Duke Energy Corporation (Holding Company)

Hello everyone and welcome to the Duke Energy first quarter 2023 earnings call. My name is Nadia and I'll be coordinating the call today. If you would like to ask a question at the end of the presentation, please press star followed by one on your telephone keypad. I will now hand over to your host, Abby Motzinger, VP of Investor Relations to begin. Abby, please go ahead.

Thank you, Nadia. And good morning, everyone. Welcome to Duke Energy's first quarter 2023 earnings review and business update. Leading our call today is Lynn Good, chair, president, and CEO, along with Brian Savoy, executive vice president and CSO. Today's discussion will include the use of non-GAAP financial measures and forward-looking information. Actual results may be different than forward-looking statements, and those factors are outlined herein and disclosed in Duke Energy's SEC filings. The appendix of today's presentation includes supplemental information, along with a reconciliation of non-GAAP financial measures. So with that, let me turn the call over to Lynn.

Abby, thank you, and good morning, everyone. Today we announced adjusted earnings per share of $1.20 for the first quarter. These results reflect a 22-cent headwind from weather, with January and February ranking among the warmest winter months on record across our service territories. In fact, DEP had its warmest January and February in the last 32 years. In response, we've already taken action activating agility measures across the enterprise, which Brian will walk through with you in just a moment. With three quarters remaining, including our strongest quarter still ahead, we are reaffirming our 2023 guidance range of 555 to 575 with a midpoint of 565. We're also on track to deliver our long-term EPS growth rate of 5% to 7% through 2027 at the midpoint of the 23 range. Before I turn to our regulated utilities, I'd like to provide an update on the sale of our commercial renewables business. As you know, we have separate sales processes underway for the utility scale business and the distributed energy business. We are in the late stage of the process for both transactions, and we'll look to update you in the near future. We continue to anticipate proceeds in the second half of the year. Moving to slide five, we're making meaningful progress in our strategic initiatives in each of our jurisdictions. In North Carolina, we recently reached a partial settlement with public staff and SIGFR, who represents DEP's industrial customers, in the Duke Energy Progress Rate Case. With agreement on approximately $3.5 billion of forward-looking capital investments in the multi-year rate plan, The settlement represents a significant milestone on our journey to modernize recovery mechanisms in North Carolina. It positions us well to continue delivering value to customers while supporting the cash flows of the company. The settlement also provides clarity on retail rate base of approximately $12.2 billion for the historic base case and depreciation rates that largely align with DEP's proposal. Further, we reached agreement on performance incentive metrics and residential decouplings. We were pleased to be able to work with public staff and SIGFR to narrow the open items in the case. These settlements are subject to approval by the North Carolina Utilities Commission. Evidentiary hearings began May 4th and are expected to conclude later this month. Interim rates will be implemented in June, subject to refund, and we expect permanent rates to be effective October 1st. The Duke Energy Carolinas rate case is about three months behind the DEP case, and hearings scheduled to begin on August 21st. Moving to South Carolina, the Commission approved a comprehensive settlement in our Duke Energy Progress rate case in February. Revised rates went into effect in April. We also recently received Commission approval to securitize approximately $170 million of past storm costs at Duke Energy Progress. In Florida, the Commission approved our fuel capacity and storm cost request in March. Rates were updated in April and reflect recovery of deferred fuel costs over 21 months with a debt return. We'll recover storm costs associated with hurricanes Ian and Nicole, as well as replenish the storm reserve over 12 months. We also continue to expand our renewables fleet in a steady and responsible manner, adding four solar projects in March and April totaling 300 megawatts. With these additions, we now operate 1,200 megawatts of solar in Florida with plans to continue adding approximately 300 megawatts a year going forward. In Indiana, we've had an active legislative session. The legislature passed several energy bills, including House Bill 1421, which was signed into law and allows quip and rate bays for natural gas generation. These bills support our ability to execute our energy transition in Indiana while maintaining reliable and affordable power for customers. We're in the process of finalizing CPCNs, which we expect to begin filing with the Indiana Commission later this quarter. In Ohio, we've reached a comprehensive settlement with the PUCO staff and multiple other parties in our natural gas rate case. The settlement, which is subject to commission approval, includes agreement on expanded revenue caps for the capital expenditure program rider. An evidentiary hearing is scheduled to begin on May 23rd. And in Kentucky, the commission is conducting an evidentiary hearing today on the electric rate case filed in December. If approved, new rates are anticipated to go into effect in July. We're making great progress on our strategy across our entire service territory, meeting our commitments and advancing investments in a balanced way to better serve our customers. Our strong track record is reflected in our impact reports, Duke Energy's 17th annual disclosure on sustainability topics. This comprehensive report was published in April. It includes our goals and progress on a broad range of topics, including the energy transition. It also outlines our corporate citizenship and the value we're creating for employees, customers, and communities, from economic development to environmental justice and to rescaling and redeploying workers. Before I turn the call over to Brian, let me take a moment to talk about our grid investment plan, which is $36 billion and accounts for over half of our five-year capital plan. The grid is a critical part of our energy transition, and with more than 320,000 line miles, we operate the largest transmission and distribution system in the nation. The foundation of our grid plan is focused on improving reliability and resiliency, preparing the grid for renewables, and enabling electrification. Our reliability and resiliency investments are centered on strengthening the grid against storms and security threats, and improving the ability to rapidly restore power when there's an outage. We're making targeted investments across a variety of programs, including self-optimizing growth technologies, targeted undergrounding, physical and cybersecurity upgrades, and upgrading lines and substations. Our investments are already making a difference, as evidenced by our response to Hurricane Ian last fall, where we restored power in less than half the time of our Hurricane Irma restoration efforts in 2017. As highlighted on the slide, we've made great progress in establishing constructive recovery mechanisms across our jurisdictions. These mechanisms will also assist in recovering grid investments in a timely manner, mitigating lag and supporting balance sheet strength while delivering benefits to our customers. From grid improvements to installing renewables to advancing policy, we're taking collective action to transform and ready the system for the future. We have a clear path forward and are confident our investment plan will deliver sustainable value and 5% to 7% earnings growth. With that, let me turn the call over to Brian.

Thanks, Lynn, and good morning, everyone. I'll start with quarterly results and highlight key variances to the prior year. As shown on slide 7, our first quarter reported earnings per share were $1.01 and adjusted earnings per share were $1.20. This compares to reported and adjusted earnings per share of $1.08 and $1.29 last year. Adjusted results exclude the impact of commercial renewables, which has reflected in its continued operations. Within the segments, electric utilities and infrastructure was down 14 cents compared to last year. As Lynn mentioned, these results reflect extremely mild weather in January and February, which drove a 22-cent headwind compared to normal. This is the most significant weather impact we've seen in recent memory. In addition to weather, lower volumes and higher interest expense were partially offset by lower O&M and growth from rate cases and riders. Rate case impacts in the quarter were primarily driven by our Florida utility. Consistent with our current settlement terms, in January we had an annual step-up under the multi-year rate plan, as well as the impact of a 25 basis point ROE increase as a result of rising interest rates. Moving to gas, utilities, and infrastructure, results were 4 cents higher year over year, primarily due to growth from riders and customer additions. Before discussing retail volumes, I'd like to take a moment to talk about our 2023 cost mitigation efforts and full-year expectations. We're currently executing the $300 million in O&M reductions that we shared previously, which were incorporated into our base plan to address interest rate and inflation headwinds. As we've said, 75% of these savings are structural and will be sustainable into future years. In response to mild weather in Q1, we've already activated agility measures, leveraging our scope and scale to identify further savings opportunities. As we've done in the past, we're looking to tactical O&M efforts and other levers. These include deferring non-critical work, reducing spend on outside services, and limiting non-essential travel and overtime, among others. We will be thoughtful about these efforts, keeping our unwavering commitment to reliability and customer service at the forefront of our approach. Looking ahead, residential decoupling in North Carolina will be fully implemented by 2024, but until then, we will continue to flex the agility muscle that we have done so successfully in the past. Turning to volumes on slide 8, as expected on a rolling 12-month basis, load growth has moderated closer to pre-COVID trends. When comparing to 2022, it's important to note that we had a very robust first quarter last year, which saw nearly 6% growth. In addition, nearly all of the Q1 weakness this year was seen in January and February when weather was extreme. In these situations, it can be challenging to precisely estimate the weather component of total volume variances. In March and April, when weather was closer to normal, volume trends were more consistent with expectations. giving us confidence that the full year 2023 load growth will be in the neighborhood of a half percent. Continued strong customer growth in the residential class also supports confidence in our outlook. The population migration we've seen into our service territories remains as strong as ever. In the industrial class, we're seeing some weakness in the textile sector, as well as an isolated plant closure by an electronics manufacturer in the Carolinas. Lingering supply chain impacts also continue to be a factor impacting usage. With that said, fundamental growth remains strong. Many of our larger industrial customers are expanding, and economic development in our service territories continues to be robust. For example, our recently released impact report highlighted our final economic development results for 2022. Over the year, we partnered with our states to attract over 29,000 new jobs. and $23 billion in capital investments to our service territories. These new customers, which represent several key sectors, such as battery, EVs, and semiconductors, will provide meaningful load growth as operations ramp up. We're proud of these accomplishments, which support the communities we serve and give us further confidence in the long-term economic outlook for our service territories. Moving on to financial activities on slide nine, we had a productive first quarter, completing around 60% of our planned 2023 issuances. We've also been opportunistic, taking advantage of market dynamics, which made convertible notes an attractive option. In April, we issued $1.7 billion of these notes to reduce our commercial paper balance and lower interest expense. Importantly, we made good progress on fuel proceedings during the quarter as well. In Florida, We received approval for a full recovery of the 2022 deferred fuel balance, with the rates updated April 1st. We also filed in February for recovery of approximately $1 billion of deferred fuel in DEC North Carolina. We expect to receive an order in August and for rates to be implemented in September. Filings over the summer will round out the Carolinas, addressing the remaining uncollected costs. In addition, we continue to expect proceeds from the sale of commercial renewables in the second half of this year, which will be used for debt avoidance at the holding company. Combined, we expect these two items, fuel collections and the completed sale, will positively impact FFO to debt by 50 to 75 basis points by year-end. I know the balance sheet is top of mind for investors, and credit is at the forefront of our planning as well. In fact, our efforts and commitment to the balance sheet were recently recognized by Moody In April, following our annual meeting, Moody's reaffirmed our current credit ratings and stable outlook at the holding company. This is further evidence that we have the right plan in place and are taking appropriate steps to maintain our strong balance sheet as we advance our energy transition and execute our capital plan. Moving to slide 12, we remain confident in delivering our 2023 earnings guidance range of 555 to 575 and growth of 5% to 7% through 2027. We operate in constructive, growing jurisdictions, and the fundamentals of our business are strong. Our progress on key initiatives in the first quarter positions us well to deliver on our commitments as we execute the priorities that are important to our customers, communities, and shareholders. With that, we'll open the line for your questions.

Thank you. If you would like to ask a question, please press star followed by one on your telephone keypad. If you choose to withdraw your question, please press star followed by two I'm preparing to ask a question. Please ensure your phone is unmuted locally. Our first question today goes to Shah Peraza of Guggenheim Partners. Shah, please go ahead. Your line is open.

Good morning, guys. Good morning, Shah. Good morning. Just to confirm, the short-term cost-cut measures Brian touched on, those are incremental to the $300 million figure that's out there. Are any of them potentially structural in nature? And I guess the key question is, I guess, where do you guys stand within the 23 EPS guidance range under that normal weather assumption for the rest of the year? Are you still kind of comfortable within the range of this juncture?

The answer to that is yes, Char. And let me talk about the various cost initiatives that are underway. The $300 million that we identified for last year I would call largely structural. When we talk about 75% of it being achievable, it's because we're making fundamental changes in the way we're completing work, staffing work, prioritizing work, et cetera. When we talk about the actions we're taking in response to weak weather, I would call those more tactical. This is deferral. This is reducing non-critical work, third-party spend, expenses, those types of things that we have done so many times, as you know. And so the combination of all of these activities, as well as the fact we enter any given year expecting a range of outcomes and establishing contingencies in our planning in case something doesn't work out exactly as planned, we are confident in reaffirming the range of 555 to 575. And so we'll continue to update you as the year progresses, but are confident in reaffirming at this point.

Okay, perfect. And then just in commercial, uh, obviously the commercial sale being in late stages, new language, and you obviously took another, you know, $175 million charge. Um, this is obviously the second charge to date. Can we maybe just elaborate why the expectations and the sale have come off more? I mean, what's driving the second revision? Is it capital markets? Is it buyer interest? Just some sense there. And, and I guess, you know, I guess when can we see something announced? Is it 3Q? Is it closer to year end? Thanks.

Yeah, sure. Appreciate the question. And we are continuing strong progress. We're in the late stages and expect to be able to provide more information shortly on where we are. Given the fact that we have placed the business into discontinued operations, we continue to evaluate whether we have the right recognition of net book value on the financial statements and did take an additional impairment charge representing further progression of the process. I would say to you, though, that the estimated value that we see in this process remains within our planning assumptions. So there's nothing here that I would point to as a surprise for us as we've moved through the process. As we have continued the negotiations, the marketing's complete. We're in discussions with select bidders. And we have made a decision to separate the process involving, for example, two projects that we are a minority owner of and concluded that the natural owner is the majority owner based on discussions and negotiations that progressed. So you should look at all of this as demonstration that we're nearing the end of the process and we'll be anxious to announce and give you further feedback as soon as that's appropriate.

Okay, perfect. I appreciate the extra color. Thanks, guys. Have a good morning. Thank you.

Thank you. The next question goes to Julian DeMoulin-Smith of Bank of America. Julian, please go ahead. Your line is open.

Hey, good morning, team. Thank you guys very much. Appreciate it. Hey, Julian. Brian, I wanted to go back to some of your comments, and you specifically said credit is at the forefront of many people's minds. In the last question, it was brought up about expectations evolving on the renewable sale here. I just want to be crystal clear about this, especially following the affirmation. Barring any changes in CapEx here, which you obviously do in a fairly annual cadence, can you just – elaborate a little bit on how you're thinking about the balance sheet. It seems like you've got a target here to get back to 14%. You talk about the 50 to 75 basis points, but very specifically here, your comfort level with the plan and the need to address any further equity or equity-like considerations to expedite getting to that long-term target.

Now, thanks, Julian. And, you know, it's the right question, and it is top of mind for us and for investors. You know, thinking about what what was the pressure we felt in 2022 it was really focused on deferred fuel all right we under collected nearly four billion deferred fuel we also um had storm restoration costs of around a half a billion so the balance sheet wore four and a half billion dollars of of uh cost that we didn't plan for as we moved into 2022. we're starting to recover that deferred fuel at dep and at duke energy florida Duke Energy Carolinas will happen later this year. And we put a chart in the slides to show that balance come off over the next two years. And as we recover those deferred fuel balances, along with the proceeds of commercial renewables, we feel that the balance sheet is where it needs to be. The target of 14% FFO to debt is the right target with the right cushion to deal with contingencies that come year in and year out and positions us for no equity through 2027.

Excellent. Thank you for hitting that clearly and good progress on the fuel. And then separately, Lynn, if you can comment here. I mean, obviously a lot of different utility assets moving around, potentially changing hands here. We'd love to hear your thoughts more specifically therein as you think about the options. You've got obviously a full plate in some respects on a lot of novel angles, especially in the Carolinas here. But can you elaborate at least your latest thinking around perhaps evaluating further assets here?

You know, Julian, I would say our primary focus at Duke is executing what we think is one of the strongest organic growth plans around. As you look at the clean energy transition going on in the Carolinas, Indiana is beginning transition of generation as well with CPCNs coming yet this year. Florida is continuing. to deliver strength with not only solar development, but also grid investment from the storm protection plan. So we feel like we've got just a robust capital plan moving forward and strong jurisdictions. So our primary focus is on organic growth. As you note, though, assets do become available from time to time. We will look at them if they make sense for us. But we'll do so in a disciplined way that maintains a focus on our balance sheet, maintains our focus on growth, maintains a focus on constructive jurisdictions that recognize the right balance between utility health and customer value. And I'll just leave it there.

Excellent. And then if I could clarify earlier, just super quickly, with respect to Indiana, obviously you've got this IRP out there. I'm just curious, A, if that could change your CapEx entry year, and B, if you have any further thoughts about what that could look like here.

It's a really good question, Julian, because we have continued to update the IRP in Indiana. You know, our core retirement profile remains largely the same, but we are seeing increase in renewables as a result of the IRA, and we're also seeing the impact of, you know, MISA's new planning assumptions. and how we ought to be addressing that over time. So we are on the verge of CPCN filings that will include both intermittent and non-intermittent resources. We will update the IRP again in 2024 and continue to evaluate whether we're moving at the right pace around the energy transition. I would say as we get into the back part of the decade, there probably is more potential in Indiana around that transition, but we'd like to work through this process to get it started in a way that makes sense for customers in the state. So more to come on Indiana. Really pleased with the progress we're making.

Excellent. Thank you, guys. Talk soon. Thank you.

Thank you. Thank you. The next question goes to Steve Fleischman of Wolf Research. Steve, please go ahead. Your line is open.

Hey, good morning. Thanks. Hi, Lynn.

Hi, Steve.

So just on the North Carolina settlement agreement, is there any other parties in the case? Are they opposed to it or are they just not taking a position? Where's kind of the other parties, if at all?

Yeah, you know, Steve, I would say, you know, we're really pleased with public staff and the industrials, two important parties in the case in Indiana. The Attorney General will be there as well as, you know, some of the consumer groups, environmental groups, et cetera. But we feel like the settlement is very strong with public staff and the industrials. We also have a settlement on the performance incentive mechanisms that you know, allocation and transmission. There are a host of things included. So we believe it's a demonstration of strong progress. We're on the stand, you know, starting, I guess, May 4th. That's last week. And feel like we have a very strong case.

Okay.

So I can't speak to the other parties on what they may think about what we've put together, but I believe the strength of the settlement public staff and SIGFR is noteworthy.

Okay. Uh, good. And then just in terms of thinking about, you know, a lot of the issue North Carolina over the years was just dealing with lag and the multi-year plans kind of help hopefully deal with lag. You know, obviously ROE cap structures still need to be finalized, but is it fair to say the parts that you agreed upon here are kind of the pieces that would address, you know, kind of lag, regulatory lag, um, in North Carolina in this settlement?

I feel like it's a really key step in that direction, Steve, because for the first time we have approval of forward capital in a way that gives us some confidence. And the construct of the legislation is such that we have an opportunity to adjust price as that capital is spent in a way that, as you know, is really new in the Carolinas and will reduce regulatory lag. So I think, you know, starting back with the legislation, we've been making progress toward modernization. And now with the settlement, have approval of that capital or have a settlement around that capital, of course, commissioned to approve in a way that we feel like we're making strong progress.

Okay, great. Thank you.

Thank you.

Thanks, Dave.

Thank you. As a reminder, if you would like to ask a question, please press star, follow by one on your telephone keypad. Our next question goes to David Alcaro of Morgan Stanley. David, please go ahead. Your line is open.

Hi. Thanks for taking my question. Hi, David. Morning. Let's see. I wanted to check in just on the Florida 10-year site plan. I just wanted to confirm whether there could be upside to the CapEx outlook now that you've gotten that filed?

Yeah, David, I would say we're continuing with our progress of about 300 megawatts a year. And as we get deeper into the plan, I think we'll consider whether we're moving quickly enough. The multi-year rate plan for Florida runs through 25, 24. The team is signaling me here. So effective 25 will kind of reset that expectation in Florida, and we'll continue to look at whether we're delivering the right amount of capital and customer value as we go, always focused on not only continuing to develop renewables at a pace, but also delivering value to customers along the way.

Okay, got it. Thanks. And then I also just wanted to follow up on Carolina's settlement. I was just wondering what your current thoughts are about potentially achieving a settlement at the Duke Energy Carolina's rate case now that you've been successful in getting the partial settlement at progress.

David, I think our posture is always to look for ways to achieve settlement. If you think about the calendar or the procedural calendar of any rate case, typically parties file their positions and then you have an opportunity to sit down and discuss. We will, of course, pursue that in the DEC case as we did in this one. And we'll keep you updated as the summer progresses.

Okay, great. Thanks very much.

Thank you.

Thank you. The next question goes to Bill Apichelli of UBS. Bill, please go ahead. Your line is open.

Hi, good morning. Just was wondering if you could get some additional color around the sales trends. I know you commented that when you have the extreme weather, it can distort the weather normalization trends, but maybe just some more color around why you feel better about the trend you saw in March and April.

Brian, you want to?

Definitely take that, Bill. Thanks for the question. I want to remind you that Q1 of 2022 was a robust quarter. We had 6% year-over-year growth that quarter, you know, strength in all sectors as we were coming out of the COVID rebound. That was the peak point. And so we're comparing to a high watermark, and volume trends normalized to our expectations over the course of 2022. And when we looked at this year with extreme weather in January and February, as I mentioned, it's really hard to pinpoint what the true weather normalized volumes are in those situations. And when we analyzed March and April results, weather was close to normal in both those months, and the volume trends were on track with our expectations for the year. So we do feel like this is bracketed into January and February as far as the weakness. And We feel confident that our half percent load growth in 2023 and the long-term outlook around a half percent is right for us because of the customer growth we're seeing at 1.7%, as well as the industrial expansions and economic development activity in our regions.

Okay, great. Thank you. And then just one other quick follow-up. On the corporate and other, there was an 8-cent pickup year-over-year increase. I know you cited some investment gains. Can you just provide some color around that?

Yes. Bill, we have investments in benefit trusts and other types of investments like that, our captive insurer, and market returns go up and down. We obviously had a strong first quarter. S&P was up around 8%, and that was reflected in the market returns in that section.

Okay, great. Thank you so much. Thank you.

Thank you. We have no further questions. I'll now hand back to Lynn Good, Chair, President, and CEO for any closing comments.

Well, thank you, and thanks to all of you who joined today and for your interest and investment in Duke. We're available for follow-on questions after this call and look forward to talking soon. Thanks so much.

Thank you. This now concludes today's call. Thank you so much for joining. You may now disconnect your lines.