable. As we move forward with next steps on Bakken East.
Brian Russo: Okay. Great. And then also, just again, to follow-up on the guidance revision to the top end. Is there a way to quantify those various drivers? Some seem to be one-time or others might be ongoing whether one-time. I think maybe the planned outage might also be one-time versus, you know, what's kind of ongoing maybe related to the, you know, the dis-synergy cost from the Everest transaction?
Jason Vollmer: Yeah. No. Thanks, Brian. Happy to try to do whatever we can. Yes. The planned outage, I mean, we had planned for that, and that was part of our original guidance range that we had looked at already. And that really stayed pretty true to what we had expected there. So don't expect much of a difference there. Weather, of course, that's, you know, one of the items that it's tougher to plan for as we look through that. So what we did see in the second quarter was warmer weather, especially impacting volumes at the gas business.
Now, you know, thankfully, we do have some very good mechanisms in most of our states where we've got weather normalization in a lot of our states. We are not weather normalized or decoupled in the states of Idaho or Montana. So we did see some impacts there. You know, to quantify that, broadly speaking, and I think if you look at our SEC filings, we talk about roughly $1 million of impact just related to weather in the quarter alone here. Other items that we see as far as payroll and various, you know, items along that line, of that can vary a little bit depending on your timing of capital projects and are we capitalizing labor or not.
There's various items that can impact that. Of course, we have seen increases for employees along the way, which doesn't add to payroll until you, you know, file new rate cases and really get recovery of some of the increased cost of service there. But, overall, again, as we stated earlier, from a run rate perspective, what you saw in the first half of the year on a year-over-year comparison basis, we don't expect that to be a similar run rate to what we see the balance of the year. That number will come in some, but certainly did have an impact for us in the first half of the year and in the second quarter.
Brian Russo: Okay, great. And then just lastly, you mentioned you were in active discussions with more data centers. Just curious, when will kind of and the capital-light strategy in the ESAs, right? When do you think that these pockets of excess capacity can be absorbed, can absorb, you know, any incremental load before MDU would need to build generation infrastructure to serve that incremental demand? Like, how many megawatts do you think is there to be absorbed, I guess?
Nicole Kivisto: Yeah. So what we have shared in the past on that particular topic is that we do believe we have additional capacity without the build-out of new infrastructure. However, saying that, probably not to the level of what you're seeing currently in that 530 that we have developed at Ellendale. So there are pockets within our system where we could do a similar capital-light strategy, and we continue in conversation with potential customers in that regard.
That being said, I think what we shared here in my earlier remarks is we are willing to explore other opportunities to perhaps invest in transmission or generation to serve incremental load over and above what could have been served with the capacity we were previously talking about. So the conversations continue to be fluid. Our approach has been that we really come forward with where we're at once we have an energy service agreement. So we will certainly keep the market aware when that happens.
But we did want to provide the data point that conversation continues in terms of data center customers across the various footprint, whether that be incremental generation or transmission investment opportunity or in areas where we have the ability to continue on this capital-light approach. Thank you. This marks the last call for questions. If you would like to ask a question, please press star then number 1 on your telephone keypad. The webcast can be accessed at www.mdu.com under the investor heading, select events and presentations, and click Q2 2025 Earnings Conference Call. After the conclusion of the webcast, a replay will be available at the same location. And at this time, there are no further questions.
I would like to turn the conference back over to management for closing remarks. All right. I want to thank you all again for joining us today. We appreciate your interest in and support of MDU Resources Group and look forward to connecting with you throughout the year. With that, I will turn the call back over to you. Operator?
Sylvie: Thank you. Ladies and gentlemen, this concludes today's MDU Resources Group conference call. Thank you for your participation. You may now disconnect your lines.