Good morning, and welcome to Trican Well Service Q4 2025 conference call. All participants are in a listen-only mode. After the speaker's remarks, we will conduct a question and answer session. To ask a question at this time, you will need to press star followed by the number 1 on your telephone keypad. As a reminder, this conference call is being re-recorded. I would now like to turn the call over to Brad Fedora, President and Chief Executive Officer. Thank you. Please go ahead. Thank you, everybody, for joining us, and good morning. First, Scott, our CFO, will give an overview with quarterly results, and then I'll provide some comments with respect to the quarter, current operating conditions, and the outlook over the next few quarters, and then we'll take some calls. There's a few members of our executive team in the room today, so we should be able to answer any questions that come up. I'll now turn the call over to Scott. Thanks, Brad. Before we begin, I'd like to remind everyone that this conference call may contain forward-looking statements and other information based on current expectations or results for the company. Certain material factors or assumptions that were applied in drawing conclusions or making projections are reflected in the forward-looking information section of our MD&A for Q4 of 2025. A number of business risks and uncertainties could cause actual results to differ materially from these forward-looking statements and our financial outlook. Please refer to our 2025 annual information form for the year ended December 31, 2025, for a more complete description of business risks and uncertainties facing Trican. This document is available both on our website and on SEDAR. During this call, we will refer to several common industry terms and use certain non-GAAP measures, which are more fully described in our Q4 2025 MD&A. Our quarterly results were released after the close of market on Wednesday evening and are available both on SEDAR and our website. So with that, a brief summary of our quarterly results. My comments will draw comparisons to the Q4 of last year, and I'll provide some commentary about our current activity levels and expectations going forward. Trican's results for the quarter, compared to last year's Q4, were generally stronger, as overall operating activity came in a bit higher, despite a challenging commodity price environment exiting the year. Our results for Q4 of 2025 also incorporate a full quarter of Iron Horse results following the closing of the acquisition in Q3 of 2025. Oil pricing was challenged as we came through the second half of 2025 and had a significant impact on Q4. Oil-focused customers delayed, and in some cases, shelved projects in response to deteriorating economics, significantly impacting the Iron Horse division during the quarter. But overall, our revenues for the quarter were CAD 322.7 million, compared to the CAD 275.5 million we generated in Q4 of 2024. Adjusted EBITDA for the quarter was CAD 73.4 million, or 23% of revenues, compared to Adjusted EBITDA of CAD 55.6 million, or 20% of revenues generated in Q4 of 2024. Adjusted EBITDAS for the quarter came in at CAD 75.3 million, or 23% of revenues, up from the CAD 58.6 million or 21% of revenues in Q4 of last year. To arrive at EBITDAS, we add back the effects of cash-settled, share-based compensation recognizing the quarter to more clearly show the results of our operations and remove some of the market-to-market impact of the movements in our share price between reporting dates. On a consolidated basis, we generate positive earnings of CAD 31.9 million in the quarter, which translates to CAD 0.15 per share, both on a basic and a fully diluted basis. We generated free cash flow of CAD 46.6 million during the quarter. Our definition of free cash flow is essentially EBITDAS less non-discretionary cash expenditures, which includes maintenance capital, interest, current taxes, and cash-settled stock-based compensation. You can see more details on this in the non-GAAP measures section of our MD&A. CapEx for the quarter totaled CAD 15.1 million, split between maintenance capital of about CAD 12.8 million and upgrade capital of CAD 2.8 million. Our upgrade capital was dedicated mainly to the electrification of our fourth set of ancillary frack support equipment and ongoing investments to maintain the productive capability of our active equipment. From a balance sheet perspective, we exited the quarter with positive non-cash working capital of CAD 179.2 million. On December 31, we had debt of CAD 79.9 million, net debt of CAD 79.9 million, comprised of loans and borrowings of CAD 92.4 million, which was offset by cash of CAD 12.5 million. Our debt at December 31 was primarily related to the acquisition of Iron Horse and our normal working capital and investing activities during the quarter. This translates into just under a third of a turn of leverage, using our trailing twelve-month EBITDAS figure, and a portion of this is already unwound, and we expect our net debt and position to trend downward as we move through 2026. With respect to our return of capital strategy, we repurchased and canceled 1.4 million shares under our NCIB program in the Q4. On an annual basis in 2025, we repurchased and canceled 12.1 million shares at a weighted average of about CAD 4.4435 per share, representing 6.4% of the shares outstanding at the beginning of the year. Subsequent to Q4 of 2025, we've repurchased and canceled about 300,000 shares, and we continue to be active in our buyback program when market prices are at levels that provide for a favorable investment opportunity. As noted in our press release, the board of directors approved a dividend of CAD 0.0055 per share, reflecting approximately CAD 11.5 million in aggregate, aggregate to shareholders. The distribution is scheduled to be made on March 31, 2026, to shareholders of record as of the close of business on March 13, 2026. And I would note that these dividends are designated as eligible dividends for Canadian tax purposes. So with that, I'll turn things back to Brad. Okay, thanks. I think overall, Q4 went really well and pretty much as expected. You know, we've worked hard in the last few years to try to create a customer list that has allowed us to be fairly level-loaded throughout the year, with maybe the exception a little bit of Q2, but I mean, it seems to be working. You know, our quarters all now seem to be quite similar in volumes, and you know, that's a great advantage from a staffing and an equipment allocation perspective. As you know, you can rightsize the business for the entire year, not you know, you're not just staffing for the peaks and then absorbing the costs during the valleys. So I think all of that has gone really well for us. I mean, as usual, it seems like in Q4 lately, we did experience some pricing pressure. Just some of our competitors are less busy than we are, and, you know, there's they they're trying to fill their board. We generally just sort of get through that. Of course, you know, we don't live in a vacuum, but, most of our customers are all very long-term relationships, and we seem to get through a lot of that. Obviously, we know we have much improved natural gas prices compared to the last 18 months, so that has helped. I mean, it's been a very warm winter in Western Canada, and I think we've done a really good job of sort of fighting our way through that. You know, we had very much springlike conditions for the bulk of February and lots of January. So it's been a little bit choppy, but I would say we're having a good quarter, and we always factor that into our forecasting. And so I think Q1 will be very much in line with consensus. I don't think there'll be any big surprises there, even though, you know, we did have some tough weather to deal with. Our customers are still very focused on technology and efficiency. I think we've done a really good job with this. You know, particularly, they wanna burn natural gas in place of diesel anytime they can, just due to the cost savings and the lower emissions. And so our pumping assets, in particular, and our electric equipment, that's leading the industry with that regard. You know, we're very fortunate to have a customer list that is, that is focused on technology and does recognize the investments that we've made. And so we're working together to make sure that as, as their programs develop and evolve, we're making sure that we keep up from an asset and a technology perspective so that, you know, we can look at the long term together and say, you know, "What is this, what is this industry gonna look like in five, five years?" And make sure that we're on the forefront of those changes. I would say, even with the Iron Horse acquisition, most of our work is natural gas. We're probably 70% now, 30% oil projects. So, you know, we're happy that natural gas has got back to more reasonable levels. Obviously, oil in the last week or so, above $65 or even dollars, is very helpful to the Iron Horse division, and that should make for a sort of a much more robust year this year than last year. So we're kind of crossing our fingers that oil prices hang in there. We have seen a lot of the BC work slow down, but it's been more than picked up by the Duvernay work that we've been doing. So, you know, we're not really experiencing any changes there. In many ways, you know, the Duvernay work is in, is right in the backyard of a few of our operating bases, so happy to, happy to be in that play. I'd say, in general, all four of our divisions, being Trican Frac, Iron Horse Frac, Cement, and Coil, are all working really well. And I'll maybe just touch on all four of those divisions. So the Trican Frac, which is the deep fracking, the big pads in Northwest Alberta, Northeast BC, again, going very well. We spent the last few years really differentiating our service offering with natural gas pumping assets and electric ancillary equipment on location. You know, we're the only company in the basin that provides a full suite of electric assets on location. It's been very well received. You know, we've just put into the field our fourth set of ancillary equipment, which includes, like, blender and chem blending, things like that, so the sand belts, et cetera. So we basically cannot keep up with demand on those electric assets. When you combine the electric equipment with our Tier 4 equipment, and in the future, our 100% natural gas equipment, you'll have, you know, basically almost full displacement of diesel on location. So again, very well received. Without a doubt, we would be viewed as the technical leader in this industry with respect to... We're still seeing wells get longer, using more sand per well. You know, I think we-- this, in 2025, I think we pumped about 8.5 million tons of sand as an industry, and there's lots of analysts that are forecasting that that's gonna grow to over 12 million tons per year by 2030. So that's without a doubt a trend that we're making sure we capitalize on. You know, the flip side of that, though, is we are seeing more customer-supplied sand, which is fine. You know, our customers are looking to save money wherever they can. That's okay. You know, we'll try to replace some of that margin with our greatly expanded logistics business. You know, we've really focused in the last few years of building up our logistics because, you know, you're dealing with these kinds of sand volumes. And again, I've used some of these analogies before. You know, we've got, you know, like, 50-100 rail cars of sand being pumped into a well over a period that might only be 48 hours long, and so you're having a B- train of sand show up every 12-15 minutes on locations. Getting that, getting that logistics part right is a huge driver in efficiency for our customer and profitability for us, so. We've done a fantastic job of building out our logistics business. You know, we're not able to actually build it as fast as we would like it, just due to availability of drivers. But we will continue to expand that. We're a leader in sand logistics in Western Canada, and I don't see that changing anytime soon. You know, and just to put this into perspective, we were on a Duvernay well not too long ago, where over a 24-hour period, delivering sand with our trucking fleet, you know, I think we drove over 60,000 kilometers in a 24-hour period, which is 1.5 times around the world. So it helps put that in perspective, just how important logistics are, especially in a compressed timeframe like we're dealing with. So, you know, kudos to our logistics team and, you know, we'll continue to highlight that and showcase that to our customers to help continue our differentiation. We have received now our first 100% natural gas Cat, are called 3520 natural gas high-rate frac pumpers. This testing of that equipment is going very well. It will be deployed into the field in the Q2. We expect to have a full suite of a 10, a 10-pumper frac spread available and operating by early fall. And we know what this enables us to do is have less pumps on location, less people, pump a 100% natural gas instead of a combination of natural gas and diesel. So for our customers, it means, you know, lower fuel prices, lower emissions. And for us, you know, I think these new assets will be a little bit better at dealing with a variety of field gas, so we should have more efficient operations on that, in that respect as well. So really looking forward to that. And when you combine those assets with our electric ancillary equipment, you know, we'll have basically 100% natural gas operation. As well, later in the year, we will be receiving our first natural gas semi-trucks. So, you know, what pulls the big tractor units that pull the sand around, and we will slowly but surely evolve our trucking fleet to run on natural gas. We're a little ahead of our time, with respect to the fueling stations that are available throughout Western Canada. So we are gonna be working with our customers in conjunction with them, to make sure that there are fueling stations in all the places we need. But really looking forward to this. Again, lower fuel prices should be lower R&M. And just generally, it's nice to see that we are, you know, we, as a service provider, are burning the natural gas that our customers are producing every day. So we're working with them in conjunction to really build out a rounded industry. On the Iron Horse Frac side, which is sort of on the oilier coil fracking, really happy with the acquisition. The integration's going really well. I would say we're very pleasantly surprised with the synergies that we've been able to extract. It's with respect to like, things like fuel, chemical, sand. You know, we hadn't really built a lot of that into our acquisition, but that is working better than we had, than we had hoped, or certainly better than we had planned on. Obviously, we're a little disappointed with oil prices post the acquisition. You know, the field work volumes came down. That's okay. You know, oil prices have firmed up here, and I expect that they'll be getting up to a level that we were, that we were sort of banking on last year. But the acquisition's gone very well. You know, they're the number one provider in that part of the world, which is sort of Eastern Alberta, Saskatchewan, into Central Alberta. They provided us with previously, we had almost zero market share. You know, we'll use their relationships to grow our cementing business in that part of the world as well. So, very happy with that acquisition. On the cementing side, cementing division continues to perform extremely well. Very high market share in plays like the Montney and the Duvernay. We have expanded recently into the SAGD market in the Christina Lake area. That's gone very well. We expect that we will be able to grow that sort of area fairly significantly over the next 18 months. You know, I think in Q4, our revenue and jobs are up 33% in Q4 2025 versus 2024. So, you know, that division continues to perform very well. You know, we're adding AI technology to things like our bulk plant to reduce blending errors, increasing blend qualities for our customers. So, you know, even though we've been active in that business for a while, you know, we're taking advantage of technology anywhere we can to make that division perform even better. You know, we actually will have what we will call, like, a hybrid cementing unit soon, too, where it's partially electronic or electric. So getting rid of a lot of the hydraulics that, you know, you can have trouble with in. So I would say slowly but surely, that division will evolve into sort of an electric style, equipment, just much like our natural gas assets or our fracturing assets. On the coil side, the buildup of the coil business is going very well. You know, we had reorganized our management team about a year ago or so, and now that division is getting the attention that it always needed. A great portfolio of customers. We have all the top operators in the basin. You know, we set horizontal and depth records last year. You know, our performance has allowed us to add Montney and Duvernay customers. You know, we have a wide variety of oil strings, so I would say that division build-out is going very well, and it's now sort of financially performing more consistent with the other three divisions as well. So I think that'll slowly, surely just grow in size and scale, which... On the long-term outlook perspective, you know, we're still incredibly bullish about Western Canada. You know, when we look at the plays here, like the Montney and the Duvernay, in the context of North America, you know, this is the place, this is the place to be. I think the key, the key with being a service provider in these plays is you've got to be constantly pushing and evolving your, the technology offering that you have and making sure that, you know, as these plays get developed, we become more and more efficient. And we are seen as sort of the technical leader in the pumping space, which, you know, certainly we have been. You're gonna have ups and downs, you know, based on the gas price, et cetera. But, you know, certainly when you view what's happening on the LNG side, getting up to full capacity this year with more LNG to come, you know, we think there's gonna be a, like, a foundation of gas pricing in Canada for the next years and beyond. And certainly, we are very happy with the position that we've built up in plays in Northwest Alberta and Northeast BC, which will be fueling LNG. So, great place to be. We're not looking to change any of that. In fact, you know, if anything, we're looking for acquisitions to own, not even with, you know, just consolidation Iron Horse, but other service lines as well, just because we think Western Canada will be a great place to be operating for the next, you know, five years and beyond. Where do we see sort of revenue growth come from? It's obviously the well count will increase as the gas price solidifies and grows. We're seeing increasing sand volumes going into each of these wells, which just means more time on location for us. We're seeing our logistics division expand, and when we look at the coil and cement divisions, you know, we think both of those divisions can continue to acquire market share in all of the plays in Western Canada. So again, you know, very optimistic about the next five years. Just back to the return on capital that Scott had touched on. You know, we generate—we continue to generate significant free cash flow, and we expect that we'll maintain a conservative balance sheet. We've always subscribed to a diversified return on capital strategy, meaning combination of dividends and NCIB. The NCIB volumes will go up and down with the opportunities in the context of the other opportunities. You know, we very much view our NCIB as M&A. But I would expect that over the next few years, we will allocate probably about around 50% of our free cash flow to shareholder returns, you know, whether it's in the form of dividends or NCIB. And just, we'll always be looking in the context of the market to see what else is available. We're not afraid to use our bank lines. You know, we do hold a conservative balance sheet, but that's to make sure that we have the capacity when we need it. So we're not afraid to use our bank lines if we find an attractive investment or even, you know, organic growth opportunities like we did with Iron Horse. We're always looking for the best possible returns for our shareholders, and we'll, you know, we'll allocate capital accordingly. We are starting to see, I would say, more growth opportunities than we've seen in prior years. You know, and we'll just be very diligent and disciplined when we're looking at acquisitions, and, you know, good things take time. So, you know, we will get over our skis. We'll just be very analytical and, we'll see if we can get something interesting done in the next few years. So I just wanna stop there, given it's year-end. I just wanna say a thank you to our customers and our employees. And as I think everybody knows, Trican's committed to improving its workplace safety and creating an environment for our employees. You know, we operate a very complicated business with large capital requirements. We're in the field 24 hours a day with logistics and engineering support, running specialized equipment in very remote operating areas under what are fairly extreme conditions. You know, our employees make our field execution look easy, and I can assure you it is not. So thanks to our customers, thanks to all our employees for their dedication to Trican and the Iron Horse division, which is now part of the Trican family. And I just wanna say thanks to everybody. As you know, we can't do it without all the great staff that we have. So I'll stop there, operator, and we'll turn the call back for questions. Thank you. As a reminder, to ask a question, please press Star followed by the number one on your telephone keypad. We'll pause for just a moment to compile the Q&A roster. Our first question comes from Aaron MacNeil from TD Cowen. Please go ahead. Your line is open. Hey, morning, all. Thanks for taking my questions. First question, and you may not wanna get into specific customers, but, you know, ARC recently removed Attachie Phase Two from its five-year plan and has withdrawn its broader, Attachie-related guidance. Have you seen any direct impact to this yet? And how are you thinking about it in the context of, you know, overall basin demand for pressure pumping on a go-forward basis? Projects are always being added and subtracted. We're not fussed by that. I mean, there's nothing wrong with you know, certain people like ARC sitting back every once in a while and saying, "Hey, can we, can we do this a little differently? Can we do this a little bit better?" I mean, maybe they should have used us to frac their wells. You know, we're not too fussed. We're not too fussed by stuff like that. You're gonna see that from time to time. You know, an active basin, you know, technical basin. That's healthy. Fair enough, but safe to say you didn't have any exposure to that directly? No, like, we do work for them. There's no such... We don't operate in a vacuum. Like, when things like that happen, assets get freed up. But, I mean, we're still very bullish on Northwest Alberta, Northeast BC. Fair enough. Can you say a bit more about, you know, wet sand? How prevalent is it today? Sure. How prevalent do you think it'll be in the future, and what the, you know, potential impact might be on your sand infrastructure, assets, and logistics businesses? Yeah, like, what Aaron is asking about is there's recently a few companies have been trialing wet sand in Western Canada. What that means is just using a lower grade, but closer source of sand that generally comes more almost from a gravel pit than a frac sand mine. So it's not sorted, it's not dried, questionable, you know, consistency, quality, but it's close, which means it's cheap. Because by the time frac sand gets to location, probably 70%+ of the total cost of that sand is just the transportation of it. So anytime you get the opportunity to use a sand source that's very close to the project area, there's a big opportunity for transportation savings. Now, what you're saving in transportation, you're giving up in sand size, consistency, quality. But, you know, they did it in the US. I think we're having a look at it in Canada because it does have water, you know, frac sand today is dried. Because it does have water in it, it makes it a little tricky to operate in the winter. But, you know, the customers are gonna trial it. It still needs to get from A to B, and so our logistics group is still gonna be very much active in that. You know, we don't really hold any other fixed assets from a logistics. I think anytime the industry has the opportunity to cut costs, which will undoubtedly result in more wells being drilled, you know, I think that's a good thing. But it, it'll be a while yet before the wet sand sort of opportunity gets... Yeah, it's very limited volumes at this point. It has been just a handful wells that's been trialed with inconsistent results, frankly. Fair enough. Thanks, Brad. I'll turn it back. Our next question comes from John Gibson, from BMO Capital Markets. Please go ahead. Your line is open. Morning. Thanks for taking my call. Just on pricing, you know, you talked about it coming off in Q4 and the start of the year. You know, as we think about the improved commodity backdrop and maybe a pickup in gas-related drilling, how do you expect pricing to go, you know, up or down as 2026 progresses? I think it is gonna be fairly level here for a while, with, I would say, an upside bias, just with improving commodity prices. Okay. Hard to say- Does it- Hard to say when, but... Does it differ per region, or does it kind of rise and fall across the basin fairly easily? I would say it differs with definitely. There's two very distinct, there's natural gas, and then there's oil, you know, with, like, with our Trican Frac division versus our Iron, Iron Horse Frac division. You know, they're in two very different commodities, right? So you definitely can have sort of opposing forces going on at any given time. So, you know, we definitely would look at the two commodities distinctly there for those two divisions. Got it. In terms of the new fleet, will this be additive to your current horsepower, or is it gonna replace some older equipment? No, we certainly hope it will be additive. You know, when we were ordering this and just talking with our customers about what their plans were for the next five years, we don't see any reason why this won't be additive, but, you know, it. You may never get the timing exact, but certainly, we ordered this with the intention that it is fleet. Okay. And then last one for me. Not sure if you even know the answer to this, but just given your last mile logistics moves over the past few years, along with some of your peers, can you estimate how much capacity you've added to the basin in terms of pumping capacity that was maybe previously constrained? What you're asking is, with improved logistics, how much pumping capacity of increase does that result in? Yeah. It seems like the last few years, one of the constraints is last-mile logistics, and you and your peers have been working on this for quite a while. So I'm just wondering, you know, if and when things turn a little bit, you know, what is the incremental, you know, sand you could pump or that sort of stuff- Yeah - that was previously constrained? I don't. I couldn't tell you the answer to that off the top of my head. I, I would say this, though. I think the sand volumes are gonna grow faster than our ability to add logistics assets. You know, the sand volumes have grown from 4 million tons a year to 8 million tons a year in the last, say, four or five years, and I would doubt that the logistics fleet has doubled. There's a long lead time on tractors and trailers and, you know, getting experienced drivers that can drive in the conditions that we're asking, you know, versus like long-haul drivers. My guess is we'll be fighting to keep up with the growth in sand volumes. Hey, got it. I appreciate those responses, those facts. Thanks. Our next question comes from Colby Sasso from Daniel Energy Partners. Please go ahead. Your line is open. Hi, thanks for having me on. I just wanted to ask, with exports from LNG Canada beginning in 2025 and further LNG exports anticipated in 2026, how does Trican expect these developments to influence the industry? And additionally, how is the company approaching the opportunities created by this emerging market? Okay. That's, that's a big question. Certainly, LNG, you know, what we produce 19 BCF a day in Canada. When LNG Canada train, I guess you call it, is just under 2 BCF a day. So we've... You know, 10% of Canadian production is now getting exported. And as other LNG assets get added, I think you just, you know, you put a floor in your natural gas pricing just 'cause you're not just selling into the North American market anymore. You know, a lot of the other things we don't talk enough about too is our customers have very sophisticated marketing plans, where they're selling gas, you know, not just to Canadian LNG, but actually to U.S., into U.S. LNG and another sales point around the U.S. So we're not just relying on a Canadian gas price anymore. So, you know, it should be a foundation of activity going forward that we've never had previously. And so what are we doing? I think I talked about that in the call, which is, you know, we're building the most technically advanced fleet, and we're continuing to reinvest our capital into the Canadian marketplace to ensure we're the number one service provider as this industry unfolds in the next few years. So, you know, I think we'll be a direct recipient and our customers will be direct beneficiaries of the capital that we've invested. Thank you so much for the color. I'll turn it back. Our last question comes from Tim Monticello, from ATB Capital Markets. Please go ahead. Your line is open. Hey, good morning, guys. Try to keep it short here. In terms of the commodity price rally that we've seen in oil and, and the Iron Horse outlook, it sounded like at least during the Q3 conference call, that Q1 was gonna be a pretty busy quarter for, for Iron Horse, and then you'll hit some typical seasonal slowdown. So I guess the reduced sort of outlook for the year, at least at Q3, was coming from the back half. So with commodity prices in that north to $65 range, do you think you can get back to that CAD 80 million mark, which was sort of initially contemplated when the acquisition was done? Yeah, maybe not, maybe not this year. You know, weather in Q1 actually probably affects them more than us, just given the wonky weather we had. So they, they're having a good Q1, don't get me wrong, but, you know, if we certainly, if oil holds in at these levels, we'll get back there. You know, exactly when, I don't know, but, you know, the workload is very elastic to oil pricing in that part of the world. So, yeah, we're still really happy with that acquisition. Do you get any sense from customers on, I guess, a changing mood or sentiment around what they're gonna do in the back half yet, or is that too early to call? Yeah, I... The sense we get is, especially here at the $65 level, if oil holds in here, that will be a direct response to that. You know, you need to have it for more than a couple of days, obviously. But certainly, you know, when you talk to customers, they've got, you know, lots of what-ifs built into their budgets, right? And budgets go up just as easily as budgets go down. So, if we hold in at the $65 level, we would expect them to have a busy second half. Okay, got it. And then second question. It sounds like you're building or deploying some new natural gas equipment in other ancillary service lines, like, in the trucking and cementing business. Can you talk a little bit about, I guess, the capital outlay that's gonna be required over the next couple of years to, I guess, integrate all of that equipment? And, I guess, to what degree do you expect to replace equipment that's, you know, not natural gas or upgraded current equipment? Yeah, Tim, if we kinda look at 2026 on its own, you know, about half of our capital program is what we would call expansion. So, you know, our CAD 120 million split in half, roughly 60-60 of that is expansion, and the bulk of that, about 40 of it, is related to our natural gas fleet. ... You know, so that's kind of a ballpark number you would need to think about if we go forward. You know, maybe one of those fleets per year would be the maximum we could possibly do, just from a timing and a logistics and a build perspective. But we're certainly not in a massive rebuild CapEx cycle. You know, as we pick away at things like natural gas tractors in the logistics side, those are small bites as we go through. And then even thinking about the stuff that Brad was talking about around the cementing assets, those are fairly small bites as well. So I don't see this as the start of a massive CapEx cycle. We're gonna pick away at it, and the biggest chunk by far would be kind of looking at that natural gas frack fleet. Got it. And the one cementing unit, I guess, that's gonna be natural gas. Is that an upgrade or is that, like, a new unit? It's an upgrade, and so it wouldn't be full natural gas, you know, tractor and stuff. It's, you know, a certain part of it will basically be electric. Yeah. And so it's called a hybrid unit. We're looking at fully electric, what we would call fully electric units. And what happens is, you know, you got these big electric drilling rigs on location, and so we sort of basically, for lack of a better way to. When we get there, and so, you know, you don't haul electrical generation equipment like frack, because of course, that just wouldn't be practical. You know, your cement jobs don't last that long. As the rest of the industry sort of generates, is generating electricity via natural gas on location, that allows you to sort of evolve and build out assets that can work in conjunction with them on location. Okay, got it. All right. That was all my questions. Appreciate it. Thanks, Tim. Thanks. We have no further questions. I'd like to turn the call back over to Brad Fedora for closing remarks. Okay, thank you, everyone. We appreciate your time and your attention to our call. If there's anything else you'd like, like to ask, please, just call us. We'll be in the office all day today. Thanks again. This concludes today's conference call. Thank you for your participation. You may now disconnect.