And yes, you heard that right, TNMP and FERC rate base are now over half of our consolidated rate base. Turning to Slide 5; consistent execution of our plans has resulted in a strong track record of achieving our financial targets. We remain flexible, responding to changing conditions each year and making adjustments to stay on track. We hold ourselves accountable to delivering results. We have achieved 6% earnings and dividend growth since 2019 and are positioned to continue this trajectory even in the current market environment. And lastly, I'm still here, and the team is still here, and we're focused on continuing to deliver our plans to customers, communities and shareholders. Both Don and Lisa have been at the company over 20 years and have helped shape the course we've been charging.

We had a strong financial profile three years ago. And with our increased diversification, it is even stronger today. Now turning to Slide 6, we are reporting ongoing earnings today of $2.82 for 2023, once again ahead of expectations. While some pieces of our recent PNM rate decision were disappointing, the questions around recovery of our legacy generation assets are resolved, and we now have a clear path going forward. From a 2024 base, we are targeting 6% to 7% earnings growth through 2028. This is based on a 10% rate base growth over the same period, and Lisa will walk you through our financing assumptions in the earnings power slide. I know how much you have all missed that slide and its back. Our 2024 guidance incorporates the PNM rate decision in our range of $2.65 to $2.75.

Don will talk more about our regulatory plans moving forward. But before that, let me provide a quick update on our sale of New Mexico Renewable Development or NMRD. We are still on track to close this month. Our net proceeds are anticipated to be $115 million to reflect our 50% ownership share in the entity as we monetize the cash flows from this unregulated business. With that, Don, I'll turn it over to you.

Don Tarry: Thank you, Pat, and good morning, everyone. I'll pick up on Slide 8 with more on our investment strategy at TNMP. The continued high growth across our three service territories in Texas require substantial infrastructure investments to support customer growth and grid reliability for existing customers. Economic growth across the state continues to push the demand on our system to new levels after setting new system peaks. Over the last few summers, TNMP has already seen a new peak in 2024 as cold temperatures in January pushed the system demand beyond the record-setting levels of last August. Additionally, in response to concerns about extreme weather events and grid conditions, the Texas legislature in 2023 passed a series of bills aimed at encouraging investments to enhance grid reliability and resilience which I'll talk more about in a minute.

Our service territory is scattered across three distinct areas of the state, North Central Texas, the Gulf Coast and West Texas. Each of these three areas has different industries in their economy, which means our growth is well diversified. As the larger metropolitan areas in the state continue to grow, these economies have been extending out further into our service territory. Turning to Slide 9; the regulatory framework in Texas also strongly encourages investments into the grid by providing timely recovery through rate mechanisms outside of general rate cases to minimize regulatory lag. On the transmission side, the transmission cost of service or TCOS mechanism has allowed for semiannual filings for several years. TNMP has already made their first filing in 2024 in January, requesting recovery for an incremental $97 million of transmission rate base.

We expect to follow our usual pattern and file again in the second half of the year. On the distribution side, this will be the first year TNMP expects to make two distribution cost recovery factor filings or DCRF filings after semiannual filings were permitted through legislation last year. Recovery under the DCRF continues to require an earnings monitoring test to prevent over earning on the year-end rate base, which we will file in the spring. We will then make our first filing in the second quarter and our second in the fourth quarter of this year. The regulatory clock on these filings has also been shortened to be similar to the transmission side with an advanced notice period for customers and then a 60- to 75-day period for commission review.

We also expect to make our first resilience plan filing this year under the new rules implemented the legislature passed last year. An independent evaluation and development of a system resiliency plan covering three years is required in the filing. Under the rules, we may choose to recover the associated cost of capital investments under the existing TCOS or DCRF rules, deferring depreciation on assets until recovery begins. We have estimated $450 million of projects in our current investment plan that could be part of our filing. The rules also allow for recovery of certain O&M costs like vegetation management expenditures that exceeds the amount authorized for recovery in our base rates. There is a 180-day clock for these filings and we would make our filing this summer and expect recovery to begin in 2025.

Some additional items that were passed in last year's legislative session are working their way through the PUCT rules. We continue to believe temporary mobile generation will play an important role across each region of our service territory, assisting TNMP and restoring power to distribution customers after a significant event. We have not included any potential amounts related to this need in our current capital plans. In regards to the legislation on West Texas transmission planning, the PUCT has required ERCOT to file a reliability plan no later than July of 2024. And after an opportunity for stakeholder feedback, we would expect the commission to review and approve a reliability plan for the Permian Basin, which could lead to additional investment needs.

Another law shortens the time frame to consider applications for certificates of convenience and necessity, or CCN, for the new transmission across the state to further encourage new transmission development. TNMP recently gained approval for a couple of projects in December and January that were reviewed and approved under the shorter schedule than we've seen historically as the commission moves closer to that 6-month clock. Legislation was also implemented to allow for recovery of total employee compensation. And while this is not material to TNMP's bottom line, we would plan to include these costs in the future under a general rate review filing. In total, these mechanisms provide TNMP, the opportunity to earn our authorized return. And we will likely see additional investment opportunities in the future currently not included in our capital plan.

Now turning to PNM on Slide 10; our investments at PNM are similar and that they are focused on customer-driven T&D projects to strengthen the grid. PNM hit a new system peak in 2022 and in 2023 after not seeing one in nearly a decade. Clean energy mandates in New Mexico over the next 20 years, where we'll acquire additional transmission resources to integrate a growing amount of intermittent renewable resources on the system. The transition to clean energy has also led to some economic development wins for the state, including Maxeon Solar, first U.S. manufacturing facility being built in Albuquerque. Grid modernization investments for utilities across the state are also being considered at the commission level now under rule making prompted by legislation.

We have reduced the amount of capital investments into generation resources substantially over the last decade to support lower costs for our customers. The renewable resources chosen to replace our San Juan coal plant and our Palo Verde lease capacity were secured through renewable and storage purchase agreements. We do think there is an operational advantage to having utility ownership of battery storage on our system as we have more control on how the resource is cycled to support our customers' patterns of use. With the passage of the IRA, utility ownership on a cost basis has become more competitive and we currently have a proposal in front of the commission for storage through utility ownership and the capital for the own storage is in our plan.

Otherwise, our generation capital supports our existing fleet of resources that provides overall system liability to our customers. Turning to Slide 11; the ratemaking structure in New Mexico provides the opportunity to earn our authorized return through the use of a future test year and specific riders, such as the fuel clause. Generation and distribution system costs are completely tied to serving our retail customers and are recovered through a general rate review mechanism. Our transmission system is used to serve both retail customers and FERC transmission customers that are moving energy across our system, and those costs are allocated between the different sets of customers based on utilization of the system. FERC transmission costs are recovered through a formula rate, which allows for an annual filing to update the system utilization and corresponding rates for the customer.

In the past several rate filings, the most controversial issue has been recovery of our generation resources. In the general rate review decided last month, the commission resolved the remaining generation transitional issues that date back to decisions made by the prior commission in 2016. The decision in this case resolved those issues and allows the focus to turn towards a forward-looking solution of grid modernization and resiliency investments that are required as we transition to carbon-free while providing value to our customers. Our application for distribution level of battery storage did not have any opposition from interveners and was approved by the commission for recovery in 2024 rate change. We received recovery in this case for over $2 billion of incremental investments and approval for 97% of our requested O&M costs.

Our fuel clause was also approved for continuation. Another application currently in front of the commission proposes grid modernization investments, including smart meters and other distribution level projects designed to empower customers and lay the groundwork for a more resilient grid. We expect the decision on this case by the third quarter. We also expect a decision this summer on our proposal for new resources in 2026. We have put forth 350 megawatts of solar and storage purchases along with a 60-megawatt utility-owned battery. Recovery for any new resources approved in this docket that cannot be included in our fuel clause would be also part of our next rate case filing. We have a couple of upcoming filings on our agenda. We will make our annual filing associated with our FERC formula where we expect to see increased utilization of transmission system by FERC customers based on new contracts.

We also plan to make our next retail rate filing this summer for rates that would become effective in the third quarter of 2025. The filing will use a future test year ending partway through 2026 and we assume a 13-month regulatory clock. On Slide 12, after taking into account these changes, the average residential bill at PNM is significantly lower than both our regional and national average. The Energy Transition Act is achieving its goals for customer benefits as we exit coal. We are seeing load growth to reduce the per-customer impacts and our fuel costs have been significantly reduced by our participation in the Western energy imbalance market and its optimization of renewable resources. We have also exercised discipline in our O&M costs and are focused on initiatives that provide direct benefits to customers.

With that, I will turn the time over to Lisa to walk through the financials.

Lisa Eden: Thank you, Don, and good morning, everyone. I'll start on Slide 14 with a summary over the year-over-year changes in 2023 earnings. As Pat reported earlier, 2023 ongoing earnings are $2.82 per share, a $0.13 increase from 2022. Load growth and weather added to PNM's and TNMP's combined earnings on a year-over-year basis. At PNM, lower operating costs as we transition our generation portfolio to carbon-free energy and higher transmission margins driven by increased usage of our system increased earnings year-over-year. Continued rate recovery of transmission and distribution investments at TNMP through TCOS and DCRF filings increased earnings. These increases were partially offset at both utilities by expenses for depreciation, property tax and interest associated with new rate-based investments.

Lower earnings at corporate reflect higher interest rates year-over-year, partially mitigated by the hedges we've previously put in place. Detailed segment-level drivers can be found in the appendix of today's presentation. Slide 15 provides an overview of our financial outlook. Our guidance for 2024 is a range of $2.65 to $2.75. I'll walk through the drivers of 2024 earnings compared to 2023, along with our estimated quarterly earnings distribution. I'll then move into our capital investment plan which has been carried out through 2028 and reflects rate base growth of 10% and our financing plans to support these investments. And then I will carry those assumptions forward into our earnings power slide, showing the earnings potential of our business through 2028.

Lastly, I'll recap our dividend and payout ratio based on the increase announced in December. Let's get started on Slide 16 with 2024 guidance. We are introducing a range of $2.65 to $2.75 for 2024. At PNM, our recent rate case outcome at $0.12 to year-over-year earnings. Keep in mind that going into this case, PNM was able to earn its return by offsetting the regulatory lag on new investments made since 2018 through the energy transition. We expect to earn our authorized return in 2024 since new rates have trued up our investments and costs. At TNMP, rate relief through the TCOS and DCRF mechanisms increases earnings, including our first year of implementing two DCRF filings, along with the recently approved resiliency rules. Higher transmission margins and income from our decommissioning trust also adds to earnings of PNM in 2024.

These increases at both utilities are offset by the depreciation, property tax and interest costs associated with new investments. At Corporate, the increase in debt balances to fund future growth are partially offset by the equity issued in 2023 and the proceeds from the sale of NMRD expected in February. We continue to have $600 million hedges in place in 2024 to hold the underlying interest rate at 3.5%. Our guidance reflects the additional shares issued through our ATM program in 2023 to support capital investments. We issued a total of 4.4 million shares which has a $0.14 impact on year-over-year earnings per share. As for our quarterly distribution of earnings, we remain a summer peaking utility with the third quarter being our largest quarter from an earnings perspective.

The remaining three quarters are fairly evenly split. Turning to Slide 17, we have updated and rolled out our capital plan through 2028 for a total of $6.1 billion over five years, but in large part, it remains the same as the capital plan that we shared with you on our third quarter earnings call last year. TNMP continues to be our largest category of investments as we support the increase in system demand across our service territory while also benefiting from a supported legislative and regulatory environment, as Don discussed earlier. Based on the new legislation, there may be additional opportunities beyond the current plan for things like temporary mobile generation or additional transmission investments in West Texas. PNM T&D includes nearly $300 million in 2024 through 2028 for the grid modernization investments that are currently being considered by the commission.

Approximately $175 million of those costs are associated with automated meters, which we believe is a priority for customers and necessity to implement more advanced rate structures. PNM own battery storage includes $135 million for the 60-megawatt utility-owned battery included in our 2026 resource filings. We expect a decision this summer. Our plans also include another 30 megawatts of the smaller distribution level battery storage that will be required - that will require a separate commission approval, and we see potential for that need to grow. We do not have any other new utility-owned generation included in our plans but as economic development efforts continue in New Mexico, we will see a need for additional resources beyond 2026. In this circumstance, regardless whether they are utility-owned or PPS, we would need to put forth a filing with those resources for commission approval.

The bottom of the slide shows that this investment plan translates into 10% rate base growth for 2024 through 2028. TNMP is our fastest-growing area of 13% and surpasses the level of rate base at PNM Retail by 2028. On Slide 18, I'll share the financing assumptions in our plan. In 2023, we raised $200 million of equity through our ATM program to support investments made at both utilities and issued those shares in December. We expect $115 million of proceeds from our MMRD sale in February, and we issued $343 million in securitization bonds in November. I also noted earlier that we continue to have $600 million of hedges in place for 2024 and $300 million for 2025. As we move forward, we continue to see an equity need of $100 million per year on average through 2028 for a total of $500 million to support our 10% rate base growth.

We currently have two term loans at the holding company, totaling $1 billion with half maturing in 2025 and the other half maturing in 2026. We've previously talked about our intentions to refinance this amount on a longer-term basis. As we do this, we will look to utilize debt instruments that provide equity credit to benefit our metrics and support our ratings. We believe this provides an efficient way of financing growth but also refinancing the business more permanently. As we have done in the past, we are being transparent about our modeling assumptions upfront, but we have not made any firm commitments to these instruments or timing. We will evaluate market conditions as they evolve in order to optimize our financing over our longer-term plans.

Before we leave this slide, S&P recently moved our outlook from positive to stable at all three entities. The move up to a positive outlet was done following the 2020 announcement of our merger based on the benefits of being part of a larger entity. The stable outlook brings us back to the same rating and outlook held prior to the merger announcement. Now let's turn to Slide 19 for the highly anticipated return of our potential earnings power slide. This view incorporates our capital investment plans and financing assumptions and it supports our targeted earnings growth of 6% to 7% through 2028 from our 2024 guidance midpoint of $2.70. We have rolled forward rate base to incorporate the CapEx plan that we just walked through for PNM Retail, PNM FERC and TNMP.

We are assuming that we earn our authorized return on rate base with the currently authorized equity capitalization. I'll note that PNM Retail incorporates the newly authorized ROE of 9.26% and equity capitalization of 50% for all years. At FERC, we've been able to offset regulatory lag and earn our 10% authorized return these last few years after acquiring the Western Spirit transmission line in 2021. Total PNM also includes items not in rates, which accounts for any short-term interest expense and offsets through AFUDC, decommissioning and reclamation trust income and certain incentive compensation that is not recovered in rates. TNMP earns its return in each year. Any regulatory lag stemming from the use of a historical test year is largely offset by low growth, the addition of a second DCRF filing and improved recovery under the resiliency rider.

Short-term interest expense is offset by AFUDC and the incentives provided by the energy efficiency rules fills any remaining gaps. The Corporate and Other and equity financing lines reflects the financing assumptions that I covered on the previous slide. Again, these are modeling assumptions and the range of impacts we're showing on this slide allow for flexibility as we optimize these financing plans based on the market conditions. The consolidated EPS is a range supporting our target of 6% to 7% growth through 2028. This is an update from our previous target, which incorporated various outcomes, impacting PNM and our overall financing needs. The resolution of PNM's rate case gives us increased confidence in our plans. When comparing to our rate base growth of 10% over the same period of 2024 through 2028, the difference is primarily financing costs.

We feel confident in our plan and the ability to execute on our growth targets. As we move forward, we will continue to update this slide to provide transparency into our plans and reflect any material changes. Before I hand things back to Pat, Slide 20 shows our dividend. We increased our annual dividend to $1.55 in December, a 5.4% increase. We maintained dividend growth throughout the merger process and look to grow the dividend to stay within our targeted payout ratio as we manage the business over a long-term horizon. With that, I'll turn it back over to Pat.

Pat Vincent-Collawn: Thank you, Lisa. Before I open it up for questions, let me acknowledge all of our teams here at PNM Resources. Everyone here plays a part in executing our business strategy, whether it's working on infrastructure construction from start to finish, answering customer calls, restoring power or supporting our teams and the customers that are the core of our purpose. Thank you. Your efforts are both seen and appreciated. And I hope that you all agree that we are still standing better than we've ever been. Lynea, let's please open it up for questions.

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