Duke Energy Corp
NYSE:DUK
Earnings Call Analysis
Q3-2023 Analysis
Duke Energy Corp
The company reported an adjusted earnings per share (EPS) of $1.94 in the third quarter, which is an increase from $1.78 for the same period last year, showcasing strong financial performance and continued progress on regulatory outcomes and business simplification. Investors can be heartened by the company's ability to navigate through and even capitalize on regulatory changes, which is a testament to its operational excellence.
Management is actively working on the cost structure to combat the impacts of mild weather and weaker industrial volumes anticipated in the coming year. They are implementing agility measures, savings opportunities, and efficiency improvements without compromising safety and customer service.
Significant regulatory approvals in North Carolina have set the stage for considerable future growth. The North Carolina Utilities Commission's approval of a rate base increase, performance-based regulation, and an improved return on equity (ROE) enhances investor confidence in the company's financial prospects. Furthermore, settlements reached regarding the Duke Energy Carolinas rate base increase and capital investments reinforce the company's position for sustained expansion.
The company filed a unified resource plan that emphasizes diversification of energy resources, including renewables, battery storage, and natural gas, to meet growing demands in key regions. Plans for solar procurement and additional natural gas generation affirm the company's commitment to grid reliability and the transition toward cleaner energy sources.
The completion of the commercial renewables sale signifies the final step in the company’s pivot toward full regulation. This strategic repositioning, alongside regulatory successes across multiple jurisdictions, reinforces the company's resilience and readiness to deliver sustainable shareholder value despite macroeconomic headwinds.
The company's earnings growth was driven by a mixture of rate cases and riders, cost initiatives, and favorable weather conditions, offset by higher costs such as storm damage and interest expenses. They maintain an efficient tax rate, projected to be at the low end of the 11% to 13% guidance range, through ongoing tax efficiency efforts.
Looking ahead to the fourth quarter, the company targets $1.50 to $1.60 per share, benefiting from regulatory growth, cost management, and optimism about economic turnaround in mid-to-late 2024. The outlook is bolstered by positive trends in customer growth and economic development, particularly in key sectors such as battery, EVs, and data centers.
To maintain a robust balance sheet, the company is actively managing deferred fuel balances, reducing debt, and implementing settlements that support credit metrics. The targeted FFO to debt ratios for the upcoming years aims to reinforce creditworthiness while leaving room for capital increases to support the energy transition.
You don't have any saved screeners yet
Good morning. Thank you for attending the Duke Energy's third quarter earnings review and business update. My name is Matt, and I'll be your moderator for today's call. [Operator Instructions] I would now like to turn the call over to our host, Abby Motsinger, Vice President of Investor Relations. Abby, please go ahead.
Thank you, Matt, and good morning, everyone. Welcome to Duke Energy's Third 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 the reconciliation of non-GAAP financial measures. With that, let me turn the call over to Lynn.
Abby, thank you, and good morning, everyone. Today, we announced strong results for the third quarter, adjusted earnings per share of $1.94 compared to $1.78 for last year. During the quarter, we also made great progress on regulatory outcomes and simplification of the business. This momentum is underpinned by our strong fundamentals. We have a track record of operational excellence and serve growing jurisdictions with a long runway of investment opportunities. This positions us well for the future and gives us confidence in reaffirming our long-term earnings growth rate of 5% to 7%. For 2023, we continue to work on cost structure to offset mild weather and weaker industrial volumes. Brian will talk more about load and cost agility efforts, but I want to take a moment to recognize the incredible work across the organization to mitigate pressures in 2023. Across the company, agility measures, savings opportunities and efficiency improvements are well underway, while never compromising on our commitment to safety and customers. We expect to finish the year within our guidance range trending to the lower half of the range. Moving to Slide 5. Let me spend a moment on the meaningful progress we've made in North Carolina. In August, the North Carolina Utilities Commission approved our Duke Energy Progress rate case application and related settlements. This order is the culmination of years of work with stakeholders and represents a significant milestone, the first implementation of performance-based regulation, including multiyear rate plans authorized by HB951. The order approved a retail rate base of $12.2 billion, a $1.6 billion increase from our last case, along with roughly $3.5 billion in future capital investments in the multiyear rate plan. Importantly, the order also recognized the rising cost of capital increasing the allowed ROE to 9.8% and the equity component of the capital structure to 53%. This outcome positions us well to continue delivering value to customers while supporting the cash flows of the company. New rates and residential decoupling were implemented on October 1. Turning to the Duke Energy Carolinas rate case. In late August, we reached a partial settlement with the public staff on many aspects of the case. The settlement provides clarity on retail rate base of approximately $19.5 billion, a $2.6 billion increase from our last case and includes nearly $4.6 billion of capital investments in the multiyear rate plan. A second settlement with the public staff further narrowed the open items in the case and also addressed nuclear PTCs, which Brian will provide more detail on in a moment. We expect the NCUC to issue its decision by the end of the year, and expect permanent rates to be in effect by January 2024. We're pleased with the constructive outcome at DEP and look forward to finalizing the DEC rate case in the coming weeks. North Carolina is our largest jurisdiction. So constructive outcomes are critical to supporting a strong balance sheet and derisking our 5-year plan. Turning to Slide 6, I'd like to highlight our updated Carolinas resource plan, which is driving material growth and capital investment opportunities as we lead the nation's largest energy transition. In mid-August, we filed our updated resource plan with the Public Service Commission of South Carolina and the North Carolina Utilities Commission. The single unified resource plan for the Carolinas is designed to meet the needs of this growing region, spurred by rapid population growth and significant economic development activity. The plan maintains an all of the above strategy with a diverse deployment of additional resources, including renewables, battery storage and natural gas as well as energy efficiency and demand side management. It also provides the opportunity to evaluate emerging technologies, pursue an early site permit for advanced nuclear and early development activities for expanded pumped storage hydro at Bad Creek. The filing included details about our annual solar procurement, which targets over a gigawatt of new solar each year beginning in 2027. It also outlines plans to build additional natural gas generation to maintain reliability and affordability as coal plants are retired. Since the resource plan filing, we filed pre CPCNs with NCUC, for a combined cycle plant on September 1 and combustion turbines on November 1. We will make our full CPCN filings in the first quarter of 2024. Similar to previous filings, the Carolinas resource plan is based on significant stakeholder engagement and outlines multiple portfolios, each of which preserve affordability and reliability while transitioning to cleaner energy resources. Next steps will include hearings in both states in the spring of 2024. We expect an order in South Carolina in mid-'24 and an order in North Carolina by the end of '24. Turning to Slide 7. With the closing of the Commercial Renewables sale last month, our portfolio repositioning is complete. We are now a fully regulated company, operating in some of the fastest-growing and most attractive jurisdictions across the U.S. I just mentioned some of our progress in North Carolina and our other utilities continue to deliver as well. At Piedmont, we recently received South Carolina Commission approval of our settlement in our RSA proceeding. We also received approval of our settlement in our ARM proceeding in Tennessee. These annual rate updates allow for efficient recovery of investments as we continue to modernize our natural gas system. And at DEC South Carolina, we've made significant investments since our last rate case in 2019 and are evaluating the timing of our next rate case application. These investments have strengthened the grid against storms, reduced outage times and maintained a high level of reliable service our customers expect. In Florida, we're seeing some of the fastest customer growth in the state and have efficient recovery mechanisms for our grid and solar investments. Our response to Hurricane Idalia in September, yet again demonstrated the value of our grid-hardening investments. The storm caused over 200,000 outages, and we restored power to 95% of customers within 36 hours. Further, our investment in self-healing grid technologies saved more than 7 million outage minutes for customers. Shifting to the Midwest, in October, the Kentucky Public Service Commission approved the new rates in our electric rate case, which utilized a forecasted test year. And the commission approved a 9.75% ROE, a 50 basis point increase from the previous case as well as increasing the equity component of the capital structure to 52%. Across our footprint, we've built considerable momentum over the last year, and our long-term organic growth strategy has never been more clear. This past year has made our company stronger and more agile as we've responded to macroeconomic headwinds. I'm confident we're well positioned to deliver sustainable value and 5% to 7% earnings growth over the next 5 years. And with that, let me turn the call to Brian.
Thanks, Lynn, and good morning, everyone. I'll start with a discussion on quarterly results. As shown on Slide 8, our third quarter reported earnings per share were $1.59, and our adjusted earnings per share were $1.94. This compares to reported and adjusted earnings per share of $1.81 and $1.78 last year. Please see the non-GAAP reconciliation in today's materials for additional details. Within the operating segments, Electric Utilities and Infrastructure results were down $0.01 per share compared to last year. We experienced earnings growth from rate cases and riders, favorable weather and lower O&M from our cost mitigation initiatives, which I will discuss further in a moment. These positive items were offset by lower weather-normalized volumes, higher storm costs and higher interest expense. Shifting to Gas Utilities and Infrastructure. Results were up $0.01 due to riders and customer growth. And within the Other segment, we were up $0.16 over the prior year, primarily due to a lower effective tax rate which reflects the ongoing tax efficiency efforts in the company. We expect our full year 2023 effective tax rate to be at the low end of our 11% to 13% guidance range. As I mentioned, we are tightening our full year 2023 guidance range to $5.55 to $5.65. We entered the year with 1 of the mildest winters on record. And although weather improved in the third quarter, we remain $0.20 below normal. We also continued to see weakness in volumes estimated at approximately $0.20 year-to-date, some of which may be attributable to weather, but also to a softening of industrial load and return to work for residential customers. To mitigate the impact, we have increased our 2023 agility target to $0.30, which includes tactical O&M savings a lower effective tax rate and other levers. As we look to the fourth quarter, we expect a strong finish to the year, targeting $1.50 to $1.60 per share. Our original plan was back-end loaded due to growth from rate cases and riders. We will also see the benefit of our ongoing cost management efforts. We are closely monitoring volume trends and have included fourth quarter drivers in the appendix. Turning to Slide 9. Let me discuss more specifics on volume trends. Volumes are down 1.2% on a rolling 12-month basis. Many of our industrial customers are acknowledging a near-term pullback, managing inventory levels and cost in a disciplined way due to uncertainty in the broader economy. Most are describing the pullback is temporary, and there is optimism about a turnaround in mid- to late 2024 and into 2025. We continue to see strong customer growth from population migration and robust economic development, giving us confidence in growth over the long term. Based on recent success in economic development efforts in key sectors such as battery, EVs, semiconductors and data centers, we see meaningful load growth over the next several years as outlined on Slide 9. For example, in 2024, we expect economic development projects coming online will add between 1,000 and 2,000 gigawatt hours. As we look further out, we have line of sight to 7,000 to 9,000 gigawatt hours by the end of 2027, giving us confidence in our 0.5 to 1% growth rate. Turning to Slide 10. Let me spend a few minutes on 2024. A Consistent with historical practice, we will provide 2024 earnings guidance and our detailed capital and financing plans in our February update. Today, we have provided growth drivers for 2024. We've executed an active regulatory calendar this year that has yielded constructive outcomes as we head into next year. The multiyear rate plan in DEP will be in effect for a full year and we expect permanent rates under the DEC multiyear rate plan to be effective in January. In Florida, we will see the impact of the third year of our multiyear rate plan and growth from storm protection plan investments. In the Midwest, we'll see the impact of our Kentucky rate case and grid riders in Indiana and Ohio. In the gas segment, we will see robust growth from rate cases, integrity management investments and customer additions. From a load perspective, we project a pickup in 2024 from return to normal weather. Additionally, while we continue to closely monitor customer usage trends, we expect higher weather-normalized volumes driven by economic development activity and residential customer growth. Recall, residential decoupling will be in place in 2024 in North Carolina. So both DEC and DEP revenue growth will be based on customer increases, which have been robust. We expect interest rates to be higher for longer, resulting in increased financing cost in 2024. For O&M, we have aggressive efforts underway to sustain all cost savings identified in 2022 for 2023 as well as about half of the agility efforts we identified during the course of 2023 to mitigate weather and volumes. As we continue to pursue a technology-enabled, best-in-class cost structure, we expect our culture of continuous improvement to drive 2024 O&M to be lower than 2023 and significantly below our spending level in 2022. Moving to Slide 11. Let me highlight some of the credit supportive actions we've taken to maintain balance sheet strength. We continue to collect deferred fuel balances and have filed for recovery of all remaining uncollected 2022 fuel costs with about 90% approved and in rates. We're on pace to recover $1.7 billion of deferred fuel costs in 2023 and expect our deferred fuel balance to be back in line with our historical average by the end of 2024. As Lynn mentioned, we completed the sale of our commercial renewables business in October. With that, about $1.5 billion of commercial renewable debt will come off the balance sheet, further supporting our credit metrics. In August, as part of our ongoing DEC North Carolina rate case, we reached a settlement with public staff on the treatment of nuclear PTCs related to the Inflation Reduction Act. The settlement provides for the flowback of annual PTCs to customers over a 4-year amortization period. If approved by the commission, this settlement would provide savings for customers and be supportive to our credit metrics. We intend to utilize the transferability provisions of the IRA and have engaged an external advisor to run a formal auction-style process, providing access to a broad range of qualified buyers. With these positive developments, we are targeting FFO to debt between 13% and 14% in 2023 and 14% in 2024 through 2027. Finally, as I mentioned, we will provide an update in February on our financing plan, along with a comprehensive refresh and roll forward of our 5-year capital plan. We expect our capital plan to increase as we move further into the energy transition. We will take a balanced approach to funding the incremental capital, supporting our growth rate and balance sheet strength. As part of this balanced approach, we will evaluate modest funding through our dividend reinvestment plan and at the market program. The growth potential in our business is at a level we haven't seen in decades. For customers, we will achieve the right balance of affordability, reliability and increasing clean energy. And for investors, we will achieve growth while maintaining balance sheet strength. Moving to Slide 12. We're executing on our priorities and are excited about the path ahead as a fully regulated company. We operate in constructive growing jurisdictions, which combined with our $65 billion 5-year capital plan, strong operations and cost efficiency capabilities give us confidence in our 5% to 7% growth rate through 2027. Our attractive dividend yield, coupled with long-term earnings growth from investments in our regulated utilities, provide a compelling risk-adjusted return for shareholders. With that, we'll open the line for your questions.
[Operator Instructions] The first question is from the line Shahriar Pourreza with Guggenheim.
I know you mentioned in your prepared remarks that you'll be obviously updating the capital plan in February, as you always do. And directionally, you're talking some upside bias with CapEx, but maybe you can help at least frame the potential magnitude. So is it kind of supportive of the 5% to 7% or more potentially better? And where you see the increases coming from? So sort of the various buckets in which states as we think about CapEx upside?
Sure. And Shar, the capital is really underpinned by the integrated resource plans that we have filed. And so if you look at the Carolinas alone, the filing that we made in August compared to where we were in 2022, we see load growth and we also see the need to raise the reserve margin as a result of all of the growth going on in this region and the winter peaking nature. And so if you look across all of the types of megawatts from solar to battery, natural gas, et cetera, you see an increase there, and that will become reflected more fully in our capital plan, of course, working through that process with the commission in '24, but we see a need for additional megawatts in the Carolinas really driven in large measure by population growth, economic development and reserve margin. We're also moving deeper into generation transition in Indiana. So as we have filed integrated resource plans and we've accelerated our thinking around the timing of coal retirements, we see natural gas coming into the picture in Indiana as well as renewables. And so CPCNs will be filed in the next several months, really setting the cadence for Indiana. And then I think you know on our regular schedule in Florida, we will be updating the multi rate plan effective 1/1/25 and so expectations for capital spending there will be updated. And then the gas business continues to see not only extraordinary growth for a number of customers, but integrity management continues as capital. So we are in an extraordinary period of growth in all of our jurisdictions. It's transparent. It's filed with our commissions in the form of integrated resource plans on the electric side and clear on the gas side as well. So we're anxious to provide that update to you in February and have a chance to talk further about it at that point.
Got it. And then, obviously, you highlighted that the current base plan assumes no equity through '27, which is consistent. But you're obviously leaving it open for potential equity to fund spending above the current base plan. As we think about sort of your balance sheet capacity, should we be assuming that every dollar of incremental CapEx is funded with a balanced cap structure, so 50-50 debt equity? Or is that too simplistic and we should be also factoring other sources of equity funding above straight equity? So just, I guess, help us bridge "balanced approach" with balance sheet strength.
And Shar, I would think about balanced approach kind of in the 30% to 50% range. And when I think about equity, we've talked about shareholder-friendly equity. You have seen us accomplish that with our transaction in Indiana. I don't know how much potential exists for that given present cost of capital, but we would, of course, explore that and then evaluating the role of dividend reinvestment and at-the-market programs as well. I would also say that the other couple of things that we're watching, we have yet to finalize the DEC case. So we'll have more visibility on that in December. And then waiting for treasury guidance on these nuclear PTCs and the transferability market, those are also very consequential from cash flow standpoint. So I feel like we have just a number of levers available to us, and we will exercise them in a way that maintains our growth rate, but also underpins the strength of the balance sheet.
Next question is from the line of Julien Dumoulin-Smith with Bank of America.
Just coming back at the same direction as Shar here, just in terms of balance sheet, obviously, has been a source of continued conversation as illustrated by the first couple of questions here. How do you think about maybe shoring up the balance sheet incrementally in addition to funding these incremental upside here? I just want to make sure that we're clear about how you think about that piece of it, right? Obviously, coming into a position of strength here with the rate case resolution that you already -- or resolutions that you alluded to by 4Q here, but how do you think about kind of getting to that next step where perhaps conversation's a little less focused therein.
Yes, Julien, thanks for that. And I as we lay out what we laid out today, I think you're watching us strengthen the balance sheet, $1.7 of deferred fuel to be collected in '23, another $1.7 billion of deferred fuel to be collected in '24. And the multiyear rate plans, which have not only given us an opportunity to reset rate base from historic spending but also prepare and put into effect rates for future, I think those will be credit positive. The transferability that I mentioned on IRA will be credit positive.
And so as we bring to you a financing plan and think about the future and the continued growth that we see from capital investment, we will be targeting a minimum of 14% as we go forward and feel like we have the tools to accomplish that.
The next question is from the line of Steve Fleishman with Wolfe Research.
Just so the -- you mentioned a couple of times the monitoring the sales trends and I know you gave a little bit of color on the return to work. And could you just talk a little bit more -- in more depth on what's going on with sales in your territories and some of the recent weakness?
Sure. And Steve, I'll give it a start, and then I know Brian will have something to add to it. So we've seen some weakness in '23. And I think you saw us early in the year trying to figure out do we have volume weakness or is it weather because we had such extraordinarily weak weather in the first and second quarter. But the weakness has continued into the third quarter. I would mention textiles, I would mention paper as 2 industries that have been impacted. And then outside of those industries, we're hearing from our customers, supply chain, labor, interest rates being an impact to them that they're adjusting to. They also -- many of them have inventory they're working through, so they've dialed back production. And production, of course, hits us in terms of lower volumes. But I would say there's optimism in that same industrial group about a rebound later in '24 and into '25. And what I would further say is we have evaluated this. Residential, of course, return to work, but we think we're probably where that return to work trend is situated. Meaning no more impact from return to work. I think we've pretty well worked ourselves through that transition. And then for our largest jurisdiction, we go to a decoupled environment in 2024, and customer growth continues to be very strong and it's customer growth that will drive revenue.
And then on the industrial side, the rebound is positive on existing customers, but this economic development has been extraordinary. And we've given you a sense of what that can look like. It starts to layer in as early as '24. And so that gives us some confidence around our longer-term growth rate that we've got customers sort of working through the macro trends here in the short term. But over the long term, we continue to see this economic development being incredibly strong. And I'm sure you saw yesterday in the Journal, that Toyota battery plant is expanding further, also sitting here in the North Carolina territory. So that's what I would share. And Brian, what would you add?
I would add, Steve, North Carolina residential has contributed a significant amount to the weakness this year, over half. So going to decoupling is something we need to really emphasize, it's going to mitigate risk and volatility going forward. And our Florida jurisdiction has seen strong growth in the residential space. It's been a hot year in Florida, but we've also had strong population migration, strongest in the state of Florida. So we see positive shoots coming out, and we do see this industrial load in the Carolinas turning as we talk to customers kind of mid to late next year.
Great. That's helpful. One other separate question. Just on when you're doing your plan and your growth rate from the standpoint of interest rates, are you generally just kind of using whatever the forward curve is of rates for what -- for financings or refinancings and the like?
We are generally -- yes, absolutely, absolutely. And as you know, that's a dynamic area. So we look at a range, a range of outcomes. We did that in '23, we'll do it again in '24. And as we talked about all of the work we're doing on cost structure, our objective is to offset the impact of interest rates in 2024.
The next question is from the line of Nick Campanella with Barclays.
I just wanted to ask, there's been some pretty significant changes in the Carolinas in terms of just rate structure with these NYRP and I know that you're a little lower in the range for fiscal '23, but could you just help frame EPS volatility '23 versus '24? And the residential decoupling just stands out to us, if you could just frame how that informs your confidence to hit the 5% to 7% implied EPS growth for '24 specifically?
So Nick, I would confirm that it does underpin our confidence in 5% to 7% growth. This modernized construct in the Carolinas is consequential. It's kind of a first in the history of the utility that we will have multiyear rate plans, the ability to set price as we go forward, of course, delivering value to customers every step of the way, but also more closely matching the expenditure of capital with return. And I would add to that, our confidence in the capital underpinning that 5% to 7% growth, very transparent, integrated resource plans, the outline what it's going to be necessary to serve this growing state.
So the Carolinas are very well positioned for the future. And as Brian mentioned a moment ago, continue to see extraordinary growth in Florida. And we have strong capital in Florida and grid and solar will be updating our multiyear rate plan, and our investment in the Midwest continues well along both generation and grid in Ohio, for example. So I feel like we've got all of the elements to underpin our confidence in the growth and the jurisdictions are constructive jurisdictions that find the right balance between benefits to customers and investors, and we're confident in the future.
Okay. Great. And what about just on O&M. I know in slides where you kind of talked about 50% sustainable after '23. But just looking back to prior calls, I think we've kind of talked about 75%. So just maybe that's just different buckets and I'm mischaracterizing it, but could you help reconcile that view? And then how do you just think about '24?
Yes. And Nick, I really appreciate that question because we have 2 different $300 million that I think as I look at some of the commentary has been confusing to you all. So let me step through it for you. You may recall that we entered '23 with a cost initiative identified at driving out $300 million of cost, primarily in the corporate center. And we said to you at that time we thought 75% of that $300 million would be sustainable. We have executed on that throughout 2023 and have been confident that the 75% is going to 100% that we'll be able to sustain all of it into 2024. And then further, we have developed mitigation plans based on weak weather and volume in 2023, which is including not only O&M, but other levers, including tax ideas, those total $300 million as well. And we think 50% of those are sustainable into 2024. And we also highlighted on our drivers schedule that we will continue to look for cost savings ideas, part of the continuous improvement structure. That's what we're talking about on Slide 10. So we believe we have various elements in place to continue to drive O&M lower. We think '24 will be lower than '23 and that's just part of our conviction to continue to drive productivity and efficiency in our operations.
The next question is from the line of Durgesh Chopra with Evercore.
All my the questions have been answered. I just had a -- all my questions have been answered. Just a quick clarification, Lynn. I think in response to the first question, you mentioned 30% to 50%. I believe you were referring to the equity content of any incremental CapEx. Could you just clarify if that -- if my understanding is correct there?
That's correct, Durgesh. It was in response to what does balanced mean. And so that's the range to think about. And of course, we'll bring a concrete financing plan and capital plan in February that will lay this out more clearly. But as we think about all of the tools and levers and cash flow opportunities that we have across all of our business, that is the range I would consider for incremental equity matched with incremental capital for growth.
Next question is from the line of Carly Davenport with Goldman Sachs.
You've got John Miller on for Carly. Maybe just to start with the North Carolina resource plan, just curious if there's any areas where you expect, if any, to get some pushback? Obviously, a healthy chunk of renewables in there with the wind and solar, but also a share of natural gas as well. So curious if you're expecting the focus on reliability with that to outweigh any ESG concerns with the natural gas?
John, I appreciate that question. And I'd start by saying these integrated resource plans are informed by a very robust stakeholder process. And as you imagine pulling stakeholders together, there are different points of view across the spectrum from renewables to batteries to natural gas to nuclear some pro, some con. But we believe what we've put forward is a very balanced all of the above strategy that provides the right balance between reliability, affordability and increasingly clean, which is our commitment to the state.
So we think all of those elements will be closely reviewed and evaluated as part of the process in front of the commission. And we believe we'll work through this in a very constructive way, consistent with the way we've moved forward in the previous plans, and we'll keep you posted every step of the way.
Got it. That's helpful. And then maybe just 1 follow-up to the O&M discussion. I know that of the business agility savings will come in 4Q, but as we are now in the year at November. Just curious if you have any indications of where you're trending towards that target of 50% being sustainable.
We're going to make 50% sustainable.
That's right. Yes. We're there, John. We have line of sight to the Q4 efforts because a lot of it was tied to the fall outage season as well as just a culmination of work that takes a couple of months to implement, and we've evaluated the ability to keep those going on for 2024 and beyond, and we've confirmed that.
Thank you for your question. There are no additional questions waiting at this time. So I'll pass the call back to Lynn Good for any closing remarks.
Well, thank you all. Appreciate your engagement today investment at Duke, and we're looking forward to seeing all of you at EEI. So we'll continue the conversation then. And of course, IR and Brian and I are always available. So thanks so much.
That concludes the conference call. Thank you for your participation. You may now disconnect your lines.