With a combined revenue of $21 trillion and $2.1 trillion in profits, the 2026 Fortune 500 is the definitive list of America's largest companies.

Fortune 500

Almost $20 trillion in revenue—and a record-breaking $1.87 trillion in profits. Introducing the 2025 Fortune 500, the definitive list of the biggest companies in America.

The Fortune 500, in its 70th year in 2024, ranks the biggest U.S. companies by revenue.

The Fortune 500, in its 69th year in 2023, ranks the biggest U.S. companies by revenue.

This year’s Fortune 500 marks the 68th running of the list.

This year’s Fortune 500 marks the 67th running of the list.

F500-2021-342-CenterPoint Energy

THe Houston-based company provides electricity and natural gas to the Houston area and in seven states. In April, the company sold its Arkansas and Oklahoma natural gas LDC assets to Summit Utilities for $2.15 billion in cash. The company dropped 82 spots on the <em>Fortune</em> 500 list this year after its revenues fell by 28% in 2020.

This year's Fortune 500 marks the 66th running of the list.

F500-2020-260-Centerpoint Energy

The Houston electric and natural gas utility company provides energy to customers in eight states and energy-related services in upwards of 40. It employs approximately 14,000 people and holds nearly $29 billion in assets.

This year's Fortune 500 marks the 65th running of the list.

This year's Fortune 500 marks the 64th running of the list.

This year's Fortune 500 marks the 63rd running of the list.

This year's Fortune 500 marks the 62nd running of the list.

This year's Fortune 500 marks the 61st running of the list. Wal-Mart claims the top spot again. See who made the list.

Wal-Mart stayed on top as its sales crept closer to half-a-trillion dollars. Apple moved into the top five. And UnitedHealth Group continued its steady climb. 

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Founded in 1866, CenterPoint Energy is a Houston-based public utility company in the United States with operations in both electric transmission and natural gas segments. The electric segment maintain the wires, poles, and electric infrastructure serving more than 2.9 million metered customers in the greater Houston area and in southwestern Indiana. The natural gas segment handles intrastate natural gas sales, as well as the transportation and distribution of natural gas to residential, commercial, and industrial customers in states such as Indiana, Minnesota, Ohio, and Texas. This segment also oversees permanent pipeline connections, and provides home repair protection plans to natural gas customers in several states through a third party.

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CenterPoint Energy (CNP): Company Profile, Stock Price, News, Rankings

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CenterPoint Energy

centerpoint energy

Good morning, and welcome to CenterPoint Energy's Fourth Quarter and Full Year twenty twenty four Earnings Conference Call with Senior Management. During the company's prepared remarks, all participants will be in a listen only mode. There will be a question and answer session after management's remarks. I will now turn the call over to Jackie Rickert, Senior Vice President of Corporate Planning, Investor Relations and Treasurer. Ms.

Good morning, and welcome to CenterPoint's fourth quarter twenty twenty four earnings conference call. Jason Wells, our CEO and Chris Foster, our CFO, will discuss the company's fourth quarter and full year twenty twenty four results. Management will discuss certain topics that will contain projections and other forward looking information and statements that are currently based on management's beliefs, assumptions and information currently available to management. These forward looking statements are subject to risks and uncertainties. Actual results could differ materially based on various factors as noted in our Form 10 K, other SEC filings and our earnings materials.

We undertake no obligation to revise or update publicly any forward looking statements. We reported $1.58 and $0.38 for the full year and fourth quarter of twenty twenty four, respectively, on a GAAP basis. Management will be discussing certain non GAAP measures on today's call. When providing guidance, we use the non GAAP EPS measure of diluted adjusted earnings per share on a consolidated basis referred to as non GAAP EPS. For information on our guidance methodology and reconciliation of the non GAAP measures used in providing guidance, please refer to our earnings news release and presentation on our website.

We use our website to announce material information. This call is being recorded. Information on how to access the replay can be found on our website. Now, I'd like to turn the call over to Jason.

Thank you, Jackie, and good morning, everyone. I would like to begin by extending my sincere appreciation to all of our frontline personnel that work through the unprecedented winter weather we experienced across our various service territories. We experienced sub zero temperatures in Minnesota, freezing rain in Indiana and record breaking snowfall in the Houston area. Through it all, our team worked to keep the lights on and the gas flowing for our customers. On today's call, I'd like to address four key areas of focus.

First, I'll touch on the fourth quarter and full year 2024 financial results. Second, I'll provide a broader regulatory update, including highlights of our recently filed system resiliency plan for Houston Electric and touch on the significant progress we've made in our various rate cases. Third, I'll share an overview of the transaction we have proposed to ERCOT that we believe benefits all stakeholders. And lastly, I want to highlight the impressive growth drivers across the Houston area and how that growth informed the substantiated load filing we recently submitted to ERCOT. Now starting with our fourth quarter and full year financial results.

This morning, we announced non GAAP EPS of 0.4 for the fourth quarter and $1.62 for the full year. Chris will provide additional details of these strong results in his section. The $1.62 per share translates to 8% growth over our 2023 actual results. This is now the fourth consecutive year of meeting or exceeding our annual non GAAP EPS guidance. It is also important to note that we have rebased our long term growth targets off these higher earnings levels each year as we seek to deliver value for our investors each and every year.

Consistent with this approach, we are reaffirming our 2025 non GAAP EPS guidance range of $1.74 to $1.76 which equates to 8% growth at the midpoint from our delivered 2024 non GAAP EPS of $1.62 dollars Over the long term, we continue to expect to grow non GAAP EPS at the mid to high end of the 6% to 8% range annually through 02/1930. We also expect to grow dividends per share in line with earnings growth over the same period of time. Now turning to my second key area, an update on our broader regulatory efforts, starting with our recently refiled system resiliency plan at Houston Electric. In line with our commitments, we refiled our system resiliency plan at the January. This filing proposes a total spend of $5,750,000,000 from 2026 through 2028 to improve system resiliency.

$5,500,000,000 of this spend is related to capital expenditures. Chris will discuss the associated capital expenditure increase from our previous plan in his section, but I want to briefly touch on the system improvements we are focused on in this filing. Our plan outlines 39 specific resiliency measures that are designed to strengthen tens of thousands of miles of our transmission and distribution system. The investments included in our filing represent the largest single investment in grid resiliency in our company's history as we work to improve the customer experience for those that live and work in higher risk areas. As a result of our planned work through 2028, we expect that our transmission system will be fully hardened with no remaining wood structures and that nearly all substations will be elevated above the five hundred year floodplain.

I am proud to say that with our accelerated pace in less than a year since Hurricane Bharrel, we will have more than doubled the number of circuits that have automation on our system and we won't stop there. With our system resiliency plan, in another three years, we will triple the number of automated devices since Hurricane Bharrel. We estimate that our actions over the next several years will save customers more than 1,000,000,000 outage minutes in extreme weather events. In addition to contributing to an improved customer experience, beginning in 2029, these investments are anticipated to result in an estimated $50,000,000 of reduced storm related costs per year, which naturally support lower electric delivery charges over the long term. As I've mentioned before, this is not the beginning of our journey to a more resilient system, but an acceleration of what we started a few years ago when we targeted hardening and modernizing the electric transmission backbone as well as some of our substations prone to flood risk.

We believe that these investments combined with the other actions outlined in our Greater Houston Resiliency Resiliency Initiative set us on a clear path to become the most resilient coastal grid in the country. Next, I want to focus on the continued regulatory progress at Houston Electric. As many of you recently saw, we reached a settlement in our 2024 rate case. We believe that the proposed settlement is constructive for both our customers and our investors. The proposed settlement, if approved, includes an annual revenue requirement decrease of $47,000,000 which translates to a reduction of approximately $1 per month in the average electric delivery charge for our residential customers.

It also includes an increase to both our return on equity and equity ratio. These improvements strengthen our competitiveness in the capital markets that we regularly access to efficiently fund capital investments for the benefit of our customers. This unique outcome of lower customer bills with improvements of both the cost of capital and capital structure comes despite the fact that we've increased our vegetation management spend by 45% over the last few years. It also exemplifies our ability to improve customer outcomes, while also efficiently executing O and M reductions throughout the business. We'd like to thank all of our stakeholders for working together to submit to the PECT what we believe is a constructive settlement for all parties.

Beyond the rate case, we've also made progress on our traditional interim mechanisms and storm cost recovery filings at Houston Electric. Chris will provide further details regarding these items in his section. Now turning to Indiana Electric. A few weeks ago, we received a final order in our Indiana Electric rate case. The final order was approved in line with the settlement filed in May of last year, which included a total annual revenue requirement increase of approximately $80,000,000 and a 9.8% return on equity.

We believe this is a fair and balanced outcome as we have continued to invest for the benefit of our customers, while also being conscious of the impact of our capital investments on the customer bill. Our move away from older generation facilities has enabled us to eliminate nearly $40,000,000 of O and M directly benefiting our customer bills. We also previously securitized the remaining book value of one of our aging facilities, foregoing profits related to this plant for the benefit of our customers. Moving forward, we will continue to be mindful of our customer bills and the reliability needs and work with stakeholders to achieve balanced outcomes for all parties. Moving to our Minnesota Gas Rate Case.

During the fourth quarter, we reached an all party settlement in our Minnesota gas rate case. The settlement includes a total revenue requirement increase of nearly $104,000,000 for 2024 and 2025, which reflects over 75% of our proposed revenue increase of approximately $136,000,000 Interim rates for the 2024 increase went into effect in January of last year and interim rates for 2025 went into effect last month. These rates closely mirror the increased revenue requirement included in the proposed settlement that is now pending a final order from the Minnesota Public Utilities Commission. The commission has a statutory deadline of July 1 to issue its final order in this case. We also want to thank all stakeholders for working together to achieve what we believe is a strong outcome for all parties.

Finally, I want to briefly touch on our rate case for Ohio Gas. At the October, we filed our Ohio Gas rate case application, which included a revenue requirement increase of $99,500,000 Over the last several years, we've had one of the lowest customer bills in the state. Our request reflects an investment recovery rate that will put us more in line with our Ohio peers. In addition, this larger revenue requirement increase will allow us to more efficiently fund and continue to prioritize pipeline modernization investments that we believe contribute to the overall safety and efficiency of the system. Before closing out my remarks on our regulatory progress, I want to put into context what has been a very busy and constructive regulatory cycle.

Over the last eighteen months, our teams have been busy as they have filed five rate cases. Of the five, we have received final orders in two and are awaiting approval of settlements for our Houston Electric and Minnesota Gas businesses. Together, these four rate cases represent over 80% of our enterprise rate base. Should these cases be improved in line with their current proposed settlements, we will have been able to improve our consolidated return on equity and equity ratio, which naturally increases the earnings power of the company. I want to thank all of our teams for their hard work and dedication for working with stakeholders to achieve such strong outcomes for both our customers and our investors.

Now I'd like to provide an update on our proposed temporary generation transaction. Through engagement with a diverse set of stakeholders, it is clear that there is no longer a desire for transmission and distribution utilities in the state to invest in large temporary generation facilities to mitigate the impact of large load shed events. In response to this, we have worked with the same set of stakeholders to develop what we believe is a truly unique Texas solution that benefits Houston Electric customers, other ERCOT customers and CenterPoint investors. I will briefly walk through the contours of this transaction and Chris will provide additional details related to the financial impacts. Our proposal to transfer the use of our units to a Texas peer utility will provide a temporary bridging solution for summer peak reliability needs in the San Antonio area.

We will make these units available for this purpose for up to two years starting this spring. After that, we intend to market the 15 large units to third parties at what we expect to be prevailing higher market rates. Given current market demand, we believe that the revenues earned from marketing these units after the period that they're in San Antonio will exceed the foregone revenues during the period these units are donated to ERCOT at no cost. We truly believe this Texas solution is a win for all stakeholders. As part of this solution, we will make an unprecedented contribution of value for the benefit of the ERCOT grid.

Houston Electric customers will be made whole on charges related to the large temporary units. And finally, our shareholders will receive the benefit of their investment when we take into consideration the anticipated profit from marketing after the period these units operate in the San Antonio area. We appreciate all stakeholders for providing their feedback and working collaboratively to identify this unique solution that ultimately benefits everyone. Now switching gears, I want to highlight the strong organic growth we continue to see, especially in our Texas service territories. While my earlier commentary focused on capital investments related to resiliency enhancements on our system, I want to emphasize that we continue to experience significant electric demand growth across Texas, and particularly the Greater Houston area.

We are proud to partner with both existing and potential new customers to support their energy needs as our region continues to experience rapid economic development. It is these discussions that have informed our estimated electric load forecast for the Houston region that we recently submitted to ERCOT. I want to briefly touch on what we included in our submission and equally important, what we excluded. Last year's ERCOT load report was largely focused on Texas electric needs outside of the Greater Houston region. We are excited to have now submitted our expected load increase for the Greater Houston region this year.

Like our peers, we've experienced an unprecedented level of interest in connecting to our grid. In fact, we have received approximately 40 gigawatts in load interconnection requests. Those load requests are incremental to our current peak of about 21 gigawatts. While we're actively pursuing this full set of load interconnection requests, we believe our submission is a more realistic reflection of the load growth that will materialize by 02/1931. Currently, we are forecasting a nearly 50% increase in peak demand from 21 gigawatts today to nearly 31 gigawatts by the February.

To put that in perspective, the 10 gigawatt increase we are forecasting over the next seven years is more than the increase the Greater Houston region has experienced over the last twenty five years. Our rigorous approach to forecasting low demand gives us confidence in our projections. Our outlook also benefits from the fact this growth is not driven by a single industry or theme. Houston has clearly earned its reputation as the energy capital of the world, but our types of economic expansion go well beyond this core sector. It may come as a surprise to some that today, energy constitutes only a little more than a third of the Ares economy.

When looking at Houston's Load Drivers, we see three economic activities as the catalyst for significant long term load growth. First, Houston is a major logistics hub for The United States. Boasting the largest port by waterborne tonnage, Houston is a gateway for goods coming from and going all over the world. We forecast that opportunities for port electrification, fleet electrification and other associated projects will drive approximately 20% of the 10 gigawatt increase through 02/1931. Second, Houston is home to the largest medical complex in the world and it is only growing.

It continues to expand not only its offerings for patients who come from all over the globe for treatment, but continues to pioneer medical innovation and medical manufacturing. We forecast that its continued expansion as well as other commercial activities including data centers will drive 30% of our anticipated load growth by 02/1931. Third, Houston is and will continue to be at the center for energy refining and energy exports. As the global energy mix continues to evolve, Houston will play a central role in the development and exportation of that energy. This significant growth will certainly require continued and increased investments in electric infrastructure, especially with respect to the transmission system.

As a reminder, Houston makes up just over 2% of the geographic area of Texas, but is approximately a quarter of ERCOT's peak load. On any given day, we import as much as 60% of the electricity consumed in the Houston area. Prior to formalizing our capital investment plans related to this immense growth, we need the feedback and final decisions from the Texas Public Utility Commission regarding the seven sixty five kV or three forty five kV standard for transmission build outs. We anticipate further clarity on this topic by May of this year. Regardless of the direction the PUCT takes, the continued growth of the Houston area is undoubtedly a long term tailwind and is one that is truly unique to CenterPoint.

The diverse underlying fundamentals driving Houston growth gives us continued confidence in our belief that we have one of the most tangible long term growth plans in the industry. This growth will continue to drive investment opportunities for years to come, but also provide a sustainable platform for our customers whose charges will continue to benefit from the ever growing population. We are privileged to serve such a growing and vibrant area and look forward to continuing to partner with customers, communities and other stakeholders to further enable this truly remarkable growth. And with that, I'll hand it over to Chris.

Thanks, Jason. Before I get into my updates, I want to echo Jason's gratitude for not only our CenterPoint coworkers, but also the external frontline crews who aided in the restoration in Indiana and kept energy flowing for our customers throughout our various service territories. This morning, I will plan to cover four areas of focus: first, the details of our fourth quarter and full year financial results second, I'll touch on our capital deployment execution for the year as well as our upwardly revised capital plan that now reflects our recently filed system resiliency plan and an update on our other capital investment trackers. Third, I'll go into further detail on our temporary generation proposal and the associated financial impacts. And finally, I'll provide an update on where we completed the year with respect to our balance sheet.

Let's now move to the financial results shown on Slide eight. On a GAAP EPS basis, we reported $0.38 for the fourth quarter of twenty twenty four. On a non GAAP basis, we reported $0.4 for the fourth quarter of twenty twenty four compared to $0.32 in the fourth quarter of twenty twenty three. Our non GAAP EPS results for the fourth quarter removed the impacts associated with the sale of Louisiana and Mississippi gas LDCs. In the fourth quarter, these impacts included an $8,000,000 deferred tax remeasurement reflecting a slightly lower effective state income tax rate post sale.

Now taking a closer look at the quarter, growth in rate recovery contributed 0.05 when compared to the same quarter last year, which was driven by the ongoing recovery from interim mechanisms for which customer rates were updated in addition to approved interim rates related to our Minnesota Gas rate case. In addition, O and M contributed 0.05 of favorability when compared to the comparable quarter of 2023. This favorability was primarily driven by the approximately $0.03 of work that was pulled forward in Q4 of last year that we did not replicate this quarter. In addition to O and M and rate recovery, weather and usage contributed an additional $0.02 favorability quarter over quarter. Interest expense and financing costs were $0.03 unfavorable when compared to the comparable quarter in 2023.

These $0.03 were primarily driven by the $3,000,000,000 of net new debt issuances quarter over quarter. And despite the headwinds we faced this year, we were still able to deliver for our investors our full year 2024 non GAAP EPS target of $1.62 I want to take a step back to discuss how we're thinking about O and M. Over the last few years, we've been able to reduce our O and M by nearly 2% annually. We are now committed to continuing to do more vegetation management work at Houston Electric, where we are now proposing to transition from our current five year vegetation management cycle to a three year cycle. This positions us well given the long seasonal growth periods and has us leading statewide in Texas and among the few in our industry that seek this level of proactive vegetation management.

This more aggressive cadence will naturally reset our O and M levels in the near term. However, we will be laser focused on continuing to take costs out of the business elsewhere and continuing to target 1% to 2% O and M reductions from these higher levels, ultimately benefiting customer charges. For example, as Jason pointed out earlier, starting in 2029, we anticipate saving roughly $50,000,000 of storm costs annually from the investments outlined in our recently filed system resiliency plan. This overall level of execution gives us confidence in reiterating today our full year 2025 non GAAP EPS guidance target range of $1.74 to $1.76 The midpoint of this range represents annual growth of 8% from our actual 2024 non GAAP EPS of $1.62 as we seek to deliver value for our shareholders each and every year. Next, I'll touch on our capital investments execution for 2024 as shown here on Slide nine.

In the fourth quarter of twenty twenty four, we invested $1,200,000,000 of base work for the benefit of our customers and communities. For the full year, we invested $3,800,000,000 exceeding our 2024 capital expenditure target of $3,700,000,000 and this is despite multiple diversions from performing base work due to storm restoration. As Jason touched on, our recently filed system resiliency plan includes capital investments of $5,500,000,000 This updated plan results in a $500,000,000 increase to the $47,000,000,000 capital investment plan that runs through 02/1930. As such, we are updating our capital investment target to $47,500,000,000 through the end of the decade, and we will fund our incremental capital investments consistent with our prior guidance. As such, you should assume we will fund in line with the enterprise's approximate consolidated capital structure of 50% equity and 50% debt.

Separately, we are back now in our more traditional rhythm of seeking ongoing capital plan recoveries using existing mechanisms. At the same time, we continue to make progress on storm recoveries. Related to those recoveries, we are focused on progressing through the securitization process here in Texas and are currently ahead of plan. That is because we have now reached a settlement in principle on our May derecho event costs. As part of the proposed settlement, we will recover 98% of the costs attributable to this storm.

This is a great outcome and one that further illustrates the constructive business and regulatory environment in which we operate here in Texas. We're also still on track to make our cost recovery filing related to Hurricane Barrel in the second quarter. In addition, we continue to advance on our capital recovery mechanisms at Houston Electric. During the fourth quarter, we filed both our transmission and distribution trackers. In our transmission tracker or TCOS, we requested a revenue increase of approximately $63,000,000 which was approved and rates were updated to reflect this increase in mid January.

Our distribution tracker or DCRF was filed at the December and reflected a requested revenue increase of approximately $100,000,000 We recently withdrew this filing because we're updating it with the revised figures to reflect the capital investments included in the rate case filing. We will also incorporate incremental capital investments through the December 2024 in our revised filing that we anticipate filing by the end of the first quarter. I'd now like to discuss the expected financial impacts for customers and investors associated with our temporary generation transaction that Jason referenced. First, I want to take a step back and walk through how we're thinking about our investment related to the lease of our large temporary emergency generation units. There are essentially three periods with the lease running through June of twenty twenty nine.

First, the period where the units were available to our CenterPoint customers to mitigate potential large load shed events second, the period the units will serve our fellow Texans and third, the period where we will seek to market all 15 large temporary generation units to third parties at prevailing market rates. When crafting our proposal, our focus first and foremost was on our customers. We intend to be responsive to stakeholders that have expressed a desire for us to offset collections from regulatory recoveries of roughly $475,000,000 That's approximately the amount we'd seek to offset for our customers. Let me summarize how we would go about doing that. There are three components of customer benefit at a high level.

First, in the spring of this year, we are proposing to make all of our 15 large temporary emergency generation units available to serve the San Antonio area to support reliability needs identified by ERCOT ahead of the summer load peak. We will make an unprecedented contribution for the benefit of Texans of approximately $180,000,000 of value for an up to two year period. That's the time in which we would propose the large temporary generation unit will serve ERCOT customers, resulting in us not seeking future recovery of this balance from Houston Electric customers as they will cease to be a regulated investment. Second, our Houston Electric customers will receive the benefit of the Houston Electric rig case settlement, when approved, saving customers around $250,000,000 over a roughly five year period. And third, as we highlighted in the third quarter, we performed significant incremental work related to both the May storms and hurricane barrel recovery, and we will not seek recovery for roughly $110,000,000 of these costs.

We anticipate that during the time the units are serving as a statewide system benefit, cash flow will be slightly lower as collections from customers will be reduced to account for the foregone recovery related to the future use of these units. At the end of that time, the third period will begin, where we seek to market all 15 large temporary generation units to third parties at prevailing market rates. The market has and continues to move favorably for mobile power units such as these, where we have seen market rates that are roughly double our original lease rate. As I briefly touched on, once these units move to the San Antonio area, we will not earn a regulated return with respect to our investment in them. Given the unregulated nature of this investment, going forward, we will remove the impacts, both favorable and unfavorable from our non GAAP earnings numbers.

Although we project the earnings and cash flow profile have the potential to equal or better the prior regulated investment profile, this is now largely a timing item and the asymmetric earnings profile of this investment is not consistent with our core regulated business. I will reiterate Jason's sentiments with respect to this Texas centric solution. We believe this transaction is a tremendous outcome for all stakeholders. Finally, I want to touch on our balance sheet and how we're thinking about funding our increased capital plan. As of the end of the year, our adjusted FFO to debt ratio based on the Moody's rating methodology was 13.6% when removing storm related costs.

This is slightly below our target range of 14% to 15%. But as a reminder, it is transitory in nature as we anticipate receiving approximately $1,000,000,000 in cash proceeds next month from the closing of our Louisiana and Mississippi LDC sale. We also expect an additional $500,000,000 of securitization proceeds by the June, and we continue to expect to file for securitization of the $1,100,000,000 of storm costs related to Hurricane Barrel within the next few months with proceeds anticipated coming by the end of the year. We will continue to stay laser focused in supporting balance sheet health, while also investing for the benefit of our customers and communities. With now four consecutive years meeting or exceeding expectations, we continue to reaffirm our non GAAP EPS target of 8% this year and the mid to high end of 6% to 8% thereafter through 02/1930.

And with that, I'll now turn the call back over to Jason.

Thank you, Chris. In summary, I'm proud of our team for persevering through 2024, which marks our fourth year of meeting or exceeding our financial guidance. This performance places us in the top decile within our utility peer group. In addition, we have a strong foundation in place for 2025 and beyond, a foundation that includes a comprehensive plan to deliver the most resilient coastal grid for our customers. Incremental CapEx announced today of $500,000,000 driving 10% rate base growth through the end of the decade, which is one of the highest in the sector.

Constructively settling four rate cases representing over 80% of enterprise rate base, giving us clear line of sight for the next four years and the privilege to serve one of the fastest growing regions in our country with an expected peak load increase of approximately 50% in the Houston area through 02/1931, powered by a diverse set of economic drivers. This load growth undoubtedly provides incremental CapEx tailwinds to an already industry leading plan. We look forward to sharing more comprehensive details about the long term investment opportunities later this year.

Thank you, Jason. Operator, we're now ready to take Q and A.

Thank you. Our first question comes from Steve Fleishman with Wolfe Research. Your line is open.

Yes. Hi, good morning. Thanks. Can you hear me?

Yes. Hi, everyone. So just I guess the you kind of talked to this at the end, Jason, but just on the growth forecast

any way to kind of compare what you gave to what ERCOT might have used last year for this? And then also how to think about how much of this growth kind of in your capital plan or what's still like upside including the transmission decision that you mentioned coming up?

Yes. Happy to shed a little color on that. As it relates to the ERCOT submission, as we've discussed over the course of last year, that was largely related to West Texas, really a focus on the Permian originally. So last year, I think we submitted roughly it had to be less than half a megawatt gigawatt of interconnection demand. We basically had we weren't a participant in last year's study effectively.

So this will be the first time that the growth in the Houston area is really going to be reflected in ERCOT's substantiated load finally moving forward. So it will be a 10 gigawatt increase to what they were projecting last year. Now as we've also talked about, I would have to imagine that some of that load last year that was submitted it was submitted under a standard that was designated as speculative load. ERCOT is trying to tighten the planning parameters and have moved to more of a substantiated load, essentially a higher level of confidence in that load materializing. And so there may be a little bit of downward pressure on the total ERCOT market, but undoubtedly we will add about 10 gigawatts of new demand to what otherwise existed last year.

So hopefully that provides the context around the ERCOT submission. As it relates to the CapEx, as I mentioned, this is an incredible tailwind for the company. It's still a little early to size it. It really is going to come down to the decision on voltage whether we pursue a seven sixty five kV standard or three forty five kV standard. What I would say though, because we are a low pocket here in Houston, on any given day, we're importing 60% of our energy needs.

This will undoubtedly drive at least another $3,000,000,000 in electric transmission CapEx. It's not in the plan. I would really be surprised if it's not higher than that. But ultimately, we need policy direction on the voltage standard to refine that estimate. And so we'll be providing more of that update as we get through the course of the year.

Okay. That's very helpful. And then on the any update on kind of rating agency views? I know you gave the metrics just when are they going to are they mainly going to be focused on the recovery from Burl to kind of see stabilizing of the ratings?

Good morning, Steve. I think it's probably three factors. First is just the constructive nature of the Texas regulatory environment, which I think we've been able to already showcase our interim capital recovery mechanisms as a key area of progress there. Two, it's the Houston Electric rate case again for the certainty that that provides. I think that as you've seen there, we have an all party settlement and ideally hoping for action there at the PUCT either March '27 here would be ideal in their next public meetings.

Third is certainly the securitizations of the prior storm costs. What I would point out there is we are actually ahead of plan and have been sharing that with the rating agencies, meaning the $500,000,000 associated with the May storm impact, we have now achieved a settlement in principle, which puts us ahead of plan in terms of being able execute toward the end of this quarter excuse me, toward the end of the second quarter, the actual securitization. Finally, I do think it's going to be important for them to see progress on the prudency review step associated with the hurricane barrel related costs and we'll get that filing filed at the PUCT here in the next few months. So ultimately, I think those are the three factors that they're watching and I think we're already able to show progress on certainly two of the three, if not three of the three.

Thank you. Our next question comes from Shar Pourreza with Guggenheim Partners. Your line is open.

Morning. Just to follow-up on Steve's question. Just have you committed to an Analyst Day? Any sense of timing there? And are you going to know enough around the 50% load growth upside that you guys kind of highlighted for Houston to embed that in the capital plan for the Analyst Day?

Yes, it's a great question, Shar. And yes, we are committed to updating and rolling forward what will be a new ten year plan for capital investment this year. We do want to make sure that we incorporate this policy decision or direction that Texas will make in terms of the voltage standard. We anticipate that by May this year. And so our update to the market will likely follow that so that we can incorporate better estimate of the transmission CapEx increase associated with serving this really just tremendous load growth here.

So we haven't set a date, but we're committed to providing an update to the market here this year. I would also say that while we're talking a lot about the electric transmission opportunities here in Texas, which are significant, as I mentioned, they're not our only set of CapEx tailwinds. We continue to see, I think, really constructive opportunities for our customers around some localized transmission here in the Greater Houston area on the gas side of the business. And we're going to be pursuing some electric transmission opportunities up in Indiana. And so I think the tailwinds from a CapEx standpoint are significant and we look forward to sharing them a little later this year when they come into better focus.

Okay, perfect. And then just in terms of financing needs, I know you guys obviously there's a slight change in language around the ATM use versus equity content. Can you just elaborate on the range of options and timing of equity funding? And is kind of asset optimization still an avenue given the emphasis we're seeing in your core Houston jurisdiction? Thanks guys.

Sure. Good morning, Shar. I think if you look just at the immediate year itself, we have indicated we've taken care of the equity needs for 2025 for the plan. As you go beyond that, we have consistently said and they're staying there that we'd be utilizing the ATM to take care of our modest equity needs going forward. And as we mentioned today, you should assume we continue to fund the business, the enterprise at 50% debt, 50% equity.

And I'll just say again, we consistently evaluate the most efficient way to fund this growth CapEx going forward. I mean really just like the Louisiana and Mississippi gas LDC sales that we referenced will actually be closing this quarter. So I think you've seen here the team demonstrate that ability to look at multiple different options, everything from utilizing the base ATM to the hybrid structures and junior subordinated notes that we utilized as well as the potential for transactions when they are the most efficient way to produce excuse me to pursue this financing.

Okay. So this will also be a big part of the update that we have later in this year. We're committed to funding any of the equity needs efficiently as we have demonstrated and we're also committed to preserving the balance sheet, creating a healthy cushion between that downgrade threshold and where we are running the business. And so that will be part of this comprehensive update that we'll provide later this year.

Yes. And I appreciate it. And you guys have been fairly successful on the asset optimization side, which is why I asked the question. Thanks guys. Appreciate it.

Thank you. Our next question comes from James Dahlaker with BMO Capital Markets. Your line is open.

Good. How are you? I just wanted to touch quickly on your cost control program and target to keep the O and M at like a 1% to 2% decline across your plan given the increase in resiliency spending including the higher vegetation management spending.

Could you talk a little bit about the discrete levers you are looking at or identified to allow you to kind of deliver on this O and M reduction program as you go forward?

Sure. Thanks. Good morning. I think if you look at what we talked about this morning, we will have a substantial increase which is needed for our system for a much more aggressive vegetation management standard. But really nothing has changed in terms of our focus on taking out 1% to 2% per year.

We have delivered that clearly over the last three years that actually just shy of 2% per year. Going forward, there's probably a couple of areas I would touch on. I know we mentioned in our prepared remarks the ability to actually reduce O and M as a direct result of the capital that we'll be putting on the system for the system resiliency plan. And the basic way to think about that is we'll have fewer truck rolls because we'll have automated devices on our grid which allow for self healing, right, in those instances where otherwise you would have to roll a truck for our frontline team members to take care of a fuse on the system or otherwise we reenergize. A second area of focus for us will be on really legacy systems and standardization across the footprint that we have.

We have the ability in certain instances to sync up our IT systems and network systems as well as standards that are utilized that are slightly different in the different states that we serve and we're utilizing the lean operating system here together to really focus on ensuring that we've got strong standardization that we've got in some instances vendor rationalization and other steps we can take to reduce costs year over year. And then the third, I would say is really just our focus on empowering those closer to the work ultimately, James. That allows us to really allow for year over year improvements on everything from empowering our co workers to be able to evaluate existing standards, take out those costs and just make the processes simpler to get the work done. So when you look across those three areas, we have a high level of confidence. We'll continue that track record of 1% to 2% out per year over the plan.

That's great. We appreciate the color, Chris, and congratulations on a great quarter.

Thank you. Our next question comes from Jeremy Tonet with JPMorgan Securities. Your line is open.

Just wanted to come back to the mobile gen a little bit more. Thank you for all the details on how that would look. On the financial side, I was just wondering if you might be able to expand a bit more, I guess, on how conversations have evolved with regulators, with other stakeholders in the state, just wondering kind of state of affairs as you can share?

Yes. Jeremy, I appreciate the question. We continue to have dialogue with all stakeholders and I think folks recognize the value here. ERCOT has signaled a real need in the San Antonio region that if otherwise wasn't addressed, it could impact the entire ERCOT market. We want to be a constructive partner and have said that from day one.

I think our commitment to donate these units effectively at zero cost to help the Aerocont market reflects that. And I think people stakeholders as we've had these conversations recognize that that is a pretty significant gesture on behalf of the company. We also have heard loud and clear the demands to make our customers whole for the period where our customers benefited from this equipment. And I think we've worked hard to find a great solution there that Chris outlined. And so I'm optimistic that we are moving to a path where collectively this is a win win for all stakeholders.

I think the next time this will be addressed is at the special meeting for ERCOT on February 25. ERCOT really wants these units in place before the summer season, so I'd expect this to get resolved here over the coming month or so, so that we can get these units in place by this spring.

Got it. That's helpful there. And then go into the legislative session, Texas, a little bit more. Any proposals that are out there that are on your radar right now and really kind of thinking about the proposed SB six regarding large load and transmission charges. Just wondering if passage happens here, how this could impact Centerpoint in your mind?

Yes. Thanks for the question. The Texas legislature is really now just starting to kick off and pace is going to really increase from here. A lot of the work to date has been committee assignments and kind of policy orientation. What I would say, Jeremy, is we were pretty active in the 2021, '20 '20 '3 legislative sessions.

We'll probably be less active in this one, obviously working to support constructive legislation that continues to help drive resiliency of our system as well as help support this incredible growth that Texas economy is experiencing. With respect to Senate Bill six, look, I really look at that as making sure that large loans pay their fair share as sort of a cost allocation focus. Those large loads encompass a lot of our largest customers here in the Greater Houston region given our strong industrial base. And so we're going to work constructively with obviously our legislators, regulators, customers to find what is a fair cost allocation for everyone. I think it's early days in that regard, but we're working with all parties to find a, this had a constructive outcome.

Got it. We'll stay tuned there. And just a real quick last one, if I could. Any guardrails you could put on the transmission opportunity depending on ERCOT's seven sixty five decision?

Jeremy, guardrails in terms of where do I think they're going to land or how much in terms of incremental CapEx? Just tell me kind

Yes. Look, I think the seven sixty five kilobytes standard will result. And obviously, more capacity on the system, but at a higher cost, right? And so when I threw out that we think it will be at least $3,000,000,000 if not more, I think that's reflective of more of a three forty five kV standard. Also, there's still some work to be done on the specific routes, but I think the number we will push well north of that under a 7,065 kilobytes standard at or above that level under a three forty five kilobytes

Thank you. Our next question comes from Durgesh Chopra with Evercore ISI. Your line is open.

Hey, Tim. Good morning. I just had one question on 2025 guidance. Maybe just Chris, can you for our models, can you help us bridge in 2024, what was included for temporary generation? And in 2025, what are you excluding?

CenterPoint Energy (CNP) Q4 2024 Earnings Call Transcript

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