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spk00: For any further assistance, please press star zero. I would like to turn the call over to your speaker today, Chris Soros, President and Chief Financial Officer of Clearway Energy, Inc.
spk06: Good morning. Let me first thank you for taking the time to join today's call. Joining me this morning is Akil Marsh, Investor Relations, Chad Plotkin, our Chief Financial Officer, and Craig Cornelius, President and CEO of Clearway Energy Group. Craig will be available for the Q&A portion of our presentation. Before we begin, I'd like to quickly note that today's discussion will contain forward-looking statements, which are based on assumptions that we believe to be reasonable as of this date. Actual results may differ materially. Please review the safe harbor in today's presentation, as well as the risk factors in our SEC filings. In addition, we refer to both GAAP and non-GAAP financial measures. For information regarding our non-GAAP financial measures and reconciliations to the most directly comparable GAAP measures, please refer to today's presentation. Turning to page four. For Clearway Energy, the last quarter has been historic in terms of strategic execution and providing the company with an unprecedented level of financial flexibility to allocate toward growth in CAPTI per share. I am also very proud of and want to thank our teams who have operated safely for the past year and a half on the face of a pandemic. Their continued work on behalf of the company during this difficult time is of immeasurable value. I'm pleased to report that Clearway's financial results year to date are in line with our sensitivities and we are maintaining guidance for 2021. Clearway has announced an increase in its dividend by 1.6% to $0.34 per share for the fourth quarter of 2021. This achieved our goal of growing the dividend at the upper end of our long-term target in 2021, establishing a new baseline of $1.36 dividend per share on an annualized basis. Chad will review the results in more detail later in the presentation. I'm pleased to announce that Clearway has agreed to sell our thermal business for $1.9 billion, with an expectation of $1.3 billion in net proceeds after the assumption of non-recourse debt, estimated state taxes, and other transaction costs. This transaction was represented at approximately 20% of our market capitalization prior to announcement, compared to 10% of our current CAFTI, affords C1 an extraordinary level of financial flexibility, allowing us to drive long-term shareholder value while increasing our renewable portfolio footprint. Due to this flexibility, we require the remaining 50% interest in Utah on an unlevered basis for $335 million, adding $30 million of CAFTI on a five-year average basis, thereby replacing approximately 75% of the annual thermal CAFTI contribution of approximately $40 million, while only utilizing 25% of the $1.3 billion of thermal proceeds, an asset that has the benefit of 15 years remaining on its BPAs and a stable generation profile. Clearway will also fund its remaining capital commitments from previous announced drop-down transactions with this capital, allowing for $680 million of proceeds remaining to be allocated after funding all of these current growth investments. Let me be clear. We at Clearway do not take this capital as a license to lower our underwriting standards and return targets or to grow simply for the sake of size. We will allocate this capital with a core focus on driving sustainable per-share CAFTI and dividend growth. Hand-in-hand with this flexibility in capital allocation, Clearway Group continues to expand its development pipeline, including over 1.9 gigawatts of late-stage development projects with anticipated funding between now and 2024. We have been working with our Clearway Group colleagues on some exponential drop-down investments and tend to finalize economics when tax policy becomes more transparent. In addition, over the past quarter, we have further executed on contracting a significant amount of the financial position at our California natural gas assets beyond the expiration of their existing contracts in 2023. Specifically, we now have resource adequacy contracts for approximately 80% of marsh landings and 100% of Walnut Creek's net qualifying capacity at terms that maintain project-level CAFTI through the end of 2026. For those of you who have been following Clearway for some time, the success on a significant amount of previously open megawatts at strong prices is a significant step in maintaining the stability of CAFTI per share for years to come. As a result of this, Although it is the unprecedented financial flexibility afforded to Clearway via the thermal transaction, I am pleased to announce that we now see the ability to support our CAFTI per share and our corresponding dividend per share growth in the upper range of our 5% to 8% long-term growth objective within our payout ratio targets through 2026. I will review in a couple slides our potential path to target per share CAFTI in excess of $2.15 when the capital from the thermal sale is deployed. Turning to page five, this provides an overview of the thermal transaction. As discussed previously, Clearway has signed a binding agreement with KKR to sell the thermal business for $1.9 billion of total consideration, resulting in $1.3 billion of net expected proceeds. This results in a very accretive implied CAFTA yield, with the transaction expected to close in the first half of 2022. These net proceeds eliminate the need for Clearway to issue any new equity to fund the remaining $620 million of committed growth investments resulting from the previously announced transactions with CEG and the acquisition of Utah on a longer basis. After allocating capital to existing commitments, Clearway has remaining $680 million of excess proceeds, or more than $3.30 a share, to allocate to maximize shareholder value. This capital will be deployed with an adherence to our core underwriting standards that have served Clearway well in a variety of market conditions, focused on driving sustainable CAFTI and dividend per share growth. As a result of our current NOL position, excluding the impact of any new business activity or deployment of the $680 million, we anticipate our tax runway to come in by approximately three years to approximately 6.5 years, with some potential state tax obligations. It's important to note that while the NOL will move inward because of the strong economics of this transaction, we see the ability to maintain or lengthen that tenor depending on our deployment of capital and growth in the future. In previous years, we have been able to maintain our NOL runway through investment and additional assets. Looking at the right side of the page, this transaction allows us to improve the balance of the platform that comes from renewables. As a result of the transaction, our investment in committed investments, but not on allocated capital, our pro forma CAFTI contribution from renewables will increase from approximately 62% to 75%, and our adjusted EBITDA from 59% to 82%. For all the economic logic of the thermal transaction, the ability for Clearway to emphasize renewables as a part of its growth story is another key benefit to the portfolio. as it focuses the company's future more centered on the higher growth renewable sector. Page 6 provides an illustration of Clearway's allocation of $620 million of the thermal sale proceeds. Turning to the left side of the page, our remaining commitments from drop-down transactions account for $286 million of capital. These transactions have been factored into our growth outlook into 2022 and are on track for closing by year-end. These commitments will be funded under our revolver until repaid with the final proceeds of the thermal sale. On the right side of the page, we are now showing our Utah acquisition on an unlevered basis, allowing for $30 million of asset CAFTI, or a 9% asset-level CAFTI yield. This replaces 75% of the thermal CAFTI contribution while only allocating 25% of the proceeds by redeploying the capital into an operating solar portfolio with 15 years remaining under its PPAs and low operational volatility. Clearway has a high degree of confidence in the Utah asset's performance, having owned 50% of it since 2017. The ability to play capital at a strong unlevered CAF deal, an operational asset in which we have significant operating history, and the ability to drive operational synergies creates a strong investment opportunity for the company. Clearway will fund this acquisition through a bridge facility that will be repaid upon closing of the thermal transaction. The allocation of $620 million of the thermal sale proceeds of these investments allows Clearway to eliminate the need to issue any equity to close these transactions, while leaving $680 million of capital remaining to be profitably employed. Page 7 provides an update to our pro forma CAFTI outlook with the allocation of the thermal sale proceeds. With this allocation, and from the recontracting of the majority of our California gas assets, we see a path to be in the upper range of our 5% to 8% dividend growth target through 2026. starting with our current $1.85 of CAFTI per share pro forma guidance, where reduced CAFTI of $40 million from the sale of thermal, but regained $30 million of that with the acquisition of the 50% of Utah we don't already own. This, combined with the avoidance of issuing approximately 11 million shares that underpinned the investment that produced the $395 million of CAFTI in the first column, produces an updated pro forma CAFTI outlook of $1.90, with $680 million left to be deployed. If one assumes that Clearway allocates $680 million at an 8.5% CAFTA yield, that drives our CAFTA to $440 million in absolute terms and north of $2.15 on a per-show basis. This financial flexibility affords Clearway the ability to maintain its underwriting standards while not requiring additional capital. This ability to be efficient with our capital base will be employed as we look to identify drop-down opportunities that we're working on with our colleagues at Clearway Energy Group. Clearway has always emphasized that it is per share CAFTI that drives dividend growth and returns for our investors, and our focus on acquiring attractive assets as well as being disciplined with capital deployment and our NPV and IRR targets are the driving forces behind quality growth. With that, I'll turn it over to Chad. Chad?
spk04: Thank you, Chris. I'm turning to slide nine. For the third quarter, Clearway is reporting adjusted EBITDA of $337 million and and cash available for distribution, or CAPTI, of $161 million. Year-to-date, results continue to be within the company's sensitivity range, having now realized $900 million of adjusted EBITDA and $301 million of CAPTI. For the third quarter, the company benefited from excellent performance at the conventional segment and higher volumetric sales at the thermal segment. However, this was in part offset by low resource across parts of the renewable portfolio and as well as the timing of project-level debt service, which occurred in the third quarter versus the fourth quarter. For the conventional segment, availability across the California natural gas assets was above 99%, again demonstrating their value as critical reliability resources in the state. For thermal, the business continued to realize higher volumetric sales with an increase through the third quarter of approximately 6.5%, versus the same period last year due to favorable weather and ongoing recovery from the COVID-19 pandemic. At the renewable segment, challenging wind conditions observed in June extended into July where resource was exceptionally low. However, the wind portfolio did produce above average generation combined in August and September, bringing total wind portfolio performance during the quarter to around 91% of median expectations. For the solar segment, irradiance was also below expectations, as performance was at 94% of estimates. That said, on a year-to-date basis, the strength of the AltaWind project through most of the year and solid first-half solar production has insulated overall financial results. Lastly, results relative to estimates were impacted due to the timing of a debt service payment at a non-recourse entity. However, this will offset in the fourth quarter, so there is no change relative to four-year expectations. Given these factors, overall year-to-date CAPD is in the company's sensitivity ranges, so we continue to maintain CAPD guidance of $325 million. As a reminder, this guidance does continue to assume P50 median renewable production for the full year and is also affected by the approximate $25 million impact in the first quarter due to the February winter event in Texas. Moving to the balance sheet. During the third quarter, the company successfully refinanced the outstanding 26 senior notes with a new green bond that matures in 2032 at an interest cost of 3.75%. With this refinancing, the company has now cost-effectively extended the maturity of all its outstanding corporate indentures with the earliest maturity now in 2028. For capital formation, since the company now intends to fund all committed growth using cash proceeds from the thermal sale, whereby eliminating the need for new equity issuances, We will utilize existing and new temporary facilities to close transactions during the interim period. In that regard, we currently have $375 million available under the revolver, and we are working through an expected bridge financing facility to support the funding of the Utah transaction until the thermal sale closes. Now turning to slide 10 to discuss the update to the company's long-term pro forma CAPT outlook in 2022 expectations. Today we are announcing a revised view of our pro forma CAPTI outlook to $385 million. As noted on the slide, this figure captures the full exit from the thermal business, the expected average contribution from all committed growth investments, and continues to assume P50 median production estimates. It also assumes the California gas assets operate within current run rate profiles post-contract maturity, which is now significantly mitigated given success in recontracting. This figure does, however, exclude any further growth that may be realized from the deployment of the $680 million of excess proceeds from the thermal transaction. While the pro forma CAPD outlook and further growth potential is most critical for the company's ability to meet its long-term commitments, today we are also establishing 22 CAPD guidance. As noted on the slide, we provide a summary explanation from 2021 to 2022 CAPD guidance, including the effect of growth realization, the Utah transaction net of bridge financing costs, and a reversal of the February 21 winter storm event impacting current year results. This leads to the establishment of 2022 CAPT guidance of $395 million. However, please note that due to the timing of uncertainty of when the thermal sale will close, current 2022 CAPT guidance does factor in an expected $40 million on a full year basis from the thermal business. As is our normal practice with strategic transactions, we will provide an update to current year expectations upon the closing of the thermal sale. But as noted, the exit of the thermal business has already been accounted for in the $385 million on a pro forma CAPT basis. Now turning to the next slide to summarize where we stand from a balance sheet perspective relative to our pro forma CAPT outlook. Balance sheet management and the maintenance of our long-term credit metrics continue to be core strategic principles for the business. This is critical to grow the company over the long run as adherence to these standards supports the most effective cost of capital for the enterprise. As we evaluate where we stand today versus where we will be in the future, the trajectory is not only favorable relative to Clearway's ability to meet its growth objectives, but also as it relates to maintaining its credit ratios and and maximizing balance sheet flexibility and capacity over the long run. Using our pro forma outlook today, you will note in the left side of the table that relative to our targets, we are in range as corporate debt to corporate EBITDA is around 4.5 times and FFO to corporate debt is at 18%. Importantly, this excludes the impact to net debt given the excess $680 million in proceeds from the thermal sale that has yet to be allocated. As noted on the right side of the table, as we begin to allocate that excess capital and put consideration into the potential CAPD that can materialize from the deployment of this excess $680 million, not only will we be in a better position to extend the dividend growth runway, but our credit metrics will also improve. This is evidenced by the presentation of a potential reduction in our leverage metric to 4.0 times and an improvement in FFO to corporate debt to 21%. Given the strength of of these potential metrics, the company will build even further flexibility to execute on growth and maximize financing capacity while importantly adhering to its long-term balance sheet targets. And with that, I'll turn the call back to Chris for closing remarks.
spk06: Thank you, Chad. Turning to page 13, I cannot overstate how critical our accomplishments this year have been toward achieving our goals not only in the short term but also for years to come. In 2021, we've been able to maintain our guidance and deliver our commitment to grow the dividend at the high end of the range for 2021. During 2021, we have continued to optimize the balance sheet through our issuance of the 2031 and 2032 green bonds, which will result in interest savings and expansion of our maturity profile. Clearway has also benefited from the success in third-party M&A through the acquisitions of Mount Storm and the remaining 50% of Utah, resulting in $40 million of CAFTE for Clearway at attractive returns. As a result of our successful thermal transaction and the extension of our contracts on our California gas fleet, for the first time, we've had the privilege of becoming CEO of this company in May of 2016. Clareway has the visibility to confidently see a path forward being able to support per share CAFTE and dividend growth in the upper range of a 5% to 8% long-term growth target through 2026. We look forward to continuing to grow and achieve our goals around shareholder value creation. Thank you. Operator, open lines for questions, please.
spk00: Certainly, and as a reminder, to ask a question, simply press star 1 on your telephone. To withdraw the question, press the pound or hash key. Please stand by while we compile the Q&A roster. Our first question is from Colton Bean with Tudor Pickering Holt. Your line is open.
spk05: Morning. So just on the RA agreements at Marsh Landing and Walnut Creek, Can you characterize the interplay of rate and tenor, if any, or ask differently, were the counterparties solely focused on that three to three-and-a-half-year time frame, or was there some consideration of longer-term agreements but at a lower rate?
spk06: There's, I mean, a wide range of outcomes. They basically ask you to bid. I think the counterparties were focused on that three-and-a-half-year time frame, but you'll provide them a variety of bids with a variety of tenors, and that's where we ended up.
spk05: Got it. And then just on the... On the dividend guide now extending through 2026, guided to the upper end of the range, can you speak to what level of coverage you think about needing at that point in time with the recontracting window now aligning in 2026 as well?
spk06: It may phrase differently. We think that the dividend growth rate we've talked about at the upper end of the range can be achieved between our 80% and 85% payout ratio, if that was kind of your question.
spk05: Okay. Yeah, that makes sense. And really just trying to understand how you think about, you know, growing the dividend through 26 with natural gas now aligning with the 2026 recontracting window as well.
spk06: Yeah, I think from our view, it's almost that we now have confidence because of, A, the amount that we have been able to contract through 2026, and, B, obviously the thermal proceeds from a great transaction that gives us the confidence and that visibility through 2026. So I think, to your point, it's almost that now that we've reduced the risk significantly in our California portfolio through the contracting of those two gas assets, we feel much better about the volatility or lack thereof through 2026. Got it.
spk05: Appreciate the time.
spk00: Thank you. Our next question comes from Julian Domolin-Smith with Bank of America.
spk07: Hey, good morning, Keith. Thanks for the time and the opportunity here. Well done on all these updates, really. Kudos. So perhaps if I can kick things off first on the remainder of the cash here that you guys are raising from the thermal sale. I mean, just any further thoughts on just the direction that you guys want to talk to? I mean, it seems obviously like the pipeline itself is growing organically. I mean, should we expect this just to be feathered in in a normal course, or is there some sort of accelerated process pace of either acquisitions from the sponsor or, frankly, you know, third party that we should be watching care. As well as, if you can comment, now that you've contracted up, again, kudos on California, is there any thought process around further monetization of those assets?
spk06: Open question. Sure. So a couple different questions there, Julian. So I think part one is we think about the remaining cash. It's not as though, I think what I tried to emphasize was the flexibility it affords us. There isn't necessarily, and I think importantly, as I also try to talk about on the call, it's not we're going to deploy the cash simply to deploy the cash, right? We're going to remain very disciplined in how we think about IRR, NPV, and CAPT accretion. This isn't an opportunity to say, well, I'll do things at a 6.5% CAPT yield, for example, simply because it's accretive. And so from our view, we're going to continue to work with our colleagues at CEG around the development pipeline to kind of hopefully be able to allocate some of that capital to there, work through third-party M&A, And keep in mind, we talked about that the transaction would close kind of in the second half of 22. Just for clarity, if you said, what's the probability of February? That's not really a fair probability. It's much more the second quarter than probably the first half in terms of the more probable outcome. So to me, we're going to continue to work on with CEG any drop-down opportunities that they might have, third-party M&A, and also see where we sit in kind of, let's say, May of 2022 when we actually close the transaction as an illustrative example and see what our opportunities are. And I think that could include return to capital to shareholders if that makes the most sense as well. To your other question around California natural gas and monetization, I think for us, as I've indicated, we really look at the portfolio on a holistic level, kind of looking at all the pieces together. This obviously provides us with a pretty good runway. We're going to also continue to try to contract those assets. Just because we got contracts through 26 doesn't mean, as you've seen with some of the CCAs, that they're willing to go out further. So there's nothing that says, you know, we could try to contract in 2027 on a forward basis with some of these entities. So I think, Julian, our approach on the California gas is, A, we're always open to sale of assets at appropriate value, but, B, this definitely buys us time in terms of thinking about those assets and any monetization thereof.
spk07: Gotcha. And then if I can follow up here real quickly, how are you thinking about standalone storage within the portfolio? It looks like the pipeline seems to be including some of this. as well as just opportunities to complement your existing gas assets with those kinds of resources in California, given just how constrained and limited those opportunities might be for Greenfield.
spk06: Sure. To your point, we do look at storage as part of the, you know, drop-downs that we have in the future. I think in terms of our existing platform in natural gas, keep in mind we've already installed Black Start and the process of installing Black Start capability at our marsh landing assets. So, It doesn't have an infinite amount of space at that site, but we constantly evaluate if storage makes sense at those natural gas assets. But just for clarity, we do have black start at marsh landing, so some of that space, so to speak, has already been allocated.
spk03: Chris, I could add that from a tenor and contractual structure perspective, Julian, where we're developing standalone storage assets, we're doing so generally where – the market design will allow for those projects to be contracted to produce contracted revenue profiles that are compatible with the investment mandate that Clearway Energy Inc. has or where they provide some complementary risk reduction for other assets. And we also see opportunity for hybridizing existing operating renewable plants in places like California. So as we're developing both paired and standalone storage assets, we're trying to think about the fleet as a whole. We're selectively developing those storage assets so that once built, they fit together with the whole of a portfolio, which is intended to be low risk in its cash flow generation and balanced in terms of resource and customer diversification.
spk07: Sorry, one quick clarification, if I can, on credit. Obviously, your peer NEP had some updates with rating it too late. Is that a further angle with you all? Sorry, just to throw that out there. Chad, why don't you take that?
spk04: Yeah, Julian, I think I know what you're referring. I mean, I think, look, I think as we look at our forward metrics, we kind of look at the two core metrics between corporate debt to corporate EBITDA, which we define, and FFO to debt. I think you kind of look at those collectively in the sense of the strength of the credit of the platform. And I think given where we stand and the trajectory we have, we remain in those targets. But I think I recall what you're referring to. I don't have the specifics exactly on what they were doing, but I believe our FFO to debt number is well within that range.
spk07: Okay, just curious if there was some comparability. All right, excellent, guys. Thank you. Congrats again.
spk00: Our next question comes from Michael Lapdis with Goldman Sachs. Your line is open.
spk01: Hey, guys. Thank you for taking my call. I want to come back to the California gas plants because I think the contracting announcements that you're disclosing today is actually really, really important for investors to understand. Pricing-wise... you know, we've seen RA pricing in the $5 to $7 a kilowatt month range on, you know, kind of annually. It's obviously seasonal, seasonally different a little bit. Just curious if that type of tenor extends out to the 25, 26 timeframe, meaning if you can get that kind of pricing that far out. That's question one. Question two is, now that you've got five years of certainty really on two out of the three assets, do you think about recapitalizing them, right? When the debt fully amortizes by 2023, about reissuing debt, upstreaming some of that cash to the parent, using that cash for incremental renewable growth?
spk06: Thanks, Michael. So a couple questions. I think, one, you know, obviously the contracts are confidential in terms of pricing and the like, but I think importantly for us, we think about, you know, where CAFTI would be neutral from where we sit today. And so I think, you know, the pricing you're indicating is generally in line with how we think about it. In terms of the question around recapitalizing, we'll look at that kind of as the whole portfolio comes together as we approach 23 and kind of see are there opportunities to your point. If there's a lot of excellent growth investments, maybe it makes sense to raise capital on that book. If it doesn't, we'll kind of leave them. Obviously, we've tried to engage in new contracts so that any concerns about crafty diminution in an unlevered case versus levered today would be mitigated. Obviously, if we then relevered them, we would probably have lower crafty, everything else held constant. But I think from our view, we really want to kind of take the optionality in those assets and look to see when we approach 2023, if there's refinancing opportunities that make sense, we'll do it.
spk00: Got it. Thank you. Our next question comes from Steve Fleischman with Wolf Research. Your line is open.
spk09: Thank you. Thank you. Wow. Taking care of a lot of things at once. Congrats. Just on the California, what's your sense on the – do you think you'll be able to contract the last plant this year as well?
spk06: I think it's probably more 2022, Steve, in terms of versus 21. I think that'll take a little bit more time. Obviously, you know, there's the RA procurement next summer as well. I mean, we continue to work on it, but if you're asking, do we think we'll close it out this year? I don't think that's an expected outcome.
spk09: Okay. And then the, I guess a question maybe for Craig in terms of just the, you know, market, Development market overall, be curious your thoughts on, at least for your company and development there, the impact that the Biden clean energy credits could have to the growth of your business.
spk03: Yeah. It's hard to overstate how transformational the family of bills that are working their way through Congress would be for a long-term, robust renewables growth platform like ours. So it's very meaningful for us. When we look at what it allows us to do in accelerating development of projects that could be built at scale through the midterm, it allows us to make very substantial investments in projects that are large and that extend into geographies where renewables hasn't historically been built at scale. And so you see that in what we've disclosed around our pipeline growth, which is substantial and accelerating. Some of the features of the policy also allow us to adapt capital structures that we would employ to make certain types of projects even more compatible with the investment mandate of Clearway Energy, Inc., which is something we're excited about. For example, being able to make projects qualified for solar to be a production tax credit Eligible resource allows us to optimize capital structures so that for a typical solar project, CWIN will be able to deploy more capital. And we really like the idea of driving even more solar into this fleet as well. And, of course, being able to have storage assets be qualified for investment tax credits, whether they're paired with solar or not, allows us to think about deployment of storage assets and repowering also of existing wind assets around the fleet. So when we think about what we can do with the combination of our operating portfolio and our development platform during the course of the next five to ten years, this legislation once enacted is going to allow us to dramatically increase the size of this business and do so in a way that really drives shareholder value. And we're extraordinarily excited about what the next five years have for us.
spk09: Great. And I would assume that CWEN, particularly now that it's got this stronger balance sheet and all this money and, you know, a few years down the road, scale-wise, that it can kind of keep up with the growth of the development arm such that, you know, a lot of that or most of that gets directed down to CWENT.
spk03: Yeah, that's our objective. And, you know, I think that the range of financing structures that we have the potential to employ, you know, allow us to also have the structure of the investments that CWEN makes into these projects really be optimized to drive shareholder value around the family of metrics that Chris cited as important for capital allocation in addition to CAFD and PV and IRR. So, yeah, that's certainly our goal. We think of our development work as really being focused on driving growth in an operating portfolio that underpins the fundamental value of our business.
spk09: Great. Thank you.
spk00: Thank you. Our next question comes from Noah Kay with Oppenheimer. Your line is open.
spk08: Good morning, and thanks for taking the questions. I guess first just a quick clarifying one. The revolver and bridge facility you're working on, will those cover the full expected proceeds from the thermal sale or just up to the scope of the committed investments?
spk04: Go ahead, Jeff. Yeah, no, we're focused on up to the committed investments on those. Yeah. That's the current expectation, but yeah.
spk08: That's super helpful. And then, and this may be for Craig as well, you know, appreciate all the comments you just made around the potential policy impact. Maybe a little bit shorter term, though, you know, we obviously have seen a lot of cost inflation across the industry, steel prices, labor availability, et cetera. Just curious what you're seeing on IRRs for projects under development as well as timing and You know, how is sort of the cadence and the IRR profile trending versus prior expectation?
spk03: Yeah. You know, fortunately, I think the way that we approach our business likely manages risk with more care and discipline than some of our peers, and also, again, the nature of the relationship that we have with our principal suppliers is such that they prioritize favorable outcomes for us given our scale and our industry leadership position and our history of working with them in collaborative ways. So at a point like this one where, you know, capacity is congested you know, the partners with whom we're implementing projects are very engaged in working with us to mitigate impacts that may be more acute for others than for us. So, you know, when we think about inflationary factors, really, you know, they're, I think, principally a problem for projects that are planned for commissioning through, say, 2023 or 2024. Beyond that, We feel very solid about the ability to pass cost inflation through to the revenue contract prices that we offer to customers while still providing a really favorable value proposition for those customers. We feel that way because, in the long run, The cost inflation we anticipate is in large measure still being offset by technology improvements, and also on average PPA prices in our industry have been, say, 10% to 20% below the avoided cost for load-serving entities or commercial and industrial customers participating in wholesale markets. So we have room to move up price as needed in the long run. What our industry is working through – is really the risk and management of inflation on projects where revenue contracts are signed already and where projects are expected to be built during the next three years. And we feel very solid about how we are managing that interval, partly enabled by the advantages that I referenced and our ability to work flexibly around schedules and plant layouts and equipment delivery sequences and things We expect that we will be producing favorable returns for CWEN on the investments that it makes on projects that are commissioned through 2024, and also that we will produce returns for our parent company investors that are consistent with the objectives they set for us as a business.
spk08: That's very helpful. Color, thanks. And then maybe just the last one. You mentioned all the potential benefits in the Biden plan. An additional benefit could be incentives for clean hydrogen production, which we haven't had before, and the ability to develop green hydrogen, taking advantage of some tax credits on the power side and then on the production side as well could make for some very compelling economics. So can you talk a little bit about any collaborations, partnerships, or developments you may have as a platform with hydrogen production entities?
spk03: Yeah. We like that we have a lot of incumbent advantages to bring to bear in a market where consumption of green hydrogen is growing during the course of the forthcoming decade. When we think about those advantages, we think of an existing operating fleet in California and in Texas that Different markets, different end-use propositions, but both places where I think we'll see consumption of green hydrogen grow around distinct delivery infrastructures and also distinct end-users and incentive regimes. And so we are thinking about how our projects, as they evolve during the course of the forthcoming decade, can be value-effective sources of electric generation for green hydrogen. Also, our development pipeline in the West has a number of assets that fit nicely with forthcoming consumers of hydrogen. And as you could imagine, we're engaging both with equipment suppliers and end users around an optimal business model for our delivery of those renewable resources as production sources for green hydrogen. And we also like what hydrogen can do to maximize the value of those renewable resources by detaching locational marginal prices at the time that renewables produce from the fundamental value of a green hydrogen commodity. So we're excited about what it could mean for our industry broadly. We're excited about what it can mean for decarbonization, and we see a lot of complementarity with our existing strengths.
spk08: Right, right. Well, thanks and congratulations to the team on the meaningful strategic progress this quarter.
spk00: Thank you. Our next question is from William Gripen with UBS. Your line is open.
spk02: Thanks. Good morning. First question was just on the California gas assets. Is there anything unique about the remaining capacity there that you have left to contract that might make you more positive or more cautious on the ability to do that on favorable terms?
spk06: It's a combined cycle for El Segundo, if that's your question. Obviously, it's a little bit different than the two peakers. The energy component is more relevant in terms of the overall economic equation. I'd say that's really the only difference. The machines here are 10-minute fast start in a load pocket, et cetera. Those attributes are the same given the other assets. The only difference is the combined cycle.
spk02: Got it. With respect to the thermal transaction, you know, you mentioned possible shareholder returns. I'm just curious what your thought process is on the willingness to kind of sit on cash, you know, waiting to redeploy versus making a decision on possible shareholder returns.
spk06: I think, you know, once again, I'm not going to get, yeah, the transaction hasn't closed yet. So I think that's part one is really, as I talked about on the call, we're really emphasizing flexibility. If your question is, Would we sit on $680 million with no visibility and deployment for three years? That answer is no. If it is, well, we have a visibility to deploy that 680 binary approach in the next nine months from when it closes, we probably would sit on it. So I think for us, we're going to have a combination of looking at third-party M&A, looking at the drop-downs that we're working on currently and probably some of the other developments that Craig's talked about on the call, take all of that together, and kind of when the transaction closes, look at it holistically, and then determine if there is capital that's residual to be sent from a return to shareholders. We would prefer to put all into growth and kind of new assets commensurate with our NPV, IRR, and CAFTA requirements. But those opportunities aren't there. We're not going to just sit on cash to have a cash hoard.
spk02: That makes sense. Thank you.
spk00: And as a reminder, if you have a question, press star 1 on your telephone to get in the queue. All right. I don't see any further questions in the queue, sir. I would like to turn the call back to Chris Sotos for any final remarks.
spk06: Nothing in particular. Thank you, everyone, for joining. And really, once again, I think this has been a great quarter, so I appreciate everyone's investment in the company. Take care.
spk00: And with that, we end our call. Thank you for your participation, and you may now disconnect. Have a wonderful day.
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