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Thank you for standing by. My name is Tina, and I will be your operator today. At this time, I would like to welcome everyone to the Riley Exploration Permian Incorporated First Quarter 2025 Earnings Conference Call. All lines have been placed on mute to prevent any background noise. After the speakers’ remarks, there will be a question-and-answer session. [Operator Instructions] I would now like to turn the call over to Philip Riley, CFO. Please go ahead.

Good morning. Welcome to our conference call covering first quarter 2025 results. I'm Philip Riley, CFO. Joining me today are Bobby Riley, Chairman and CEO; and John Suter, COO. Yesterday, we published a variety of materials, which can be found on our website under the Investors section. These materials in today's conference call contain certain projections and other forward-looking statements within the meaning of the federal securities laws. These statements are subject to risks and uncertainties that may cause actual results to differ materially from those expressed or implied in these statements. We'll also reference certain non-GAAP measures. The reconciliations to the appropriate GAAP measures can be found in our supplemental disclosures on our website. I'll now turn the call over to Bobby. Thank you, Philip. Good morning, and welcome to our earnings call. Riley Permian has once again demonstrated capital efficiency with strong performance this quarter. Our modest capital investing during the first quarter allowed us to generate substantial free cash flow and further reduce debt, setting us up favorably for the year ahead. We're excited to announce that we have reached an agreement to acquire Silverback Exploration for $142 million in cash. This strategic acquisition involves a largely undeveloped asset base in New Mexico, which is contiguous and overlapping with Riley Permian's existing position in the Yeso trend, thereby extending our footprint in the region. The asset includes approximately 47,000 net working interest acres and significantly enhances our long-term upstream development potential. It adds over 300 gross incremental undeveloped horizontal locations to our inventory, along with around 50 overlapping gross undeveloped horizontal locations, which will increase Riley Permian's current working interest in existing units. Notably, 98% of the acreage is held by production, providing flexibility for future development. We anticipate further synergies from this acquisition in several areas. Number one, water handling. The asset comes with existing water disposal infrastructure and SWD injection capacity to further support future hydrocarbon production. This is particularly important in New Mexico with the regulatory bodies making it difficult to get new SWD permits. Number two, gas takeaway. The undeveloped locations will bolster our previous decision to invest in midstream gas infrastructure in the region. And number three, power generation. We plan to extend our proven processes from Texas to New Mexico, enhancing our power generation capabilities. Despite the current market volatility, we believe this acquisition is justified giving our long-term outlook for both our industry and our company. This year, we are prioritizing the acquisition and preservation of high-quality inventory over the conversion of inventory to production. We believe Riley Permian is well positioned to succeed in the current market environment with our strong asset base, disciplined capital allocation philosophy and robust hedging profile. Now I'll turn the call over to John Suter, our COO, to discuss operational results for the quarter, followed by Philip Reilly, our CFO, who will discuss the acquisition financing and forward guidance.

Thank you, Bobby, and good morning. Once again, Riley demonstrated excellence in operations through safe operating practices. The team achieved a total recordable incident rate of 0 for the first quarter of 2025. We achieved 93% safe days in the first quarter, a metric requiring no recordable incidents, vehicle accidents or spills over 10 barrels. This is a record percentage of safe days in a quarter for Riley. Congratulations to the entire team. Moving on to activity. You will remember that we dropped the 1 rig used in the 2024 campaign in late December. Our 2025 drilling campaign kicked off in Q1, spudding our first well for the year in late March. We plan to use the rig to drill a 10-well program this year, replenishing the DUCs we've completed thus far in 2025. For Q1 2025, we drilled 0, completed 10, and turned in line 0 gross operated wells. 5 of those completed wells are flowing back now and will begin production in May. The other 5 wells will come on in the second half 2025 with minor infrastructure additions. Net production declined slightly from 1.46 million to 1.41 million barrels of oil quarter-over-quarter in Q1, but increased 9% compared to the same quarter last year. Equivalent production is up 19% compared to the same quarter last year from 1.85 million to 2.2 million barrels of oil equivalent. Our average daily net production was [15.6200] barrels oil per day and [24.4300] barrels of oil equivalent per day for the first quarter of 2025. All of this was accomplished without any new wells being added during the quarter, which is a testament to the high-quality assets that we operate. This relatively flat quarter-over-quarter production outcome was achieved while lowering operating costs. Our LOE per BOE for Q1 2025 was $8.34 per equivalent barrel, a 2% reduction from Q4 2024 and an 8% reduction from the first quarter a year ago. Our operations team provides -- prides itself on driving the best economic outcomes no matter what the activity level. Service costs are a subject we're keeping a close watch on, particularly in light of uncertainty around current and future tariffs. That said, based on the recent activity, we see an average of 10% compression in many service costs over last year. While tariffs could have some offsetting impact on tangible costs, even factoring that in, our position remains strong. We're very encouraged by how significantly tangible costs have come down pre-tariffs and even post tariffs, we're still well positioned to lower overall well cost. Should we see a significant decline in rig count such as 30, 40 rigs in industry, we believe our cost compression in the range of 20% could be realized. We're very excited about the Silverback acquisition that Bobby just mentioned. It roughly doubles the size of our Yeso footprint in New Mexico, located adjacent to our Red Lake asset to the West, Southwest and overlapping our acreage in many areas. Here are a few more details on some of the synergies that Bobby mentioned with this combination of assets. A large water disposal system with 5 SWDs that will augment Riley's already robust water operation by roughly 35% to 40%. Water disposal capacity in conjunction with gas takeaway are key facets to enabling development plans in this area. A combination of 2.6 million barrels of recycled water storage is located in 2 primary facilities. This could be a significant cost-saving mechanism for Riley frac jobs and aligns us well with the current regulatory environment. With the acquisition of Silverback increasing the magnitude of our New Mexico holdings, the value and timing of our midstream project are key for development optionality between both assets. Let me update you on what we've accomplished so far with our project and describe our flexibility of completion. During Q1, we completed the first phase of our New Mexico gathering and compression project with the commissioning of our [Birdie] compressor station on the west side of the Red Lake asset. This was completed on time and on budget. We established roughly 15 million cubic feet per day compression capacity toward our existing gatherers high-pressure system and in the process, left additional low-pressure capacity to fill in the interim. In the short term, this new station will increase our ability to deliver gas from this asset more consistently and reliably. It began initial flows to the purchaser on March 26. Once our 20-inch high-pressure transmission line to Targa is completed in 2026, we will swing gas deliveries from this station to that outlet. We're currently finalizing the path and purchasing right of way as per our schedule through late summer. As mentioned earlier, we're keeping a close eye on cost. We have the flexibility to order pipe and begin construction at a time that makes economic sense with commodity pricing and cash flow considerations. The station is designed to be expandable to 100 million cubic feet per day with additional compressors installed as needed. Prior to completion of the high-pressure transmission line, our goal is to maximize the utilization of the compressor station by focusing on near-term development plans approximately to the station. We continue to utilize our power generation station with a greater percentage of our existing Texas assets with 50% to 60% of our power needs provided by self-generation in Q1. We're evaluating the benefits of a similar installation in New Mexico. With the expanded size of our portfolio in New Mexico and infrastructure improvements planned with gas and water, the power generation support will more fully allow us to develop unconstrained. In summary, for the quarter, we are pleased with our delivery of relatively flat production at lower LOE, especially considering no new wells turned in line as per plan. We made significant midstream progress with the completion of our compressor station in Red Lake, all while delivering stellar safety metrics. We picked up a rig and look forward to efficient and cost-effective Q2 development. I want to congratulate the Riley development and operational team for a very successful quarter. Philip, I'll turn it over to you.

Thank you, John. Our first quarter financials are straightforward. We converted $54 million of operating cash flow before working capital to $39 million of upstream free cash flow on account of a lighter CapEx quarter, reinvesting only 35% in the upstream while keeping volumes mostly flat. We allocated upstream free cash flow as follows: 56% went to debt reduction and cash, lowering debt by $21 million quarter-over-quarter to 0.9x leverage. A combined 23% was invested in our midstream and power projects and 21% was allocated to the dividend. I'll next describe some of the acquisition mechanics and funding estimates. With the transaction effective date of January 1 and an estimated closing date of July 1, we'll benefit from 6 months of cash flow that will serve as an adjustment to the funds required at closing. At current prices, this may amount to a $15 million reduction at closing and after accounting for some transaction expenses may result in $130 million draw on the revolver. We do forecast a modest debt increase during the second quarter on a stand-alone basis based on current estimates from the impact of working capital movements. By the third quarter, pro forma leverage after the acquisition will increase but to a level with which management and the Board is comfortable, and we believe similar to levels where we were at the end of 2023. We'll focus on managing the leverage profile in the second half of the year, which will be impacted by market prices, cash flow and spending. We have a track record of paying cash for an asset and subsequently deleveraging over time, and that's our plan here. We'll benefit from some novated hedges coming with the acquisition entity as well as additional hedges we've put on recently. For the balance of 2025, on a pro forma combined basis, we've hedged oil prices for 70% of forecasted PDP volumes and 57% of total oil volumes at a weighted average $67 downside price. For 2026, on a pro forma combined basis, we've hedged 67% of forecasted PDP volumes at a weighted average $59 downside price. Let's now discuss our modified guidance. In March, we announced 2025 investing guidance calling for material investments across upstream, midstream and power as we seek to build complementary assets in a self-reinforcing model. On our last call, we forecasted staying debt neutral for the year at around $70 WTI. Since then, both realized prices and the forward strip have been well below that level. Additionally, the Silverback acquisition opportunity manifested, and we and our Board decided that was worth pursuing even a volatile down market. Given the combination of these factors, we decided to adjust down our CapEx across each of upstream, midstream and power. On a stand-alone basis, before accounting for the acquisition and reinvesting any of its cash flow, we're reducing 2025 total investments by $105 million or 50%, including upstream CapEx by 41%, midstream CapEx by 71% and the Power JV investment by 25%. The impact on stand-alone upstream volumes is modest with midpoint oil guidance only down 4% and still showing year-over-year growth. One way we're achieving this is by turning to sales already completed wells. We plan to complete more wells than we're drilling owing to the fact that we have an inventory of DUCs to utilize. We also provide guidance combined with the acquisition, showing the second half of 2025 for combined volumes and the full year averages, which only include a half year benefit from the acquisition. At this point, we forecast only modest incremental development activity and reinvestment of the acquisition cash flow, perhaps 2 net incremental wells given the currently depressed price outlook. On an inflation-adjusted basis, oil prices are at their lowest levels in the past 20 years, aside from 12-month periods in 2015, 2016 and then again in 2020. We believe this is a better time to procure and preserve inventory, as Bobby said. We're certainly excited about the long-term development potential of the assets. And while we believe breakeven development prices are far below the current market, we believe more favorable market conditions will return for bringing on new production. On the midstream project, John described how we're spending selectively while pausing for now on the order of the pipe material itself. This will help reduce the concentration of the project spend and spread more into 2026. Additionally, we may explore some financing alternatives for the midstream project. There's a scenario where we elect to use entity-level financing and reaccelerate the project. We'll report back next quarter. On power, we continue with good progress and foresee reprioritizing a few elements following the acquisition, including adding battery backup to the self-generation project in Texas, adding another self-generation project in Mexico and using the thermal generators from one of the five ERCOT projects for that, while finally deferring the battery generation aspect of the ERCOT project. Net-net, we forecast this reducing our power equity investment need in 2025 by $5 million or 25%. I'll turn it back to Bobby for closing. Thank you.

Thank you, Philip. Once again, we appreciate your time and interest in Riley Permian. While we're pleased with our Q1 2025 results, our focus remains firmly on the future. We are committed to building a long-term value through disciplined capital allocation, strategic infrastructure investments, and operational excellence. Our recent initiatives position us for sustained growth, and we believe our long-term strategy will continue to drive shareholder value well beyond this upcoming year. Thank you for your continued support. Operator, you may now turn the call over for questions.

[Operator Instructions] Our first question comes from the line of John White with ROTH Capital.

Congratulations on the Silverback acquisition. It looks like a very nice transaction for you. I was going to ask about the held by production content, but you had -- Bobby addressed that in his opening remarks. What do you think the motivation for the seller was? Was it driven by private equity structure or something like that? What do you think?

Yes, John, this is Philip. I'll take that. Yes, the seller here was one of the large -- large private equity shops, and they often focus on kind of $3 billion to $5 billion type of entities and exits. While this is great scale for Riley Permian, maybe eventually, it was going to be just a bit too small for them. At the same time, there's a real strategic move and unlocking that we're doing here. A lot of the region has been constrained by some infrastructure, including gas. And there are some efforts being made by third-party midstream companies to believe that, but probably insufficiently. So the project that we started in the fall that we announced there in January, building our pipe really gives us a strategic advantage here. And we believe that we were really best positioned to unlock that whereas somebody else really couldn't take advantage of that. Does that help?

Yes, very helpful and makes very good sense. Thanks for the extra detail and I'll turn the call back over to the operator.

Yes, sure. I'll start off here and then pass it to John to add in here. In general, this acquisition absolutely supports our decision to invest in infrastructure. You can see the map. It's a beautiful map there with the complete adjacency and overlapping acreage. What we'd say is we can definitely take advantage of the pipe that we're building. We'll also need more, frankly. We'll have more -- sorry, we won't need another pipe, but we'll probably want some additional gathering and compression over time. It's not something we have to do. That's what John could speak to here. But it does absolutely offer some synergy. We're excited about that. I'm referencing gas here, but it's also water. John talked about that. So yes, Jeff, there's absolutely ability to take advantage of that from the upstream side for operations. And then if you put the midstream business hat on, this represents a substantial amount of additional volumes that can go through the system. It's slightly lower working interest, pretty similar to what we've got. But as we described on the prior earnings call, we can bill out to working interest partners and most of the royalty owners, the fees there. And so this represents some win-win. John, do you want to add something there?

Yes. The way we think about hedging is a risk management tool. There's a covenant compliance aspect, but then there's also the risk management perspective, which is more of the driving factor. We like to think of that ahead of the troubled times. And so we're fortunate that we did that. So we're not having to hedge now necessarily. Generally, how we treat this is that the more leverage we have that might -- and the more fixed costs that we see, commitments that we see, we're going to want some more protection. For example, we had some nice 60/80 collars for some of 2026, $60 downside, $80 upside that we decided to convert to some swaps that provided an uplift of maybe $5 or $6 when you converted it to a swap. And so that, in turn, led to, say, a $6 or $7 premium to what the swap was at the time, which we're happy to do, which gives us just a little bit clearer stream of cash flow there for the upcoming year. For this year, we feel good about it. We have a smaller delta perhaps between PDP and the total volumes on our forecast than sometimes we do just given we're not spending a ton this year on the development, as I described earlier. And so that allows for a little bit easier hedging profile as well.

Lastly, on power. Are there any significant permitting differences between what you might need to do power-wise in New Mexico versus what you've been doing in Texas?

I can start. Maybe, John, you can help me. But yes, the air permits a little bit more. It's just a functional item you add to the generator and SCR. And so what we're talking about for the behind-the-meter installation there, which I kind of hinted at there in my prepared remarks, that adds just a little bit of cost. But otherwise, we're looking fine on the permitting and feel pretty good about it.

[Operator Instructions] And our next question comes from the line of Derrick Whitfield with Texas Capital.

Congrats on a strong update and transformational acquisition. Maybe starting first with the Silverback acquisition. It's clear the acquisition materially increases your net undeveloped locations and offers considerable synergy opportunities. Could you guys speak to how this asset competes for capital and the opportunity you see to accrete working interest across this position over time?

Yes. I think especially the East side of this asset, the East half is really, we think, identical to reservoir quality that we already have. And so it's -- I think it's really going to revolve around the infrastructure, at least initially, we want to be able to develop maybe the East side of the Novo asset and the west side of the Riley asset as a starting point just to take advantage of that existing compression station and pipeline to Targa. So that's kind of where we see it. But as far as the economic side, I would say those 2 areas are really similar.

Great. And then maybe shifting over to the stand-alone business. It's quite remarkable that production is only impacted by 3% given the near 50% decrease in 2025 capital. As you guys think about the adjustments you're making to the capital plan for non-D&C capital, does that give you adequate runway once you're in a position to increase capital to the upstream business?

Yes, I can start. It is a mix here of drilling and completions capital that we're cutting, but also some infrastructure admittedly. That was part of the initial kind of $200 million budget that we started with earlier this year. That includes a variety of, say, non-power JV power installation like PME, some water. We also had some growth capital in there, frankly, for some land acquisitions that we kind of earmarked this acquisition as effectively just a giant land budget there. And so there's some things that we are cutting this year as far as D&C. There's other things that we're effectively deferring a bit that we're fine to defer, and we'll layer in and smooth out over the coming 12 to 24 months or longer.

Our final question comes from the line of Noel Parks with Tuohy Brothers.

I just have a few. Just a housekeeping item. Is there any assumed debt with the transaction?

No.

Okay. Great. And you did already comment on the hedges. Just curious about what the recent drill bit pace was with Silverback? Have they been active or not?

Yes. They really haven't been too active drilling-wise. To be honest with you, it's not because of the quality of what they have to develop. They just were really hamstrung with having a longer-term access to infrastructure. I mean that word keeps coming back up, but it's -- they were kind of constrained in that area. They did drill -- they have drilled some wells, but they weren't what I would call active.

Yes, it's been 1.5 years since they drilled their last well.

Wow. So a host of quite a few other PE exits we've seen over the years where they really ramp up the production to sort of pump up the valuation is not one of those cases.

You could drill some wells individually, but you really can't drill to scale to be able to do that again, and that's kind of like we had on our last conference call where -- earnings call where they asked Bobby about that, but it really gives us a competitive advantage when we hold kind of the key to the infrastructure that we believe would result in opportunities like this. So it's kind of played out to some degree.

Got it. And I guess I was just curious, someone did ask about the seller's motivation, but you mentioned that the opportunity was clearly attractive even in a weaker oil environment. And -- but when I saw the map of where the acreage location, it's like, okay, you are obviously aware of this, you know, this division's operation. I can't really think of a closer bolt-on I have seen in the deal recently. So did this sort of I guess, was maybe the degree which they're constrained was that evident to you before you got into due diligence? And do they come together relatively quickly? Or is this something that has been on the back burner for a long, long time?

I can try to characterize it, Noel. Generally, people are aware of the regional constraints for gas takeaway in the Permian, both in the basin and even up on the North West Shelf. You can look simply at Waha differential and see how much less valuable gas is here in the Permian versus the Haynesville or the Marcellus. So that's not a secret. As far as the deal coming together, I'll say we did our best to make it happen. Obviously, we've worked through some volatility in the past 6 weeks, and we're happy to present to you today what we were able to achieve.

Yes. I think their technical team always -- they're kind of carbonate experts, I think. And so we're always looking up and down the shelf to see what opportunities are out there if the chance ever exists.

Okay. Well, great. It’s terrific to see such a high-quality acquisition. I was sort of under the impression that there wasn’t a lot out there that most of kind of what was coming to market was sort of pitched over. So this is like a welcome surprise. So congratulations.

Absolutely. No, it's -- you still don't get something like that where you aren't rushing to cover either the decline or the expirations. But we're in really good shape here where we can take advantage of some of the infrastructure they did have on the water side and kind of take our time and deploy money when it makes sense and again, to take advantage of the new compression that kind of borders both of our assets.