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spk12: Good afternoon and welcome to SUN Run's fourth quarter and full year 2023 earnings conference call. All participants have been placed on mute. Please note that this call is being recorded and one hour has been allocated for the call, including the question and answer session. To join the Q&A session after prepared remarks, please press star one at any time. We ask participants to limit themselves to one question and one follow-up question. I will now turn the call over to Patrick Shobin, SUN Run's Senior Vice President Investor Relations. Please go ahead.
spk01: Thank you, Operator. Before we begin, please note that certain remarks we will make on this call constitute forward-looking statements. Although we believe these statements reflect our best judgment based on factors currently known to us, actual results may differ materially and adversely. Please refer to the company's filings with the SEC for a more inclusive discussion of risks and other factors that may cause our actual results to differ from projections made in any forward-looking statements. Please also note these statements are being made as of today and we disclaim any obligation to update or revise them. During today's call, we will also be discussing certain non-GAAP financial measures, which we believe can provide meaningful supplemental information for investors regarding the performance of our business and facilitate a meaningful evaluation of current period performance on a comparable basis with prior periods. These non-GAAP financial measures should be considered as a supplement to and not a substitute for or in isolation from GAAP results. You will find additional disclosures regarding non-GAAP financial measures discussed on today's call in our press release issued this afternoon and our filings with the SEC, each of which is posted on our website. On the call today are Mary Powell, Sunrun's CEO, and Danny Abadjen, Sunrun's CFO. Ed Fenster, Sunrun's co-founder and co-executive chair, along with Paul Dixon, Sunrun's chief revenue officer, are also on the call for the Q&A session. A presentation is available on Sunrun's investor relations website along with supplemental materials. An audio replay of today's call along with a copy of today's prepared remarks and transcript including Q&A will be posted to Sunrun's investor relations website shortly after the call. We have allocated 60 minutes for today's call including the question and answer session. And now let me turn the call over to Mary.
spk08: Thank you Patrick and thank you all for joining us on our call. We have a lot of exciting things to talk about today. First, our team delivered on our storage first and margin focus strategy in 2023. In the fourth quarter we far exceeded our storage capacity installation guidance and landed in our guidance range on installed solar capacity. This transition to higher value subscription offerings resulted in significant increases to our subscriber values, up 7% from Q3 and 18% year over year. And in combination with continued cost discipline, net subscriber values also exceeded our guidance. We generated $11 million in cash in the quarter and grew net earning assets to over $5 billion. We now operate a fleet of more than 1.3 gigawatt hours of storage capacity and near 7 gigawatts of solar capacity with over 933,000 customers. We remain focused on driving meaningful cash generation in the business and are reiterating our strong cash generation outlook for the year. The fundamental demand drivers of our business continue to be robust. First, utility rates continue to rise. Due to the stress and strain of climatic events on the grid and the massive utility capital expenditures. Second, solar and storage equipment costs are declining while our install labor productivity continues to improve. Third, capital costs have stabilized and could decline. Finally, customers remain eager for clean, affordable and resilient energy to power their lives. We are extending our differentiation by making clean, affordable and reliable energy accessible to families across America with the most pro-consumer offerings and delivering the best customer experience and service in the industry. Being the chosen trusted provider to deliver this clean energy future is critical. As a testament to our customer first approach, our customer net promoter scores at the time of installation continue to increase reaching 73 points in Q4. I am pleased to report that our volume trend is strong. Q1 sales are growing 23% compared to Q4 led by California where sales are growing at over 40% sequentially. We believe this sales growth will flow through to installations over the coming quarter leading to a sharp uptick in Q2. Q1 is seasonally a low installation quarter and typically declines from Q4. Results in Q1 will be influenced by the slower than expected recovery in California last year and our strategic decision to exit certain unprofitable markets as we discussed on the last call. Most important, we continue to increase the mix of storage. We installed 220 megawatt hours of storage capacity in Q4, growing 154% compared to the prior year and 25% from the prior quarter. Our storage offerings provide customers enhanced value and generate significantly higher margins for Sunmar. At the same time, they are the foundation for future monetization by providing at scale distributed power plant capabilities. Our storage attachment rate was over 45% of installations across the country in the fourth quarter, up from 33% last quarter and 15% at the beginning of the year and this number continues to rise with new sales. We remain disciplined in how we participate through the affiliate channel. We value our partners that are focused on customer experience and that value our brand, platform, storage first product suite and sustainable pricing model. There are pockets of irrational behavior in the affiliate partner segment of the market with several financing only participants scaling with pricing that we consider unattractive. Our decision not to compete for such business can influence short term affiliate channel volumes. We've seen this behavior several times in the company's nearly two decade history and won't chase volumes at economics that we do not view as sustainable. We believe our diversified market approach, which includes an integrated sales force and fulfillment capacity, provides insulation from these behaviors from financing only firms and is a strategic benefit to Sunrun. I am excited to announce today that we have selected Lowe's as our home improvement retail partner. Lowe's presents a new and exciting partner, one that has a great homeowner focused model that overlaps with our target markets and geographies. With many years of experience reaching customers through retail activities, we thoughtfully evaluate opportunities and are excited about our Lowe's partnership. We launched in Lowe's on February 16th, transitioning our sales staff out of Home Depot the prior day. We are incredibly encouraged by the results so far. Over the last few months, we advanced several strategic priorities, including launching an early renewal pilot and commencing storage retrofit installations for existing customers. I believe one of Sunrun's most underappreciated assets is the base of customers that we will serve for decades and the numerous opportunities we have to provide valuable products and services beyond our initial subscription agreement. As the trusted company who has built strong relationships with customers from the initial sales consultation to the installation and ongoing service, we are in an enviable position to be able to offer and realize value from additional products and services at many touch points throughout the customer life cycle. Our early renewal pilot highlights most customers are interested in extending the length of their subscription agreement even well before they expire. While the pilot only targets several hundred customers, thus far approximately three quarters are eager to renew their contracts for five years at their current pricing and agreement terms or are in the process of evaluating proposals. Nearly all of those that have renewed did so an average of five years before the end of their initial contract to lock in the peace of mind and energy savings provided by their current subscription service. Only about one quarter of customers opted not to renew early at our first attempt of presenting the offer. However, about half of these customers have expressed interest to buy the system outright, explore upsizing their systems with Sunrun with new equipment, or express that they might be moving. All of these scenarios provide incremental margin opportunities for Sunrun. Customers are also eager for our battery retrofit offering. While it's still early days and only available in select markets, orders have been growing rapidly and customer interest is high. Sunrun is uniquely positioned to see significantly better total lifetime customer value realization than financing only providers who do not develop the strong relationships we do with customers through the sales and installation and ongoing service we provide. While we are only targeting several hundred customers, we are pursuing the pilot to optimize sales strategies, systems, and processes to tackle these opportunities at scale in the years ahead. Shifting gears, I want to highlight our thoughtful and disciplined approach to funding Sunrun's growth and generating value for our investors before Dani covers it in more detail. We ended 2023 with more total cash than recourse debt and we generated cash in both Q3 and Q4. During Q1, we executed numerous capital transactions that are aligned with our disciplined capital strategy and approach. First, we expanded our 1.8 billion non-recourse senior warehouse facility by 550 million to 2.35 billion and extended the maturity date by approximately three years from 2025 to 2028. Second, we extended the maturity of our recourse working capital facility from January 2025 to November 2025 with a provision to extend the maturity further to 2027, subject to meeting certain conditions. The terms of the extended facility are consistent with our objective to generate cash, extend maturities at a time some of our competitors are at risk, reduce recourse leverage, and optimize our cost of capital, all to drive increased shareholder value. Third, we continued to execute tax equity funds and term out financings with strong terms, recently closing an approximately 470 million term out transaction. We are proactively and prudently managing our parent debt profile and funding to support growth and drive shareholder value. I am so appreciative of our finance team at Sunrun and our financial partners who share a vision to make clean energy affordable and accessible to all. Before handing the call over to Danny, I want to take a moment to celebrate our people, the heart and soul of this customer-led revolution in energy. First, thank you to our team in Bakersfield, California, who were our top-ranked install crew based on safety, storage attachment rates, and customer experience this quarter. Thank you for all of your contributions and leadership at Sunrun. Second, a big shout out to our friends at Bright Panel Solar, our top sales dealer in Puerto Rico. We are so thankful for your partnership over the years and look forward to many more to come. With that, let me turn the call over to Danny for our financial update.
spk11: Thank you, Mary. Today I will cover our operating and financial performance in the quarter along with an update on our capital markets activities and outlook. Our team is delivering strong volumes, leading with storage and financing our growth in a efficient and appropriate way. Turning first to the results for the quarter on slide 11, we have now installed over 90,000 solar and storage systems. We expect storage installations will grow substantially in the quarters ahead. Recent sales of storage-attached systems have been approximately 48 percent nationally, which should continue to drive installed attachment rates higher in future periods. Our backup storage offerings carry higher margins, typically by several thousand dollars per customer. During the quarter, we installed 220 megawatt hours of storage capacity, significantly topping the high end of our guidance and reflecting an increase of 154 percent from the same quarter last year, bringing total network storage capacity to over 1.3 gigawatt hours. In the fourth quarter, solar energy capacity installed was approximately 227 megawatts and within our guidance range of 220 to 245 megawatts. Customer additions were approximately 30,000, including approximately 27,000 subscriber additions. Our subscription mix represented 92 percent of our deployments in the period, an increase from 89 percent last quarter and the highest level in many years. We ended 2023 with approximately 933,000 customers and 781,000 subscribers, representing 6.7 gigawatts of network solar energy capacity, an increase of 18 percent -over-year. Our subscribers generate significant recurring revenue, with most under 20 or 25-year contracts for the clean energy we provide. At the end of Q4, our annual recurring revenue, or ARR, stood at over 1.3 billion, up 28 percent over the same period last year. We had an average contract life remaining of nearly 18 years. Turning to slide 12, in Q4, subscriber value was approximately 50,300 and creation cost was approximately 36,900, delivering a net subscriber value of $13,445. Our Q4 subscriber value and net subscriber value now reflect a blended 33.8 percent investment tax credit, benefiting from the energy community's ITC adder and a portion of the systems eligible for the low-income adder. Total value generated, which is the net subscriber value multiplied by the number of subscriber additions in the period, was $363 million in the fourth quarter. Our present value-based metrics are presented using a 6 percent discount rate, but our financial underwriting already accounts for our current capital costs, which is in the 7.5 percent area. As a reminder, to enable ease of comparison across periods, we generally do not update the discount rate frequently. Instead, we provide advanced rate ranges that reflect current interest rates, enabling investors to calculate the obtainable net cash unit margins on our deployments. In addition, we provide a pro-forma net subscriber value using the capital costs observed for the quarter. At a 7.5 percent discount rate, net subscriber value was $8,447 and total value generated was $228 million. We expect additional tailwinds to net subscriber value in future periods from the following variety of factors, sequential growth in volume, higher storage attachment rates, increased realization of ITC adders, and lower costs from hardware price reductions, labor efficiency, and operating leverage from volume growth. On slide 13, we detail the tailwinds from ITC adders and hardware costs. During the fourth quarter, we continue to recognize cash proceeds for the energy community's adder, while proceeds from the awarded low-income adders are still pending final government approval on each application, which we would expect in late Q1 or Q2. Proceeds from domestic content adders are expected to be realized in the coming quarters. Guidance on what will qualify for the domestic content adder has been issued. However, we are still awaiting additional rulemaking processes sometime this year. Combined, these three adders represent up to $450 million or more in additional annual run rate cash proceeds. We continue to see decreasing prices for key hardware components, which are gradually flowing through our reported costs as we finish consuming our higher cost inventory. On a -for-like basis for a 7.5 kilowatt solar with backup battery system, by the end of this year, hardware costs are expected to decline by over 18 percent, or nearly $2,500 per system from their peak in the second quarter of 2023. These beneficial trends may be obscured by an increasing mix of storage, which carries higher net margins, but will increase hardware and install costs and therefore impact creation costs. Turning to slide 14, we have presented a pro forma net subscriber value to show the potential impact to unit margins from the forthcoming ITC adders, if fully realized, along with the hardware cost tailwinds we expect in the coming quarters. Based on our mix of business and Q4, pro forma net subscriber value with these benefits was approximately $15,300 at a 6 percent discount rate and $10,300 at a 7.5 percent discount rate. Turning now to gross and net earning assets in our balance sheet on slide 16. Gross earning assets were $14.2 billion at the end of the fourth quarter. Gross earning assets is the measure of cash flows we expect to receive from subscribers over time, net of operating and maintenance costs, distributions to tax equity partners and partnerships flip structures and distributions to project equity financing partners, all discounted at a 6 percent unlevered capital cost. Net earning assets were $5 billion at the end of the fourth quarter. Net earning assets is gross earning assets plus cash less all debt. Net earning assets increased by $466 million this quarter. Net earning assets does not include inventory or other construction and progress assets or net derivative assets related to our interest rate swaps, all of which represent additional value. The value creation upside we expect from future grid services opportunities and selling additional electrification products and services to our customer base, including our storage retrofit offering, are not reflected in these metrics. We programmatically enter into interest rate hedges to insulate our capital costs from adverse near-term fluctuations. The vast majority of our debt is either fixed coupon long dated securities or floating rate loans that have been hedged with interest rate swaps. As such, we do not adjust the discount rate used in net earning assets to match current capital costs for new installations. We ended the quarter with $988 million in total cash, an increase of $36 million compared to the prior quarter. Turning to our capital markets activities. We have been incredibly active over the last few months arranging capital to support our growth and further optimize our balance sheet in ways we believe can drive considerable long-term shareholder value. We have successfully extended and upsized our non-recourse revolving senior warehouse facility to support our scale. This facility finances assets temporarily before we raise term out financing, principally in the asset-backed securitization market. We increased the size of the facility by $550 million from $1.8 billion to $2.35 billion and extended the maturity by approximately three years from April 2025 to February 2028. The effective credit spread increase of 50 basis points was commensurate with recent movement in the securitization market for term out transactions with similar advance rates. The facility continues to have a diversified set of nine relationship lenders. We also achieved certain other improved terms that afford more flexibility to fund our anticipated future product and geographic mix. Our team also continues to execute tax equity transactions, including structures that facilitate ITC transfers to a deepening pool of large buyers. The traditional tax equity market has been tighter recently, which we believe is owing to the calendar year tax planning exercises that our partners undertake, along with the options now available to increase the size of structures by utilizing ITC transfers. This structural rethinking can impact the timing of fund commitments. That said, our long-term track record as a sponsor and relationships which have spanned well over a decade continue to put us in a good position to arrange tax equity funding. As of today, closed transactions and executed term sheets provide us with expected tax equity capacity to fund over 195 megawatts of projects for subscribers beyond what was deployed through the fourth quarter. Sunrise also had $577 million in unused commitments available in its non-recourse senior revolving warehouse loan at the end of the quarter pro forma to reflect the subsequent upsize and amendment. This unused amount would fund approximately 211 megawatts of projects for subscribers. Our strong capital runway allows us to be selective in timing transactions. In February, we also closed an ABS transaction with a private credit investor, along with arranging subordinated financing. The $361 million non-recourse senior debt was rated A- by CROHL and was priced with a 232.5 basis points spread. This demonstrated yet another improvement in capital costs with spreads declining from our last securitization in September that was priced with a 240 basis points spread. We placed a $109 million subordinated loan on the portfolio as well. The all-in full-stack weighted average cost of capital was approximately .5% and resulted in a cumulative advance rate as measured against our contracted subscriber value metric of over 80%. The use of private credit investors shows the strong interest in our assets from a growing and broad set of investors. On the parent capital side, we have a couple of updates to share. Our overarching strategy is to drive the lowest cost of capital across the enterprise, supporting high asset level financing to generate cash while appropriately managing parent leverage to make sure we have flexibility in terms of our debt maturity timelines. It is prudent to extend facilities early to navigate potential and unexpected macroeconomic conditions and volatility. Consistent with this strategy, we have been planning to refinance our recourse working capital facility and we recently closed that extension. We reduced the size from $600 million to $447.5 million with an option to upsize the facility to $477.5 million prior to September 30, 2024. The reduction in the facility is in line with the reduced working capital needs of the business, especially as we have substantially reduced inventory as pandemic-related supply chain challenges fade into the past. We amended the facility to extend the maturity from January 2025 to November 2025. We also included a feature that will further extend the maturity to March 2027 should we meet the requirements for this provision. The facility now has typical grid-based pricing tied to utilization with spreads ranging from 325 to 375 basis points. This facility can be refinanced without penalty at any time. Shifting to our convertible debt. In 2021, we issued $400 million of zero-coupon debt that is due in February 2026. During Q4 and into Q1, we have opportunistically taken advantage of the market dislocation and the pricing of these bonds by repurchasing nearly $26 million of principal value at a significant discount to par in the open market, deploying approximately $20 million. These repurchases reflect a healthy low-teens area yield to final maturity, levels we believe are accretive to shareholders. This afternoon, we also issued a press release indicating we are launching a $475 million convertible debt offering. I will refer you to read that release for more information on the proposed transaction, the use of proceeds, and the cap call transaction that is intended to mitigate dilution. As of today, we have $374 million of 2026 convertible bonds outstanding. Our previous transactions buying the 2026 bonds resulted in a reduction to net debt. We also recently reduced our working capital facility by about $153 million, contemplating this balance sheet optimization opportunity that is consistent with our strategy of being prudent with the quantum and duration of recourse debt. Depending on the execution of the new convert issuance and the repurchase of the 2026 notes, total recourse indebtedness could either decline or increase, unlikely material in either direction, while the maturity schedule will be extended significantly. When we think about our balance sheet, we prioritize a strong cash position and use of asset-level non-recourse debt financing. This strategy provides the lowest cost of capital to finance cash flow producing assets backed by high credit consumers and to use parent recourse debt that is appropriately sized and balances maturity dates, cash interest costs, and flexibility. Turning now to our outlook on slide 19. The market remains very under-penetrated and we continue to believe we can sustain robust growth throughout this decade. In this strong long-term demand backdrop, our priority is to generate cash by continuing to increase customer values through growing storage adoption and other high-value products and services and by reducing costs by driving further efficiencies across the business. Storage capacity installed is expected to be in a range of 160 to 170 megawatt hours in Q1. This represents 125 to 139 percent growth year over year. For the full year, we expect storage capacity installed to be in a range of 800 megawatt hours to 1 gigawatt hour, reflecting 40 to 75 percent growth year over year. Solar energy capacity installed is expected to be in a range of 165 to 175 megawatts in Q1. This represents a decline of approximately 25 percent from Q4 at the midpoint. Q1 is typically the lowest period of the year based on seasonal constraints to sales activities in Q4 and Q1, along with weather-related obstacles to installations in Q1. Our volume has declined from Q4 to Q1 and every year we've reported our volume, and this year is no exception. In addition, the continued discipline we are exercising in the affiliate partner segment has a slight effect along with the fact that we exited Arizona. Because of the pull-in of demand in California in early 2023, year over year comparisons are less relevant in Q1. We are confident that Q1 volumes will mark the low point, and we expect very robust sequential growth in the Q2 and the rest of the year. For the full year, we expect solar capacity installed to be in the range of down 5 percent to up 5 percent. This represents market share gains as the strength of our subscription offering and our disciplined -to-market approach delivers strong results. Our growth in the value we create with this volume will be much larger. We forecast subscriber values will increase by greater than 10 percent in 2024 as we increase our mix of higher value offerings and input cost decline, resulting in growth of total value generated of greater than 15 percent in 2024. Turning to slide 20, we expect our discipline and focus strategy will allow us to capitalize on our long-term opportunity with our current focus on cash generation in 2024. We are reiterating our range of $200 to $500 million in recurring annual cash generation, which we expect to achieve by the fourth quarter of 2024. We generated cash in the fourth quarter, the second consecutive quarter of positive cash generation. We continue to expect cumulative cash generation to be positive from Q4 2023 through the end of 2024. Keep in mind, cash generation can be lumpy quarter to quarter based on project financing timing and inherent seasonality in our business. To this point, we expect to have lower cash generation in Q1 owing to the timing of financing activity and lower volumes, the latter of which results in worse fixed cost absorption. In addition, refinancing our warehouse facility will result in a one-time reduction to cash as we reflect the new advance rate on assets in the facility. Our cash generation range is based on assumptions we have outlined on the bottom of slide 20. With that, let me turn it back to Mary.
spk08: Thanks, Danny. I am so appreciative of the work of the Sun Run team executing on our transition to a Gorge First Company to extend our differentiation, expand our margins, and deliver the best value to customers. Importantly, I believe our steadfast commitment to our disciplined growth strategy will maximize the value we can create in the long run. Operator, let's open the line for questions.
spk12: Thank you. We will now be conducting a question and answer session. If you would like to ask a question, please press star 1 on your telephone keypad. A confirmation tone will indicate your line is in the question queue. You may press star 2 if you would like to remove your question from the queue. For participants using speaker equipment, it may be necessary to pick up your handset before pressing the star keys. As a reminder, please try to only ask one question and one follow-up. Our first question comes from the line of Andrew Pericogo with Morgan Stanley. Please proceed with your question.
spk14: Hi, guys. Thank you for taking the question this evening. I guess just to start out with your guidance, I just want to break down your solar growth guidance for the year. You're showing some pretty impressive sequential growth within your slides. Can you just maybe provide some context on what you're breaking into that guidance in terms of California and non-California growth throughout the year?
spk08: Yeah, for sure, Andrew. Nice to hear from you. What we're really seeing is that Q1, we've seen some nice sales growth volume as I hit. We've seen sales growing 23 percent, California is growing 40 percent sequentially. In our constant monitoring with all of our sales leaders across the company, yes, we feel very comfortable around the demand that we're seeing. As you also know, we're very, very focused on not just that solar volume but also the storage attachment rate where we've seen, again, really, really healthy upticks in the percentage of the attachment rate as well as what we're seeing every single week from the field in the context of the attachment rate that they're selling. We're feeling really good about the volumes we talked about and we're also really expecting, again, that net subscriber value growth tied a lot to the storage attachment rate, the retrofit work we're doing, and some of the other initiatives we hit.
spk14: Understood. That's helpful context. Then maybe just switching gears a bit, this renewal pilot is really interesting, so I want to double-click on that for a second. I guess based on the conversations you're having with some of your debt providers, what do you need to demonstrate to start getting some of that renewal value credit within the underwriting process? It seems like this is a pretty small sample size and you're still working through it. How far are you in those conversations and what needs to be done in order to start getting additional credit as you come to market with future securitizations?
spk11: Yeah, great question. I think it's more track record, getting the numbers to continue to build. I think there's also obviously a variety of things we can pilot and test in this period where we have customers that have the long-term relationships with them. We can go back to different subsets of customers and test the effectiveness of what works. I think it's really continuing at it and building the track record. I think we're encouraged with the initial results. I think from a debt underwriting perspective, it's really the track record lengthening and the numbers building.
spk14: Understood. Thank you so much.
spk12: Thank you. Our next question comes from the line of Julian Mullen with Smith with Bank of America. Please proceed with your question.
spk05: Thank you, operator. Good afternoon, team. Nice to chat with you guys. Just kicking things off on cash and obviously the ramp to meet your cash guidance, can you talk a little bit about external financing needs beyond the present context here as you think about ramping up into that more ongoing sustainable cash number? How does today's developments juxtapose against the ongoing needs presumably that you achieve by the end of the year here in terms of cash?
spk11: Yeah, I would say the exercise and the activity that we've been talking about is really about taking care of the parent recourse level, the maturities, the amount of leverage, and then at the asset level as we talked about with the warehouse, pushing out for three years the runway of warehouse financing in line with the strategy to maximize the non-recourse level. All of that taken together is within the backdrop of, more importantly, the cash generation picture and delivering into that later this year which is looking on track.
spk05: Got it. Do you want to talk a little bit more about the volumetric breakdown here? What stands out to me is your commentary on sales here even in the start of the year seems to reflect some, as you use the word, sharp uptick. Do you want to elaborate a little bit more geographically on what you're seeing out there? You talked about the enthusiasm from the field. How does that juxtapose against maybe some of the other data points that we're seeing about California specifically here if you can elaborate? Obviously, it seems like that's really informing your second quarter expectations on installs too.
spk08: Yeah, for sure, Julian. What we're seeing is recent trends are positive. As we talked about before, we were managing through some changes in the context of policy in California, but the trends particularly in California are positive and growing. In fact, California is growing faster now than the rest of the country for us. We're feeling good about the build back in California. Again, we're seeing really good results in other parts of the country. What you see with us largely in Q1 is a result of what I view as really important, prudent decisions we made on volume that, again, is just seeing its way through a quarter that traditionally always has lower volumes. It's a reflection of our disciplined focus on sustainable, profitable growth. That's, again, what drove up our net subscriber value that we talked about. It's really our execution of that.
spk05: Wonderful. Thanks, guys. Thank you.
spk12: Thank you. Our next question comes from the line of Kashi Harrison with Piper Sandler. Please proceed with your question.
spk07: Thank you. Good afternoon, everyone. Thanks for taking the question. Thank you. First one, just a quick financing strategy question. Mary, as you indicated, you've exited the year with $680 million in unrestricted cash, and it sounds like the cash balance is going to be higher by the end of 2024 given the cash gen commentary. Why pursue a convert rather than just pay it down since you would have had excess cash after the convert pay down?
spk11: Yeah, I think I'll take that. The exercise here is obviously with a few facilities involved across the stack, maturity extension, near-term liability management. That's been driving some of the timing of the layering of financings. I think we saw, again, the convertible bonds, where they're trading, looked very apparently dislocated to us. We did go ahead and purchase a bit of that. I think pricing moved during that few-week process that we were repurchasing. But I think generally it was the near-term focus on the liability management. We think that's prudent, extending out the maturities, and then shifting for the balance of the year with that behind us to cash generation, and then optimizing the use of that extra cash as it arrives to maximize shareholder value.
spk07: Fair enough. And then my follow-up question is on the cash generation target guidance that you reiterated. Can you just remind us what the sensitivities are to interest rates all else equal, and then maybe part and parcel with that? I guess I would have thought project costs would be maybe closer to 7% given recent securitizations and the drop in the benchmark rate versus the time of the last three-queue call. I guess I'm just curious why your project finance costs only moved down 25 bips relative to the last update. Thank you.
spk11: Great questions. The first one is about a quarter point is about one point in, or about 75 basis points in advance rate move. I think we've gotten a little bit less rate sensitive as kind of the baseline of rates has stabilized higher. On an annualized basis, that's between $40 and $50 million of cash generation change per quarter point of change in interest rates. And on the second one, that's a fair observation. I would say the .5% does skew a little conservative relative to what we've been seeing in the market. I think there's a possibility we'd end up a tad lower on a subsequent transaction.
spk12: Thank you. Our next question comes from the line of Moses Sudden with BNP Paribas. Please proceed with your question.
spk06: Thanks for the question. I just have a follow-up to cash you on the convert. Just to clarify, do you expect to repurchase a majority of the 374 million 2026 convert? I get this is mostly a refi. I'm just trying to understand if the majority of that would be repurchased. And do you expect an arbitrage considering using a convert to buy a discounted convert to try and understand if there would be a pricing premium relative to the 2026?
spk11: Yeah, I think I do want to just kind of refer you more to the press release. I think a repurchase was noted in the press release. And I think that's kind of use of proceeds as to how much I think that will come out in due time. We did note in the script that we could see leverage fall as a result of the transaction. It could go slightly up. But generally, that's the positioning on the range. But in either direction, not intending to be material.
spk06: Got it. That's very helpful. I guess shifting to NM 3.0, Mary, I believe you noted TA is growing faster for you now than the rest of the country, which is quite astonishing. I know it relates a lot to the storage attach rates. How much do you think it relates to the underlying NM 3.0 return profile? We get that there's a lot of friction, 2.0 to 3.0. There was a lot of pull forward. So it's really hard to get a real-time sense of the economics. With eye-popping time of use rates, I'm curious if there's a misconception out there on how NM 3.0 return looks.
spk08: Yeah, I mean, Sunrun, the story is our differentiation because we had expertise in storage. And so, again, we innovated, as you know, with a product to grab customers as soon as possible, that shift product. And then we found that really what customers were wanting across California was whole-home backup. And we have great expertise in that. And we launched, as you know, we called 2023 the year of storage. And we were leading with storage. And our numbers show that that was a very effective strategy, particularly in California. So California is, for some, still probably a challenging market for companies that are selling solar only or who don't have this kind of differentiation. You also note, and it's correct, that utility rates, there's nothing stopping the pressure on utility rates. So over time, that also is certainly helpful in the context of the Sunrun value proposition with our solar plus storage offering.
spk06: Excellent. Thank you. I'll pass it on.
spk12: Thank you. Our next question comes from the line of Michael Bloom with Wells Fargo. Please proceed with your question.
spk02: Thanks. Good afternoon. I want to go back to the program you have here to renew the contracts for customers. Can you just kind of walk through the process of turning those indications into actual signed contracts? And what are the plans to roll this program out more broadly to your customer base?
spk08: Yeah, great question. We're really excited about the early results. And as you know, we were really pleased to get this renewal pilot going. We have Paul Dixon here who's led this effort. So Paul, why don't you address some of those questions?
spk09: Yeah, thanks for the questions. I think really the focus for us, obviously, as was mentioned in an earlier question around financing these assets and securitizing the full value that we're creating with these customers. But on these initial pilots, the focus is really for us in better understanding our consumers' needs and desires and interests. And as we've dug into doing customer polling and now actually selling customer renewals, we're finding exactly what we hope to find, which is customers love the product. They're eager to extend and renew. And there's a whole host of avenues that we can take that with adding additional products and increasing rate or keeping where they are with their steady escalator. So there's a lot on the table for us as we open the store and expand it. But really, it's about understanding the assets that we're sitting on and taking full value of them and giving customers what they're looking for.
spk02: Great, thanks for that. And then you recently, as you noted, you switched from Home Depot to Lowe's. Just wondering if you can address the difference in the arrangements there and just more broadly maybe how you're viewing the different sales channels from Lowe's.
spk09: Yeah, so we like having a strong presence in a home improvement area for retail. And as we've been focused on cash generation and driving profitable growth and evaluated the opportunity in Lowe's, we found some really interesting and advantageous things about that as a host site, if you will. One being a really high homeowner demographic and two, just the general reality that there's been far less solar presence in those retail sites. And although it's only been a few days of selling in that site, it's been really encouraging. So we're really excited about the consumer demographic and the relatively unpenetrated nature of it.
spk12: Thank you. The line of Tristan Richardson with Scotiabank. Please proceed with your question.
spk16: Hi, good afternoon, guys. Just a question on the cost reductions you're seeing on the equipment side. You mentioned 18% or greater than 18% off the highs. Is that just sort of what you're seeing today in terms of your product categories? And then also
spk00: you
spk16: talk about realizing this over the next couple of quarters. We're hearing throughout the value chain that pricing pressure is not completed yet. Is there a possibility that that 18% over the next couple of quarters could end up higher than 18%?
spk11: Yeah, great question. So definitely the 18 is being driven by actual pricing on procurement activity we are conducting in the market. The reason we are talking about it in a lag manner, again, is the amount of inventory we've been carrying on hand has been a little bit more sticky in terms of being above target. I think it's moving towards target over the next quarter or two as we've guided to over the last couple of quarters. And as that moves through, we do have good line of sight into that greater than 18. It could certainly be more. At this point, it's most heavily being driven by battery prices and module prices, which are obviously the most significant part of the stack. But definitely pricing has softened up a bit and remained that way, and there could be opportunity for a bit more.
spk16: Appreciate it. And then just to follow up, I think going in the same vein around the you said greater than 100 days maybe on last quarter and today were approximately 100 days. Does that reflect the uptick in sales activity you guys are talking about seeing here in one queue? Or should we expect that to accelerate down or just given what you're seeing early in the top of the funnel?
spk11: Yes, so not yet reflected. And part of what brings it down is apart from just bringing down the gross dollars of inventory balance, the significant increase we are expecting in install activity that will follow our sales. And that's also in line with that kind of one to two quarter guidance as our daily rate of installs will be much higher and our balance will be lower. So we should naturally get to our target days.
spk16: Super helpful. Thank you guys. Of course.
spk12: Thank you. Our next question comes from the line of Joseph Osa with Guggenheim Partners. Please proceed with your question.
spk13: Hi everybody. Two kind of interlinked questions. First understanding that this convert was largely refi. Can you give us some ratio or set of limits that we can use to think about what the trajectory of recourse debt for the company might look like? And in that vein, when you talk about the two to five hundred million dollars in annualized cash generation by Q4 this year, can you commit to us that that is cash generation that occurs without the benefit of equity or equity linked or recourse debt issuance? Thanks.
spk11: Yes, yes. And just to that second part, the cash generation here is really geared towards maximum use of non-recourse. So it's really implied here is a growing amount of non-recourse that is exceeding the cost to generate the origination. So that is the cash generation. That's not, you know, that's obviously different. That's not a plan to raise more parent capital.
spk13: Okay. And on that first question, how can we think about what recourse debt, how we should think about that? Yeah,
spk11: I think, yeah, obviously, you know, with a transaction, with a 144A transaction in the market, you know, I will have to kind of reiterate pointing to that. But, you know, I'll kind of like reiterate the part of the prepared remarks. You know, no material movement in either direction in the amount of like net parent leverage.
spk13: That is net recourse.
spk11: Recourse, recourse, correct.
spk13: Okay. Thank you very much.
spk12: Thank you. Our next question comes from the line of Philip Chen with Ross MKM. Please proceed with your question.
spk03: Hi, all. Thanks for the questions. As it relates to renewals, was wondering if you could share, sorry if I missed it, but can you share from a renewal standpoint, the dollar or megawatt volume that could be up per year this year, next year, and how that might scale thereafter?
spk09: Thanks. Yeah, so this year we have no customers that are up for renewal. It's a proactive pilot, so we're reaching out to customers that in, you know, three to four years from now begin to start renewing. And so we're proactively talking to them to understand what those opportunities are.
spk08: And in fact renewing them early. Right. So again, like it is about learning and scaling. So again, we're not at all thinking about this as something like we're going to sit here and wait for customers to renew. We're going to come up with programs and ways to meet their needs ahead of the end of their renewal period.
spk03: Yep, I totally get everything you said and understand the renewals are not for some time, but was wondering if you guys had a view as to what the volume might be. That's it. I'll move to the second question here. With your flat 24 megawatt guide as a backdrop, you know, our work with Freedom Forever, which I believe is one of your largest, if not largest, dealers, suggests they may be growing 60 to 100% year over year. So our estimates, our estimates suggest they might may have contributed 250 megawatts to your business in 23. In 24, this could be closer to 380 megawatts as they're splitting their volume between you and Everbright. So our rough numbers suggest that they might be adding roughly 130 megawatts to your megawatts in 24 of your roughly one gig. So given that you have guided flat year over year, can you give us some color on what is happening with the rest of the business if they're growing 130? You know, perhaps our assumptions on the freedom situation are off the mark, you know, maybe correct us if we're wrong, but maybe share with us what's going on with the rest of your dealer business year over year. And from a direct standpoint, how is that business going? Is your direct business? I know on slide 26 there, slide 6, it shows that, you know, you have a direct business growing really well, but was wondering where freedom is categorized. Are they categorized in the affiliate program there or partner or is that in the blue sun run? So you
spk08: can
spk03: share some more color on that situation. That would be fantastic. Thanks.
spk08: Yeah, so that's what I was going to point you to is slide 6, which really gives you a very clear picture of how we see 24 currently. And yes, Freedom Forever, who has been a partner for quite a long time, a valued partner, shows up in the affiliate partner installations category. You know, currently, no affiliate partner is over 10% of our volume. And yes, you're right, we're seeing our direct business growing nicely.
spk12: Thank you. Our next question comes from the line of Brian Lee with Goldman Sachs. Please proceed with your question.
spk10: Hey, everyone. Good afternoon. Thanks for squeezing the end. I know a lot's been covered here on the call, but maybe just one from me on this slide 20 where you're talking about the different levers and assumptions on the cash flow generation. You mentioned it's going to be lumpy throughout the year, but can you give us a sense for I guess what are maybe milestones, events, capital raises, et cetera, that would give you and maybe in what timeframe more visibility as to whether you hit the low, mid, high end? I mean, it seems like if I just parse through some of this, you're already tracking to well above the storage mix that's embedded here in the assumption that you mentioned to a prior question. The seven and a half percent might be a bit conservative already here starting the year. So just trying to understand, you know, one, the puts and takes, but also the timeline as to when, you know, that that view kind of crystallizes as we move through the year. Yeah, granted, it's going to be lumpy on a quarter to quarter basis. Thank you.
spk11: Great question. So I'll start. I'll maybe highlight a few of the factors on the page on volume. I think we talked about directionally throughout the year, picking up sequentially considerably throughout the year and implied there is hitting that 15% year over year mark in the back half of the year. Of course, we also highlighted that the year over year comps in the first half won't look as good. We do have the Q1 sequential decline, you know, really pacing out of that, you know, gives us a very decent return back on operating cost leverage in the business. And as we get that, you know, that will be trending. Well, the backup storage mix, we believe we will exceed based on the remarks. The ITC adders, we're a little bit shy of about 34%. I think we have pathways building again in that kind of Q3, Q4 timeframe to getting more of it. I think the two factors there would be more geo targeting where it relates to energy communities and low income. And of course, on domestic content, the onset of that as the regulations get crystallized and then capital costs. So that's obviously, you know, in a range, we are giving the range at the moment and saying, you know, quarter point is between 40 and 50 million dollars. So there's north of 100 basis points of cushion from high end to low end of range as it respects capital costs.
spk10: All right. Appreciate the color. I'll pass it on. Thank you. Thank you.
spk12: Thank you. Our next question comes from the line of Colin Rush with Oppenheimer. Please proceed with your question.
spk15: Thanks so much. Could you talk about the maturity of the VPP monetization? Obviously, with incremental deployments of energy storage, just want to get a sense of on a portfolio level, how you see that that value potentially increasing the, you know, the NPV portfolio. Yeah,
spk08: we're really pleased with the PGD. I'm sure you saw the press release that we did with that program where 8500 customers participated in a program over a number of months. We think it sets up a really good framework for future, you know, virtual power plant structures that we do. You know, that really results in like a, you know, a view that over time it would be a net subscriber value of about two thousand dollars.
spk15: Fantastic. And then just mention labor efficiency and both on the sales and installation front. I just want to get a sense of order of magnitude you're expecting to see over the course of the year and the cadence of that efficiency as we go throughout the year.
spk08: Yeah, I mean, we're really pleased with the efficiency gains we've seen across the business. I would say in the installation area, particularly where that productivity has really resulted in some great benefits. You know, CAC as a percent of subscriber value is coming down. Obviously, you know, and that is happening despite the distortion created by some of the mixed change. You know, so yeah, we're really pleased, particularly as again, we've moved to a solar plus storage company. So that also, as you think about productivity gains and you think about the gains we've had where we are in essence having our folks selling two products, installing two products. So yes, we've been really pleased by the results we've seen around our kind of maniacal focus on cost in the business.
spk12: Thank you. Our next question comes from the line of Maheep Mandalo with Mizzouho. Please proceed with your question.
spk04: Hi, this is David Benjamin from Heap. I have a question on the convert. Can you please talk or give a little bit of color around the timing? I understand that is for the refinance, but the converts to in 2026 doesn't go current until 2025. So just any color you could provide around that would be helpful.
spk11: Thanks. Yeah, I think, you know, really, you know, in early, you know, getting out ahead in early liability management exercise, you know, the revolver was the same thing. The warehouse was the same thing. I think we like the, you know, market conditions. You know, we have obviously, you know, good depth in the, especially on, you know, the, I'm not addressing the convert directly, but across the capital spectrum. I think just, you know, deep pools of capital available to us and just wanting to be exceptionally timely in handling all of that.
spk12: Thank you. That concludes the time that has been allocated for Q&A. You may now disconnect. You have been removed from the call. Goodbye.
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