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Good day and welcome to the Vistra's First Quarter 2023 Results Conference Call. Today, all participants will be in a listen-only mode. [Operator Instructions] Please note, that today's event is being recorded. At this time, I would like to turn the conference over to Meagan Horn, Vice President of Investor Relations. Please go ahead.

Good morning, and thank you all for joining Vistra's investor webcast, discussing our first quarter 2023 results. Today's discussion is being broadcast live on the investor relations section of our website at www.vistracorp.com. There you can also find the copies of today's investor presentation and earnings release. Leading the call today are Jim Burke, Vistra's President and Chief Executive Officer; and Kris Moldovan, Vistra's Executive Vice President and Chief Financial Officer. They are joined by other Vistra's senior executives to address questions during the second part of today's call, as necessary. Our earnings release, presentation and other matters discussed in our call today include references to certain non-GAAP financial measures. Reconciliations to the most directly comparable GAAP measures are provided in the press release and in the appendix to the investor presentation available in the Investor Relations section of Vistra's website. Also today's discussion contain forward-looking statements, which are based on assumptions we believe to be reasonable only as of today's date. Such forward-looking statements are subject to certain risks and uncertainties that could cause actual results to differ materially from those projected or implied. We assume no obligation to update our forward-looking statements. I encourage all listeners to review the safe harbor statement included on slide two of the investor presentation on our website that explain the risks and forward-looking statements, the limitations of certain industry and market data included in the presentation and the use of non-GAAP financial measures. Thank you, and I'll now turn the call over to our President and CEO, Jim Burke.

Thank you, Meagan. Good morning. Thank you all for joining our first quarter 2023 earnings call. I will begin on slide five. We entered the year focused on our four strategic priorities, and we are making great strides. First, our integrated model continues to demonstrate its value and effectiveness. As you probably recall, we spent a majority of 2022 executing on our comprehensive hedging strategy that we said was locking in earnings opportunities for 2023 through 2025. We utilized available liquidity last year to support this strategy as we believe the additional EBITDA opportunities were significant. This first quarter of 2023 we saw this strategy translate into real value as mild weather was experienced across the major markets in which we operate, which led to lower than expected cleared power prices. While we saw power prices clear at approximately $30 a megawatt hour on average, our first quarter results reflect a realization of average prices of around $45 per megawatt hour given we were highly hedged entering the year. In addition, in the outer years where we have been more open, we have seen prices and spark spreads increase as compared to this time last year. We have continued to opportunistically hedged to secure an increasing out year earnings potential. We believe this is important not only because it provides an enhanced resiliency of our earnings profile despite an uncertain commodity market, but also because it ensures we can deliver on our commitments to reliably serve our customers, consistently return capital to shareholders, maintain a strong balance sheet, and transform our fleet as we strengthen our position for the long-term. Second, our return of capital to our shareholders remains consistent and robust. Kris will provide a detailed update on our capital allocation plan in just a moment, but I want to highlight that of the aggregate 4.25 billion share repurchase authorization, we have returned approximately $2.7 billion to shareholders from November, 2021 through May 4th, 2023. Additionally, we are on track to pay $300 million in common stock dividends in 2023 as planned with our Board approving a second quarter dividend in the amount of $20.40, representing an approximately 15% increase over the second quarter dividend paid in 2022. The share repurchase program together with the structure of our dividend plan work in tandem to provide our shareholders with the expectation of dividend growth each quarter, as the aggregate $300 million in annual dividends is spread across a decreasing number of shares of Vistra common stock. Third, we continue our focus on a strong balance sheet. As we see margin deposits return, we are positioned to utilize that cash for opportunistic delevering and/or to reduce the amount of debt we expect to incur to close the Energy Harbor acquisition we announced in March of this year. While the first quarter is typically the lowest free cash flow quarter for Vistra, we were able to repay approximately $500 million of short-term debt. Of course, we're expecting our net debt balance to grow over the balance of the year to fund the Energy Harbor acquisition, which we expect to come with a significant amount of EBITDA. But we remain focused on our goal of a long-term net leverage ratio, excluding any non-recourse debt at Vistra

Thank you, Jim. Starting on slide nine, Vistra delivered $554 million in ongoing operations adjusted EBITDA, including $583 million from generation and a loss of $29 million from retail. Generations results were strong despite the significant impacts of milder weather on pricing, primarily driven by in the money settled hedges opportunistically backing down generation at times when prices were below unit cost, and the recognition of the net bonus position in PJM for Winter Storm Elliott. Those benefits were partially offset by headwinds for the quarter that were known at the time guidance for 2023 was set, including default service migration costs, and lower PJM capacity revenues, as well as entry year impacts relating to timing of hedges and opportunistic acceleration of planned outages into the first quarter. While retail was also impacted by mild weather, it is important to note that due to strong counts in margin management, the results for retail for the first quarter are in the range of what we expected coming into the year. Given the entry year shaping, we continue to see due to higher power costs in the winter and summer months, we anticipate substantially all of the ongoing operations adjusted EBITDA for retail to be achieved in the second and fourth quarters. Accordingly, we are confident in our ability to meet or exceed the midpoint of the $905 million to $1.065 billion range of ongoing operations adjusted EBITDA for retail that we announced on our third quarter 2022 call. Turning now to slide 10, I'll share a quick update on capital allocation. As of May 4th, we had executed approximately $2.7 billion of share repurchases since the beginning of the program in the fourth quarter of 2021. We expect to utilize the remaining approximately $1.55 billion of authorization by year in 2024 with at least $1 billion of cumulative repurchases expected in calendar year 2023 as originally planned. Notably as of May 4th, our outstanding share account had fallen to approximately 373 million shares, a significant reduction of approximately 23% from the aggregate number of shares that were outstanding when the program started in November of 2021. As a result of our robust and consistent share purchases, our dividend program of approximately $300 million per year or approximately $75 million per quarter continues to result in significant growth in the dividend per share received by our shareholders. To that end, the second quarter 2023 common stock dividend of $20.4 per share, which is payable on June 30th, 2023, is approximately 15% higher per share as compared to the dividend paid in the second quarter of 2022. While we remain committed to consistently returning capital directly to our shareholders, we also remain steadfast in our commitment to a strong balance sheet. Accordingly, we continue to target a long-term net leverage ratio, excluding any non-recourse debt at Vistra

We will now begin the question-and-answer session. [Operator Instructions] Today's first question comes from Shar Pourreza with Guggenheim Partners. Please proceed.

Hey, good morning guys.

Hey, good mornings, Shar.

Good morning, Shar.

Good morning. Good morning. I think you sort of touched on this quickly, but I guess what point could you revisit and update the two-year commentary you guys have been providing. And then, obviously, those numbers have been floated around first in 2022. I guess, what kind of O&M inflation is embedded in those? Maybe put differently, we've seen a few of your peers kind of flag strong, increases in O&M costs of late, so I guess what are you guys seeing in those numbers as well? Thanks.

Yeah. Shar -- excuse me. This is Jim. Thanks for your question.

Hey, Jim.

The two-year, if I understood your question, the two-year view you're speaking to is about 2024 and 2025. And as you noted, we had put out the 3.5 to 3.7 range last spring when we started to see the forward curves move and we've been opportunistically hedging into that. When we got to the end of 2022 and we started to talk about 2023, obviously we put out a 3.7 midpoint, which was at the upper end of this midpoint range, which was a construct we were trying to use to signal to the market that we see the earnings power of the business improving, but there's still a lot unhedged at the time we first put it out. Since we've continued to hedge, we see us continuing to move up. So, using the May 4th curves, and this is without including Energy Harbor, we see that midpoint opportunities for 2024 to 2025 start to move up higher than the 3.7, and we see it in sort of the 3.7 to 3.8 range. Again, this is the midpoint of those opportunities, so when we would formalize guidance at the end of this year for 2024, we'll have a bigger range around that, just given the inherent variability of managing through the business. But as we continue to perfect these hedges, we still have some open, obviously, in 2025, we're more hedged in 2024. We see this earnings power definitely improving for 2024, 2025, and in 2026 we're even more open. And if you rolled forward to 2026, we see an increase even further from these numbers.

Okay. Perfect. And then just -- I'm sorry to ask, but what's the O&M inflation you guys are embedding in those numbers?

Yeah. So, the O&M inflation, it depends on which category we're referring to, Shar. We're using, and we have consistently seen something between 3% and 10%, depending on the nature of the input. Labor is different from OEMs doing outages, which is different from variable chemicals we use in the power production process. But it's in that range. And obviously, as a competitive company, we're contracting and procuring as competitively as we possibly can, but we don't have any go gets, if you will, built into the numbers to that we are trying to solve for, this is our best line of sight of what it takes to run this business.

Perfect. Perfect. And then just last, I would love to get maybe a pulse check on sort of the legislative cycle right now, and your expectations for resource adequacy in ERCOT. Anything seem to be a little quieter. Now that the Senate has passed several items. I guess, what are your expectations for pathways forward as this session comes to a close? Thanks guys.

Sure. Yeah. Sure. The -- it's coming down to the final three weeks in Austin. I do think there's been a lot of attention and appropriately so on reliability, and we've talked about that, especially when you consider that Texas is the nation's leader in wind and soon to be the nation's leader in solar, which helps from a sustainability point of view, but we've actually see that there's needs to bolster the grid from a dispatchable generation point of view. That was the impetus for the performance credit mechanism that was adopted by the Public Utility Commission in January. And the timing is such that depending on how the legislative process wraps up, the stakeholder process would begin for this PCM mechanism to be able to create a market mechanism to reward reliability. There's still many bills being considered in the house and the Senate, so it's hard to predict what might pass. But I think from our standpoint, the PCM is meant to address not only the incentives for new generation, but ensure that existing generation doesn't retire prematurely because some of the other forms of generation are getting production tax credits, which as you know, can create downward pressure on market power prices. So from our standpoint, we think the reliability focus is important. If the PCM is well designed and it moves forward, we think that it'll bolster the competitive market. We obviously want to continue to see support for our integrated model in Texas. We think it's a business that serves customers well, and we would intend to invest in building gas fire generation if there is a well designed PCM. So, we think policymakers are focused on the right aspects of what it takes to keep the grid affordable, reliable, and sustainable. And sure, our view is we want to be part of that solution here in our home state, but we still have three weeks to go and we'll obviously have to provide more updates as the session wraps up. But I do think the attention on this is well deserved and we'll be involved as much as we can through this session and the stakeholder process.

Very helpful, Jim. Thank you so much. Have a good morning. Appreciate it guys.

Thank you, Shar.

The next question comes from Julien Dumoulin-Smith with Bank of America. Please proceed.

Hey, good morning team. Thank you for the time. Appreciate it. Look, I wanted to just follow up on the success of the Energy Harbor transactions. Obviously, got a lot of folks attention. Can you talk a little bit about your thoughts about looking into potential further inquisitive activities? Obviously, there's a NorthStar around, buybacks and commitments there in and maintaining that throughout. But can you talk today, especially in reaction Energy Harbor, how you would think about perhaps leaning in further to, whether that's nuclear or other angles that could include retail renewables or what have you. But we'd love to hear your thoughts.

Thank you, Julien and good morning. Look, we have generally stayed away from commenting on M&A. I think it's one of those activities that opportunistically comes your way and you have to be prepared for it. You have to always be what we'd say, hang around the hoop a little bit on opportunities. However, I think the Energy Harbor transaction is a very significant one for us. Certainly, it's our focus right now, not only getting through the approval process with the key agencies, but the integration activities with the team at Energy Harbor and with our team. As you note, it's transformative in a lot of ways, because we used it as a platform to highlight just how much of a business we have with the carbon free aspects of our business. And obviously, we're going to more than double that amount of generation with this transaction. The strong balance sheet and the returning capital, the reason we keep repeating the four priorities is because we have to find things that fit within those four priorities and not everything is going to. And I think that's a commitment we've made. I think the Energy Harbor transaction reinforced. We mean those that we're going to stick with those four core principles. So Julien, nothing is ever off the table from the standpoint of looking at it, but it needs to fit the criteria that we've laid out and we're going to remain disciplined in that regard.

Got it. No, fair enough. I appreciate that. Look -- and then with respect to the transaction itself, I mean, can you comment a little bit? I mean, seems like there might be a slight delay in the close the transaction, just what caused that, what approval process, or just the execution process? And then related, you talk about a significant jump in generation here. You all obviously have a pretty sizable retail platform. You saw some quarter-over-quarter declines in retail customers. How do you think about building out that retail platform a little bit further here in light of Energy Harbor, Oregon? Is that less of a priority considering things like the nuclear PTCs that might deemphasize the need to want to quote unquote balance that retail business with generation, if you will?

Sure. Well, on the first matter, I think we're progressing well on the approvals process. We announced the transaction early March. We made the filings, the key filings in April. We believe the NRC is working towards an early October approval, which to be on the six-month track for a license transfer, we think, is actually on the more efficient side of the scale in terms of where we would go. We've talked about closing this in the fourth quarter, and I think that is achievable. Julien, as you know, we don't have anything built into our numbers for 2023 related to Energy Harbor. So, hopefully, there's some opportunity there. But just I think we're tracking well. There's nothing that we're concerned about at this stage, but it's still early in the approval process. But so far so good. On the retail side, our reduction in counts has been more outside of the ERCOT market. We've made some strategic exits in a couple states. The Energy Harbor platform does give us an opportunity to bolster some of the areas where we do currently operate in retail. And obviously, it gives us an asset base, including some attributes like the emissions free energy credits, which customers are becoming more interested in that the nuclear units can offer. So, I like our retail, we like our integrated model. We do think the Midwest Northeast market reforms in some of the retail markets is still warranted. As we've talked about, Julien, the level of competition there in terms of the degree to which you can differentiate your products, there is still rather limited. It's more of a hedge channel and being able to serve customers with your assets than it is a true business to consumer or business to business differentiated marketing strategy. We hope to get there in some of these markets and we'll continue our efforts from a stakeholder outreach perspective. But the integrated model is certainly well intact with this acquisition, because it comes with a retail business in addition to a generation. But we do need to see these markets open up a little bit from a reform and being open to innovation in these markets, the way Texas has been open innovation. And so, we do have some work to do there, Julien.

Excellent. All right. I'll leave it there. Best of luck guys. We'll see, speak soon.

Thank you, Julien.

Our next question comes from Michael Sullivan with Wolfe Research. Please proceed.

Hey, good morning.

Hey, Michael.

Good morning.

Hey, Jim. Hey, Kris. Wanted to just confirm on the upside you're seeing in 2024 all the way out to 2026, that's based on basically current curves. And then if so, maybe if you could just give us your own point of view on where you think things could go just based on supply/demand dynamics in your major markets.

You bet, Michael. Thank you. Yes. We base this off of using the May 4th curve. So, it's a function obviously, of where we have hedged, what we still have open, and the curves as of May 4th. Not that the liquidity is infinitely deep in some of these outer years, but it's not based on a point of view. It is based on curves. We know that this is something that you and our investors are trying to follow, which is, are we seeing some upside? As Kris laid out in his chart, from the time we first initiated the strategy of talking about a three-year horizon, the curves have actually improved in those outer years. So, while we've seen the front of the curves come down because of a number of factors, I'm going to ask Steve Muscato, our President of Wholesale, to comment. We've seen the out years actually strengthen, and we think that that's actually a sign of opportunity for Vistra long-term. But in terms of the dynamics by market, I think it might be helpful for Steve to share a few thoughts as to how we see these markets being impacted by some of the factors obviously late last fall and through this year and where we see that headed. Steve?

Thanks Jim. Sure. I would add, if we start with natural gas, which is kind of a big driver behind power prices, the marginal shell has now become the Hainesville, which is a dry shell. We're seeing limited growth in the Utica and the Marcellus due to limited pipeline take away and all the growth in the Permian that's happening, even though that's a wet shell, it's not the marginal shell. It's being used to really feed growing LNG export markets. So, that's really provided support on natural gas, which is why you're seeing it stay $4 and above, at least 2025 and beyond. The front end of the curve is really influenced by a -- some excess storage inventories that are due to a mild weather, that if you look going forward, if you assume normal weather should balance itself out once you get to the 2020, late 2024, early 2025 period. In terms of like, say, fundamentals in each market, you're seeing this integration of renewables, particularly challenging in PJM, you see a lot of coal leaving the stack over time, but a slow incremental movement in renewables. Not only are renewables less effective in markets like PJM because lower capacity factors, it doesn't have the same irradiance or wind speeds that you see in markets like Texas and Mico. But it also takes a lot to replace it. You could see five to nine to one replacement levels needed in order to maintain same levels of reliability. You also have problems with east coast gas markets to the extent they can recouple with European markets. That could also cause some volatility. And I think Jim mentioned some of the things that are already happening in ERCOT in terms of reform. You have solar pushing the peak out. You only have one hour batteries coming into ERCOT, which it really doesn't help on an extended heat wave that may occur or extended cold front. And so, I think uncertainty around gas and coal assets and determine what happens with the legislature in addition to an aging fleet provides this collision we're seeing over time, which is going to win out the renewables or fossil fuels, and at least in the intermediate term, it appears gas is going to be needed. It's going to be stressed. And so, we think that's supporting fundamentals out.

Steve, thanks for that. I'll just add, Michael, that in addition to the dynamics we're seeing of the resource fix and how it's changing, we've seen obviously a handful of significant environmental regulations that have been issued and potentially forthcoming that could also put some pressure on assets that currently are providing a reliability service on these grids. And our assets even with a Vistra Tradition and a Vistra Vision, coal is 25% to 30% on a go forward basis of Vistra Tradition. It's predominantly our combined cycle gas fleet. We think that has a lot of value in helping these grids be able to sustain a reliable operation while integrating more renewables. And then, of course, our Vistra Vision is anchored by Vistra

Okay. Thanks. That was super comprehensive. Maybe just one quick follow up there on the environmental rules. So, from where you're standing right now, Jim, like any near term impact in terms of whether it be investments that you have to put into some of your coal plants that you were planning to keep online?

Not in the near term, Michael. A couple things. Obviously, the CCR, ELG rules we have talked about for years, and that does have impacts on our coal fleet, which we've communicated multiple times that will have retirement dates and that sort of 2027, 2028 horizon except for two of our sites. Casper or the Good Neighbor Rule, it did -- it was recently stayed. So, you have an opportunity here for the state of Texas to revisit this rule. Obviously in the fifth circuit, it's going to take some time to sort that out. That could impact some of our old gas units, could impact the Martin Lake if it were to be fully implemented. But I think there were good reasons for the challenge and we're certainly not the only party in that challenge. There's many industry participants outside of even power as well as the state. But no, Michael, we don't have any anticipated large CapEx spend as a result, but we stay active. Again, reliability is important and we think that that this transition that's occurring on the grid needs to be done so thoughtfully, but nothing -- no near term impacts with the stay, maybe a little bit pushed out from that standpoint in terms of impact on our fleet.

Appreciate all the color. Thank you.

Thank you, Michael.

Next question comes from David Arcaro with Morgan Stanley. Please proceed.

Hey, good morning. Thanks so much for taking my question.

Hey, Dave.

Hey. Let's see. Wanted to check on the retail business. Just wanted to confirm, is that on track for the year, given the first quarter results? Are you going to -- need to pursue some more proactive initiatives to keep kind of in line with the guidance range for this year? Or is this really just the -- maybe more natural ebb and flow of the EBITDA results for retail?

Yeah. Thanks for the question, David. As we noted in the comments, 29 -- the loss is $29 million that was expected -- that was within the range of what we expected when we set the guidance. So, that's not far off of what we were expecting going forward. We continue, and I noted this, but we continue to expect retail to be able to meet or exceed the midpoint of its guidance range that we provided in the third quarter of last year. We don't -- we see some timing effects over the balance of the year and some margin and count benefits that have carried through that we see will offset some of the pressures they saw from weather in the first quarter. So, we don't see anything in particular over the balance of the year that we need to stretch to meet that goal. Again, as we would note, the shape continues to be that we're going to see pressure on the retail side from an EBITDA perspective in the first and third quarters. And the second, fourth quarters is where they're going to make substantially all of the EBITDA. And that's because they typically have flat prices through the year, but the power costs in the winter and summer months are the highest. So, there's some pressure on EBITDA in the first and third quarters and the second, fourth quarters is where they make it up.

Got it. Okay. Thanks. That's helpful. And then, similar topic, I was just curious what the latest trends you're seeing are in customers moving to default service. Is that still a trend that's happening or which direction are you seeing right now?

Yeah. David, we're still seeing some default prices increase in the markets through their kind of delayed procurement, but you are seeing competitive offers in the market that are now south of that default level. So, you are not seeing the same level of migration to default. You're going to start seeing and we are seeing folks moving from default back into the competitive arena that is part of this market dynamic. I was mentioning that from a reform standpoint, ideally you would have a one-to-one relationship with the customer and not have it a customer bouncing between a utility and a retailer. But at this stage of the game, obviously prices have crested, they've started to come off in the wholesale market and that's creating opportunities for our retail business. But it's also creating some of the migration in some markets away from default and default prices because they're still increasing in some markets through May, that's going to create more and more savings opportunities for customers.

Okay. Great. That makes sense. Thanks so much.

Thank you, David.

Our next question comes from Durgesh Chopra with Evercore ISI. Please proceed.

Hey, good morning team. Thanks for giving me time. Hey, just wanted to make sure Jim, I sort of heard this clearly in the response to Shar's question earlier, for 2024 and 2025, the midpoint is in the $3.7 billion to $3.8 billion range, and 2026 is expected to be higher than that for the base business?

That is correct.

Okay. And kind of above $900 million for Energy Harbor in 2026 as well?

Yeah. That is the view that we have. And obviously we've talked about this on a hedge basis, which is largely open in 2026 Energy Harbor. We've talked -- because we are 2024, 2025 numbers that we've given, you have hedges in them for Energy Harbor. Once you get to 2026, Energy Harbor is pretty open. We're pretty open. And actually you could see Energy Harbor doing better than $900 million when you get out to 2026 again at current curves.

Understood. Thank you for clarifying that for me. And then just as we look to the end of the year or maybe as you close on Energy Harbor, what should we expect in terms of disclosures? It is your -- is it going to be sort of a three-year, kind of like you did last year EBITDA guidance and free cash flow range? Just any color you can share, that would be helpful. Thank you.

Yeah. We're going to -- I think we will obviously update guidance for the balance of 2023 and then 2024 at or at the time of closing. We haven't made a decision as far as how far out we'll continue to update. We'll probably continue to give directionally where we see things going. But I think we're -- I don't know that we plan to continue to consistently give three-year ranges going forward. But as we get closer to closing, we'll getting updates to what we've put out so far.

Understood. Thanks Jim and Kris.

Thank you, Durgesh.

Today's final question comes from Angie Storozynski with Seaport. Please proceed.

Thank you. So -- actually some questions. One about flexibility in financing of the Energy Harbor transaction. So, I think we're all watching credit spreads. You have this deal to finance. You have the bridge financing in place, but you plan to refinance it before the end of the year. So, I'm just wondering if you could use, for example, any of the project level debt you mentioned at the renewable assets to maybe help yourself here. So that's one. And number two from the -- a bigger picture question. So, when you look at the mark-to-market of earnings of Vistra Vision and Vistra Tradition at these prices, you are solving for deleveraging pretty quickly. Probably 2025 if not sooner. So, would that change your thoughts about keeping these two businesses together, i.e. could we see a separation of Vistra Vision, again, which would unlock the true value of these assets? Thanks.

Angie, I'll handle the first question where we talked about financing of Energy Harbor. Obviously we -- in the -- when we announced the transaction, we put out some assumptions on the amount of cash that we would use and the amount of debt in the split of the debt. We continue to look for opportunities. First as you saw, the margin deposits are coming back as expected. We saw about over $1 billion, approximately $1.2 billion come back from the end of the year into -- through March 31st. And we continue to see some margin of deposit returns as we settle our hedges going through the summer this year. So, you can expect us to continue to optimize the amount of cash that we're going to use from the balance sheet. As we -- and so it could be larger than the amount that we indicated on the call when we announced the transaction. As far as debt, we're going to look at a number of opportunities. We're going to be opportunistic as to timing and which market that we're in. So, we're already preparing for those opportunities. And I think you'll see us look at a number of different avenues to raise that debt and not just wait until the end and try to do it all in one market.

And Angie, this is Jim. I'll add to Kris' comments on that. The idea obviously with Vistra Vision as it was conceived in order to execute on this transaction and keep a strong balance sheet, did obviously do two things that highlighted the amount of our earning stream that has a zero greenhouse gas emissions profile. It also created an investment vehicle for some of the key shareholders for Energy Harbor to participate in this future entity. I still step back and think about this as a customer business that is -- that has a changing sort of view of what they're looking for from the electric grid, including a more sustainable grid, but also a reliable grid. That in essence is Vistra. I mean, that is what we're doing. We're doing it, we're expressing it through different transactions. Energy Harbor obviously is the most significant one, but with the Ambit and Crius and growing our retail presence and then our launching of our own opportunities with Vistra

That's great. And just the last one question. So, you mentioned on some of it, that we're seeing relatively limited liquidity in those forward curves for power, right? There's always this question, is gas more liquid versus power and maybe those spark spreads that look incredible in forward years, I mean that are just to be true. So, I mean, is there a way for you to basically capture that strengths even with limited trading liquidity in power markets, either through some derivative transactions, gas driven hedges, you name it.

Yes. Angie, we can. Obviously, gas is more liquid than power, and gas many times is a good proxy for power. But to your point, it's not a perfect proxy for power. And Steve, why don't you comment a little bit on some of the things that we do to try to use liquidity efficient means and how we're thinking about capturing this value. Because we are sensitive, Angie, that the further out we go, depending on how we hedge, there obviously is a use of liquidity, and we balance that into our thinking. And we're not also thinking that these curves just go away tomorrow because again, the fundamentals of what we think is happening with the electric grid speak to reliability and assets with flexibility, which is our portfolio. And we think those are getting valued and they're getting valued differently than they have in the past, because reliability was taken for granted. But Steve, why don't you comment a little bit on how we're thinking about blocking this in.

Sure. I think for nuclear assets, gas is a decent proxy as a hedge. And so, we are able to use gas instruments like the NYMEX and different NYMEX structures to at least either lock in value or put a range of value in place to kind of protect downside. But we do have the PTC, so that's a consideration. In terms of the sparks, we do have to buy the gas in order to lock in the spark, and some of the specific gas locations is more challenging. I think ERCOT, PJM, there's more liquidity than places like New England for sure. But we try to do it in a liquidity efficient manner because as you get out further, the independent postings or the independent -- the initial margins that you have to post with exchanges can be quite expensive as you go out in time. And so, we're looking at trying to increase credit using first lien structures when we go out that far, or even bilaterally with counterparties to get that done. And so, it's a little bit slower from both, because we're trying to use liquidity efficient channels, and also going directly to customers and other wholesale counterparties. But it is something we've begun working on in 2026, even out as far as 2027. But it will definitely take time. And again, trying to use liquidity efficient channels is important, like first liens and direct to bilaterals.

Great. Thank you.

Angie, thank you for the question.

Yes. Thank you. I want to thank everybody for joining us this morning. We appreciate your interest in Vistra and please know that our Vistra team is working hard to execute well for the summer, and our strategic priorities, and we look forward to giving you future updates. Have a great morning everyone. Thanks.