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spk02: Hello all and welcome to the Duke Energy fourth quarter and end year 2023 earnings call. My name is Lydia and I'll be your operator today. If you'd like to ask a question during the Q&A, you can do so by pressing star followed by one on your telephone keypad. I'll now hand you over to Abby Motzinger, Vice President of Investor Relations, to begin.
spk10: Thank you, Lydia, and good morning, everyone. Welcome to Duke Energy's fourth 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 CFO. Today's discussion will include the use of non-GAAP financial measures and forward-looking information. Actual results may differ from forward-looking statements due to factors disclosed in today's materials and in Duke Energy's SEC filings. The appendix of today's presentation includes supplemental information, along with a reconciliation of non gap financial measures with that, let me turn the call over to Lynn.
spk00: Abby Thank you and good morning everyone today we announced 2023 adjusted earnings for share of $5 and 56 cents finishing the year within our guidance range. and demonstrating once again our ability to exercise agility and managing our business and meeting our commitments. We also announced 2024 guidance of 585 to 610 with a midpoint of 598. This represents 6% growth from our original 2023 guidance. And we extended our 5% to 7% EPS growth rate through 2028 off the midpoint of our 2024 range. We entered the year with significant momentum. 2024 marks a fundamental repositioning of our investment proposition. With a commercial renewable sale, we've transformed our business. to become a fully regulated utility for the first time in decades. Along with improved regulatory constructs, we're poised to deliver on our simplified, 100% regulated growth plan. Our Southeast and Midwest utilities operate in some of the fastest growing and most attractive jurisdictions across the U.S. We expect growth in our service territories to accelerate as we move further into the energy transition driving substantial investment. We are now projecting $73 billion in capex over the next five years, an $8 billion increase versus our previous plan. Turning to slide five, 2023 marked another year of outstanding accomplishments across our business, building on our compelling growth story as we move into 24. As I mentioned, we completed our portfolio repositioning and delivered multiple constructive regulatory outcomes while maintaining our commitment to safety and customers. We executed five rate cases, and I'm proud of the constructive results the teams delivered. We received orders approving $45 billion in historic and future rate-based investments that will provide growth to customers for years to come. There was also recognition of the rising cost of capital with improving ROEs and equity ratios. And in North Carolina, we implemented forward-looking multi-year rate plans for the first time ever. The performance-based regulations authorized by HB 951 provide certainty, predictability, and value to customers and the company. This milestone was accomplished through years of work with policymakers, legislators, and other stakeholders. Shifting to operations, our teams performed well throughout the year, serving our customers in extreme weather conditions and restoring power following historic storms in Indiana and Florida. Providing safe, reliable power in all seasons and circumstances remains our mission. In fact, in 2023, Duke Energy Florida had its best reliability performance in more than a decade, largely due to our significant storm protection plan investments. These investments also aided restoration efforts in Hurricane Adalia, saving outage minutes and speeding return to service. In the Carolinas, our nuclear fleet continues to generate safe, reliable, carbon-free power, achieving a capacity factor of 96%, the 25th year in a row above 90%. And underpinning all of this and a hallmark of our commitment to operational excellence, 2023 marked our best safety performance in company history, as measured by a total incident case rate of 0.31. Safety is a core value at Duke Energy, and I'm proud of our employees' commitment to event-free operations. Finally, the Piedmont team continues to excel in customer service. For the second year in a row, J.D. Power ranked Piedmont number one in residential customer satisfaction for natural gas services in the southeast. And our Carolinas electric utilities continue to achieve strong results as well, remaining in the top quartile. Moving to slide six, we start the year entering the next phase of our energy transition, a period of execution and record infrastructure build to meet the evolving energy needs of our customers and communities. We're working with stakeholders to develop resource plans to support the phenomenal growth in our communities. In the Carolinas, demand is already outpacing the forecast used in our August resource plan filings, and we filed supplemental portfolios in January. We're committed to meeting this growth with a diverse and increasingly clean energy mix that includes renewables, natural gas, next generation nuclear and storage resources, as well as energy efficiency and demand response tools. We're also taking steps to build new generation. In North Carolina, we'll file CPCNs for over two gigawatts of new natural gas generation in 24. We'll continue to advance annual solar procurements targeting one gigawatt per year. And in Indiana, we'll file CPCNs for new generation resources around mid-year. These new facilities will add to our diverse mix of resources and are critical to meeting growing customer demand as we reliably exit coal by 2035. From a regulatory perspective, we've announced two rate cases in 2024, starting with DEC South Carolina in early January. Since the last case in 2018, we've invested more than $1.5 billion in to improve reliability and resiliency and meet the growing energy needs of our more than 650,000 customers. And in Florida, we notified the Commission of our intent to file a rate case in April. Similar to our current multi-year rate plan, which runs through 2024, this filing will cover three years of investments beginning in 2025. Our plan will add over 1,000 megawatts of new solar, and include over $3 billion of grid investments to serve population growth, increase reliability, and reduce storm-related outages. Finally, since our last rate cases at Duke Energy Indiana and Piedmont, North Carolina, we've continued to make investments to strengthen our system, and we're evaluating the timing of our next filings in these jurisdictions. In closing, I'll move to slide seven, which depicts the transition of Duke Energy over the last many years to the premier regulated utility that it is today. The strategic and financial clarity provided by optimizing our portfolio over the last decade has simplified Duke Energy to a powerful, core regulated business operating in vibrant jurisdictions, growing through population migration and strong commercial and industrial economic development. Our growth potential is the highest it's been in decades and is reflected in our $73 billion capital plan. This plan is driven by grid investments to transform the largest T&D system in the US and IRP-related generation investments to support our growing jurisdictions and fleet transition. And efficient recovery mechanisms allow us to translate these investments into customer and investor value. In closing, we have positioned Duke for long-term value creation. and our path forward is clear as we navigate the coming decade of record infrastructure build. This pivotal point in our history drives a differentiated, low risk, total return proposition going forward, and I'm confident we will deliver. With that, let me turn the call over to Brian.
spk03: Thanks, Lynn, and good morning, everyone. Turning to slide eight, 2023 marked a year of solid growth for our utilities. We achieved full-year adjusted earnings per share of $5.56, which represents about 6% growth over 2022. For the year, we saw top-line growth from constructive rate case outcomes, multi-year rate plans, and rider growth across our jurisdictions. Additionally, we delivered on our cost and agility efforts, which offset record mild weather, lower volumes, and higher interest expense. 2023 was a year full of significant headwinds, and I'm proud of the team for executing on our agility plans, including strong fourth quarter results to deliver on our financial commitments. Turning to slide 9, we are introducing 2024 guidance range of 585 to 610. The midpoint of $5.98 represents more than 7% growth over 2023. Within electric, we expect normal weather and retail volume growth of roughly 2%. We also enter the year with updated rates for our North Carolina utilities, including the benefit of the historic base case, as well as year one of the multi-year rate plans. Additionally, we have updated rates at Duke Energy Kentucky and expect updated rates for DEC South Carolina in August. We'll see growth from year three of the Florida multi-year rate plan currently in effect, and we will continue to see growth from grid investment riders in the Midwest and Florida. Partially offsetting these favorable drivers are higher interest expense, as well as depreciation in property taxes on a growing asset base. Our gas segment continues to deliver strong growth, with investments across all jurisdictions related to integrity management and to serve a growing customer base. Finally, we expect the other segment to be impacted by higher interest expense and a higher effective tax rate. We ended 2023 with an ETR of 10%. Although we continue to pursue a robust set of tax optimization strategies, we expect our 2024 ETR will increase to between 12 and 14%. Turning to retail electric volumes on slide 10. In 2023, we saw strong residential customer growth in all jurisdictions, highlighted by the Carolinas and Florida at 2.1% and 2% respectively. In fact, over the course of 2023, we added 195,000 new customers, the largest customer increase in company history, and a continuation of the trend we've seen over the past few years. As a reminder, residential decoupling in North Carolina began in DEP in October and in DEC in January. This will reduce volatility and align growth with positive customer migration trends. We have also seen significant growth in economic development opportunities in our service territories, as reflected in the recent Supplemental Carolinas Resource Plan filings. As we evaluate which projects to include in our financial plan, we recognize that site selection processes are often very competitive. We generally only include the most mature and committed projects, focusing on those with letter agreements or in very late stage development. This gives us upside potential should additional projects progress. Economic development opportunities in our service territories are diversified across many industries. Semiconductors, EVs, batteries, pharmaceuticals, and data centers, to name a few, which will provide growth from the projects themselves, as well as incremental growth from residential and supplier demand. These economic development and customer migration trends give us confidence in our one and a half to 2% load growth expectation over the forecast period. Turning to slide 11, Duke's proven track record of cost management will support our ability to execute an energy transition that is rooted in discipline and a commitment to safety for our employees and reliability and affordability for our customers. As I mentioned before, We delivered on our significant O&M and agility targets for 2023 in response to macroeconomic headwinds and unfavorable weather. In 2024, we expect O&M to be largely flat to 2023, offsetting inflationary pressures with sustainable efficiencies. And we will continue to target a flat cost structure over the five-year plan. Duke Energy is a leader in the industry when it comes to cost efficiency, driven by our culture of continuous improvement. We consistently rank in the top quartile across a variety of O&M measures, and our ability to manage our cost structure creates significant value for our customers and shareholders. Turning to slide 12, I'd like to provide an overview of our five-year $73 billion capital plan, which has increased $8 billion over our previous plan. About half of the incremental capital is the result of rolling the plan forward a year to include 2028. The update reflects an early estimate of the supplemental Carolina's resource plan filed in January, as well as approved spend in the North Carolina multi-year rate plans. Over time, our capital plan has steadily increased as we move further into the clean energy transition, supporting a 7.2% earnings-based CAGR through 2028. Grid investments represent 50% of our five-year capital plan and will improve the reliability and resiliency of our system. Significant generation spin ramps up in the latter part of the plan as we add more renewables and storage assets, extend the life of our carbon-free nuclear fleet, and make prudent investments in cleaner natural gas to better serve our growing customer base. Looking ahead, about 90% of the electric investments in our capital plan are eligible for efficient recovery mechanisms, which is critical to maintaining a strong balance sheet, mitigating regulatory lag, and smoothing customer rate impacts. Moving to slide 13, our ability to execute our robust capital program is underpinned by a healthy balance sheet, and we remain committed to our current credit ratings. With that in mind, we are introducing modest equity to fund the increase in capital plan we announced today. We expect to raise $500 million annually over the five-year plan starting in 2024 using at-the-market and dividend reinvestment programs. Turning the FFO to debt, we have provided a walk-up showing the path to achieve our 14% target by the end of 24. Compared to 2023, we expect improvements from normal weather, rate case activity, the collection of remaining deferred fuel balances, the monetization of nuclear PTCs, and equity issuances under the DRIP and ATM programs. These credit-supportive drivers give us confidence in achieving 14% FFO to debt in 2024 and a minimum of 14% over the long term. Let me talk a bit more about the nuclear PTC, an important element of the Inflation Reduction Act that will provide substantial savings to our customers over time. As an operator of 11 low-cost nuclear units in the Carolinas, We expect to qualify for several hundred million dollars per year of nuclear PTCs beginning in 24. We intend to monetize the credits in the transferability markets established by the IRA. In North Carolina, we worked with the public staff on a settlement regarding the treatment of nuclear PTCs that was approved in our DEC rate case order last year. We will flow back the benefits to customers over a four-year amortization period. This treatment allows customers to benefit from bill reductions over time and is supportive of the utility's credit metrics. Moving to slide 14, our robust capital plan, strong customer growth, and constructive jurisdictions provide a compelling growth story. And our commitment to the dividend remains unchanged. We understand its importance to our shareholders, and 2024 marks the 98th consecutive year of paying a quarterly cash dividend. We intend to keep growing our dividend, balancing the payout ratio with the need to fund our capital plan. Over the next five years, we anticipate a steady decline in the payout ratio, and we are adjusting our target payout ratio to 60 to 70% from 65 to 75%. This updated range provides additional financial flexibility, minimizes external equity needs over time, and is more consistent with a company investing in our current pace. As always, dividends will be subject to approval by the Board of Directors. In closing, 2023 was a year of execution, and we have tremendous momentum as we head into 2024. The fundamentals of our business are stronger than ever, giving us confidence in our ability to deliver sustainable value and 5% to 7% growth through 2028. With that, we'll open the line for your questions.
spk02: Thank you. Please press star followed by the number one if you'd like to ask a question, and ensure your device is unmuted locally when it's your turn to speak. If you change your mind or your question has already been answered, you can withdraw your question by pressing star followed by the number two. Our first question today comes from Shah Peraza of Guggenheim Partners. Your line is open. Please go ahead.
spk04: Hey, guys. Good morning.
spk00: Good morning, Shah.
spk04: Good morning. Just on the capex expectations, the $8 billion increase reflects, quote unquote, obviously an early estimate of the Carolina IRP filing at the end of March. Can you just maybe elaborate on what you mean by early? So what scenarios embedded? Is there room for upside? And then to what extent does the plan include IRPs you'll be filing this year in Indiana, Kentucky? Thanks.
spk00: Yeah, sure, thank you. You know, an early estimate would say we've begun to contemplate what the January IRP includes, and I think you've seen us demonstrate that we've not only seen an increase in megawatts, but frankly we've seen an increase in price for certain of the resources that we're adding. But we believe that capital plan is subject to continued refinement, not only as we move through the regulatory process in the Carolinas, but we will introduce More around Indiana. We have a 10-year site plan that we're filing in Florida this year. So refinement will continue with the capital plan. But what I would leave you with, Char, is we have a wealth of opportunities. I mean, there is growth that is strong throughout all of our service territories, and we'll be making, along with our regulators, the decisions on reliability, affordability, increasingly clean as we move through these IRPs. So, just a really strong growth story for Duke.
spk04: Got it. Okay, so more to come. And then just, Lynn, on the nuclear PTC, it's a material driver of that FFO. I guess, what are you seeing in sort of that transferability market from a demand perspective? What discounts are you seeing? And then, like, we're getting questions on this all morning. It's like, how do you price in the risk of an IRA repeal? And in the worst case scenario, can you make up that lost FFO?
spk00: Yeah, so a couple of things. On the transferability market, Char, we have begun to test that market. We had a pilot transferability transaction in 2023. The discount on the transferability was right within our planning range, so very strong response to that initial test, and the Treasury group and team are already working on how we might execute in 2024 as well. So we do believe the market is developing, and I think around the industry you've seen similar transactions. executed in an effective way. On a potential repeal, what I would say to you is we continue to be very engaged with policymakers at the federal and state level around the need for infrastructure as we continue to pursue growth, onshoring of U.S. manufacturing, leadership in artificial intelligence, battery manufacturing, EVs, et cetera. And we believe there's a lot of support to continue to build that infrastructure and to build it at a price that's affordable and the point I would emphasize for us on tax credits around infrastructure. It goes directly to customers, it reduces price over time to customers dollar for dollar. And so I believe both of those messages continue to resonate with policy makers and will continue to make them. I think it's essential that we keep moving on this infrastructure build in order to serve the growth that we're seeing in our service territories. On the impact to credit metrics, our goal sure is to be minimum of 14%. So even in the event that the credits could be impacted in some way, Over time, we still believe we'll have time to adjust. We'll look at our overall plans and continue to run our business with a commitment to our balance sheet and with a strong balance sheet to pursue the growth.
spk04: Okay, great. Fantastic. Thank you, guys. See you next week.
spk02: Thank you. Our next question comes from Julian D'Amelian-Smith of Bank of America. Your line is open.
spk07: Hey, good morning, Lynn and team. Hey, thank you. Look, I just wanted to follow up on the last question a little bit in the same focus on the nuclear PTCs here, just in as much as can you discuss the reductions in the forecasted rate base? Obviously, an increase in capex here today, and obviously there's some timing-related matters as it pertains to the nuclear PTC impacting rate base, but can you talk to what other factors might be impacting rate base, not just in the near year here, but through the forecast As you think about the puts and takes here?
spk00: Yeah, so maybe a couple of things. On the capital side, Julian, much as Char described, we'll continue to refine these with the wealth of opportunities. I do believe we'll have an opportunity to continue to introduce really strong capital in all of our jurisdictions. But on translating to rate-based growth, what we show you with rate-based is capital offset by tax attributes. So the nuclear PTCs, because we're amortizing them over a four-year period in a very credit-supportive way, we have a reduction in rate-based as a result of that. So this is, you know, an opportunity for us to do both, grow and maintain the strength of the balance sheet. And we feel like we have developed a very constructive settlement in North Carolina to achieve exactly that.
spk07: Yep. No, that makes sense. There's just nothing else that's impacting that. And then can you discuss the revised low growth outlook? I get 2% is a real acceleration from the 0.5% to 1% from last year, and ultimately I get that last year had down load, if you will, so it's a new starting point. But just reconcile a little bit of the low growth commentary, especially considering the commentary from the last call here. What has sort of reaccelerated? How do you think about both the near year and the longer term here, if you will, just a little bit more?
spk00: Yeah, thank you, Julian. I'm going to turn to Brian to discuss load.
spk03: Yeah, good morning, Julian. So when we look at 2024, the setup on load growth is really underpinned by three main points. So you start with economic development visibility we have in 2024, projects that are in late stage construction that are coming online. And we've got that on one of our slides. And that represents a little under a 1% growth as we look into 2024. On the residential side of things, you know, we've seen this normalization coming out of COVID of return to the office, right? During COVID, we had a lot of residential usage at homes. As return to the office, you saw this kind of lower usage at homes, more in commercial businesses. And in the back part of 2023, we saw that level out. So we will start growing residential more in line with customer migration trends, which has been really strong, 1.7, 1.8% in recent years. And so residential growth, we expect to be on an upward trajectory. And then lastly, the existing CNI customers, where we saw a reduction in load in 2023, and we talked about it throughout the year. Those customers are very optimistic in 2024. They've kind of seen a rebound happening maybe mid-ish year. So those three factors give us confidence that 2% load growth in 24 is definitely in our sights.
spk00: And over the long term Julian you know all of the things that Brian talked about right we're going to continue to experience customer migration or existing customer base continues to. demonstrate some strength over the five year period, but probably the most you know new or significant driver is this economic development load and we've given you a range of what we're seeing. And what we've put on the slide are the things that we believe have a high degree of confidence of being achieved. So dirt is moving, letters of agreement have been signed, and we're moving forward. And so the combination of our existing base population migration and the strong economic development gave us confidence to raise the long-term growth rate.
spk07: Got it. Excellent. So it sounds like things have re-accelerated here even just quarter over quarter even, just on the margin.
spk00: Well, and I think, Julie, we were continuing to grapple with this economic development all through 23 and came to our filing here in the Carolinas in January. really reckoning with where we think this is going. So we have continued to mature our own thinking, working with our customers, working with the prospects coming to the area, and believe this represents a really solid range. And when we're looking at that range, the growth is going to come along with it on megawatt hours, and that's what you're seeing in our update.
spk07: Great. Thank you, guys. See you soon.
spk02: Thank you. Our next question comes from Steve Fleishman of Wolf Research. Please go ahead.
spk09: Thank you.
spk02: Good morning, Steve.
spk09: Good morning, Lynn and Brian. Just one more on the nuclear PTC. Any sense on when we're actually going to get it, details from the Treasury in setting it, any update there?
spk03: You know, Steve, our best intel is the first half of the year. So we're thinking kind of sometime in Q2, we would get the final guidance from Treasury. And I think that's the general consensus.
spk09: Okay. And obviously, you'd need that to then go do the monetization, I assume.
spk08: Sure.
spk09: Sure. Yeah. Okay. On the financing, the equity plan, the DRIP and ATM, Any kind of color on how much of that can be done through DRIP relative to ATM? Yeah.
spk00: So, Steve, you should think about DRIP as being about $200 million a year. It's about 40% of it. Yep.
spk09: And then just on the gas plant filing in the Carolinas, when would these – When would you be roughly targeting for these plants to come online?
spk00: So 28, 29, Steve. Combined cycle plants 2 and 28, or I'm sorry, CTs 2 and 28, CCs 1 and 28, 1 and 29. OK.
spk09: And obviously some of the capital would be hitting and AFDC hitting within the end of your point.
spk00: Yes, you start to see it. You know, the largest capital spend is in the last couple of years is construction, as you know from, you know, history on these. But you'll see us beginning to ramp up well within this five-year period.
spk09: Okay, great. That's it for me. Thank you.
spk00: All right.
spk02: Thank you, Steve. Our next question comes from David Arcaro of Morgan Stanley. Please go ahead. Your line is open. Hi, David.
spk06: As we think about the 1.5% to 2% low growth, I was just curious, is that concentrated in certain service territories more than others? Are you seeing certain states growing faster versus others in your footprint?
spk03: You know, David, I would think about that the Carolinas have seen the largest portion of the economic development prospects we see, but we do see healthy growth across our jurisdictions. Indiana, with this reshoring of manufacturing, has really seen economic development growing. Florida continues to grow in a really strong way at 2% customer migration trends, as well as the commercial businesses that support it. I would say Carolinas is slightly ahead of the others, but all of really, really good growth.
spk06: Okay, got it. Not several percentage points faster in any specific state, but fairly tightly grouped around there.
spk00: Yeah, and you know, David, I would say, you know, building on what Brian said, residential growth has been stronger in the Carolinas and Florida. Commercial and industrial in the Midwest has been good. And it's also been good in the Carolinas. So, you know, the growth kind of varies by customer class. But I would go back to where I commented a moment ago. We have a wealth of opportunities. And these are not only good for, you know, Duke Energy's growth, but they're good for our states. It's capital investment. It's job creation. Supply chain is coming with a lot of these manufacturers. So it's good for the service territories that we're serving.
spk06: Understood. Yeah, that's helpful. And I'm not sure if you gave this level of color, but just going forward, as you're thinking about all of these other CapEx opportunities to add to the plan, how are you thinking about financing that? Is there a rule of thumb for how much incremental equity you would need, you know, kind of per dollar of CapEx as you're expanding the investment going forward?
spk00: You know, David, I think it's premature to to talk about that because the first thing that we'll do is run through capital optimization and allocation, putting the capital in the area that both delivers the most customer value and is delivering the best returns. And I think we'll have more on this refinement of capital as we move through IRP approvals in the Carolinas this year and then Indiana next year 10-year site plan as well. So we'll continue to keep you updated. And our commitment remains to growth and a strong balance sheet.
spk06: Okay, great. I appreciate the color. Thanks so much.
spk02: Thank you. The next question comes from Nicholas Campanella of Barclays. Please go ahead.
spk01: Hey, thanks for taking my questions today. Good morning. Hey, Morten. So I guess just the payout ratio, you're taking that down, obviously, which seems very prudent. I know you've already been kind of growing into a lower payout ratio over time. The dividend growth's been lower than the EPS growth here. So just, I'm kind of wondering just how to think about your five to seven EPS CAGR now, like where you are in that range. Are you at the high, low, or midpoint of that? And then when do you get back into this kind of 60 to 70% payout ratio in the plan? Thank you.
spk00: So Nick, pulling that all together, we're very confident in our 5% to 7% growth rate. We have been building the capital plan to accomplish that as well as the regulatory mechanisms for several years. And so what we're putting in front of you, we have a high degree of confidence on. And as a result of that, we see the payout ratio declining over the next five years. We'll be under 70% in 2024. And so as we look at our commitment to the dividend. We intend to continue growing it. We're committed to the dividend as we have been for a long period of time, but believe in this moment with the level of capital that we have that introducing some financial flexibility in our range so that we can make good choices around dividend, capital, and growth is just prudent. And so as you know, we'll look at dividend every year. The board is involved in that approval process. But given the total composition of growth and dividend, we believe a 60% to 70% payout ratio is appropriate at this point.
spk01: Okay. I appreciate that. And then I guess just, I know you just recently filed in Florida. You have a history of, there's a history of settlements in that state and constructive outcomes. Is just anything kind of changing in regulatory strategy that wouldn't allow you to pursue another settlement in the future?
spk00: Now Nick what we have accomplished so far is procedurally what we need to do to provide notice and the filing would follow late March early April. As you know, we have a history of engaging with intervening parties and all of our jurisdictions as part of the regulatory process and we will do endeavor to do that in Florida as well and we'll keep you posted every step of the way. It's a very constructive jurisdiction in Florida, understanding the need for infrastructure to balance the growth that the state is maintaining or achieving, and also maintaining critical infrastructure investment for reliability, storm response, et cetera. So we'll look forward to keeping you updated on the rate case.
spk05: Thank you.
spk02: Thank you. The next question is, from the guest Chopra of Evercore. Your line is open. Please go ahead.
spk05: Hey, uh, good morning. Thank you for, uh, good morning, Lynn. Maybe just, uh, I think the, uh, the, the, the equity 500 million a year, uh, you know, two and a half total for the plan versus the CapEx raises towards the low end. I think you might have said 30 to 50% fund to lose equity in the past. So maybe just a little bit more color, kind of what puts you at that low end of the range since, you know, sort of we discussed this in November last year.
spk00: Yes. And Durgesh, I think about all of these variables, the capital, the regulatory outcomes, the equity issuance, the fact that we see You know, nuclear PTC is something that we've been able to negotiate in a credit-supportive way. You've got all of those variables that we evaluate in establishing, you know, the plan that we have in front of you and believe that at this level, that 30% ratio gives us the best match between the growth we're trying to achieve as well as the strength of the balance sheet. And so that'll be, you know, that's always our goal is to achieve both for investors, and we believe we've accomplished that.
spk05: That's helpful, Lynn. Thank you. And then the rate base is, you know, when I look at year-over-year growth rate and rate base, it's pretty healthy. You know, it's within your 5% to 7% EPS, long-term EPS growth guidance. Do we think about annual EPS growth rates? within that range as well in that 5% to 7% range or is that more kind of a CAGR approach and back-end weighted?
spk00: No, Jurgesh. We endeavor to hit it every year. Every year. And that's how we plan our investments. That's how we plan our strategies around regulatory and otherwise. And so that's how I would share it with you year-over-year.
spk05: That's very clear. Thank you, Lynn. I appreciate the time.
spk00: Thank you.
spk02: And our next question is from Ross Fowler of UBS. Please go ahead.
spk08: Morning, Lynn. Morning, Brian. How are you?
spk03: Hi, Ross.
spk08: Morning, Ross. So first one, maybe to follow up on Nick's question, just shifting that to Indiana, how are you thinking about the timing and what considerations should we be thinking about for the Indiana
spk00: So, Russ, we evaluate, as you know, periodically where we are with capital investment, rate case, you know, cycle. And in Indiana, we have a lot of investment in riders, but some of those riders are 80% of the investment. So we need a general base rate case to pick up the other 20%. We also have in front of us in Indiana CPCNs for generation that are in our regulatory minds or regulatory calendar. So we'll continue to evaluate that. What is the right timing? When do we go in? How does it relate to other things that we're trying to accomplish in Indiana? And by flagging it for you in this call, we're indicating that it's under review. And we'll keep you posted as we get closer to a final decision.
spk08: Thank you. I appreciate that very much. And then maybe one for you, Brian. Excuse me. A little under the weather today. But as I look at the bridge to 2024, over 40% of that's coming from this $0.12 of other. And I think I get the higher interest rates impact. And maybe can you scale or scope the other things in there for me? There's a lower tax rate. And then there's return from investments. I think that's probably coming from either Bison, the insurance side, or the NMC stuff in Saudi Arabia around Petrochem. How do I think about that as I look at my 2024?
spk03: Yeah, I would point to the tax optimization, Ross. You know, in 2023, we had an opportunity for an item in tax optimization that was I would say outsized from our normal tax optimization work that was part of our agility efforts, which you would expect us to do because we had record mild weather. We were looking at every opportunity to offset that. As we look forward in 2024, we're seeing a more consistent level of tax optimization that we had in previous years. So that's the other major driver in the other section. But we still have a robust set of tax optimization, and our tax team is doing fabulous work in that front. But that's what I'd point to. And, you know, we signaled our agility of $300 million that we were pursuing in 2023. About half of it would be sustainable. And I would point to that tax optimization as about that half that's not sustainable.
spk08: Okay. Okay. I got you. Thank you, Brian, for that clarity. Appreciate it very much.
spk02: Thank you. This concludes our Q&A session for today. So I'll turn the call back over to Lynn Good for any closing comments.
spk00: Well, let me close by just thanking everyone for participation today. I know when we do these annual updates, we give you 40 or 50 slides to digest. So we're also available for questions and comments. The IR team, Brian, I'm available and really appreciate your interest and investment in Duke. Thanks so much.
spk02: This concludes today's call. Thank you for joining. You may now disconnect your line.
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