Ladies and gentlemen, welcome to the Smart Sand Q2 2024 Earnings Call. At this time, all lines are in listen-only mode. Following the presentation, we will conduct a question and answer session, at which time, should you wish to ask a question, just press star one on your touchtone phone. If at any time during this call you require immediate assistance, please press star zero for the operator. This call is being recorded on Wednesday, August 14th, 2024. I would now like to turn the conference over to Chris Green. Please go ahead, sir. Good morning, and thank you for joining us for Smart Sand's second quarter 2024 earnings call. On the call today, we have Charles Young, Founder and Chief Executive Officer, Lee Beckelman, Chief Financial Officer, and John Young, Chief Operating Officer. Before we begin, I would like to remind all participants that our comments made today will include forward-looking statements, which are subject to certain risks and uncertainties that could cause actual results or events to materially differ from those anticipated. For a complete discussion of such risks and uncertainties, please refer to the company's press release and our documents on file with the SEC. Smart Sand disclaims any intention or obligation to update or revise any financial projections or forward-looking statements, whether because of new information, future events, or otherwise. This conference call contains time-sensitive information and is accurate only as of the live broadcast today, August 14, 2024. Additionally, we will refer to the non-GAAP financial measures of contribution margin, Adjusted EBITDA, and free cash flow during this call. These measures, when used in combination with our GAAP results, provide us and our investors with useful information to better understand our business. Please refer to our most recent press release or our public filings for our reconciliations of gross profit to contribution margin, net income to Adjusted EBITDA, and cash flow provided by operating activities to free cash flow. I would now like to turn the call over to our CEO, Charles Young. Thanks, Chris, and good morning. In the second quarter, we continued to build off of our first quarter momentum and once again delivered strong results. Sales volume were just under 1.3 million tons in the second quarter, which exceeded our projections. 2024 sales volume through June were 15% higher than sales volumes for the first six months of 2023. Contribution margin in the second quarter improved to $19.8 million, and adjusted EBITDA increased to $11.8 million. Additionally, we generated $13.5 million in free cash flow for the quarter. Due to our strong results, we are now free cash flow positive for the year through June. Importantly, we expect to remain free cash flow positive for the full year, and as a direct result of our focus on generating free cash flow, we expect to announce plans to return value to our shareholders later this year. We also remain focused on managing our cost structure. We have driven down our production costs and administrative costs in the quarter. These efforts have directly resulted in improvements to contribution margin and Adjusted EBITDA. We will continue to benefit from these savings initiatives in the future and remain committed to finding new ways to drive efficiency in our business. In the second quarter, we continued to execute on our long-term goals. We continue to strengthen our market-leading Northern White franchise. We continue to build market share in the Bakken and Marcellus basins. Through our Blair facility, we are establishing Smart Sand as a consistent and growing supplier of Northern White sand into the Canadian market. We are expanding the markets we serve. We invested in two new terminals in Minerva and Denison, Ohio, which will open up the Utica Shale formation as a market for us. The terminals are now operational in transloading sand. We are establishing markets for our Industrial Product Solutions business. We continue to make strides with new industrial sand customers, making the change to Smart Sand to meet their industrial product needs. We are laying the groundwork this year to position Smart Sand to compete for new business as industrial sand contracts come up for renewal in 2025. We remain committed to high standards of product quality and service delivery for our last mile business. We continue to strive to be the best in class in last mile solutions and continue to look to improve capabilities of our product and services for sand delivery and storage at the well site. Our focus never wavers from having efficient and cost effective, effective sand production and delivery costs. In the second quarter, we implemented several initiatives to manage our labor costs, improve our plant product yields, and invest in more efficient mining methods. We will maintain our focus to be a low-cost producer of Northern White sand. We will not deviate from our commitment to a strong capital structure with low debt and appropriate liquidity. Lee will provide more details later in the call, but in June, we refinanced our Oakdale equipment financing into a new four-year equipment financing. We remain committed to being the premier provider of Northern White sand in North America, and we are confident that the foundation for Northern White sand demand is strong and will be durable over time. The primary frac sand markets we currently serve are the Marcellus, the Bakken, including the Canadian Bakken, the Montney, and the Duvernay in Canada, and now the Utica Shale Basin in Ohio. The basins are all primarily Northern White sand supplied markets. We believe these markets will continue to have strong and growing demand for Northern White sand for the foreseeable future. The basins we serve are evenly divided between oil and gas, with the Marcellus and the primarily Canadian being natural gas markets and the Bakken and Utica being oil-focused markets. The combination of our three operating mines in Oakdale, Wisconsin, Blair, Wisconsin, and Utica, Illinois, coupled with our direct access on four Class One rail lines, the Canadian Pacific, the Union Pacific, the Canadian National, and the Burlington Northern, uniquely positioned Smart Sand to continue to be a leading provider of Northern White Sand. Collectively, our three facilities have a combined capacity of 10 million tons annually, and as the markets grow, we have the capacity ready and available to meet its growth and needs. However, we recognize that oil and gas demand for frac sand can and will continue to fluctuate based on current and expected prices for oil and natural gas. That is why we remain focused on being a low-cost producer. We continue to move forward on our plans to convert our Oakdale facility to hydro mining, which should reduce our operating costs in the future, and we've worked to better align our labor force for their current operational needs. We're also in the process of implementing a new ERP to provide us with access to more timely, operational, and financial information. We had strong demand in the Marcellus in the first quarter. Demand in the second quarter in the Marcellus did moderate slightly. We currently expect third quarter sales volume in the basin to be relatively consistent with second quarter, but we could see a slowdown in the fourth quarter based upon current natural gas prices and expected activity. With the startup of our new terminals, we're seeing the Utica demand increase, which should mitigate any short-term slowdowns in the Marcellus. While activity in the Marcellus may slow down in the second half of the year due to current low natural gas prices, we believe the long-term demand fundamentals for natural gas supply in the United States and Canada is strong. Increasing demand from LNG export facilities and power generation for new AI data centers support the need for increased natural gas demand in the U.S. We expect this market to be a growing part of our business as we look out to 2025 and beyond. In contrast to natural gas prices, oil prices have remained at healthy levels. Activity in the Bakken Basin in North Dakota typically picks up in the second and third quarters, and this year has been no exception. We had strong activity in the second quarter in this basin, and we expect that to continue into the third quarter. Bakken activity usually slows down in the fourth quarter due to the onset of winter. We continue to work on increasing our market presence in the Canadian market. The first half of 2024, Canada sales have represented approximately 10% of our sales volume. We expect Canadian activity to be consistent in the second half of 2024. As we look to grow our Canadian market presence, we're looking at terminal options to establish our logistics footprint in this market. Efficient and sustainable logistics capabilities are essential to our long-term success. Our investment in our Van Hook terminal in North Dakota and our Waynesburg terminal in Pennsylvania have been key drivers in our ability to increase our market share in the Bakken and Marcellus markets. Having control of terminals in the basins allows us to deliver sand more efficiently, sustainably, and cost-effectively. Our primary objective is to deliver positive free cash flow consistently. In the second quarter, we had strong cash conversion of receivables that were built up in the first quarter, which, coupled with the effective cost management and disciplined capital spending, led to substantial improvement in free cash flow in the second quarter and positive free cash flow for the six months of the year. We expect to be free cash flow positive for the year. We are committed to start returning value back to our shareholders. Given our generation of free cash flow over the first six months, and our expectation that we will remain free cash flow positive for the year, we expect to communicate our plans to start returning value to our shareholders later this year. We believe Northern White sand will continue to be a key product for both the energy and industrial sand markets. In the second quarter, we continued to build off our solid first quarter performance. While there may be short-term blips in natural gas basins due to current low natural gas prices, the long-term fundamentals for Northern White sand in general, and Smart Sand in particular, continue to be strong. We believe no other company is better positioned to take advantage of the market for Northern White sand than Smart Sand. We couldn't have delivered these results without the hard work and dedication of our employees. I want to thank all of our employees for their continued support and dedication to Smart Sand. As always, we'll keep our employees' and shareholders' interests in mind in everything we do. With that, I'll turn the call over to our CFO, Lee Beckelman. Thanks, Charles. Now I'll go through some of the highlights of the second quarter 2024 compared to our first quarter 2024 results. We sold 1.27 million tons in the second quarter, a 5% decrease from the first quarter sales volumes of 1.34 million tons. Total revenues for the second quarter were $73.8 million, compared to $83.1 million in the first quarter. Total revenues were lower in the second quarter, due primarily to lower sand sales volumes, lower average frac sand sales prices, and lower SmartSystems revenues from reduced utilization of our fleet. Our cost of sales for the quarter were $60.7 million, compared to first quarter of $71.2 million, a 15% decrease. Decrease was due primarily to lower sales volumes in the quarter, coupled with ongoing cost and efficiency initiatives to reduce production costs. Total operating expenses were $9.5 million in the second quarter, compared to $11 million in the first quarter. The decrease sequentially was primarily due to higher incentive compensation and higher royalties from increased sales volumes in the first quarter. During the second quarter, we had a $1.3 million loss on the extinguishment of debt. This expense was related to the payoff of some equipment leases that were part of the refinancing that was completed in June. Contribution margin was $19.8 million, or $15.53 per ton in the second quarter. First quarter contribution margin was $18.5 million, or $13.85 per ton. Adjusted EBITDA in the second quarter was $11.9 million, compared to $9.3 million in the first quarter. While sales volumes were down in the quarter, contribution margin and Adjusted EBITDA both improved sequentially due to our continued focus on managing our cost structure. Second quarter, 2024, we had $14.9 million in cash provided by operating activities, which led to $13.5 million in free cash flow after we spent $1.4 million on capital expenditures. This compares to $3.9 million in cash used by operating activities and a negative $5.5 million in free cash flow in the first quarter. The improvement in cash provided by operating activities was primarily due to reduced working capital requirements as sales volumes leveled out, and we had higher cash conversion of our receivables in the quarter. We ended the second quarter with $2 million in borrowings on our credit facility. Today, there are no outstanding borrowings on our credit facility. We had approximately $6.3 million in cash and cash equivalents at the end of the second quarter. Between cash and availability from our credit facility, we currently have available liquidity in excess of $28 million. In June, we completed the refinancing of our Oakdale equipment financing, along with a couple of smaller equipment financings. We refinanced this debt with a new $10 million facility. This new facility amortizes over a four-year term and has an implied interest rate of approximately 8.6%. Our current $20 million ABL credit facility comes due in December. We are in the process of refinancing this facility and expect to close this new facility in the third quarter. While sales volumes did moderate in the second quarter, we still delivered solid sales results and improved contribution margin, Adjusted EBITDA and free cash flow. As Charles highlighted, we do expect some pullback in the Marcellus due to lower current natural gas prices, but that should be mitigated some by expected increased volumes in the Bakken in the third quarter, as well as new sales volumes into the Utica Basin. Currently, we expect third quarter sales, sand sales volumes to be in the 1 million to 1.2 million range. Contribution margin per ton improved to $15.53 per ton in the second quarter. We expect third quarter contribution margin to be in the $14-$16 per ton range. We evaluate and manage our capital expenditures on a quarterly basis. With our projects planned to date, we currently expect capital expenditures for the year to be in the $10 million-$13 million range. The increase in capital expenditures in the second half of the year, from the $3 million spent through June, is primarily due to the completion of projects that were started in the first half of the year. We delivered strong free cash flow in the second quarter, and while we expect quarterly free cash flow to moderate in the second half of the year, we still expect to be free cash flow positive for the year. This concludes our prepared comments, and we will now open the call for questions. Thank you, sir. We will now begin the question and answer session. To ask a question, please press star and one on your touchtone phone. If you're using a speakerphone, please pick up the handset before pressing any keys. To withdraw your question, please press star two. Once again, star and one if you wish to ask a question. One moment for your first question. And we now have our first question, and this comes from the line of Stephen Gengaro from Stifel. Your line is now open. Please go ahead. Thanks, and good morning, everybody. Good morning, Stephen. So two questions from me, and I know the first one might be hard to dissect, but I'm gonna ask. You talked about some of the things you're doing on the cost side and your contribution margin per ton in the quarter, and the guidance for the next quarter, given the volumes, is very strong. Is there any way to quantify or give us a sense, maybe, you know, on a year-over-year basis or off of some level, sort of the level of sort of cost savings that are sticky, that we should sort of think about as we try to model going forward? Hi. Great, Stephen. That's a kind of a hard question to quantify, but in general, I think with some of the things we're doing in terms of managing our labor to be more in line and more flexible with our operations and sales volumes, as well as the hydro mining in particular we're doing at Oakdale and other things of that nature, that it could potentially, you know, on average, you know, reduce our production costs by potentially $1 or $2 per ton on average, if we're operating at a fairly high utilization. Yeah, and Stephen, what I would add to that is, I think, with a lot of the removal of, the yellow iron, you know, the haul trucks and things like that, and moving that to electrically driven, pumps and hydro mining, as we discussed, you know, allows us to kind of avoid some of the spikes we've seen in the past. You know, when diesel gets to $5 and $6 bucks, you know, that, that provides the, you know, real headwind to us that should... You know, we should have mitigated kind of going forward. So it provides a little bit more of an ability to see out and not have to worry so much about that stuff. Okay. No, that helps. It's obviously a very positive trend. So the other question I had, just quickly, is when you look at the various markets you're serving, I mean, we've heard about sand pricing, mostly around the Permian and some other markets, but what are you seeing kind of on the spot market, maybe just kind of relative to what your contracted volumes currently look like? In terms of pricing? Yeah, in terms of pricing. I think John or Charles can add to this, but pricing has been... ... relatively flat. And so over the last couple of quarters, we saw a good pickup in pricing through the first half of last year, it kind of moderated down, and it's been relatively flat for the last couple of quarters. Yeah, I would just add to that. It's a little bit market dependent. You know, Canada seems to, you know, allow for a little bit higher pricing, you know, and some of the markets in the U.S. are a little bit lower pricing. But, we have been in a relatively stable pricing environment now for quite a while, right? And, you know, we're not seeing kinda what we were seeing back when the market was weak, you know, pricing in the teens, you know, not sustainable. We're seeing pricing kind of in the mid-20s, you know, and we're seeing interest in contracting at those levels. And so, you know, knock on wood, the pricing seems to be, you know, we don't see anything that's gonna take it out of that stability. You know, market demand and Northern White sand supply seem to be still in relative balance. You've heard us say that before. And you know, I think that going forward, we don't anticipate much of that's gonna change. And one other thing I'd add is our sand, Northern White sand, is heavily dependent on rail logistics, and our rail logistics setup is, you know, premier in the industry. We have the best assets. Great. Thank you. And maybe just one quick one on that. We've been hearing and I don't know if this affects you at all, but we've been hearing about the Canadian rail strike, and I forget, honestly, the drop-dead date. Does that have any impact on you guys? Yeah, so it sounds like I think August 22nd is the big date for that as to when they're enabled to go on strike. Now that we've been told by our rail partners that that is going to affect primarily Canada. That doesn't impact the lower 48 where the bulk of our volume goes today. But yeah, we're hopeful that that gets resolved in a way that doesn't impact our operations, similar to the rail situation in the U.S. a few years ago, where it went right to the eleventh hour and then got resolved and didn't end up impacting us. But, you know, the Canadian market is still a growing market for us. It's certainly going to be a very important market for us, but I think that this strike, assuming it's resolved, relatively quickly, shouldn't have too much of an impact on us. Excellent. No, thank you for all the details. Thanks, David. Thank you. Thank you. And the next question comes from the line of Josh Jayne from Daniel Energy Partners. Your line is now open. Please go ahead. Thanks. Good morning. Hey, Josh. Good, Josh. First question I wanted to ask is on the Canadian market. Could you talk about how much sand you're selling into that market today, and where it could ultimately go in 2025? And then maybe just sort of a broad overview. When I look at the rig count, it's been holding up much better in Canada than the US. So could you talk about how much sand demand annually is coming from the Canadian market for Northern White? Yeah, Josh. Right now, obviously, it fluctuates by month and quarter, but approximately 10% of our sales are going to the Canadian market. And we do believe that that market has good, strong growth potential. It's hard to get great estimates on actual demand, but we kinda put demand currently in that market, probably in the 8-10 million ton range, and we think that market could grow, you know, grow substantially over the next couple of years. Most of the activity is going up into Northwest Alberta and Northeast British Columbia, in the Duvernay and Montney shale, and that gas is really being driven by the LNG export capacity on the West Coast. And we're really seeing a good pickup in activity, and we expect that to be a growing and strong market for us. We're at 10% today, and we hope to see that grow as we get into 2025 and be at a higher percentage of that. It's hard to give you an exact number, but we expect that to be growing as we get to 2025 and really extend our logistics network into Canada to really be more efficient in getting our sand into that market over time. Is there much of a difference between what you're selling, just from a grade standpoint, into the Marcellus versus the Canadian market? Could you talk about that a bit? Yeah, that's actually a pretty good question, Josh. So that mine that we've got up there in Blair is slightly coarser than our other reserves. But the Canadian market tends to be a little bit coarser than the lower 48 market. And so when we produce, call it the 30/70 product, for Canada, we produce, you know, a decent amount of 100 mesh that we keep down here primarily. So that mine tends to be pretty balanced with Canadian demand and then being able to put kind of the 100 mesh product into the lower 48. So it's You know, it's not something we anticipated when we picked the property up, but it's something that's actually kinda interesting from a standpoint of that mine has got good efficiency, and we're able to use most of the product that we're making. Okay, that, that's helpful. Thanks. I, I wanted to ask, sort of a follow-up on supply, demand. You mentioned in your prepared remarks, the market is balanced, and there was a question on pricing. But when I think about the capacity today at Oakdale, let's just call it nameplate, is 5.5 million tons. Based on today's staffing levels, what's the maximum amount of sand you believe you could sell today as product? And could you just give us a reminder of how much you would have to produce to arrive at that number of tons sold? Yeah. So with you know, we've talked a little bit about some of the changes we've made, particularly in Oakdale, with going to hydro mining and whatnot. And so, you know, where we are today versus getting to 5.5 million, it's not a substantial increase in staffing. There is some increase in staffing, but we've got you know, 5 dry plants in Oakdale, 2 wet plants, and we operate, to varying degrees, all of those plants all of the time. So, to increase that doesn't require you know, doubling the staff or any of that kind of stuff at Oakdale. You know, there'll be a little bit of increase in variable costs there to do that. But it is not a, it's not a 2x thing. It is, it's adding a handful of staff here and there, just to move to full 24-hour operation, seven days a week and not shutting plants down. So, you know, we think that that's a really good tailwind for us, you know, as market demand increases. You know, at Blair, it's kind of a similar story. You know, Blair is a single—it's got two dry plants and one wet plant, all on site with the rail there. And so, you know, both of those sites are well positioned to be able to add incremental volume without huge capital expenditure and without having to add a ton of, you know, variable costs with employees and whatnot. Additionally, Josh, the reserve at Oakdale really lines up well with what the market demand is, so that's probably our premier asset. For sure. And just to follow up, I guess, and a little bit deeper. I think what I'm trying to get at is, if nameplate is 5.5 million tons, and that was... That, that's what you could produce. I guess I just wanna better understand, you know, your yield is not gonna be 100% on that, right? And so when we think about supply demand in the market, I'm just trying to understand what the maximum, I guess, that could actually be produced product from the mine or based on where you're staffing today, if that helps frame the question a little better. Well, Josh, we don't get into specifics of the yields by plant, but generally, you can think about, you know, that we're probably in a 70%-80% yield on average. Okay. And so getting up to 5.5 million tons in terms of the sand we'd be producing, you know, you can kind of do the math from that. Yeah. But again, also, we look at our assets on an integrated basis, so it's not just Oakdale and maximizing its capacity, it's maximizing the value of all three of our assets in total. And we have 10 million tons of total capacity, and so actually, Oakdale and Blair are very synergistic because they can serve some of the same markets. So depending on which the best rail access is, et cetera, or what the mix of our sand is in terms of sales, we can toggle sales back and forth between the two of those. So it's not necessarily the, you know, the max volume that Oakdale can do, it's the combination of our assets and what we can get to on a combined basis relative to the market demand for the particular products. Yeah, and Josh, what I would add to that is just kind of a, you know, it's a point in time, but, you know, in February this year, you know, Oakdale produced beyond the- Yeah You know, 5.5 million tons, you know, in February, right? So, you know, from a run rate perspective, Oakdale can do it. It's just, you know, it, it's market demand and things like that. But Oakdale does have a really good ability to flex, you know, even in months that aren't particularly favorable weather-wise, like February. So it does have that ability. Yeah, I think it's fair to say with our current staffing, you know, we could get our sales volumes up north of 7 million tons with maybe an incremental 5%-10% increase in staffing. We can get beyond that and get much closer to our nameplate capacity, but that would require, you know, an incremental investment, probably in people and a bit of equipment. Understood. Thank you, guys, for the- And- for the answers. I'll turn it back. As we go to those higher levels, you know, things like adding additional terminals, which we have plans to in Canada right now, things like that additionally help as we need the throughput for the sand all the way through to the basin. Okay, thanks. Thanks, Josh. Thank you. The next question comes from the line of Bruce Keller from Keller Ventures. Line is now open. Please go ahead. Hi, good morning, gentlemen. Hey, Bruce. Good morning, Bruce. You mentioned the sales, or the beginning of sales into Utica in the second half. Any sense you can provide of the tonnage levels to expect in the second half of this year into that basin? And also, in terms of the profitability, will it be similar to the rest of the business, or are there startup costs that we should anticipate with those sales in the second half? Yeah, I'll answer the second question first. In terms of profitability, it's relatively consistent on a pricing basis, but it's actually at our terminal. So one of the opportunities we're having is shifting from third-party terminals to our terminal. And over time, typically, we can operate a terminal at lower cost than a third party. So actually, our net margins through that business over time should be better. You know, pricing is relatively consistent because we are gonna be running the terminal at a lower overall cost. In terms of volumes, we don't give specific volumes by basin. So we do expect to pick up in that activity. I think in the second half of the year, what we gain in the Utica, we might see some, you know, reduction in the Marcellus, but over time, we think it's gonna be additive. I think one way to think about it over time, we would hope that the Utica could, you know, get up to levels, you know, in the next year or two, that at least up to the Canadian levels are higher in terms of what we're selling in Canada, in terms of percentage of our sales. That's great. Very exciting. You also mentioned in the press release, the expectation of increased activity in 2025. Can you give some insight as to the visibility you're seeing on that and what gives you the confidence there? And is that also saying that you would expect, tonnage in 2025 to be an improvement over 2024? We haven't given any guidance on 2025 yet, Bruce, so we're not gonna get into that. But I would say that, as Charles highlighted in his comments, and I think this is very consistent with what you're hearing with other players out in the market, there is a real belief that demand for natural gas is gonna grow, and particularly related to the LNG export capacity that's coming online over the next 3-5 years, as well as the incremental demand for power generation to support a lot of this data center activity. And we think natural gas is gonna be a big part of those drivers for that. I think that's gonna lead to, you know, good incremental demand for natural gas, which could have it really helps us in terms of the activities and the, some of the basins that we operate in. So we see good growth. It's a little too early to give any kind of guidance on 2025, but we would expect that activity. You know, gas prices are relatively low right now, and I think that's mitigating some of the activity in the second half of this year. But as this expected demand starts to pick up, we think over the next in 2025 and going on in 2026 and 2027, that should be leading to good, strong demand growth in the Marcellus and other natural gas regions, which we have a very strong market position in today. I'd also add, as we add terminals with unit train, you know, where they can receive unit trains, you know, usually our volumes, you know, follow that. So. And that's kind of, like, what we're working on right now. Great. That's very encouraging. I also had a clarification question on the free cash flow generation. You said that you expect to be free cash flow positive for the year. You are free cash flow positive through the first half of about $8 million. I was confused whether or not you were saying you expect to generate additional free cash flow in the second half of the year on top of the $8 million generated in the first half? Yeah, again, it's a little hard to define how much free cash flow we may generate in the second half of the year, depending on volumes and kind of activity and how our working capital shifts happen on a quarterly basis. So we don't get into specifics about the actual generation and the number over the second half of the year, but we do expect to be free cash flow positive for the year. Okay. Along those lines, you mentioned some initiatives for capital return to shareholders being discussed sometime in the second half. Just curious, what in particular you're considering. Is it a dividend, a share repurchase, or some combination thereof that you're currently contemplating? I think right now we're open, and we're considering what the various options would be, and looking at, to kind of your question in terms of what, how we believe our cash flow generation is gonna be and the consistency of that, to kind of determine the best approach in terms of starting to deliver value back to the shareholder, and a combination of a dividend and/or share repurchase. So we haven't fully finalized our thoughts on that. We are still focused on moving towards to bringing share, you know, value back to our shareholders. You gotta remember, last year, we bought back 11% of our shares, so we did actually start that process in 2023. Yep. Right now, we're just evaluating the best opportunity on a go-forward basis. We're in terms of how we think we're gonna do it more consistently going forward. So that's something we'll probably have more detail on, hopefully later this year, at our next earnings call. But I think we're open, and we're evaluating all the various options. Great. Well, I really appreciate those initiatives on shareholders' behalf. I think that's terrific idea, and that is appreciated. I do have one final question. In the past, you've discussed targeting industrial end markets, you know, that are not necessarily oil and gas related, just other end market opportunities for your sales. I'm curious, you know, how the initiatives in that regard are going and, you know, if you can provide any insight on that going forward. Yeah, sure. So our industrial initiatives continue. We've installed bulk cooling and blending capabilities at our Utica mine, and we continue to grow that market. It's an interesting market and something that we're relatively excited about from a margin perspective. From a volume perspective, it'll likely be, you know, it will never be kind of what frac volumes are, but it is a business that we've invested time, effort, and money into, and, you know, we expect it to continue growing. All right. Thank you, and best of luck. Thank you. Thanks. Thank you. We don't have any further questions. I would now like to hand the call over back to Charles Young for closing remarks. Please go ahead, sir. Thanks for joining our second quarter earnings call. We look forward to speaking with you again in November. Thank you. This concludes our conference for today. Thank you all for participating. You may now disconnect.