Good morning, and welcome to TETRA Technologies' second quarter 2024 results conference call. All participants will be in listen-only mode. Should you need assistance, please signal a conference specialist by pressing the star key followed by zero. After today's presentation, there will be an opportunity to ask questions. To ask a question, you may press Star, then one on your touchtone phone. To withdraw your question, please press star, then two. Please note, this event is being recorded. I will now turn the conference over to Julian Higuera. Please go ahead. Good morning, and thank you for joining TETRA's second quarter 2024 results call. The speakers for today's call are Brady Murphy, Chief Executive Officer, and Elijio Serrano, Chief Financial Officer. I would like to remind you that this conference call may contain statements that are or may be deemed to be forward-looking, including projections, financial guidance, profitability, and estimated earnings. These statements are based on certain assumptions and analysis made by TETRA and are based on several factors. These statements are subject to several risks and uncertainties, many of which are beyond the control of the company. We are cautioned that such statements are not guarantees of future performance and that the actual results may differ materially from those projected in the forward-looking statements. In addition, in the course of the call, we may refer to EBITDA, adjusted EBITDA, adjusted EBITDA margins, free cash flow, net debt, net leverage ratio, liquidity, returns on net capital employed, or other non-GAAP financial measures. Please refer to yesterday's press release or to our public website for reconciliations of non-GAAP financial measures to the nearest GAAP measures. These reconciliations are not a substitute for financial information prepared in accordance with GAAP and should be considered within the context of our complete financial results for the period. In addition to our press release announcement, we encourage you to refer to our 10-Q that we also filed yesterday. I will now turn it over to Brady. Thanks, Julian. Good morning, everyone, and welcome to TETRA's second quarter 2024 earnings call. I'll summarize some highlights from our second quarter results and provide an update on our strategic initiatives before turning the call over to Eligio to discuss second quarter financials and additional perspectives on our third quarter. Our second quarter results can be characterized as mostly consistent with the overall trending oil and gas markets during the second quarter, which was lower U.S. completion activity, with increasing activity in the international offshore market. This, combined with our seasonal second quarter peak for our European industrial chemicals business and lower deepwater project activity in the Gulf of Mexico, contributed to our results of 14% sequential revenue growth and 32% increased adjusted EBITDA. Our completion fluids and products and water and flowback segments achieved Adjusted EBITDA margins of 28.9% and 15.2%, respectively. Water and flowback Adjusted EBITDA margins of 15.2% was an anticipated rebound from 9.6% in the first quarter, a sequential improvement of 560 basis points. Year-over-year, revenue was down 2% compared to U.S. onshore rig activity, down approximately 16%. Adjusted EBITDA of $30.2 million was seventeen point six percent of total revenue and inclusive of $1.1 million of foreign exchange losses. During the second quarter, we secured a three-well, Deepwater Gulf of Mexico CS Neptune fluids project for a Super Major oil and gas operator. This is an important milestone, as this is the second super major operator in the Gulf of Mexico to select CS Neptune for their completions program and the first Gulf of Mexico deepwater CS Neptune fluids project since the fourth quarter of 2019. Following a dramatic impact to the timing of potential CS Neptune deepwater projects due to the COVID pandemic in 2020 and 2021, we have since seen our pipeline of projects move forward and are pleased we have been successful, awarded this project. The first well is not expected to begin the completion phase until the fourth quarter of this year, and the timing of the entire project is expected to be between Q4 2024 and the second quarter of 2025. Unlike our prior CS Neptune fluid Gulf of Mexico projects, which were single wells spread out across several years, this program is a three-well batch drill and complete program, with the completion phase expected to start in the fourth quarter. As a result, it is likely that the three wells will be completed between a six- to nine-month period, assuming things go as planned. As demonstrated from the past, CS Neptune Gulf of Mexico projects, these wells represent a material revenue increase over our typical deepwater completions. Because of the back-to-back batch completion program, there are some efficiency on the inventory side planned for the project, but the overall project revenue numbers will also be very dependent on the fluid losses from each well. Obviously, we are excited for this award, and we continue to have productive discussions with other operators for CS Neptune programs in the Gulf of Mexico. For water and flowback, we previously announced that we expected second quarter margins to recover in the mid-teens, and despite lower operator completion activity levels in the second quarter, we are pleased we achieved adjusted EBITDA margins of 15.2%, a 560 basis points sequential improvement. Our strategy for water and flowback continues to be a two-pronged approach. Automation of every service aspect from BlueLinx automated movement and transfer of water to the automated SandStorm, automated, and automated drill out systems. And secondly, the treatment of operator-produced water for frack reuse and desalination for beneficial reuse. Collectively, these strategies will reduce HSE exposure for our employees and our customers, lower labor costs per job, and provide an environmental benefit of less fresh water usage while reducing seismicity risk and providing a valuable water resource for agriculture and industrial applications. While this strategy is well underway with BlueLinx and water transfer, the number of automated systems deployed for SandStorm and Auto Drill Out is only just beginning, but so far with exceptional results and customer acceptance. We're also deploying our first SandStorm to the Middle East market for a major national oil customer. If a successful trial is completed as anticipated, this could be a major new market opportunity for the company. With regards to water desalination and beneficial reuse, I would like to provide some color on where we are. We previously communicated that a South Texas commercial production facility was imminent. Unexpectedly, our customer was told that the permitting would be on hold and linked to results from a West Texas pilot program, where urgency for a solution is a bigger priority. This is highlighted by the most recent earthquakes to hit West Texas, the largest of which hit 5.1 on the Richter scale and prompted the Texas Railroad Commission to open an investigation. Accordingly, we are working closely with our customer on the commercial terms for a beneficial reuse pilot project in the Permian Basin. In addition, we have ongoing discussions with three other major customers for pilot projects that, in addition to West Texas and South Texas, include Mid-Continent and Appalachia regions. We currently have nondisclosure agreements with seven customers and have had many of them visiting our functioning pilot units at our research facility in Conroe, Texas. While the delay of the launch of our first commercial project was unexpected, we realize our customers have to work with the regulatory bodies and focus on areas with the biggest impact to the environmental challenges the industry faces. We have demonstrated that our technology is able to treat oil and gas well-produced water to the regulatory environmental specifications required, and oftentimes to be of higher quality than to what is found in rivers and in water wells, with the ability to scale for commercial applications. Since utilizing operator oil and gas well-produced water for agricultural purposes has been occurring in California for several years, we are optimistic that Texas and New Mexico will soon follow suit. Moving on to our strategic initiatives. Following our very recent visit with the Eos executive management to their plant in Turtle Creek, Pittsburgh, we are confident Eos is on the verge of materially higher production volumes, requiring materially higher, higher volumes for their electrolyte. Eligio and I were very encouraged with what we saw firsthand with their automated line and the excitement of their employees working to automate the line from start to finish. Eos recently completed a recapitalization that allowed them to source the capital to complete the first line and have the working capital required. Seeing the automated line working at Eos facility is a vast improvement from what we have seen in our prior visits. As Eos ramps and brings the automated line up, the volumes of PureFlow and electrolyte they require will increase materially over the minimal volumes that we have shipped them so far this year. We've increased our capacity in West Memphis to meet the expected Eos demand. We also continue to advance discussions with a second zinc bromide customer using PureFlow for their electrolyte technology. On the Arkansas bromine side, we're in the final stage review of an S-K 1300 definitive feasibility report, or DFS. The economic analysis is prepared based on the assumption that the bromine project is completed independent of the planned lithium project. As a reminder, the bromine project will allow us to achieve the following benefits: First, vertical integration for supply of elemental bromine at a lower cost than buying it from third parties, making this a margin enhancement project. Second, it gives us more volumes to meet the continued growth in oil and gas demand for high-end, high-value completion fluids and the growing zinc bromide long-duration battery market requirements. And third, positions us for the long term, utilizing our Arkansas bromine leases, estimated to be over 80 years of resource supply, as our current long-term elemental supply agreement comes to an end at the end of 2029. On the lithium side, we're continuing the FEED Engineering effort and are targeting a major milestone for the ±10% project cost and economics by the fourth quarter of this year. At that time, we will also be able to quantify the cost synergies for having both lithium and bromine production from the same plant and upstream Brine Unit. Summarizing on the strategic initiative side of things, the desalination of produced water for beneficial reuse, PureFlow electrolyte for long-duration energy storage, Arkansas bromine, and future lithium supply are all material financial benefit to the company that we will quantify as we complete key milestones for each throughout the year. Collectively, they are transformational for the company. It's also important to understand that the desalination of produced water, zinc bromide-based electrolyte for energy storage, and direct lithium extraction are not only new businesses for TETRA, but for the most part, are new and emerging markets for the United States. So predicting accurate timing on key events is more challenging than for existing and established businesses. Our processes have been very methodical, and our focus is to get it right and not get it out before we're highly confident with our work and our analysis. With that, I'll turn it over to Eligio to provide some additional commentary on our financial results, and then we'll take some time for questions. Thank you, Brady. Second quarter Adjusted EBITDA of $30.2 million was negatively impacted by $1.1 million of foreign exchange losses. Nonetheless, this was below our expectations, as the U.S. onshore market was progressively weaker during the quarter, especially around water transfer. We are focused on the quality of our earnings and will not be chasing work at low margins. With our focus on returns on capital and free cash flow, we are not prepared to chase lower margin opportunities.... We had committed to improve water and flowback Adjusted EBITDA margins to the mid-teens in the second quarter and achieved that with a 560 basis point improvement to 15.2%. We believe that revenue in the third and fourth quarters will be flat to the second quarter, and we expect to continue our efforts on keeping our EBITDA margins above 15% in an environment where onshore activity is flat. Brady mentioned that our efforts of leveraging technology and automation are pivotal towards gaining market share in a declining market without compromising margins. Completion fluids and products revenue saw the expected higher revenue and earnings from the peak industrial chemical season in Europe. Recall that a few years ago, we expanded production capacity in Northern Europe and took advantage of this, and of the available higher volumes this peak season. Our second quarter could have been even stronger as we managed through a few challenges. The first was a strike by port workers in Kokkola, Finland, that restricted our ability to offload limestone to produce calcium chloride and also restricted our ability to load and ship product. This strike started in the first quarter and ended early in the second quarter. Additionally, the quarter started with winter conditions harsher than normal, with a frozen harbor making the movement of vessels in and out a challenge. Despite all this, our calcium chloride business continues to perform very well. The industrial calcium chloride business is just below $140 million in revenue on a trailing twelve-month basis and represents a stable revenue, EBITDA, and cash flow stream. While the onshore oil and gas industry has been slowing for now, what appears to be a short period of time, the offshore oil and gas market continues to also do well. As Brady mentioned, we had a nice sequential improvement in Europe and Latin America that were partially offset by the timing of projects in the Gulf of Mexico. Due to the timing of deepwater completions activity, we expect the third quarter revenue and EBITDA to be comparable to what we saw in the first quarter for the completion fluids and product segment. But the fourth quarter should then see a meaningful step up from the third quarter, taking into account the first of the three CS Neptune wells. Based on all the information we are hearing from our client and assuming no delays in the work schedule, we should complete the first of the three CS Neptune wells in the fourth quarter, but there is a possibility it could move to the first quarter. Recall that we are in the middle of the hurricane season in the Gulf of Mexico. That could impact project timing. The three-well CS Neptune project is a major achievement for TETRA and is one of many projects that we have been following for a long period. Recall that we previously completed a five-well project for ExxonMobil in the Julia Field between 2015 and 2019. These types of projects are higher, are high revenue per well, given the technical environmental challenges that Neptune can address, including, in this case, downhole conditions as high as 340 degrees Fahrenheit. For the second quarter, we are also committed to an improvement in free cash flow. In this press release, we are breaking up free cash flow between the base business and cash flow from our Arkansas investments. Free cash flow from our base business in the second quarter was $19 million, a sequential improvement of $45 million from the first quarter. We further expect the third quarter free cash flow from the base business to again be strong as we monetize the inventory and receivables from the Northern Europe industrial peak season. During the second quarter, we invested $9.8 million for engineering, reservoir analysis, and other studies in Arkansas. This $9.8 million is net of what we were reimbursed by Saltwerx, consistent with our memorandum of understanding. We continue to jointly invest in Arkansas and advance towards formalizing a more formal agreement. These investments are necessary to allow us to quantify the required capital for future bromine and lithium production. Once those economics are fully understood, we can move to a more formal arrangement. Liquidity as of this week was approximately $187 million, inclusive of the $75 million delayed draw feature that is available to TETRA for the bromine project. In addition to the noted liquidity, we're also holding slightly over $14 million of marketable securities in Standard Lithium and Kodiak, and this can be monetized at our convenience. In May, we refinanced, extended, and expanded our asset-based loan facility, or ABL, at an equally attractive interest rate than our prior ABL facility. This further strengthens our balance sheet and provides us the flexibility to execute on our growth initiatives. The maturity of the ABL is May of 2029. Nothing is outstanding on this facility. All our debt is now 2029 or 2030 maturity dates. At the end of the second quarter, our net leverage ratio was 1.6x. Return on net capital employed for the twelve-month period ending June 2024 is a very healthy 17.4%, materially above our cost of capital. The CS Neptune project, which we believe to be the first of several in the coming years, plus the continued recovery of the deepwater market that can be addressed with calcium bromide and zinc bromide. Our market-leading position in the calcium chloride market and the expected requirements for zinc bromide battery electrolyte has positioned us for what we believe to be a very solid 2025. Let me turn it over to Brady for closing comments, then we'll open it up for questions. Thanks, Eligio. In closing, we're pleased that we are achieving the goals that we've set out for the company. The CS Neptune award is reflective of our strong market position in the deepwater market, and will have a material impact on our financials over the next 6-9 months. We're on track with our water and flowback business to continue margin progression through new technology, with the desalination for beneficial reuse continuing to gain momentum. We have a solid balance sheet, close to $180 million of liquidity, and we expect to continue to generate strong free cash flow from our base business to fund our strategic growth initiatives. We expect a strong finish to the end of the year, but just as important, significant momentum and heading into 2025 and beyond. With that, we'll now open it up for questions. Thank you, presenters. We will now begin the question and answer session. To ask a question, you may press Star, then One on your touchtone phone. If you are using a speakerphone, please pick up your handset before pressing any keys. To withdraw your question, please press Star, then Two. At this time, we will pause momentarily to assemble our roster. And your first question comes from the line of Bobby Brooks of Northland Capital Markets. Please go ahead. Your line is open. Hey, guys. Good morning. Thank you for taking my question. You know, my first question is just on the CS Neptune outlook, right? So great that you guys got the three projects nailed down with the one super major. But if I recall, in the first quarter, you guys talked about how the level of discussions for CS Neptune projects within the Gulf of Mexico was at the highest that you've ever seen, and that was occurring with multiple different operators. So I just wanted to get a sense of what, you know, how those conversations, obviously, these three you got, is there potential for more from this operator? And then maybe just any, how have discussions went with those other ones? I know Eligio, at the end there, talked about these might be the first of several in the coming years, so just kind of more detail on that. Yeah, Bobby, so we have a pretty extensive pipeline of projects with operators that we've been tracking for many years. I think I've mentioned before that these types of projects come a long lead time in terms of the types of testings that's required. You know, elastomer testing, formation testing, fluid compatibility with everything the operator is doing with their completion. And so, you know, we've got a very healthy list of pipeline projects. Obviously, we're pleased with this award, but we are having multiple discussions with multiple operators that are part of that pipeline. Now, some of those could materialize before the end of the year in terms of new awards. Some of them may carry into next year or beyond. It's difficult to say until, you know, you actually get the award. We want to be, you know, careful of how we communicate that. But I can tell you that we are having multiple discussions with multiple operators, regarding additional projects beyond just this, these first three. Just to clarify, that is specifically for these CS Neptune projects in the Gulf of Mexico, which obviously are very revenue intense and high EBITDA margins for you, right? That's correct. The Gulf of Mexico wells are quite unique, just from the pure volume of the fluid that's involved in the completions and the technical requirements of the fluid to meet these ultra-deepwater temperature and pressure conditions. And Bobby, just to add, this is on top of our traditional completion fluids business in the Gulf of Mexico. Some of the bigger projects that can be addressed with the basic calcium bromide or zinc bromide could range anywhere from $2 million-$5 million per well for the basic completion fluids before we move to a Neptune-type well. Got it. Thanks for that color. And then jumping over to the beneficial reuse, as mentioned, how you've signed seven, seven different NDAs with seven different operators, right? I think it could be helpful to just help frame that a little more. Maybe contrast that with how many NDAs were signed at the beginning of the year versus now. Were any of the—you know, were any of the NDAs that you had signed at the beginning of the year, did those back out? Yeah, we have not had any NDAs back out, and there is... I don't know the exact number, Bobby, but I would tell you they have definitely increased as we've gone through the year. The nature of these discussions, obviously, we have some proprietary technology, some of which we have filed some patents for. But obviously, you know, until we're issued the patents, we want to be very protective of the proprietary nature of our technology. That's the reason for the NDAs, and that allows us to have very deep discussions with the operators, the customers, for their very specific requirements around their produced water and the treatment procedures and technologies we will use for that, for their program. Which obviously, we hope evolves into a pilot program, which we've already done with, you know, the first customer we've been discussing for, for some time. But now we're in multiple, serious, you know, pilot commercial discussions with multiple, multiple operators. Got it. Thanks for that color. And then just last one for me is, could you, so, you know, $9.8 million in CapEx towards Arkansas, right? That's net of reimbursement from the partner. Are you able to disclose how much the reimbursements total? Yeah, those are covered by our NDA, so we'll obviously only report what impacts TETRA's financial statement. Assume that our partner continues to work side by side with us on all the initiatives around Arkansas. Fair enough. Congrats on the solid quarter, and I'll return back to the queue. Thanks, guys. Thank you. Thank you. And your next question comes from Josh Jayne of Daniel Energy Partners. Please go ahead. Your line is open. Thanks. Good morning. First one I wanted to ask, just on SandStorm being deployed to the Middle East market. Could you talk about the total addressable market and what it looks like for you if this is successful, maybe over the next couple of years as a starting point? Yeah, I mean, we're clearly seeing some activity increase in the Middle East, several markets for the unconventionals, markets that are developing. And clearly, there's an addressable more market today. You know, I don't wanna give specifics about the numbers in today's market, but as that unconventional activity continues to increase in several of the Middle East countries, it's a perfect application for SandStorm. So we'll keep you posted as that market develops, and we can quantify it, but it's a little early for us to do that at this point. Okay. And, switching gears a little bit to offshore completions, fluid activity. You noted that it was stronger in Q2 than Q1. Maybe you could just walk through the markets outside of the Gulf of Mexico and how you're seeing those markets shape up over the next 12-24 months, would be helpful. Yeah. So you know, we clearly, outside the Gulf of Mexico, we have strong market positions in Brazil, in the North Sea, and to a lesser degree, you know, West Africa and Asia Pacific. But certainly we see a very good growth going into 2025 in the Brazil market, and we're extremely well positioned in the Brazil market for that growth, again, outside the Gulf of Mexico. North Sea, we continue to see steady improvement, steady progress, not just in the typical completion activity, but also opportunities for us for Neptune opportunities in the North Sea. Now, typically, they're not as large of a size of projects, clearly not as large as in the Gulf of Mexico, but they are, you know, very very profitable opportunities for us as that market continues to evolve. And then, you know, we have spot markets around the world that we work with the major service providers on providing completion fluid technology for those, you know, for those markets. But overall, the international offshore market we see as a continuing trend, you know, improving, and that obviously includes the Gulf of Mexico. Okay, thanks. And then, maybe just one last one, to ask the Gulf of Mexico Neptune question a little bit differently. When we think about the margin uplift from this specific project that's gonna happen for you in Q4 and early into 2025, is the margin profile different or better for this project than we might see from traditional projects? Because not only maybe is the pricing environment a little more constructive, but also just the fact that the wells are stacked back-to-back. I was just curious if you could elaborate on that a little bit more and to help frame your expectations for the first half of 2025, and then I'll turn it back. Thanks. Josh, good question. The margin that we make on a Neptune project has many variables that go into it. It depends on how many volumes, how many thousands of volumes of fluid barrels we inject into the well. It depends on the duration of the fluid in the well, whether it's in there for a few weeks or many, many weeks, and also on how much fluid is lost in the well. The prior project that we did, the losses of the fluid in the well were quite significant. At this point, we're making an estimate as to how much fluid might be recovered from the well, but they will be higher than traditional offshore completion fluids projects, and they can move the entire segment meaningfully. Okay, thanks. I'll turn it back. Thank you. Your next question comes from Kurt Hallead of Benchmark. Please go ahead. Your line is open. Hey, good morning, everybody. Good morning, Kurt. Hey, you know, maybe I think I'm gonna just come back around to that, the water opportunity, recycling and use and so on. It's awesome to see that you guys are getting, you know, some traction with a number of different E&Ps around it. I think probably speaks to the value proposition. Now, I'm kind of curious, you know, when you think about the dynamics at play and you think about how the customer base may be pursuing this, could you give us some sense as to, is this being like, you know, supported by the governmental and regulators in Texas? Is that a key element of the driver, or is it, you know, a combination of that and maybe the E&Ps wanting to reduce their environmental exposure? Just kind of curious what the underlying drivers of this market will be that will help it make a reality. Right. So the largest fundamental driver behind this, Kurt, is the fact that the seismicity events in West Texas are clearly linked to over-pressuring the disposal wells and formations in the region. I think we've seen the Railroad Commission put restrictive injection profiles around certain areas. I think there's three or four in effect today that are starting to restrict the amount of water that operators can dispose into these formations. There was just recently, as I mentioned in our comments, a number of fairly sizable earthquakes, one of them hitting a 5.1 Richter scale just last week, that there was an article out that the Railroad Commission was going to be investigating that. And so this problem is not going to go away until there is a solution to address the over-pressuring of disposal wells and lack of pore space, you know, to inject additional disposal water. Now, you know, there's a couple solutions to that, and operators can truck water from the areas where it's being produced to other areas farther away that are not under pressure. That gets pretty expensive, you know, pretty quickly. We think that the best solution is to treat that water and turn it into a resource, you know, right on the in the general vicinity of where that water is being produced. And so, you know, operators are definitely you know, looking at those options relative to their alternatives. And we think at the price point that we can achieve, the cost point that we can achieve with our technology, that it's gonna be a sizable market opportunity for us. But that's really the drivers. The regulatory agencies are definitely tracking this extremely closely. They've actually visited our facilities, looked at our technology, given us very encouraging feedback as to the solutions that we're offering. But clearly, there's, you know, there's a lot that goes into permitting, you know, produced water that potentially has a lot of organics and nasty elements in it, to allow it for beneficial reuse. And as I mentioned in our comments, that's already happening in California today. That's been going on for several years now, where treating produced water for agricultural purposes has been in place. I just think it's a matter of time before Texas and New Mexico, quite frankly, you know, get caught up with getting their regulatory guidelines and specifications in place. Okay. That's, that's really good color. So, maybe shifting a bit and, you know, in the context of, you know, the opportunity that you have going on in Arkansas and the investments that you've been making, I know you referenced there's a final review that's kind of underway right now. But I guess my commentary is this, right? You-- yeah, you guys have a royalty agreement with Standard Lithium, you know, for what they produce. It looks like Equinor has made an investment in what Standard Lithium is doing. That follows on with the joint venture that you have with Exxon on your acreage. So, you know, what... Should we think about this dynamic at play now with Exxon and Equinor? You know, are these, you know, firm interest levels, or, or do you think that, you know, this is more of, "Hey, from an oil company standpoint, you know, we got to, you know, get a sense of what's going on here, but we're really not fully committed?" And I know what the answer is on Exxon, but I'm just kind of curious what your take is, you know, with respect to, well, Equinor's investment in, in Standard Lithium's project. And do you think that makes that more, more real and the outcomes there more real? Yeah, I mean, we know Equinor quite well from our dealings with them in the oil and gas world, and we've met their project team that's based here in Houston for that project. And you know, my perspective is, they're every bit as committed, you know, as any other operator would be for this type of a project that's invested in this, Kurt. I mean, obviously, things can change, but from what we can tell, they're very much committed. I don't want to speak for them, but that's just our observation. I think that at this point in time, you know, we're still going through the engineering process and don't want to get ahead of ourselves until we get the final engineering and the economics of the project in place that we can publish and talk about. We expect to have that completed before the end of the year. And then we'll be able to publish, hopefully, the results of that, both in terms of the CapEx, the OpEx, the financial returns, like we're getting ready to release, hopefully as soon as next week on the bromine definitive feasibility study. But until we have all those numbers kind of pulled together, and each of—whether it's ourselves, whether it's Equinor and Standard Lithium, and ourselves with Saltworks and ExxonMobil, and we don't want to get ahead of ourselves until we have some economics to speak about. Yeah. Yeah, that's all fair. All right, and then maybe just to get a wrap on this one, you guys, you know, have a electrolyte supply agreement, you know, for battery energy storage systems, as you referenced. I think there was some opportunity or possibility, you know, to start delivering those electrolytes in volume before the end of the year. Do you have any updates for us on the timing of that? Yeah. So, Kurt, just as a reminder, we did ship, and we have sold electrolyte to Eos in prior years. A lot of what they sold in 2022 and 2023 included our electrolyte. That's part of what's out in the market right now, both charging and discharging battery. We call that last year they made a decision to transition to their latest version of the technology and then suspended activity as they were making that transition. Brady and I, a little over a week ago, made another trip to Turtle Creek and visited with the Eos management team, and it was very encouraging to see how they progressed the automation of the latest version of the battery, how they are now fully automating the assembly and production of the batteries. When Brady and I were there, we saw how the electrolyte was automatically being injected into every battery. We think we're gonna go from shipping them electrolyte in totes to full tanker trucks. And just as an example, one tote can contain around 4,200 lbs of electrolyte. A tanker truck can contain 45,000 pounds of electrolyte. And what Eos was doing is modifying their facility to take tanker trucks instead of totes. We believe, based on what we saw, that they will be up in full production in Q4. And at that point, the expectation is we're gonna start shipping electrolyte in tanker trucks versus totes, and the volumes increase meaningfully, and the impact, we think, to us, is gonna be quite significant in 2025. Okay, that's awesome. Appreciate that. That's it for me. Thanks, Kirk. Again, if you would like to ask a question, please press star one on your touchtone phone. Your last question comes from Patrick Hulett of Stifel. Please go ahead, your line is open. Hey, good morning, it's Pat on for Steven Gengaro. Thanks for taking the questions. Morning. Morning. Hey, good morning. I believe you had mentioned a potential second customer for the zinc bromide electrolyte. Could you just talk about your ability to meet that sort of demand, or how margin changes if you need to source bromine from the open market? Well, first part of the question, you know, we, we've been working with the second customer for some time. You know, I think they're, they're clearly, in terms of their ramp-up, manufacturing capacity, you know, just really getting started in terms of developing that manufacturing capacity here in the United States. So, well, time will tell how fast they're able to ramp up, but I don't see a big impact back to us in terms of our overall, you know, bromine supply in 2025 or potentially into 2026. It just depends on how fast they scale up their, their manufacturing, certainly relative to what Eos has done, who've put up an entire automated assembly line with a battery coming off the line every 10 seconds or so. So it's not really comparable yet at this point. But the fact that they're using zinc bromide, the technology works. They've got commercial installations at a pretty small scale. Gives us, you know, a lot of good confidence in the technology itself, as we have with Eos. So I don't think it's really gonna be much of an impact for any third-party purchases that we would need over the, you know, next year or so to support that activity. Okay, great. Thanks for that. Yeah. So for the third quarter, could you just remind us of any seasonal impacts in Completion Fluids from Europe or maybe what you're expecting to see there? No seasonality beyond what we see in the second quarter for the calcium chloride business in Northern Europe. Obviously, we're hoping that there's no hurricanes in the Gulf of Mexico that disrupt activity, but that would be the only seasonality that might be out there. Okay, great. That's all for me. Thank you. Thank you. This concludes our question and answer session. I would like to turn the conference back over to Mr. Murphy for any closing remarks. Well, thank you very much. Appreciate you joining us, and appreciate your interest in TETRA Technologies. We look forward to our next discussion with you. Thank you. Ladies and gentlemen, this concludes today's conference. We thank you for participating and ask that you please disconnect your lines.