Thank you for joining us today for Texas Pacific Land Corporation's Second Quarter 2025 Earnings Conference Call. Yesterday afternoon, the company released its financial results and filed its Form 10-Q with the Securities and Exchange Commission, which is available on the Investors section of the company's website at www.texaspacific.com. As a reminder, remarks made on today's conference call may include forward-looking statements. Forward-looking statements are subject to risks and uncertainties that may cause actual results to differ materially from those discussed today. We do not undertake any obligation to update our forward-looking statements in light of new information or future events. For more detailed discussions of the factors that may affect the company's results, please refer to our earnings release for this quarter and to our recent SEC filings. During this call, we will also be discussing certain non-GAAP financial measures. More information and reconciliations about these non-GAAP financial measures are contained in our earnings release and SEC filings. Please also note, we may at times refer to our company by its stock ticker, TPL. This morning's conference call is hosted by TPL's Chief Executive Officer, Ty Glover; TPL's Chief Financial Officer, Chris Steddum; and Executive Vice President of Texas Pacific Water Resources, Robert Crain. Management will make some prepared comments, after which we will open the call for questions. Now I will turn the call over to Ty.

Good morning, everyone, and thank you for joining us today. The second quarter of 2025 marked another quarter of record performance across TPL's major revenue streams and key performance indicators, showcasing the company's ability to prosper amid commodity price volatility. Average WTI Cushing oil price during the quarter averaged $64 per barrel, which was the lowest average oil benchmark price since the first quarter of 2021. Despite this oil price weakness, TPL still set quarterly revenue records for produced water royalties and easements and other surface-related income. Oil and gas royalty production of 33,200 barrels of oil equivalent per day also represents a company record. Even with our direct and indirect commodity price exposure, TPL still efficiently converted revenues to cash flow with second quarter adjusted EBITDA margin of 89%. Tariff uncertainty and OPEC's decision to reduce voluntary cuts were significant factors contributing towards slumping oil prices and sentiment with WTI struggling to regain $70. Over the last few months, various operators have publicly signaled intentions to reduce activity. According to Baker Hughes, Permian horizontal oil-directed rig counts have declined over 20% from the peak in 2023. Because of this broader slowdown, we now hear more speculation about this idea of peak Permian. This is the notion that Permian production is soon set to forever be on a plateau or terminal decline. Given TPL's experience in Permian-centric position, I'd like to spend some time in my prepared remarks to share our perspective. First, some stats to put things into context. The Permian spans millions of acres spread across West Texas and New Mexico, and it contains numerous high-quality stacked pay formations. On a production basis, the Permian is the largest oil and gas basin in the world with oil production currently averaging approximately 6.5 million barrels per day. The Permian accounts for roughly half of all U.S. oil production, and it produces more than every OPEC nation other than Saudi Arabia. Just 10 years ago, Permian production was less than 2 million barrels of oil per day. The Permian also produces approximately 3 million barrels per day of natural gas liquids, bringing its total liquids production to close to 10 million barrels per day, which represents about 9% of total liquids supply globally. Simply put, the Permian is a major force in the global market. After such a remarkable run of resource development and combined with recent activity reduction, it might be easy to conclude that Permian geology is nearing exhaustion and past its peak. In our view, this is a misguided conclusion. First, a slowdown in activity due to lower oil prices should not be conflated as a slowdown due to limited drilling inventory. Upstream companies are still price sensitive. It is reasonable to slow down development when commodity prices have declined. This slowdown does not diminish or change how much resource remains underground. Preserving those reserves for when commodity prices are higher is a sensible strategy for upstream companies looking to maximize long-term shareholder value, which brings me to my second point. From our perspective, the Permian still retains a long runway of undeveloped inventory. For example, a report published earlier this year by Enverus, which is a leading provider of oil and gas analytics, estimates that there are over 60,000 locations remaining with breakevens below $60 oil and $3 natural gas. This represents undeveloped resource upwards of 30 billion barrels of oil. For context, in 2024, the Permian turned to sales approximately 5,700 wells. Assuming that same pace, which would put the Permian on a growth trajectory, that would translate to approximately 11 years of drilling inventory just for the subset of wells that break even below $60. As you move up the oil price beyond $60, that would potentially pull in tens of thousands of additional economic locations, billions of barrels of additional resource and years or decades worth of additional runway. Furthermore, these types of analysis are generally predicated on prevailing drilling and completion practices. Improvements in technology and operational efficiency can further extend the basin's longevity. As development techniques continue to evolve, which they consistently have since the advent of horizontal drilling and fracking, upstream companies will continue to drive breakeven economics lower and improve resource recovery. Past and ongoing advancements such as increased fluid and proppant loading, produced water recycling, increased lateral length, simultaneous fracs and co-completions are examples of industry innovation that have generally become standard practice for modern-day Permian well development. To provide a specific example, for horizontal wells developed in Loving County, Texas in 2025 compared to 2015, you've seen lateral lengths doubled to over 10,000 feet, proppant intensity per foot increased over 50%, fluid intensity per foot nearly double, all of which has resulted in a doubling of the NPV per well with an illustrative $60 oil and $3 gas price deck. Development trends for more recent periods show that operators continue to make impressive efficiency gains. For example, in 2023, the Permian averaged 323 horizontal rigs during the year, which then declined in 2024 to an average of 296 rigs, an 8% decrease year-over-year. Despite the drop in rig counts, total drilled feet increased approximately 5% during the same period. This equates to an approximate year-over-year increase of 15% lateral feet drilled per rig. In other words, declining rig counts were more than offset by increased drilling efficiency. A more recent example of an exciting innovation by a major operator on our royalty acreage is the use of new lightweight proppants to enhance recovery factors. This operator has been utilizing this material derived from relatively low-value refinery co-products to drive improved recoveries up to 20%, and the operator has plans to deploy it in roughly one-fourth of its Permian wells this year. In other more mature basins such as the Eagle Ford and Bakken, you also see operators recomplete wells that have already been producing for a while. Economics for recompletions can be just as good, if not better, than for new drills. In the Permian, there have been upwards of tens of thousands of wells that have been completed years ago using older, less productive development techniques. Down the road, even if it might be decades away, recompletion in the Permian could shallow decline rates, further extend the basin's resource life and ultimately allow the industry to recover significant incremental reserves. With current development techniques, only a fraction of oil reserves are recovered from shale; whether through new proppants, recompletions or any other future advancements, even just a few percentage points improvement in recovery factors could mean billions of barrels of incremental future production. This is especially lucrative for royalty owners given that these incremental recoveries are pure upside without having to bear any of the costs to implement. It's a free call option on innovation. Another example of industry ingenuity are Horseshoe wells. Horseshoe wells are basically a U-shaped horizontal lateral. These are used when operators are unable to pool or unitize leasehold acreage to accommodate longer straight-line laterals. What operators are doing instead of drilling one-mile laterals within a section, they're drilling a U-shaped or horseshoe-shaped lateral that allows longer lateral lengths while staying within the leasehold boundaries. Horseshoe wells can also contribute to a reduced surface footprint, which can be an advantage in areas with environmental concerns or limited surface availability. Though this is more operationally complex, it can save operators substantial capital and improve well economics by only having to drill one horseshoe well with, say, 10,000 lateral feet versus drilling two shorter straight-line wells, each with their own vertical section and then 5,000 feet of lateral. Three years ago, we had no horseshoe wells on TPL's royalty acreage. Today, TPL has 48 horseshoe wells by multiple operators across both the Midland and Delaware that are in various stages of development. This royalty acreage could have otherwise been stranded single sections, but with the advancement of horseshoe wells, these sections are now economic for operators to develop. The oil patch will always find a way. Even today, with the Permian already the largest producing basin in the world, these evolving and improving development practices are allowing operators to pursue new formations while also pushing the boundaries of the basin, potentially adding significant incremental drilling inventory. Some notable recent examples include the emerging Barnett formation in the Midland Basin, the Harkey formation in Culberson County and the surrounding Stateline and the Bone Spring in the Northwest Shelf of the Delaware. We're also seeing operators push the northern and eastern boundaries of the Northern Delaware and basically the entire Midland Basin boundaries on all sides. New developments in these formations and boundary extension trends are evident in new leasing activity from our acquired minerals portfolio, primarily located in the Midland Basin. Leasing activity has increased meaningfully this year, and most of these were for unleased mineral assets where we originally had not ascribed any value to when we acquired the broader portfolios. Already the preeminent engine of global oil supply growth over the last decade, the Permian still fosters a vibrant entrepreneurial industry. We are constantly impressed by all the technology and innovation that occurs here, and we're excited to see operators still exploring new formations and new areas. Longer term, as the oil cycle will inevitably turn upwards, the Permian will play a critical role towards satisfying the world's growing energy needs. And as the world will depend on the Permian to supply critical energy for many decades to come, TPL stands to benefit from our extensive footprint. There's arguably no better basin in the world to be in than the Permian, and there's undoubtedly no other public company in the Permian with TPL's size and scale combined across royalties, surface and water. Turning to our desalination efforts. We continue to make progress with our Phase 2b desalination facility. Recall, this will be a 10,000-barrel-per-day facility that will intake Permian produced water and output high-quality freshwater in addition to a concentrated brine solution. We have broken ground on location in Orla, Texas. Most of the desalination equipment has been received and is on site. We expect installation to take a few months, and we still anticipate the unit to begin taking produced water by year-end. Our CapEx estimates related to the facility remain unchanged. We have made a number of process improvements since our previous prototype, and we look forward to bringing online the largest desalination facility in the Permian to date. In addition, we have submitted permit applications for both land application and environmental discharge, and we hope to procure regulatory approvals within the next few months. As a reminder, the Permian is now generating north of 23 million barrels per day of produced water. Even if Permian oil production were to stay flat, we believe Permian produced water volumes could still grow by millions of barrels per day over the next few years due first to increased water-to-oil ratio as well as age and second, to increased water cuts from the development of secondary benches. For TPL, we've been proactive across numerous fronts towards making sure we can provide the industry with essential produced water solutions. First, TPL's surface acreage still retains millions of barrels per day of additional in-basin disposal capacity. From the beginning, we have been intentional in limiting the amount of disposal wells per section with increased regulatory attention on surface and reservoir pressure gradients, our conservative approach to signing SWDs has allowed us to preserve ample injection capacity. Second, we have been proactively acquiring tens of thousands of acres of out-of-basin pore space. We currently have well over 100,000 barrels per day of produced water that is currently being injected into out-of-basin pore space that we own, and we expect that volume to continue growing for the foreseeable future. Third is the desalination and beneficial reuse efforts that I just discussed. Conceptually, if it works economically at scale, this would reduce the amount of produced water that would need to be injected subsurface while also providing a valuable freshwater stream that could potentially be repurposed for power and data center cooling, hydrogen production or a number of other industrial activities. Today, TPL already touches and generates royalties on over 4 million barrels per day of produced water. We believe with our industry-leading and comprehensive solutions across in-basin disposal, out-of-basin disposal and desalination plus beneficial reuse that we are well positioned to capture a substantial amount of the produced water volume growth going forward. In conclusion, for TPL, we're not overly concerned with near-term commodity price vacillations. We don't have a crystal ball and can't say for sure what commodity prices will be in the near term; however, we are certain that the Permian remains a world-class resource and still retains plenty of latent growth. We do ultimately believe that current oil prices are well below longer-term mid-cycle oil prices. Despite today's broader macro uncertainty, TPL is still generating industry-leading cash flow margins. We already have a leading royalty, water and surface footprint across key areas of the Permian. We believe we're in a favored position, and should this down cycle persist, we're ready to deploy capital opportunistically, whether through substantial buybacks, organic investment or asset acquisitions or some combination thereof.

Thanks, Ty. For the second quarter of 2025, consolidated total revenue was $188 million and consolidated adjusted EBITDA was $166 million. Adjusted EBITDA margin was 89%. Free cash flow was $130 million, representing a 12% increase year-over-year. Performance year-over-year benefited from higher oil and gas royalty production, higher produced water royalties and higher easements and other service-related income, otherwise known as SLEM. Performance was partially offset by lower oil price realizations, which declined 21% year-over-year and lower water sales. Royalty production this quarter was approximately 33,200 barrels of oil equivalent per day, representing a 33% increase year-over-year and a 7% increase sequential quarter-over-quarter. As of quarter end, TPL had 6 net permitted wells, 11.1 net drilled but uncompleted wells and 5.1 net completed but not producing wells. SLEM revenues of $36 million was a company record, which benefited from $20 million of pipeline easements. The increase in pipeline easements was due to numerous new large-scale pipeline and infrastructure projects crossing our acreage. Produced water royalty revenues of $31 million was also a company record. As Ty mentioned, our commercial efforts across out-of-basin pore space acquisitions and new contracting continue to allow TPL to capture and take advantage of the secular growth trend for Permian produced water. This quarter, we generated a royalty on over 4 million barrels per day for the first time in our history. Water sales of $26 million was down by $13 million sequential quarter-over-quarter as lower oil prices during the quarter resulted in reduced activity and deferments by operator customers. We have seen operators bring back activity, and many of the wells that were deferred during this quarter are now back in our completion schedules for the second half of this year. To conclude, TPL is in an excellent operating and financial position as the broader industry works through this current cycle. As Ty mentioned, commodity prices during this quarter led to the weakest realizations we've had since early 2021 during the depths of COVID; however, comparing this quarter with the first quarter of 2021 when oil last dipped below $60, we've since doubled our royalty production and source water revenue, tripled our produced water royalty volumes and quadrupled our SLEM revenue. We accomplished that while maintaining a debt-free balance sheet and returning hundreds of millions of dollars of capital back to shareholders. We've proven we can grow the business through cycles. And whenever this commodity cycle inevitably turns upward, TPL is positioned to benefit to the fullest extent.

Thanks for your general thoughts on basin activity. My first question, I wanted to focus on your outlook for Water Resources over the second half. While you guys achieved company records with produced water royalties, water sales were a bit weaker than anticipated. And as you guys think about kind of industry activity leveling out on a pretty material reduction in activity during the first half, how do you see each of those businesses performing in the second half?

Derrick, this is Robert. I'll take that. I mean when we look at Q2, I think it was two factors in Q2 that really led to the reduction we saw. One was definitely commodity price driven. We had one of our biggest customers delay activity until the second half of the year and others reduce in certain areas. But I'd say Q2 was also combined with just kind of the spatial variation that you can see in completion activities. The decline we saw was not fully representative of commodity price decline. There's times, especially when you look at the consolidated acreage positions that have been a result of M&A over the last couple of years, that there's times that spatial variation, a lot of activity is outside of your core areas given the acreage positions they hold now. So when we look at Q3 and Q3 looks to be very strong. Q4, which happens a lot in Q4, it's kind of yet to be determined what that activity level is going to be. And I'll say probably Q4 is going to be more heavily dependent on commodity prices than any other quarter.

Great. And maybe just staying on water. I'd love your thoughts on the Aris acquisition by Western while we look at it and question it from a timing perspective as it relates to value recognition, it absolutely supports the Delaware water thesis, yours and also the value of pore space in the basin. So again, love any thoughts you guys have there.

Yes, Derrick, I agree. It supports the Delaware water thesis that we've been talking about for a while. I mean we’ve got a great relationship with Aris and with Western. So we see this as a huge benefit for TPL. I think consolidation in the water midstream just creates more opportunity for land and pore space owners.

Great. Maybe again, Ty, you or Robert, I'd love for you to kind of speak to just your cost objectives for the 10,000-barrel-per-day desal facility? And more broadly, how important is this project to attracting power generation and data center opportunities to the Permian Basin?

And Derrick, this is Robert. A couple of years ago, we recognized the challenges related to produced water that we anticipated would arise in the next five years, and we addressed them in two main ways: through out-of-basin disposal and by taking a leading role in desalination within the Permian. This project, as Ty mentioned, is set to be the largest of its kind. Although we are still in the research and development phase, we consider it research and development at scale since it is happening in the field and at scale. Live desalination will take place, which is critically important to us and the industry as a whole. We understand that achieving beneficial reuse on a true commercial scale, potentially in the hundreds of thousands or even millions of barrels a day, will take several years, but we are committed to making that happen. When we consider this alongside data center cooling and cogeneration power, the opportunities are remarkable. We will not only be testing this in the field at scale, but we will also further explore the synergies between processes like waste heat capture working in tandem with cogeneration power and the data center cooling efforts we have. There is significant synergy in both areas. We are enthusiastic about this. We know that the industry needs to reach beneficiaries out-of-basin, which will provide the necessary support and time to scale this for what we anticipate beneficiaries will be in 2028 or 2029.

That's great. And Robert, maybe just leaning in on the power generation opportunities. With the announcements we've seen with CPV Basin, Ranch Energy and Lambridge this morning, could you guys just maybe speak to your expectations for additional announcements based on the dialogue you're having with the industry?

When considering power generation in the Permian, it makes complete sense. We have the largest component for cogeneration power and access to water that isn't part of the usual water cycle. The potential of produced water in cogeneration is significant, as all the necessary elements are present. Many argue against building transmission lines from other areas to the Permian, but given the resources available in the Permian for generating power, it seems unnecessary. The recent announcement with Coterra is just the beginning. With the power demand and shortages in the Permian, particularly concerning data centers and other needs, the demand for power to support the upstream industry will increase in the coming years. Discussions are ongoing and gaining momentum, making this an exciting time for developments in the Permian over the next few years.

Great color, guys. I'll turn it back to the operator.

At this time, there are no further questions. This concludes Texas Pacific Land Corporation Second Quarter 2025 Earnings Conference Call. Thank you for joining the call today. You may now disconnect your lines.