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spk11: If you're standing by, and welcome to the Atra G Corporation's first quarter 2022 earnings release and teleconference. At this time, all participants are in listen-only mode. After the speaker's presentation, there will be a question and answer session. To ask a question during this session, you'll need to press star 1 on your telephone. As a reminder, today's program is being recorded. I would now like to introduce your host for today's program, Bill Abler, Vice President, Investor Relations. Please go ahead, sir.
spk13: Good morning, and thank you for joining us. We will begin today with comments from Entergy's Chairman and CEO, Leo Denault, and then Drew Marsh, our CFO, will review results. In an effort to accommodate everyone who asks questions, we request that each person ask no more than two questions. In today's call, Masterville will make certain forward-looking statements. Actual results could differ materially from these forward-looking statements due to a number of factors which are set forth in our earnings release, our slide presentation, and our SEC filings. Entergy does not assume any obligation to update these forward-looking statements. Management will also discuss non-GAAP financial information. Reconciliations to the applicable GAAP measures are included in today's press release and slide presentation, both of which can be found on the investor relations section of our website. And now, I will turn the call over to Leo.
spk02: Thank you, Bill, and good morning, everyone. Today, we are reporting first quarter adjusted earnings of $1.32 per share. a very good start for the year. With favorable weather and higher than planned retail sales, we are ahead of schedule and solidly on track to achieve our 2022 objectives. And we remain on track for our longer turnout outlooks. During the quarter, we continue to execute on both our near and long-term deliverables, just as we have over the last several years. We've made demonstrable progress on our operational, strategic, and financial objectives. Operationally, I'll start with some notable regulatory updates. We've continued to make meaningful progress on storm cost recovery. Texas is done, and Louisiana's securitization proceeds from the 2020 storms, plus $1 billion towards Ida, will be completed in the coming weeks. Entergy Louisiana's filing for the balance of Ida will be completed within the coming days, and the Entergy New Orleans filing will follow later this year. A financially strong utility is important for customers. Drew will discuss how securitization progress supports our balance sheet strength. As expected, Entergy Mississippi filed its annual formula rate plan, which enables continued customer-centric investment and supports our financial outlooks. We're continuing to drive progress on enhancing the resilience of our system, which benefits customers It supports local economic activity as well as our growth plan. Entergy, Louisiana completed an important transmission upgrade in the southern part of the state. This $86 million project replaced approximately 80 structures to increase resilience on several miles of critical path transmission in Lafourche Parish, an area that was severely affected by Hurricane Ida last year. To create a solid foundation, the new infrastructure was placed in steel casings. The line was built to withstand wind speeds of 150 miles per hour and will improve the resilience of the electric system. Energy Louisiana also completed a $100 million project in north Louisiana that positions the region for economic growth. The West Monroe Project will provide additional transmission capacity, improve reliability, and is built to withstand extreme weather events. What that means for customers is enhanced reliability and resilience, better integration of clean generating resources, and economic benefits through improved access to low-cost power. Bottom line is the energy team continues to focus on delivering operational excellence across all facets of our business. Strategically, I'll start with our merchant business wind down. The last step in our merchant nuclear exit is nearly complete. Palisades is on track to shut down at the end of May with a sale to Holtec following around mid-year. The Palisades team is finishing strong, and I would like to thank them for their dedicated service. We have worked to help employees with their career goals beyond the plant shutdown. Many will continue to work for Entergy at other locations. Some will continue to work for Holtec on decommissioning, and others are retiring. As you know, DOE recently announced a program to save nuclear plants that are about to shut down. Michigan's governor issued a letter encouraging utilization of this program keep Palisades open. We are supportive of federal initiatives to keep nuclear plants operating. However, we are five years into the Palisades shutdown process and we are far down the path. There are significant technical and commercial hurdles to changing course at this point. That said, alongside Halt Tech, we will work with any qualified party that wants to explore acquiring the plant and obtaining federal funding. But I do want to be very clear This does not change our strategy. Entergy is exiting the merchant nuclear business. In the event Palisades continues to operate, it will not be part of Entergy. Across all of our operating companies, we continue to be a critical partner to support strong economic development, bringing new businesses, new jobs, and new tax base to the communities we serve. For example, Entergy Arkansas, along with the Wynn Economic Development Corporation, announced completion of the Select Site Certification for a 37-acre industrial site. Certification streamlines the site selection process. Initiatives like this help track new businesses and new projects like the U.S. Steel expansion that was announced earlier this year. Over the past five years, our economic development team has helped bring to fruition close to 300 announced projects, $42 billion of capital investments, and more than 25,000 jobs. These outcomes have been critical to the economic health of our communities and have been a significant factor in the 9% cumulative industrial sales growth we have achieved over the past five years. And we continue to expect significant industrial expansion in the next several years. As we have discussed, the growth from our industrial customers has been driven in large part by cost, labor, logistics, and regulatory advantages of the Gulf Coast, as well as favorable commodity spreads, which continue to support expansion. Further, the current geopolitical state of the world makes the U.S. and the Gulf Coast in particular a top choice for stability. LNG exporters in the Gulf are being called on to expand production to help reduce Europe's reliance on Russian energy imports. This opportunity represents a win for our customers, communities, and owners, not to mention the global community. To help support our customers' growth and decarbonization objectives, we are driving progress to expand our renewables footprint. As of today, we have approximately 650 megawatts of renewable capacity in service, 625 megawatts of solar projects approved by regulators and in progress, 725 megawatts of announced projects, and up to 4,000 megawatts of RFPs. That's more than half of the 11,000 megawatts of renewable resources in our supply plan through 2030. We've made progress identifying new resources in active RFPs. Since our last call, Entity Texas concluded evaluations of its 2021 solar RFP. Several resources were selected totaling at least 400 megawatts from owned and contracted proposals. We also made selections from the Louisiana and Arkansas 2021 RFPs earlier in the year. We will provide additional details about the resources selected from these proposals once parties reach definitive agreements. We are also soliciting the next round of renewable proposals. Energy Arkansas recently issued its RFP seeking up to 500 megawatts of renewables to provide cost-effective clean energy, which furthers fuel diversity. Energy Louisiana also issued notice to proceed with renewable RFPs seeking up to 1,500 megawatts in Louisiana. Our customers' demand for decarbonization solutions, including green products, is not slowing down. The long-term solar market continues to look favorable based on an improving technology curve and higher natural gas price scenarios. However, we fully recognize the near-term cost and schedule pressures that solar projects are facing. Supply chain constraints have been exacerbated by the Department of Commerce investigation, which we expect will drive additional delays and the potential for further cost increases. These dynamics are affecting the entire U.S. solar industry, but we are continuing to work through these constraints and are executing on our solar expansion plans. It's important to note that not all of our projects are affected. Sunflower Solar in Mississippi are all the owned projects coming online this year. As its panel's on-site, the installation is nearly complete. Entergy's owned solar represents a relatively small portion of our three-year, $12 million capital plan. Roughly half of owned projects in the three-year horizon are not experiencing impacts of recent market constraints. A greater portion of our own projects are expected in the latter half of the decade which would be past the current market constraints. As we've said before, we have a large backlog of customer-centric investments and the ability to rotate capital into our plan if an opening presents itself. The bottom line is that we recognize the near and medium-term constraints and still see strong market fundamentals in the long term that supports our supply plan and customer objectives. On our last call, we told you about the new U.S. steel expansions. In support of this project and the customer's de-carbonization goals, Energy Arkansas filed for approval to acquire the 250-megawatt Driver Solar facility. Driver Solar is an example of how we can partner with customers to support their sustainability needs while accelerating the growth of our renewable portfolio within our regulated framework. It also highlights our unique growth strategy to help customers achieve the outcomes they desire which in turn drives outcomes for all energy stakeholders. Through more jobs and economic activity in our service area, increased capital deployment to support electrification, low growth offset costs, and higher rate of change towards societal decarbonization. Nuclear also plays a critical role in our customer decarbonization strategy. Entergy is one of the cleanest large-scale fleets in the nation due to our nuclear fleet. Customers are increasingly highlighting access to carbon-free resources as key to economic development. They are looking to reduce their carbon footprint, and many are indifferent to the type of carbon-free technology. We continue to see examples in the industry that reinforce the need to balance reliability, affordability, and environmental sustainability. Entergy's resource planning has always balanced these objectives. Our baseload newsletter plays a critical role. We have discussed the size of a long-term opportunity for energy to help our industrial customers to achieve their sustainability outcomes. We estimate an addressable market of approximately 30 terawatt hours by 2030. To put that into context, that's about 25% of our 2021 total retail sales. That's not to say that we won't capture the entire market, but we're working now to serve our customers' needs and maximize this opportunity. With many carbon reduction goals coming past 2030, we see even greater opportunities beyond the next 10 years. Realizing this growth will require significant investment that benefits all stakeholders. This will include meaningful transmission and distribution investment to reliably serve the load. Expansion of our renewable energy will go beyond the 11 gigawatts in our current 2030 resource plan. Financially, we continue to strengthen our balance sheet Beyond the securitization progress that I mentioned, we've also significantly reduced our remaining growth equities through 2020. Currently, only 25% of the original amount discussed at our 2020 analyst day remains. We're on track to achieve steady, predictable growth, adjusted EPS and dividends, and the opportunity to do even better. We're very excited about our upcoming analyst day on June 16th. We'll use that opportunity to provide a closer look into our multi-year strategy financial plans. That includes our plans to quickly advance resilience investment in our coastal region to lower storm risk for our system, our communities, and our customers, and to further expand our renewable support portfolio to support our customers' decarbonization goals. As I said, we've had a productive start to 2022. and we will continue to successfully achieve the milestones that keep us on track to deliver steady, predictable earnings and dividend growth, while maximizing operating efficiencies and investments to make our system the most resilient, reliable, clean, and affordable it can be. These are the outcomes our customers want by delivering them to create sustainable value for all our stakeholders. Before I conclude, I encourage you to read our recently released 2021 Integrated Report the future is on. Report lays out how we delivered results in 2021, discusses why we're optimistic and excited about energy's future. You can see how we integrate environmental, social and governance objectives to all we do. I'll turn the call over to Drew to review our first quarter results, as well as our financial strengths and outcomes.
spk14: Thank you, Leo. Good morning, everyone. Today we are reporting strong results for the first quarter. As you can see on slide three, we had adjusted earnings of $1.32 per share. The drivers are straightforward and keep us solidly on track to achieve our financial objectives for the year. We remain confident in our continued success, and we are affirming our guidance in longer-term outlooks. Turning to slide four, you'll see the drivers for the quarter. As a result of our continued customer-centric investments, we saw higher levels of revenue, as well as higher depreciation and interest expense. Other O&M increases included higher customer service support and nuclear generation expenses. The results for EWC are summarized on slide five. The drivers for that business are largely due to the shutdown and sale of Indian Point last year. As Leo mentioned, we expect to complete our exit of the merchant nuclear business in the coming months. major strategic milestones. Moving to slide six, operating cash flow for the quarter was higher than last year at $538 million. Higher utility revenue, lower fuel and purchase power payments, and lower pension contributions were the largest drivers. As a reminder, fuel and purchase power payments were significantly impacted by winter storm Uri in 2021. Non-capital storm spending was higher than last year, which provided a partial offset. Turning to credit and liquidity on slide 7, we continue to make progress on securitizations that will strengthen our balance sheet to produce significant cost savings for our customers. Our regulators recognize that financially healthy utilities benefit our customers. To that end, Entergy Texas recently completed securitization for its 2020 storms. And on the day of our last call, KLPSC approved storm recovery and financing for the 2020 storms plus a $1 billion down payment on Hurricane Ida. The approval included replenishment of Louisiana storm escrow to $290 million. Louisiana Secure Station is expected to be off balance sheet, and we anticipate a $3.2 billion issuance in the coming weeks. as Leo mentioned, we are targeting to receive proceeds by year-end. The timing of recovery will ultimately depend on the procedural schedule approved by the Commission. Entergy New Orleans is seeking approval from the New Orleans City Council to issue $150 million in securitized bonds to replenish the company's storm reserve. If approved, this reserve would enhance E&O's credit and ability to respond to potential future storms. In addition, E&O plans to file for IDA cost recovery later this year. Our net liquidity at the end of the quarter was $3.5 billion. It will be further supported by the Texas securitization proceeds received on April 1st and the $3.2 billion Louisiana securitization proceeds once they are received. Beyond securitization and liquidity, we continue to focus on resilience, which we will discuss in detail at our analyst day. Part of that discussion will include how we are actively applying for federal funding to help pay for resilience investment and mitigate customer impact. Looking at slide eight, it's been approximately two months since our last earnings call. In that time, we've reduced our equity needs by nearly $170 million through our ATM program, with roughly $570 million remaining to be executed between now and the end of 2024. Given the small amount, our plan is to close out the remaining needs with the ATM program. The four sectors shown on slide 9 represent nearly half of our industrial sales. And the fundamentals for our industrial customers remain robust in support of the continued growth and expansion. In addition, expansion of LNG export facilities is coming into the spotlight again. Majority of these potential LNG expansion projects reside within energy service territory. Looking forward to slide 10, we have a solid base plan with good visibility to achieve our guidance and outlook. We are also monitoring situations surrounding inflation and interest rates. We have not seen a meaningful impact on our operational results, and we remain on track to achieve our annual cost. As a result, we are affirming our 2022 adjusted EPS guidance range as well as our longer-term outlooks. As we move towards Analyst Day in New York in June, we're executing on our operational, strategic, and financial objectives and building on a solid foundation. In New York, we'll share our longer-term views on customer-centric investments and financial outlooks, and we look forward to seeing you there. And now, the Entergy team is available to answer questions.
spk11: Certainly. Ladies and gentlemen, if you have a question at this time, please press star then 1 on your touchtone telephone. If your question has been answered and you'd like to remove yourself from the queue, please press the pound key. We ask that you please limit yourselves to two questions. You may get back in the queue as time allows. Our first question comes from the line of Char Perez from Guggenheim Partners. Your question, please. Hey, guys.
spk09: Good morning. Good morning, Char.
spk10: Leo, from your prepared remarks, just quickly on Palisades, should we assume you don't want to even remain a short-term owner until the asset is potentially sold? So viability of the asset is really a whole tech question, or could there be changes to the whole tech agreement? And maybe just elaborate a little bit on some of the technical challenges like refueling and the capital that's needed to halt decommissioning, and can they even be overcome?
spk02: Yeah, I'm not really not going to shark it into any kind of, you know, details about what would or wouldn't work. The technical details, though, around the operations, the plant will have to stop operating in May because we'll be out of fuel. We haven't ordered fuel. There's a lot of work that would need to be done at the plant to prepare it to continue to operate beyond that cycle. We really haven't done the investigation into what that work would be, because as you might guess, we've been planning for five years to shut the plant down. We do have an agreement with Holtec, and obviously that has certain features in it that by and large have all been, all the conditions have been met, except for the plant's still operating. So it's just a real heavy lift at the last hour. As I said, we... couldn't be more supportive of the fact that continuing operation of the country's nuclear fleet is important to the reliability of the bulk electric system and to the ability for us to decarbonize the economy. Shutting those plants down is just moving backwards. So I'm encouraged by what DOE's got going on for future plants. Just at this stage with Peltz, it's just a really heavy lift is all we're saying at this moment.
spk10: Got it. Got it. And then just on credit metrics and equity, with you guys potentially trending above your thresholds, do you see any opportunities to maybe further downsize your $570 million of remaining needs as you're kind of getting closer to hitting your credit metrics and prepare to roll forward your capital plan? Do you anticipate any improvements in credit metric thresholds, especially as the business mix is improved and storm funding is moving closer to resolution? So would, like, for instance, an improvement in thresholds, let's say the 12% to 13% effectively leave you over-equitized versus the current projections?
spk14: Yeah, Char, that's true. So in terms of opportunities out there, to change or improve around our credit metrics, obviously. The one that we cited, I think, at the end of last year, I guess on our last call, was around pension. And certainly interest rates are changing that pension liability. The returns associated with the trust supporting the pension aren't as good as we were anticipating either. All that kind of balancing the one that we are looking at most closely right now. So we're monitoring that. In terms of, you know, obviously we need to get the securitizations done. We need those to be off-sheet, as we've discussed. Those things are going to be big milestones in terms of taking some debt off of Expectations around capital, which obviously also drives our equity needs, those are things that we're watching closely. We do have some capital associated with solar in the near term, and I'm sure there's going to be a question on the call about that. We can talk about that here in a minute. But we have other capital projects that are waiting in the wings, particularly around resilience. So if there is extra capital delays in solar, there's quite a bit of resilience investment that our customers are waiting on and expect us to achieve if there's an opportunity. So I don't anticipate any extra room from the capital side going forward.
spk10: Got it. And just one quick follow-up, if I may, and I appreciate that, is just on your analyst day, I know, I mean, obviously you guys talked about resiliency and sort of the green tariffs. Just given the timing of sort of the regulatory initiatives and the technical conferences and I know you obviously highlighted how they would fit in with the analyst day, but should we specifically think about the analyst day as a roll forward of your base plan and you'll qualitatively maybe discuss these opportunities with some scenario or back testing analysis? Or could we actually see some of this spending actually rolled into the capital plan? Thank you.
spk02: Well, I think, Char, we're going to let the punchlines of the Analyst Day show up on Analyst Day?
spk01: All right.
spk10: Thanks, Leo. I tried to get that passed. You got it. Thanks.
spk11: Thank you. Our next question comes from the line of Nicholas Campanella from Credit Suisse. Your question, please.
spk00: Hey, good morning, team. Thanks for taking the question. Morning. Hey, morning. So, yeah, I just wanted to hit the solar supply chain risks quick and just the impact. Could you just help us just size the amount of megawatts going into rate base that would potentially be at risk? I think you said, you know, roughly half you're secured on over the three-year horizon. So is that like 300 to 400 megawatts? And just to confirm, I heard your last comments right. To the extent that capital shifts, you were just going to backfill that with potential distribution resiliency spend?
spk09: Yeah, and this is Rod. Good morning. From Leo's comments, the near-term risk that we were referring to in terms of our existing owned projects was roughly 280 megawatts because we were discreet about both – we were explicit about both West Memphis and Walnut Bend. And so from a megawatt standpoint, they really – they really don't represent a material amount of capacity. So I want to make sure that we put that in some context. And recall Leo also mentioned the lion's share of our renewable capacity actually shows up on the back end of the decade. So we're calling it out because we recognize that there are some near-term constraints, but they really don't influence how we're thinking about our build-out.
spk02: And I think to that last point, Nick, I think Drew mentioned it, I mentioned it in the script, we've got a capital plan and a timing that's laid out. We've got other things waiting in the wings that we could or couldn't accelerate. So the ability to roll something else into the plan that provides benefits to our customers in a different way is always there.
spk00: Absolutely, absolutely. And then just Drew's comments on inflation, if anywhere, where would you call out that you're seeing the most pressure to the plan? Can you just talk about the current state of power markets, how you're managing customer bill impacts and the ability to just continue to extend your rate-based growth here? Perhaps any levers that makes your jurisdiction more unique than others that would be helpful. Thanks.
spk14: Thanks, Nick. This is Drew. The way you phrased it was an interesting way to think about it in terms of putting pressure on the plan. I would actually turn that around and say that it actually enhances the economics of the plan because we think about what the inflation does to our two central investment themes beyond our base capital in renewables and in resilience. We think that right now, and that's accelerating the pressure to get the renewables done. We've already done a lot of work around improving our gas efficiency with the CCGTs that we've built historically, and of course the Orange County Advanced Power Station is out there as well, a high-efficiency unit. So those things are helpful already, but we think it will accelerate our plan around renewables. And then, of course, around resilience A key piece of the plan is the costs associated with putting up hardened lines, distribution lines, transmission lines. on the customer bill. So I think it will drive customers to want to accelerate our plan, which will include renewables and resilience investment.
spk00: That was very detailed. Thanks for the response, and see you in New York.
spk14: All right. Awesome. Thanks, Nick.
spk11: Thank you. Our next question comes from the line of Jeremy Tonnet from J.P. Morgan. Your question, please.
spk07: Hi. Good morning. Good morning, Jeremy. I just wanted to come back to DOC a little bit more if I could. And, you know, for 2023 projects, if you could just break down price risk versus timing risk. And do you see C&I demand kind of insulating the project to a degree on both these factors?
spk09: Price risk. Ask the question again. So I want to make sure Drew and I are trying to figure out who's going to answer that. what part of the question, because I know there was a price risk question in there as well.
spk07: Yeah, just price and timing for 2023 projects.
spk09: So, on the projects that we just referenced, that being, you know, sunflower, for instance. Sunflower is not at risk. That's one of our own projects. We're expecting that one, as Leo alluded to, to to be at service sometime in August. So we're looking good there. The other ongoing project that we are expecting a bit of delay are the ones I referenced earlier, West Memphis and Walnut Bend. We're working with our BOT partners, both of whom are reputable firms, to lock down both price and schedule certainty. So there is some risk. on both because of the delays for both the supply chain as well as the DOC issues. But beyond that, I'll see if Drew has anything to add.
spk14: Well, I think the only thing I'll add to what Rod said is that, as actually Rod mentioned earlier, the bulk of our expectations are beyond kind of the next two-year window. And we've issued RFPs The DOC piece accepted. They're fully aware of all the supply chain concerns and risks. Prior to the DOC action, they were already aware of tariff activity in that space. We expect that these folks that we are working with coming out of the RFP will be well-situated to manage through the current environment. and meet the expectations that they put through in the RFPs. We expect that the DOC piece will be resolved, you know, at some point relatively near term. I mean, I think most of the folks that we've been engaging with would talk about by the end of the year. But, you know, even if it goes a little bit longer, we don't think that that puts our overall expectations in jeopardy. And certainly in the near term, as I mentioned earlier, there are plenty of other things. If Projects are delayed. There are plenty of other things for us to accelerate forward and meet other customer expectations.
spk07: Got it. Thank you for your thoughts. That's helpful. And just kind of pivoting a bit here to nuclear and really small modular reactors, I just want to know your thoughts on, I guess, how this could unfold going forward. And we saw one of your peers potentially partnering with a university to build an SMR project. Is this something that Entergy would consider doing to demonstrate the viability of the technology, or any thoughts, I guess, on SMR, when and if that could be something that Entergy is really moving more towards or exploring?
spk02: Jeremy, we're certainly monitoring what's going on in the SMR space, and as you might guess, our nuclear folks are involved in that. advisory capacities and others with various entities to make sure that we've got our finger on the pulse of where that goes. I think that the success of the technology is going to be critical to the decarbonization objectives of the economy. When you think about the ability to build cost-competitive, carbon-free, smaller projects that aren't The issue, for example, we have with the size of the capital budgets of the existing technologies is that they're as big as the companies that fund them, and that's problematic if you've got issues with construction. So we're very excited about that opportunity. When and how it fits itself into our needs, we're continuing to monitor, and it's a little bit difficult to say, but certainly I think we should all be rooting for that technology to take root. We're spending, I know, probably more of our efforts in the hydrogen space because of the unique position that we have in the hydrogen market with producers, consumers, stores, transporters all in the heart of our service territory. So there's a unique advantage there. But that doesn't mean we're not staying involved in what the SMR technology can do for us and for the economy in general.
spk07: Got it. That's very helpful. I'll leave it there. Thanks. Thank you.
spk11: Thank you. Our next question comes from the line of their guest, Chopra, from Evercore ISI. Your question, please.
spk05: Hey, good morning, guys, and Drew, long time no see. Good morning. Good morning. Other questions have been answered. Just one quick follow-up from my side. Just can you confirm that the storm IDA balance of costs, which you haven't received sort of regulatory approval for, does that still sit at $1.7 billion? I believe that was the number as of the end of the fourth quarter call. So if you could just confirm that or update us on where that sits now. Yes.
spk14: So the answer is the total cost estimate for that storm is still at $2.7 billion in total. A billion of that is in the first securitization we should expect to price in the next few weeks, and the balance would be towards the end of the year. The full 2.7 will be part of our filing that we are making in the next couple of days. We still have to get, just to clarify, we have to get approval for the full amount to not pre-approval of those costs. It's just a pre-financing.
spk05: I see. So essentially you'll be seeking approval for the full $2.7 billion and the $1 billion that you've gotten already will be applied towards it. Is that the right way to think about it? That is correct. Okay. Thank you very much. Appreciate the call today. Thanks, guys.
spk13: Thank you. Thank you.
spk11: Thank you. Our next question comes from the line of Julian Dumoulin-Smith from Bank of America. Your question, please.
spk12: Hey, good morning, team. Thanks for the opportunity here. Congratulations on the results. If I can, just to focus on the first quarter and some of the dynamics here, can you comment a little bit on the industrial demand and the 6.5% in the first quarter here? How are you seeing this trend through the balance of the year as you think about it, especially given the potential for export-oriented – industries to do particularly well here. And can you talk also in tandem at the same time about some of those trends that you observed, specifically around accelerating customer desire for renewables? You had specifically identified at the start of this year a number of very large customers, but I have to imagine, based on your comments already, that there are actually several other larger customers that you're talking to.
spk14: So this, Drew, I'll take the first part and I'll turn the second part over to Rod. So certainly in terms of the sales expectations, we did have higher than anticipated industrial sales in the quarter. Most of it was actually more or less in line. In fact, I would say compared to our expectations, obviously refiners seeing very high crack spreads performed well. chemical space, which pulled us down a bit. And then there were unplanned outages for our co-gen customers, and that actually lifted us back up. So that co-gen piece was actually fairly strong in the core. There were a number of outages that helped lift us back up. I would say that the other part, that unplanned outages for our regular customers, that was fairly significant, too. So, I mean, all in all, it's probably about what we were expecting, but a little bit higher. And as we sort on one of the slides, or some of our key industries, you know, we do expect them to continue to run at high utilization rates. You know, aside from planned or unplanned outages, you know, they're going to try and trim those off as much as they can to run as hard as they can, given the current commodity environment. And I will also say LNG wasn't on that page, but LNG
spk09: I was only going to elaborate on the LNG piece, and I'm not going to, Leo's point, give any punchlines around analyst data, because we'll give our point of view on a five-year outlook. But, you know, we are seeing greater interest in signing offtake contracts, which would support our view on expansion in the LNG space. We'll leave it to our customers to leave that conversation, but we'll note empirically that 85% of the projects under FID consideration in the LNG space are in energy service territory. And so it just further supports our point of view that we have a unique growth story, that is our customers have a unique growth story, and our ability to serve their expansions in addition to helping them meet their ESG objectives you know, remains a growth opportunity for us, and we still remain bullish about it.
spk12: Excellent. And then just one other nuance here. I'm seeing a lot of headlines here on insurance costs. I'm sure you guys have seen the headlines in Florida, but also in Louisiana itself, especially as it relates to catastrophic storms. Can you comment about any potential pressures, you know, from an inflationary perspective on your business specifics?
spk14: You're talking about insurance specifically, Julian?
spk12: Yeah, I mean, I was thinking about insurance specifically, obviously a broader backdrop here, but insurance seems to be getting headlines here outside of the utility space very late.
spk14: Okay, so insurance is, we aren't allowed to insure our poles and wires, so that hasn't been a driver on that particular space. Just like everybody else, we have seen broad insurance premium pressure. And so we are working through that, you know, regardless of whether it's property or general liability or what have you, you know, et cetera. So we are cyber, you know, we're working through that and making sure that we continue to meet our overall O&M expectations on a go We certainly have seen inflation in the fuel space. We talked about that a little bit. We are working with our stakeholders on how to manage that. In the near term, I think long term, that is a commodity which cycles, and we expect the wildcatter spirit that's out there and the oil patch to take over at some point and help bring prices back down again. As far as sort of inflation in the capital space, we talked about that a little bit with solar. We're seeing it in other materials and some of our other capital projects. But I think the thing to keep in mind on that is we're seeing it for our current marginal capital projects, but they're being added to a much larger rate base, which is already invested in and fixed. And so it's a much smaller piece of the overall rate base. and so the pressure from a customer bill perspective is not that great. Certainly, as I mentioned, the fuel piece is something we're paying close attention to, and as far as just other operating costs, we haven't seen much pressure as of late, but we're certainly mindful of that, and we are driving our continuous improvement efforts to make sure that we stay ahead of that on an ongoing basis.
spk12: It doesn't sound like it's an outsized impact to you all here. It sounds like you guys have it under control. It also sounds like a pretty good update here at the San Jose, so we're going to stay tuned. Thank you, guys.
spk14: Thank you, Julian.
spk11: Thank you. Our next question comes from the line of Steve Fleischman from Wolf Research. Your question, please.
spk04: Yeah, hi. Good morning. Just on the resilience – good morning. Just on the resilience plans that you have talked about, I think, you know, going back to last year, you talked about kind of, having discussions with key stakeholders and the like, and just, can you give any sense of how those have gone, and is there any, do you get a sense of urgency from people on this? You know, just any color there?
spk09: Hey, Steve, it's Rod. Good morning. We have just completed the analytics around you know, the risk scenarios, you know, probability and consequence of storms. And we're in that evaluation phase of the CapEx investment scenarios. And so, what you're alluding to is the beginnings of the formal and sometimes informal technical and stakeholder conferences and conversation. That actually begins in earnest tomorrow. as we began the conversation in New Orleans. And so the feedback loop is just beginning, and we'll have more color around it at analyst day. I can tell you that we have certainly had informal conversations as we were beginning the analytics. And there's a keen interest in understanding, one, what's our point of view? around the risk and the benefits of acceleration. Obviously, in the current economic environment, most of the stakeholders, customers and regulators and others alike, are always going to be interested in how we think through the cost and bill impact. And so, we're beginning, but I'm expecting very active engagement from the stakeholders as we move through New Orleans certainly Louisiana en route to what we believe to be our first formal filings in that July timeframe for the city of New Orleans. And then the state of Louisiana certainly around that timeframe, but not just likely later. Even in Texas, Steve, we've begun dropping ideas around how they ought to think about resiliency. You know, certainly their point of view might be a little different in terms of the sense of urgency that you alluded to than, say, Louisiana and New Orleans, but we certainly have their attention, especially given the role of our Texas service territory in the industrial growth space and their interest in resiliency as well. But short answer is we're just beginning. But more to say about it at analyst day, Steve.
spk04: Okay. So it sounds like at the very least you'll have better data scenarios for the analyst day of what different options are, and obviously the results will be over time depending on what customers states want. Okay.
spk09: Thank you. Thank you.
spk11: Thank you. Our next question comes from the line of Jonathan Arnold from Vertical Research. Your question, please.
spk01: Yeah, good morning, guys. One question, just can you give us a little bit of a sense, you've alluded to being conscious of commodity and gas prices and obviously take your points about the longer term benefits of some of your investment plans, but what is the sort of current build trajectory that you see over the coming months, and maybe we could just sort of focus in on that.
spk14: Sure, that's true. So in the near term, of course, it depends on the jurisdiction. The one that you're probably most interested in, of course, is Louisiana and the securitization costs associated with that. It'll depend on what the final pricing is of those securitization bonds, but somewhere in the neighborhood of about 10% once all those securitization costs are into bills. And I think that includes a little bit of uptick in the interest rates that we see. So, obviously, our customers are expecting that. They know it's out there. So, we're managing through as we discussed. The gas price piece, that reflects, it depends on the jurisdiction, but it generally gets into bills fairly quickly in Louisiana, Texas, New Orleans. There is a little bit of hedging that goes on in Mississippi and Louisiana that can help that, but it's pretty small. But they are, you know, They're used to the gas price volatility. Nevertheless, we're continuing to work through it. The continuous improvement program that we have is part of that. We also have levelized billing programs for customers that allow them to manage through their bill and avoid some of that volatility. So those are examples of things that we're doing to try to help customers go through that. You know, over time, I think gas prices are a little bit above where our previous expectations were, but they're still in a manageable range. And as we said, and as you were alluding to, Jonathan, the investments that we intend to make should help with gas price risk and inflation risk on a longer-term basis.
spk01: When you say over time, Drew, you're talking about sort of further out on the curve, right? Can you... Can you frame for us what the sort of 2022 impact on sort of top of the securitization, you know, might end up being on Louisiana customers, for example?
spk14: Well, in 2022, yeah, it's going to be a portion of what I was explaining earlier because it's not all of the overall securitization costs. So it'll be about two-thirds of that, so about a 5% or 6% increase. later this year.
spk01: Is the commodity piece incremental to that, or is that included in that number?
spk14: No, the commodity piece, you're talking about gas prices?
spk01: Correct.
spk14: Yeah, I think a general rule of thumb around there is about $1 for MMB to use, about a 3% to 4% increase in gas prices, if that's sustained over a year. Of course, we haven't seen that. but that would be kind of the thought there.
spk01: Okay. Well, thank you for that, Carl. If I could just on one other thing. When I look at your slide with the progress against guidance, in the few buckets, like utility O&M and the interest line, and then also this is parent line that's now there, it seems like you're tracking, you know, you've had more than a quarter's worth of the pressure you were expecting from the year in first quarter. I know the other taxes piece you said would be kind of more front-end loaded, but is that timing across the board, or are these some things that are building, but then you hope that kind of the sales uptick is going to hold you harmless effectively? I'm just curious if you can frame that a bit for us.
spk14: Yeah, sure. So in terms of O&M, I think in the first quarter you're talking is timing elements. We are on track for our expectations for the balance of the year. And in terms of the interest expense element, we are seeing some interest expense that's a little bit higher that we would expect to stick, you know, as we go through the course of the year. But there's also some timing elements in I think those are the two things that are going on in there.
spk01: Thank you for that. Thanks a lot. Look forward to June.
spk14: All right. Thank you.
spk11: Thank you. Our next question comes from a line of James from BMO capital markets. Your question, please. Good morning, everyone.
spk02: Good morning, James.
spk03: Just a real quick clarification. Just posted Julian's question, you know, with a slightly better sales outlook, you guys have, um, Have the drivers related to mixed change materially, ergo, just really being driven more by, you know, more robust CNI sales? Are you seeing higher demand across all classes despite, you know, an increasing trend for return to work at this point?
spk09: Okay. This is Rod. I think the short answer is it's actually going the way that we expect it with residential demand trailing off as a as our residential customers are going back to work, school, and kind of a pre-COVID life, and the growth story being driven by the CNI space, as you alluded to. So, from our vantage point, we're actually tracking according to plan there with a little bit of robustness, you know, in the CNI space. But that's about it.
spk03: Okay. Okay, great. And And just following up on Jonathan's question, too, just to clarify, the 10% increase you're talking about, that's 10% increase across total retail sales, correct, in Louisiana? Yeah. Is there somewhat of a skew across from a rate design basis? Like, you know, is there a rough idea of, like, what that could mean for residential versus commercial versus industrial sales? It might be a little too granular at this point. I can follow up offline.
spk14: Yeah, I think Bill can cover that for you offline because I can't actually answer that off the top of my head. There is a difference, of course. There's a big chunk of distribution costs, and that is going to go mostly to residential and commercial customers, not as much on industrial customers.
spk03: Okay, great. I'll follow up with Bill. Thanks so much.
spk11: Thank you. Our final question for today comes from the line of Ross Fallon from UBS. Your question, please.
spk08: Morning. How are you? Excuse me. If I think about your base capital plan at $12 billion, and I think if I remember correctly from Ian, we're talking about $5 to $15 billion of potential incremental CapEx. I just wanted to understand your comment around federal funding. Is that $5 or $15 billion of incremental CapEx sort of net of that number or would any federal funding net that number down, whatever that number happens to be, depending on the long-term opportunity set?
spk02: Yeah, the, you know, the federal funding would be outside of anything that we've got in our, our projections. So the five to 15, that isn't over the next three years that goes out through 2030, just to be clear on that. And, um, And it's really an acceleration of work that we could do over time based on the fact that we might take things that are working today but are of old standard and pull them down and put up something of a new standard. It's that kind of work that we'd be looking at. So any kind of federal funding would be used to offset the cost, and then that provides headroom that you could potentially accelerate more. So one way to think about it, Ross, would be if you were going to spend $10 billion and then all of a sudden you got $1 billion worth of federal funding, well, you may spend $11 billion would be one option to be able to, and you'd get it for, you know, effectively $11 billion worth of resilience for $10 billion. So that's the way we would think about it and likely propose it.
spk08: Okay, that's the way I understood it. I just wanted to make sure I was understanding that correctly. And then... Maybe longer term, as you get to the credit metrics you need on the balance sheet, you want on the balance sheet, think about your 5% to 7% EPS growth. As you execute some of these opportunities and maybe grow rate-based faster than that in the long term, but there might be an equity need attached to the capital, so does that bring your EPS growth rate back down? How do you think about rates and bills changing? and your long-term growth rate? In other words, is the $5 billion to $15 billion thinking about extending that $5 billion to $7 billion or maybe even the upper end of that $5 billion to $7 billion for a longer period of time? Or is there actually an opportunity to accelerate that $5 billion to $7 billion longer term given bill pressure and other things that might be happening with inflation?
spk02: I guess I'll kind of sum it up this way. We have a significant amount of growth opportunities because of the growth needs of our customers. The resilience spend is certainly one of those areas. The acceleration of renewables ahead of the schedule that we're on to meet decarbonization goals of our current customers as they want to get outsized access to clean resources, could accelerate renewables at the same load growth. The expansion of our industrial base is a growth opportunity. Just the growth that we're seeing as we've talked about the utilization rates are high, inventories are low, all the commodity spreads are in the right place. That leaves itself pretty ripe for expansion and that's what we're seeing as we have dialogue with our customers going forward. And then the electrification side of things where they're going to take existing load or existing processes that are not electrified and electrify them and that creates load growth. So there's all kinds of avenues for growth and customer demand for a higher level or different level of service that could provide capital opportunities for us. I would say at a minimum that just makes the runway pretty long for us in terms of where we are with the current outlooks. Our objective would certainly be to have a better album going forward and balance all the things that you were talking about, the growth in sales, the growth in investment, and the growth in financing needs, and balance all that out in a way that creates a different trajectory for us going forward. And I think our customers are going to demand the types of investments we need to make that happen. But that's in the future. So I think all of those combined certainly bode well for a continuation of the growth that we've seen and demonstrated over the course of the last several years. pretty much like clockwork. And then I think our objective and the work we need to do is to find a way to make it better.
spk08: All right. That's perfect. Thank you for that. And I look forward to seeing you, too.
spk02: All right. Thank you, Ross. Look forward to seeing all of you as well.
spk11: Thank you. This does conclude the question and answer session of today's program. I'd like to hand the program back to Bill Abler for any further remarks.
spk13: Thank you, Jonathan, and thanks to everyone for participating this morning. Our quarterly report on Form 10-Q is due to the SEC on May 5th and provides more details and disclosures about our financial statements. Events that occur prior to the date of our 10-Q filing that provide additional evidence of conditions that existed at the date of the balance sheet would be reflected in our financial statements in accordance with generally accepted accounting principles. Also, as a reminder, we maintain a webpage as part of Entergy's investor relations website called Regulatory and Other Information, which provides key updates of regulatory proceedings and important milestones on our strategic execution. While some of this information may be considered material information, you should not rely exclusively on this page for all relevant company information. And this concludes our call. Thank you very much.
spk11: Thank you, ladies and gentlemen, for your participation in today's conference. This does conclude the program. You may now disconnect. Good day.
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