Hello, everyone, and welcome to the Eversource Energy Q4 and full-year 2022 earnings call. My name is Nadia, and I'll be coordinating the call today. If you would like to ask a question at the end of the presentation, please press star followed by one on your telephone keypad. I will now hand over to your host, Jeff Kotkin, Vice President for Investor Relations for Eversource Energy to begin. Jeff, please go ahead. Thank you, Nadia. We apologize for the delay in starting the call. We were having a problem with our webcast link, and it had to be reset. We couldn't just start the call with only the dial-ins working. We appreciate your patience greatly, and we look forward to your questions after the intro remarks. Let me start. Good morning. Thank you for joining us. During this call, we'll be referencing slides that we posted yesterday on our website. As you can see on slide one, some of the statements made during this investor call may be forward-looking, as defined within the meaning of the safe harbor provision of the U.S. Private Securities Litigation Reform Act of 1995. These forward-looking statements are based on management's current expectations and are subject to risks and uncertainties, which may cause the actual results to differ materially from forecasts and projections. These forecasts are set forth in the news release issued yesterday afternoon. Additional information about the various factors that may cause actual results to differ can be found in our annual report on Form 10-K for the year ended December 31, 2021, and our Form 10-Q for the three months ended September 30, 2022. I'm sorry, the 10-K was for 2021. Additionally, our explanation on how and why we use certain non-GAAP measures and how those measures reconcile to GAAP results is contained within our news release and the slides we posted last night and in our most recent 10-K and 10-Qs. Speaking today will be Joe Nolan, our Chairman, President, and Chief Executive Officer, and John Moreira, our Executive Vice President and CFO. Also joining us today is Jay Buth, our Vice President and Controller. Now I will turn to slide four and turn over the call to Joe. Thank you, Jeff, and thank you, everyone, for joining us on this call this morning. We had a very strong 2022 operationally, financially, in advancing the clean energy policies of the states we serve. As we look ahead to 2023, we consider ourselves to be extremely well-positioned to deliver on our customers' expectations, whether it relates to providing them with safe and reliable service, helping communities address the impacts of climate change, or standing ready and fully prepared to respond to emergencies. The work that thousands of Eversource employees undertook following a severe windstorm two days before Christmas last year, working in bitter temperatures up to 16 hours a day before and during the holiday to ensure our customers had power, exemplifies the selflessness of our 9,600 colleagues. We treasure the hundreds of appreciative comments we've received from our customers. Our ESG efforts, we've published a new diversity, equity, and inclusion report, and we're recognized as a leader in this area among the 1,000 largest U.S. corporations by As You Sow, a nation-leading shareholder advocacy nonprofit focused on environmental and social corporate responsibility and values-aligned investing. We are now completing a new initiative on equity training across the entire company. In November, we announced that we had committed to setting a science-based target, making us one of only a few U.S. electric or gas utilities to take that challenging step. We continue to receive very positive feedback from many of our investors on that commitment and believe it will become an increasingly differentiating factor for Eversource in both the U.S. and non-U.S. investment portfolios. Slide five illustrates some of our key operational metrics, starting with two key gauges of electric service reliability. Our customers' average number of months between interruptions remained in the highest decile of the industry, and our speed of restoration when outages did occur was in the top quartile. Our key safety metrics also remain strong. In terms of our 2022 financial performance, we continued to grow our non-GAAP earnings and dividend by approximately 6%, something that we have done consistently since Eversource was formed nearly 11 years ago. As shown on slide six, our board approved an additional 6% increase in our quarterly dividend earlier this month. John will discuss some of the factors that we expect will move earnings per share growth over the next five years to solidly in the upper half of our long-term 5%-7% range. While our longer-term total shareholder return compares favorably with our peers, our 2022 return was disappointing. We understand that much of that is related to the uncertainty over our offshore wind investments. We expect to resolve that uncertainty in the coming months as our strategic review progresses. There is continued interest in both our three offshore wind projects in the nearly 175,000 acres of uncommitted lease areas that are part of our 50/50 joint venture with Ørsted. The process continues to move forward and is progressing through extensive due diligence. We expect an announcement concerning the outcome of the strategic review in the second quarter of this year. In the meantime, our work on the three projects is moving ahead. Slide seven provides a quick overview of the significant progress in recent months. As you know, construction of our first project, South Fork Wind, commenced a year ago. Installation of the onshore conduit system, including cable vaults and town roads and along the Long Island Rail Road, is now complete, as is the installation of the sea to shore conduit that will hold the transmission cable as it transitions to land. Installation of onshore cable is now underway and construction of our new onshore substation is on track to be completed this summer. Installation of the South Fork subsea transmission cable will begin later this quarter, and installation of the foundations, wind turbines, and offshore substation will begin this summer off the coast of Massachusetts. We expect that South Fork will be fully operational by the end of the year. Our two larger offshore wind projects, Revolution Wind and Sunrise Wind, continue to advance through siting and permitting, and we expect to commence construction of both projects in the second half of this year. The Bureau of Ocean Energy Management, or BOEM, issued a draft environmental impact statement for the 704 MW Revolution Wind project in September. We expect a final EIS in the second quarter of 2023, and to have all permits in hand in the second half of 2023. We continue to target a 2025 in-service date. We had two major developments late last year for Sunrise Wind, our largest offshore wind project. The project received a key New York Public Service Commission permit, and BOEM published a draft EIS for the project. As of the end of 2022, we had invested $1.95 billion in offshore wind. We made significant progress late last year procuring equipment and services, and have approximately 90% of costs locked in, up from 82% as of September 30th. On one of the slides in our appendix, you can see our updated total cost estimates for the three projects. The range is somewhat higher and narrower than it was 1 year ago. This is due to the fact that we have locked in much higher percentage of the cost, and that some of the now locked in costs, especially those related to foundation, transportation, and installation, are higher than we had estimated earlier. I should reemphasize that we consider offshore wind to be cost-effective source of significant clean energy supplies for the Northeast. We expect our electric utilities to build much of the FERC-regulated onshore transmission infrastructure needed to connect the offshore generation to a load, regardless of the outcome of our strategic review. Those investments will be closely aligned with our commitment to be a leading catalyst for clean energy development in our region. It is one of the many ways we are helping the region decarbonize, and we have seen very significant progress on a number of our Massachusetts initiatives over the past year. Turning to slide eight. On December 30th, the Massachusetts Department of Public Utilities approved the first of six proposals to unlock third-party solar generation that is currently stalled in the interconnection queue as a result of inadequate transmission and distribution capacity. If all six proposals approved, a total of 1,000 MW could ultimately be built and connected. As you can see on slide nine, the first approved project is Marion-Fairhaven. Commission proceedings are active for the other five proposals, and we expect DPU decisions on them this year. Our proposed investment in these six clusters would be approximately $980 million, of which about $310 million would be reimbursed over 15-20 years by solar developers as they fully subscribe to the unlocked hosting capacity. Late last year, as shown in slide 10, the DPU approved the implementation of AMI with a new customer information system for our nearly 1.5 million electric customers in Massachusetts. The DPU also approved our proposed continued investment in grid modernization. Today, these investments will enable customers to better manage their usage and provide us with significantly improved visibility into power flows and conditions on our electric distribution system. This will be critical for us as more distributed energy resources are connected to our system and as more of the state's space heating and transportation is electrified. We expect the new customer information system to be installed primarily over the next two years, with meter installation in 2025 through 2027 time period. We hope that Connecticut regulators will conclude their AMI review this year and approve its rollout to 1.3 million of the state's electric customers. Aside from these projects, we have many other initiatives in Massachusetts. In December, the DPU authorized a four-year plan for electric vehicle charging infrastructure that is profiled on slide 11. On slide 12, we describe three other initiatives, including a 38 MWh battery storage facility that went online in Provincetown on Cape Cod last year and can supply up to 11,000 customers this time of year with power should an outage occur on a principal distribution feeder serving the outer Cape. The slide also provides you with the status of our highly innovative network geothermal project in Framingham, Massachusetts, which is now 90% designed with construction to start this spring. Additionally, we have three proposals into the Department of Public Utilities to expand our solar generation with an additional focus on storage in equity justice communities. We are very excited about all of these proposals as they help Massachusetts achieve its very aggressive clean energy agenda and keep our region at the forefront of innovative solutions to the challenges of climate change. We hope that Connecticut and New Hampshire will embrace some of these clean energy programs and our involvement in delivering solutions. In Connecticut, there are clear signals from the Lamont administration and the Governor's Department of Energy and Environmental Protection that they are looking to promote significant investment in clean energy initiatives with both federal and utility support. To this end, we have three grid-scale battery storage projects pending before Connecticut regulators that would improve grid reliability and enable integration of clean energy resources. These proposed investments, which are not in our current capital forecast, were enabled by recent state legislation. We hope that workable regulatory frameworks will be advanced to support such investments. Finally, I want to address power supplies and energy bills this winter. As you know, we were quite concerned entering this winter about the impact of higher energy prices in New England, as well as uncertain supplies of natural gas, LNG, and oil for the region's generation. In fact, I wrote to President Biden before the heating season commenced, asking that his administration invoke certain emergency measures to ensure that we had sufficient resources this winter. Fortunately, the mild temperatures this winter have reduced customers' energy consumption and tempered the impact on bills. They also have contributed to a sharp reduction in natural gas prices, which has started to lower natural gas bills for some customers. New Hampshire electric customers are seeing a rate decline this month. For most of our electric customers, lower power supply costs will start to be reflected in bills in July. Thanks again for your time. I will now turn the call over to John. Thank you, Joe. Good morning, everyone. This morning I will be covering our 2022 results, our 2023 earnings guidance, our updated five-year regulated investment capital plan and long-term outlook, and give you an update on some current regulatory proceedings. Let me start with our 2022 results on slide 14. Our GAAP earnings for 2022 were $4.05 per share, compared with $3.54 per share in 2021. In the fourth quarter of 2022, GAAP earnings were $0.92 per share, compared with GAAP earnings of $0.89 per share in the fourth quarter of 2021. Results for both 2022 and 2021 include transition and transaction-related costs primarily associated with integration of Eversource Gas Company of Massachusetts. full-year 2021 GAAP results included charges related to the CL&P settlement agreement. Excluding those non-recurring charges, we earned $4.09 per share in 2022, up 6% from $3.86 that we earned in 2021. For the fourth quarter, excluding these charges, we earned $0.92 per share in 2022, compared with earnings of $0.91 per share in 2021. To break down our earnings by segments, electric transmission earned $1.72 per share for the full-year 2022, compared with earnings of $1.58 per share in 2021. Higher earnings resulted from continued investment in our transmission system. We invested just over $1.2 billion in our transmission facilities in 2021, compared with $1.1 billion in 2021. mostly replacing aging equipment and improving reliability and resiliency for the region. Our electric distribution segment earned $1.71 per share in 2022, compared with $1.61 per share in 2021, excluding the Connecticut settlement-related charges. Higher revenues and lower pension expense were partially offset by higher O&M, depreciation, property taxes, and interest costs. Fourth quarter 2022 results also reflect a $10 million contribution we are making to help some of our customers pay the significantly higher energy bills we have seen this winter. Our higher distribution expense primarily stem from our ongoing investments in the distribution system to improve service and reliability for our customers. We invested about $1.35 billion in our electric distribution system in 2022, up from $1.24 billion in 2021. The higher O&M was driven in part by higher storm costs in 2022. Non-deferred storm expense cost us about $0.05 per share, more in 2022 than it did in 2021. Our natural gas distribution segment earned $0.67 per share in 2022, compared with earnings of $0.59 per share in 2021. Higher revenues and lower pension expense were partially offset by higher O&M, property taxes, interest, and depreciation expense. Much of it driven by our continued investment to improve the safety, reliability, and resiliency of our natural gas distribution system. Our water distribution system segment earned $0.11 per share in both 2022 and 2021. Excluding the transition and transaction-related charges, Eversource parent and other companies lost $0.12 per share in 2022, compared with a loss of $0.03 per share in 2021. This change was due largely to higher interest expense, particularly in the second quarter of 2022 and our higher effective income tax rate. Overall, as Joe covered in his remarks, we are very pleased with our 2022 performance as we successfully overcame many challenges and delivered very positive results for our customers and all of our stakeholders. From 2022 results, I will turn to 2023 guidance on slide 15. We are projecting non-GAAP earnings of between $4.25 and $4.43 per share this year, compared with $4.09 per share we earned in 2022. The slide shows the factors that we expect to positively and negatively impact earnings in 2023 compared with 2022. One item benefiting earnings is our ongoing program to upgrade our electric transmission system, where we expect to invest approximately $1.2 billion again in 2023. I will discuss the principal drivers behind that investment and how it will benefit our customers in a moment when I discuss our long-term capital plan. We are also we also project higher revenues in our distribution companies as we continue to upgrade and expand our distribution systems. Those higher revenues are due primarily to rate adjustments at NSTAR Gas, EGMA, and PSNH that went effective on November 1 of 2022, and at NSTAR Electric just beginning of last month. We expect that they will be partially offset by anticipated increases in depreciation and property taxes. We expect enhanced returns in 2023 on an investment in a fund that we have owned related to various clean energy facilities. Those facilities have significantly increased in value in recent years and have benefited our results for several years, and now include in 2022. Interest expense will continue to be a headwind at Eversource Parent. It will also be a headwind at our distribution segments. While the portion of interest expense allocated to transmission is tracked, the distribution portion is not and will weigh on earnings. Lower pension expense was an earnings tailwind for us in 2022. Primarily due to the extremely strong asset returns, that we performed in 2021. In 2023, we expect pension costs to be a slight headwind to earnings of approximately $0.04 for the year as compared to 2022. Here are some reasons why behind this modest impact. First, a significant portion of our pension costs or pension benefit is capitalized into our capital projects. Secondly, pension expense or pension costs related to our transmission segment and to our Massachusetts electric and natural gas distribution segments are fully tracked. Third, a higher discount rate reduces the impact of amortization of prior year accumulated actuarial losses. Lastly, the higher discount rate means that our pension plan remains fully funded, and we do not anticipate making any contributions in 2023. From 2023 earnings expectations, I'm going to turn to slide 16 and cover our five-year plan to invest approximately $21.5 billion in our regulated electric, natural gas, and water distribution businesses to continue to provide customers with safe and reliable service, to address ongoing load growth in certain areas of our service territory, and to help our states meet their decarbonization goals. The increased investment is focused primarily within our electric transmission and distribution segments. Much of the increase in the transmission capital projection is due to increased investments in the replacement of older equipment in our substations, overhead infrastructure, and underground cables. This investment continues to make our transmission system more reliable even during extreme weather events. Increased storm hardening and system resiliency has resulted in no transmission-related outages through the last several severe storm events. We also are including the early years of a major new project to build an underground substation in Cambridge, Massachusetts, where the load growth continues to accelerate. A siting application for this project was filed about a year ago. We are incorporating significant additional transmission investment in the physical security of our major substations and a total of about $450 million for transmission investments in the distributed energy and offshore wind projects Joe mentioned earlier. On the electric distribution side, our updated forecast now reflects the inclusion of AMI in Massachusetts and the completion of our proposed distributed energy projects also in Massachusetts. Earlier, Joe mentioned that the first cluster of these distributed energy projects have been approved and that the hearings are ongoing for the remaining five. Our forecast also reflects the Massachusetts DPU's recent approval of our multi-year grid modernization and electric vehicle charging program. Moving on to the natural gas side. Our increased investment is primarily related to increased regulation around natural gas companies' construction activities that have evolved since the Merrimack Valley incident several years ago. We've also increased the number of projects to harden our system against flooding and added protection on our low-pressure systems. In the water segment, our updated five-year capital investment forecast of approximately $1 billion is more than 10% above the previous forecast, primarily reflecting the additional of Torrington Water, the acquisition that we completed last year, and the additional water treatment facility investments. It also includes about $70 million per year to replace nearly 25 mi annually of old water mains. Aquarion has more than doubled the scope of its water main investment program since being acquired by Eversource. Moving on to slide 17, which compares year-by-year investment levels in the years 2023 through 2026. They total approximately $3.3 billion. This is consistent with the discussions we've been having with investors since last May when we indicated that the increased investment requirements in our regulated infrastructure would likely offset 2026 earnings impact of divesting our offshore wind investments, if that is ultimately the outcome of our strategic review. Slide 18 shows that some major potential initiatives remain outside of our investment plan. Connecticut regulators continue to review our proposed AMI program, so that investment of approximately $475 million remains outside of our plan, as are some potential related storage projects also in Connecticut. Our transmission system on Cape Cod could interconnect another 1,200 megawatts of offshore wind in addition to Vineyard Wind and Park City Wind. As such, interconnections are now under technical review by the ISO New England, but we have not reflected any potential amount in our plan. In addition, we've not reflected potential transmission projects that likely will be needed to move significant sources of offshore wind generation to load centers. We've also not reflected potential clean energy alternatives we're beginning to explore as alternatives to natural gas. As you can see on slide 19, the customer-focused core business investments that are included in our capital forecast would result in a 7.5% rate base CAGR through 2027. Supported by those investments, we have maintained our EPS rate of growth rate of 5%-7% and believe we will be solidly in the upper half through the forecast period, as illustrated on slide 21. In addition to our earnings growth, we are enhancing our internally generated cash. Last year, cash flows from operations totaled just over $2.4 billion, and that is compared with slightly under $2 billion in 2021. The 2022 figure included a few cash outflows we do not expect to occur in 2023. As such as about $80 million of the pension contributions that we made in 2022, and more than $70 million of customer bill credits related to the CL&P 2021 rate settlement agreement and higher than average storm claims. We expect that the combination of enhancing credit metrics, progress on our strategic review, and equity issuance plans will allow us to maintain or, in the case of S&P, improve our current ratings. Those strong ratings provide significant benefits to customers by allowing us to borrow at some of the lowest rates in the industry. We also expect an increased level of storm cost recovery compared to 2022 as part of the NSTAR Electric rate decision. Maintaining those levels will require us to regularly infuse equity from our parent company into our regulated businesses. Slide 21 illustrates the sources of that funding. In addition to improving cash flows, as I previously mentioned, we will require additional debt issuances, principally at our regulated utilities. We expect to issue nearly $1 billion of additional equity through our at-the-market program over the coming years. We will continue to use treasury shares to fund our dividend reinvestment in employee incentive programs. Should our strategic review result in a sale of our offshore wind investments, we would expect to use all of the net proceeds on day one to pay down parent debt. This will create increased financial flexibility in the future as we fund our regulated segments. Moving on to our regulatory update. In the past years, we have had a lengthy discussion about various regulatory reviews. This year, that discussion is much briefer. As you can see on slide 22, we continue to await FERC's ruling on several pending complaints that were filed beginning in 2011, challenging the return on equity authorized for all of New England electric transmission owners. On the distribution side, the only ongoing rate review involves Aquarion Connecticut, where a draft decision is due shortly. Due to the capital program at Aquarion, as I mentioned earlier, Aquarion's returns have slipped below its currently allowed 9.63% authorized return on equity. We believe we have made a strong case for a reasonable increase in Aquarion's water rates, which are quite low compared to its peers. Elsewhere, we don't expect significant rate review activity in 2023. In Massachusetts, all three of our electric and natural gas utilities are currently operating under long-term rate plans that extend from five to 10 years. Finally, as you can see on slide 23, we continue to remind investors that they should consider our long-term track record and attractive risk profile in determining whether to invest in our company. This slide shows that over the decades since Eversource was created, we have consistently achieved the earnings and dividend growth we targeted while achieving very strong operating performance. We also have enhanced our ESG profile, which certainly ranks us among the best, if not the best in the industry. Thank you again for joining us this morning, and I will now turn the call over to Jeff. Great. Thank you, John, and thank you again for the audience for sticking with us this morning. I'm gonna turn the call back to Nadia to remind you how to enter questions in the queue, and then she'll turn it back to me, and we'll get going. Nadia. Thank you. If you would like to ask a question today, please press star followed by one on your telephone keypad. If you choose to withdraw your question, please press star followed by two. When preparing to ask your question, please ensure your phone is unmuted locally. I'll hand back over to you, Jeff. All right. Thank you, Nadia. Our first question this morning is from Durgesh from Evercore. Good morning, Durgesh. Good morning, Jeff. Thanks for giving me time here this morning. Maybe, Joe, can you comment on sort of the offshore strategic review? Originally, you guys were targeting year-end, last year for completion of the review. It's certainly taking longer than expected, so maybe what's driving that? Any color you could share there? Yeah. Good morning, Durgesh, and thank you so much for being on the call. Yeah, so, you know, I just will tell you that I am the eternal optimist. Obviously, I wanted to have some news for you by year-end, but, you know, this is complex project. It's got a lot of moving parts. As you might imagine, it's not a straightforward transaction in terms of due diligence that what has to take place here. We're talking about, you know, thousands of acres of the ocean floor, people looking at other pieces of this transaction. It took longer and, you know, shame on me, I should have been a little more realistic on the timing. I will tell you there is significant interest in the lease area as well as the projects. You know, we are going to get a fair price for these assets. I think the one thing that you should all take away from this call is that the progress that's taking place on these projects, we have not taken our eye off the ball. We will be in the wind business. We will be the first utility in the wind business in a large scale in the U.S. offshore wind business, you know, by the end of this year, which is pretty extraordinary. The other two projects are moving along quite well. As you know, the pricing of those projects is quite favorable. You know, we'll continue to drive this process and focus on this review and this exit. You know, unfortunately, it doesn't go at the pace that I like to go. You know, I like to move at a good pace, but this is very complex, and folks need to understand that any buyer of these assets is going to wanna do significant due diligence. Understood. Just maybe a quick follow-up. The Q2 kind of update on the review, what does that do to timing of a potential close? Is that still sort of mid-year or are we thinking about second half of this year, if you do decide to move forward with the sale, that is? Well, I'll tell you that the folks that are involved in the process right now are very sophisticated buyers. We do not anticipate it would take. You know, it would happen, you know, it wouldn't happen in the second quarter, but it would happen, you know, third or at the latest, fourth. I mean, this would be a very quick close because the level of due diligence that's taking place is significant. It wouldn't be like you would get into an agreement and then have that process. It's all being done up front. You know, we do. It will take place this year is our anticipation. Got it. Just one final one if I can, then just jump back on the queue. A lot of investors have asked about, you know, the CapEx raise this morning and how that translates into your long-term EPS growth rate. I I mean, the rate base growth kicker is up. It's now 7.5%. And relative to your guidance of 5%-7%, you're saying solidly in the second half. Just can you comment on that? Are you being a little conservative here? Yeah. Durgesh, this is John. I think the, you know, the wild card is where we think interest rates are going to be over the near term and longer term, right? On that front, I can tell you that, you know, we've been very conservative in our assumptions and our plan. Obviously, if those, if the actual results by the Feds don't materialize to what we have, then that'll have an impact and move us further, you know, directionally up or down. You know, the guidance range that we gave for the next year is pretty wide and, as we did last year, if you recall, we will revisit that range kind of mid-year, and we'll have a better view on things. You know, the uncertainty right now is where interest rates are going to land. That's really helpful, John. Thank you so much. Appreciate the time, guys. Thank you. Thanks, Durgesh. Our next question is from Nick from Credit Suisse. Good morning, Nick. Hey, good morning, everyone. Thanks for taking my question here. Just real quick on the fiscal year 2023 drivers. I think you said you expect an increase in equity investment valuation. Just what is that item? If you could just help us understand that, and could you quantify how large that is in terms of, you know, the fiscal year 2023 benefit? Sure. Sure. You know, I'll take you back. You know, we've had multiple years where we've had pluses and minuses. I think the pluses have always outweighed the minuses. This is an equity investment that we've had in renewable resources, primarily landfill gas generation. We, if you recall last year in the second quarter, we recognized a fair mark-to-market on that investment of about $12 million. We are seeing very attractive valuations on that footprint. So, we have baked, you know, an increase assuming that we'll get another favorable mark-to-market. To, you know, we have done this in the past where we had the conviction that we thought it was going to be favorable, but it's, you know, over the years, it's been a wild card. We've had baked these adjustments into our plan and our guidance, previously. Okay, thanks. Thanks for that. I guess just, you know, on the funding plan, can you just kind of discuss, you know, have you kind of put this in front of Moody's? What's their view and just confidence level and kind of moving off the negative outlook here? Thanks. Sure. Sure thing, Nick. Yeah. I mean, we continuously meet with Moody's and all three of the credit rating agencies, and we certainly did that post-announcement of our wind divestiture. They fully understand and appreciate our plan. We will be meeting with them over the next two months as we go through that annual cycle. I think if you recall, when we announced the offshore wind divestiture, both S&P and Moody's did take some action on some of, you know, obviously a favorable action. They are in tune and lockstep with what we are planning to do. Thanks. One last one for me. Just on your regulatory strategy, I know you've been staying out on the distribution side in Connecticut. Just, how do we kind of think about when the next rate case would be? Thanks. On the electric distribution side, as you know, we have a settlement agreement that precludes any rate change based rate changes, no earlier than 1/1/2024. Okay? You know, I think right now, we, you know, we're not going in the allowed, but we're not that far from it. I think, you know, we can stay out as far as 2025, the end of 2025. I think that's kind of where our head is at. You know, that rate case will trigger recovery of storm costs. You could very well see some filings, that we wanna start the prudency review of those storm costs later this year. Thanks for taking my questions. Thanks, Nick. Next question is from James Kennedy from Guggenheim. Good morning, James. Hey, good morning, guys. Thanks for the time. I guess just on the wind sale, you previously indicated that there could be separate sales or at least, you know, projects. Is that still the case? It also looks like there's a little bit of creep in the total costs. Where are you seeing the pressures and what's in the balance beyond that cost at this point? We do feel that the, this would be more than, you know, be two buyers, somebody for undeveloped lease areas and folks that are interested in projects. We did see higher costs associated with the foundation transportation and the installation contracts. As you might imagine, when you move to these larger turbines, the 11 MW, it was obviously very, very helpful for the project, but it also brought, you know, larger foundation bases which drove costs. That was the issue. I think, James, and we have those numbers in the appendix. I'll direct your attention to that. Okay. Perfect. Then just on the incremental spend, you guys having, you know, the slides. How should we think about the shape of that, and the, you know, sizing through the forecast window? Is it, you know, lumpy on the transmission side? Is it outside of 2027? Just, you know, how should we think about the skew there? I would say the majority, the vast majority of that will happen between now and 2026. It, some of those investments can spill over into 2027. The only one that's more longer term is the, what I mentioned in my formal remarks, and that's the Cambridge substation. That's probably a bit longer. That probably takes us out through 2028. Okay. Just, I'm sorry, go ahead. No, you go. Sorry. I would also mention that incremental, that $3.3 billion of incremental investments, I think it's important for everyone to understand that 2/3 of that has already been approved by regulators. Yeah. Okay. John, just on the sales side, any updates on efforts to mitigate the tax leakage? We continue to look and explore opportunities, but, you know, given how we want this transaction to be structured, you know, it's gonna be a challenge for us. Okay. Fair enough. Thanks, guys. Happy to jump in, yeah. Thank you. You too. Thanks, James. Our next question is from Angie from Seaport. Good morning, Angie. Good morning. Just wanted to talk about offshore wind. We saw a write down of Sunrise at Ørsted. I don't see the 10-K from you guys, but I'm assuming you didn't write down the project. I'm just wondering, is it because it was reflected at a different amount in your books versus what Ørsted had? Or is it somewhat indicative of what you have embedded as your expectation for the sale of the project? Angie, this is John. I can assure you will not see an impairment in our 10-K when we file it tomorrow. With that said, let me give you kind of the key drivers of that. Number one, different accounting. Ørsted is under international accounting standards. The joint venture is under GAAP, U.S. GAAP, and it's a different calculation as to how you assess an impairment. Okay. Two things, two conditions that prompted that. As Joe mentioned, you know, we 90% of the costs being finalized, those costs came in a bit higher than what we anticipated and the fact where interest rates are. Those are the two elements that drove Ørsted to take a look at the impairment for Sunrise. Under the international accounting standards, the first step in the assessment is you have to assess your future cash inflows, and those have to be at a discounted rate. That's really the two key measures that forced Ørsted to look at this and take the impairment charge. Okay. Okay, on. We're seeing a delay in your process, but also a delay in the sale processes for onshore wind or solar assets. I'm just wondering, is it? I mean, is it maybe that potential buyers are waiting for some clarity from the IRS about tax credits from the IRA? If that's the case, you know, when would you actually expect some clarity on those credits? Well, I think the clarity from, you know, the IRA was effective beginning this year, right? They will have to issue some guidance soon, and we think it is soon. Obviously it's an area that we feel comfortable with based on where we see the procurement coming from, and we have conveyed that to the candidates that we're speaking to. Until... Okay. Those regulations come out, you don't know what you, what you don't know. I understand. Lastly, there's been lots and lots of bills proposed in the Connecticut legislature related to utilities. I hear you that, you know, you're not likely to have a rate case within probably the next two years. There's been discussion about, you know, how regulators see settlements, and in general, you know, some push for increased supervision over electric utilities. I mean, is there any comments you can make on those points? Yeah. This is Joe. Good morning, Angie. You know, I think this time of year, you'll begin to see in all jurisdictions, legislative proposals, that come out that will cover the landscape of our business. I think, you know, in terms of settlements, I think if you, if you read the stories there, the fact of the matter is that the governor was very much on board. It was his settlement. Two of the three commissioners were on board with settlements and, even some of, you know, the consumer reps. Yeah, there's a different philosophy down there, around settlements maybe in Connecticut. It's no different than any year in terms of what takes place, up there. We will go up and we've been very actively involved in the discussions. I think everybody knows that, you know, our operations, utility operations are transparent. There's really not much that folks don't see. You know, it's just the first inning of a nine-inning game. You know, we'll have a seat at the table as we always do and discuss these issues. Great. Thank you. All right. Thanks, Angie. Appreciate it. Next question is from Gregg Orrill from UBS. Good morning, Gregg. Morning. Thank you. Just around the 2023 financing plan, is it possible to put a range around the use of the ATM? What I've been saying right along is it's not a marathon. We don't have to. It's not a sprint where we have to issue. What we've said, and I continue to say, is we will continue to be very opportunistic as to when we execute that plan and issue more. Remind everyone that, you know, we did $200 million last year in, you know, kind of the 3rd quarter at an average price of $92. I would love to be in a position to do more at $92, but we'll have to keep a close eye on our stock performance. I really can't say, you know, I'll give you a range as to what we would need to do or would want to do at this point. Okay. Thank you. Also on, the Connecticut AMI, is there anything coming up that would, that would give you, the ability to put that into the capital plan? An order would be nice. I think, you know, just given the, you know, we have to be mindful, and we have to be very sensitive of where energy supply costs are. All right? I think as we're we are starting to see it go in the right direction for customers. You know, the cycle is, as I mentioned, you know, new rates will be in effect in Connecticut in July 1st. Could, you know, PURA take that up to coincide with that? It would seem to be a reasonable outcome. I think until things tamper down, everything is done, the record is basically closed. It's just a matter of a decision by PURA. Thank you very much. Thanks, Gregg. Next question's from Paul Patterson from Glenrock. Good morning, Paul. Good morning. How are you doing? Follow up. Can you hear me? Yes. Yeah. Okay. A couple of things. One on the PBR proceeding. There was a staff proposal that, you know, concept proposal it seems, regarding performance-based regulation in Connecticut, that had sort of some U.K. elements potentially showing up. I'm just wondering, you know, if you could give us a feeling as to, A, when you think we might get more clarity as to where when the PURA will take more action regarding that proceeding. Also just if you have any initial response to what you saw the staff proposal have. Yes. Paul, this is John. I think right now it's still a little too early in this process, to be quite honest with you. You know, they did issue that straw proposal, which was very ambiguous. We are working with them, to share with them some concerns that we have and to what, you know, what the consequences could be if they go a certain direction. Right now, it's similar to what Joe mentioned in the legislative process. It's a bit too early. Okay. You mentioned the FERC 2011 ROE proceedings. Do you have any more of a sense as to when we might eventually actually get something from FERC on that? Paul, I wish I did. I think what we're looking at and, you know, there's been, you know, the MISO decision got remanded back, so it's before FERC. I really think that FERC is going to, you know, issue a decision on the MISO, and kind of fix that methodology. Then we should see, a decision on the remainder of the complaint that's out there, not just for New England, but other jurisdictions. Okay. Just finally, you know, Joe, you mentioned the optimism that you've had and stuff, regarding the offshore wind review. If you could just maybe give us a sense as to, you know, sort of the if you're kind of a gambler kind of thing, sort of like, you know, 50/50, you know, how do you think maybe we might think about handicapping this potential sale as taking place at this point in time? I feel very confident. I mean, the folks that are in the mix, the folks that have been doing due diligence, you know, very sophisticated players. Some of them have lost out on some opportunities in the Americas, so they wanna be in the business. I think that you've seen that appetite. I am very, very confident in that process and the success of the process. Okay. Thanks so much, guys. All right. Thank you, Paul. Thanks, Paul. Next question's from Ryan Levine from Citi. Good morning, Ryan. Good morning. A few questions here. What flexibility do you have in your financing plan if the offshore wind sale process gets delayed further, it's smaller in size or doesn't materialize? Any color you could share around the tools you have to manage these various outcomes and your weighted thoughts? Is your question if the transaction does not happen or is it if it gets delayed? I just wanna make sure I understand. I guess I was asking both. You know, just broadly around what options you have if it gets delayed, it's smaller in size or doesn't happen at all. Well, we would have to issue more debt. We have been financing our $1.9 billion investment by issuing debt. You know, we have to. You know, also we have, if the transaction doesn't happen, right, we are committed to those tax benefits, right? Off the, off the gate, you know, we have our first project, going live, South Fork, later this year, so there would be a sizable amount of tax credits that would be generated. That would certainly help finance that commitment. On the offshore wind CapEx, what are the remaining drivers of the variance between in 2023 and the 2024-2026? It looks like there's about $500 million of delta in the different cases. Can you unpack what's driving that delta? It's directly related to some of the recent procurements that we finalized that got us from the 82% locked in to the 90% locked in, that's primarily the foundation for some of these projects. Okay. Last question. What% increase in your equity investments are you embedding in your 2023 EPS outlook? What markers are you looking at for the landfill gas component that you disclosed earlier? On the equity, I would say we don't have a sizable component of that. Once again, I'm not gonna marry myself to that. If the market is attractive and we wanna take advantage of that opportunity, we may issue more, we may issue less. Right now it's not a significant amount. Okay. Thank you. Thanks, Ryan. Our next question's from Paul Zimbardo from Bank of America. Good morning, Paul. Hi, good morning. Thank you for squeezing me in. On the earnings driver slide, could you quantify first historically what the pension income was in 2022 and what you expect on income or expense for 2023? Well, what I would tell you, and it was part of my formal remarks, is the headwind, the difference 2022 to 2023, as a result of, you know, slightly lower pension income, to be honest with you, is about $0.04 of an impact for 2023 versus 2022. Got it. For the reasons that I, you know, took. It's a modest, negative year-over-year change. Okay, great. Thank you. Again, appreciate all the disclosures involved on the incremental CapEx. Could you help a little bit on the bridge from the old guidance to the new guidance? I know you mentioned potential interest rate headwinds, but just kind of the building blocks, because before it sounded like there was a step up in 2026 from offshore wind, and you more than replaced that with capital. Just if you could help us on moving pieces, that'd be appreciated. Thank you. Sure. I would say it's primarily, you know, two items or, you know, maybe three. You know, the incremental CapEx, the incremental investments, as shown on the slide where we show a 7.5% CAGR for rate-based growth. You know, interest rates, you know, we have a strong track record of managing our cost structure. But, interest rates, it's difficult for us to manage and control. It's a combination of that and, you know, I would say, items that we have not yet included in our capital forecast, as they materialize, will be additive and that'll have an impact on growth rate, long-term growth rate. Okay. Thank you very much. Thanks, Paul. Next question's from David Paz from Wolfe. Good morning, David. Hey, good morning. Thanks for letting me on here. Just quickly, you mentioned interest rates several times in your assumptions. Can you just share what interest rate you have baked into the midpoint of 2023 guidance? I would say pretty much aligned with consensus when the plan was received altogether. You know, I think consensus right now has multiple rate changes between now and midyear, and we have baked that into our assumptions. Okay. Are you seeing interest rates stay flat or rise or decline over the five-year period? David, you might wanna mute your phone while we're answering so we can hear. Okay. Thank you, David. Yeah, no, we, you know, we do taper off a bit in the latter years. All right. David? Great. Thank you. Thank you. No, thank you. All right. Thanks, David. Next question's from Travis Miller from Morningstar. Good morning, Travis. Good morning, everyone. Thank you. Longer term, wondering if you look out kind of two to three years, the comments around natural gas supply, electric rates, gas rates. Is there anything fundamentally you're seeing right now, either in what you're doing, capital investment, operating costs, et cetera, or what else is happening in that region that could change some of that pricing dynamic and supply dynamic? Yeah, this is Joe. Good morning, Travis. Yeah, I think what we have happening here is we have a significant amount of renewable energy that's just waiting to come online, and I think that's gonna be the game changer. Between that, I think you'll see, you know, a big push around storage. Storage is obviously a game changer when you have intermittent resources around solar and wind. It's critical, and I think we're seeing a lot of breakthroughs in that space as well. You know, I do. I mean, I do feel confident that we are, you know, on the precipice of some exciting opportunities which will drive down costs and increase supply for our customers. Unfortunately, just can't get here quick enough as far as I'm concerned. The fact that this project in New York will be up and running by year-end is exciting. The other projects are, you know, they're progressing quite well. Even our competitors' projects are going well because we're obviously involved in some of those interconnections. I do see it, but, you know, again, on behalf of our customers, it can't happen fast enough as far as I'm concerned. Sure. Okay. Just real quick on that, does the influx of renewables exacerbate the gap situation or, like you were talking about, improve it just in terms of a peak load time period? Well, you know, I think any additional resources in the region, coupled with some storage, improves the situation. You know, we are, you know, we do a very good job here in the region around gas. You know, it takes us quite some time and some planning, but, you know, we've been quite successful around, you know, that, the gas supply. I think that the introductions of renewables, or the increase in them, is gonna help the situation and not hurt it. Okay. Great. One other real quick one. O&M inflation isn't listed as one of your drivers in the pluses and minuses. Is that because you've got rate adjustments or something regulatory you expect to be offset, or is that you're just not seeing cost inflation on the operating cost side? Yeah, Travis. Good point. We are seeing that, but you're absolutely spot on. We do have inflation adjustments in Massachusetts, NSTAR Electric and at NSTAR Gas, where it's based on GDPPI, the inflation adjustment. As I mentioned earlier, you know, we have a very good track record of cost management, and we're very focused on that as well. Okay, great. Got it. Thanks so much. That's all I had. Thank you, Travis. All right. Thanks, Travis. That's the last question that we see this morning. We wanna thank you very much for bearing with us, during the beginning of the call. If you have any follow-ups, please, give us a call or send us an email. I'm just gonna turn it back to Nadia. Thank you. This now concludes today's call. Thank you so much for joining. You may now disconnect your lines.