Participants

Michael Messina; Director of Finance; ProFrac Holding Corp.

Matt Wilks; Executive Chairman; ProFrac Holding Corp.

Ladd Wilks; Chief Executive Officer, Co-Founder; Profrac Services LLC

Lance Turner; Chief Financial Officer; ProFrac Holdings II LLC

Luke Lemoine; Analyst; Piper Sandler

Arun Jayaram; Analyst; JPMorgan Chase & Co.

John Daniel; Analyst; Daniel Energy Partners

Tom Curran; Analyst; Seaport Research Partners

Presentation

Michael Messina

(audio in progress) If you exclude the contribution of Flotek. Additional details and reconciliations to the most directly comparable consolidated and GAAP financial measures are included in the quarterly earnings press release, which can be found on the company's website.
And now I would like to turn the call over to ProFrac's Executive Chairman, Mr. Matt Wilks.

Matt Wilks

Thanks, Michael, and good morning, everyone. After my prepared remarks Ladd And Mike, then we'll take a deeper dive into the performance of our subsidiaries, and Lance will provide additional insight into our financial performance.
While fourth quarter results were challenged, we continue to take strategic actions to better position pro frac for growth in 2024. And we are already seeing improved results in the first quarter despite the industry headwinds that persisted in the second half of 2023. We meaningfully grew free cash flow for the year to $293 million, an increase of 173% over 2022.
This substantial cash flow generation demonstrates the earnings capability capabilities of our vertically integrated operating structure and the resiliency and differentiation of our services in the face of market softness. We were hindered a bit in 2023 by our exposure to the spot market and our strategy to hold prices steady when activity flattened. We have adjusted and now entered 2024 with positive momentum.
I'd also like to highlight that in 2023, we grew our asset base and improved our capital structure strategy that we believe will pay dividends for years to come.
We completed the acquisition of Red Energy Holdings and Producer Services Holdings, which added six frac fleets and expanded Pro fracks geographic footprint to include the Rockies and Bakken. We also completed the acquisition of performance properties, which demonstrated our commitment to the Haynesville, greatly enhanced our vertical integration strategy and made pro frac the largest provider of in-basin sand in North America with a multi-basin footprint.
Then in October, we announced our intent to maximize the full value of our propane production segment, which operates through the wholly owned subsidiary, Alpine silica and confidentially filed a registration statement on Form S-1 with the SEC.
Finally, in December, we refinanced our senior secured term loan through two new financing, which will both mature in January of 2029. This recapitalization provides a bifurcated capital structure to allow for future optionality designed to realize full the full value potential of the proppant segment as well as enhanced projects overall financial flexibility, common theme of all these achievements and strategic initiatives that they demonstrate, how highly motivated we are to enhance proactive position as a leader in the oilfield services industry.
And these items were executed with a very targeted approach. We will remit remain steadfast in our pursuit of enhancing value and strive to navigate the market accordingly, with the end goal of being the industry's best of breed moving forward, I'm pleased to report on the transformative progress we are making as well as the improving visibility we see approaching in the current market.
We remain hyper-focused on the operational performance that we have discussed over the past few quarters, which includes vertical integration, benefits of scale enhancing utilization and cost control across all of our subsidiaries. In addition, today, we are working even more closely with each other with each customer to ensure strong working relationships, providing valued solution and maintaining long lasting partnerships. We are constantly evaluating all of our efforts in evolving these key priorities in 2024.
Before I get to that, however, I do want to comment on the challenges of 2023, both externally and internally as the market flattened out, our our position of holding the line on price caused us to miss out on the large efficiency gains experienced throughout the industry.
This combined with the ongoing integration led to lower market share as we reduced costs to accommodate, this was a mistake, we fully appreciate the negative impact this had on our financial performance in the back half of the year. We are committing to correcting that in 2024 and getting back to our foundation, the foundation we were built on, which is maximizing vertical integration and high asset utilization in the quarter, restoring our per unit operating costs to the lowest in the industry prior to 2023, we were a profit leader in our industry.
When comparing our metrics, we surpassed the overall peer group each year. In 2020, we were one of you that had positive EBITDA in 2022, we were the first in our peer group to reach record level profitability metrics. Brokertec expects to outperform in 2024 and gain market share regardless of whether activity rises or falls or remains at constant levels to achieve our goals, we are focused on three primary things. First, our customers, what we do best is pulp.
We always have and always will this new. We are doubling down on our efforts to ensure the entire team is focused on providing tailored solutions for the customer, partnering with the customer to achieve long-term results and generate long-term value with constant improvement in our value proposition. It also means that we are partnering with the right customers that set us up for success to also achieve our next goal utilization. We have expanded our targets for the benefits of utilization across the entire organization.
Today, our utilization focus is not only on total fleet count and how many fleets are deployed, but also on the efficiency of active fleets and how many hours they are able to complete, we want to improve utilization of labor hours, utilization of our manufacturing facilities, our sand mine, as well as every single asset and team at Pro frac. We are measuring it all and we plan to improve each at each and every level. This is taking one of our foundational building blocks and ingraining it across the entire organization. We have 45 of high-quality fleets. We are not satisfied until they are all pumping stage.
Finally, our focus will continue to be on costs. We believe that we have the lowest operating costs in the industry and we are going to keep it that way. In addition, if there is a strong value proposition to improve our capabilities, our utilization for our customer offering, we are prepared to deploy capital to meet that need. However, we are going to ensure that we remain lean and effective with these priorities front and center for all of our teams. We expect our business to lead the industry as we grew through acquisitions and scaled up our stimulation segment, we have adapted with a multi-prong strategy suited for all customer types and have built a more dedicated business model to deliver full cycle resiliency. This year, we expect to generate a significant amount of cash that will be focused on the balance sheet, and we intend to delever to a point that will put us in a position to talk about returning cash to shareholders.
Our focus in 2022 and 2023 was to build the business that we have today exploit the cash generation capability of that business and pass these rewards on to our shareholders. We will continue to execute upon our strategic goals and maintain focus on our key priorities to create long-term value for our stakeholders and provide best-in-class services to our customers. We believe we are well-positioned in 2024 for profitable growth.
With that, I'll turn the call over to Ed.

Ladd Wilks

Thank you, Matt.
I want to start by thanking our amazing team for their hard work and dedication and commitment to safety. We're extremely proud of the reputation that our people have built with our customers. This is a direct result of an extreme focus on the customer experience and the strong culture throughout our entire organization to make customer service our number one priority. We also recognize that the team is BiDil in order for us to accomplish our three priorities in 2024.
Now diving into our 2023 results, I'd like to give the State of the Union for PF. holdings. On the pressure pumping side, we have activated 10 fleets as we focused on utilization and a dedicated customer base. We believe that profitability per spread should revert to the $20 million to $25 million level in line with expectations for our peers and exclusive of profit generated by the profit segment.
Our focus on utilization is shining through starting in late Q2 2023, our white space in our frac calendar reached unsustainable levels and our pumping hours per active fleet dropped in 2024. We plan to improve utilization by at least 30%, while we did see some lost time in January, primarily due to weather. I'm happy to share that January was a stellar start to the year. And in the month of February, we achieved a pumping efficiency that was 20% higher than what we had averaged in Q2 and Q3 of last year. And we think there's room to grow that figure as we continue to align with dedicated high efficiency customers that have strong backlog of work.
Now that our recent acquisitions have been fully integrated into the Pro frac umbrella. We have refocused on our core pumping stages and selling sand. In addition, our leadership teams have been spending a lot of time on location with our operations teams across the organization, instilling a laser-like focus on our strategic initiatives so that all segments are aligned in our shared goals. This has already led to quicker decision, making more direct allocation of capital and improved customer service across our business lines, and we continue to prove improve on those fronts.
Additionally, we continued gearing up and preparing fleets for reactivation this year to accommodate anticipated customer demand, we remain focused on dedicated agreements with operators at favorable prices. Current pricing levels are constructive, especially when coupled with higher utilization and optimal cost structure, we're targeting approximately 80% of our fleet to be working for customers with larger programs on a dedicated basis. We also continue to maintain a strong presence and reputation with the customers in the gassy plays, which we believe will pay dividends in the future.
Moving forward, we continue to believe we are well positioned to be the preferred pressure-pumping and profit provider for large multi-basin operators. These operators require service providers with equivalent scale that can provide custody over the supply chain and materials. This is exactly what we were built for appropriate.
On the profit side, we have made a lot of progress on diversifying our customer base and we think we are poised to see the increased utilization that we have discussed entering 2024. We made organizational changes to support our strategic initiatives for enhancing growth, and we are very excited to welcome mats and Rick rentals to our profit business.
Matt has over 18 years of industry experience driving results and will lead the profit business as CEO. Rick Reynolds is COO and joined us with the performance acquisition. Brick has over 35 years of mining experience, driving operational improvements and peak utilization. We have the utmost confidence in Matt and Rick and both have already provided critical value to the business in our FP. and budgeting season, setting Alpine up for major success in 2024. Today, I have invited them to join us and give additional commentary on current operations and our expectations for the year. That takeaway.

Matt Wilks

Thanks, Vlad.
I am honored and humbled to be chosen as the steward of the profit production segment. We are extremely excited about the assets we have and the transformation taking place within the organization.
On our last call, Ed spoke about how we are marketing all eight mines for the first time with a focus on securing term contracts with customers at sustainable prices that support our goal of consistent high utilization of our mines. I am pleased to report that we had success over the recent RFP season. The contracts that we secured with customers over this process are a mixture of traditional take-or-pay and percentage of customer demand.
These percentage of demand contracts while not as desirable as take-or-pay contracts align with our desire to develop long-lasting partnerships with our customers with upside potential as our customers become more efficient or expand their completion activity while we have a great foundation with this commercial approach, we have seen weather impact us in Q1, along with customer impacts related to natural gas prices. We estimate we lost approximately 300 to 400,000 tons of sales in January and February, but expect to further increase production into the warmer months.
Our first-quarter utilization is expected to increase slightly from the fourth quarter. However, we then expect utilization to increase to 65% to 75% starting in the second quarter. We are confident that our focused effort on commercial and operational growth in our proppant segment will meaningfully improve 2024 metrics and results. Alpine is in the middle of a transformation and will produce higher throughput, higher utilization and lower cost per ton, and we believe that it will soon emerge as the sand market leader in 2024.
I will now hand it over to Lance to provide more detail on our consolidated financial results.

Lance Turner

Thank you, Matt recap the year, we generated $688 million of adjusted EBITDA on $2.6 billion in revenue for an overall EBITDA margin of 26%. We also generated $293 million of free cash flow in 2023 that was used to significantly expand our asset base, both in stimulation services and appropriate production segments.
Fourth quarter revenue totaled $489 million, a sequential decrease, driven primarily by the lower fleet count as it bottomed in the middle of the fourth quarter, EBITDA was $110 million as we experienced slightly lower efficiencies on our active assets and lower pricing for our products and services. For the fourth quarter, stimulation services revenues were down sequentially to $403 million. About 75% of this reduction was driven by a lower number of fleets. The remaining decline was driven by slightly lower pricing for our services, the number of integrated fleets fluctuated with our active fleet count, but we continued to supply approximately 30% of our fleets with materials.
Adjusted EBITDA for the segment was $58 million for the fourth quarter. This segment was impacted by approximately $10 million in shortfall payments related to our supply agreement with Flotek. The profitability per active fleet for the fourth quarter was also impacted by white space in the calendar in the first quarter as our focus on dedicated high efficiency customers takes hold. We expect to improve profitability per active fleet.
In general, we expect 60% to 70% incrementals on increased efficiencies when all else is equal profit production segment generated $383 million of full year revenues, which was up substantially when compared to the 90 million generated in 2022 due to the sand mines added during the year. Revenues for the fourth quarter were $93 million, down approximately 6%, driven largely by lower sand pricing, approximately 75% of the volumes were sold to third parties during the fourth quarter, which is in line with our commercial strategy to focus on customers where we can add the most value adjusted EBITDA for the profit production segment totaled $45 million for the fourth quarter.
The manufacturing segment generated revenues of $34 million, down approximately 22% from the third quarter. Approximately 83% of this segment was inter-company revenue as we expanded our third party sales during the quarter. For the segment, the decrease in sales in the fourth quarter was a continued result of stimulation services, reducing purchases and focusing on utilizing inventory on hand.
Adjusted EBITDA for the Manufacturing segment was $1.8 million, which was comparable to the prior quarter. This segment is also focused on reducing inventory levels and lead times on its product offering.
It has been impacted as steel prices have retreated and is working through raw materials purchased in 2022. We expect to remain at these levels of profitability until it works through its high-cost inventory over the course of 2024 and starts adding lower market price raw materials in the second half of 2024.
Selling, general and administrative costs were $59 million in the fourth quarter, down approximately $2 million, primarily due to lower stock compensation costs. This was combined with a significant reduction in acquisition related expenses as we have made tremendous progress on the integration of the recent acquisitions. Cash capital expenditures totaled $33.1 million in the fourth quarter, down 37% from the third quarter. As we've mentioned on previous calls, when we reduce our fleet count CapEx usually takes more time to be reduced. We are pleased with our ability to act swiftly to rightsized our spending levels to more accurately reflect the demand.
We are seeing from customers, and we will continue to prudently evaluate our spending going forward. As we laid out in our earnings release, we expect to incur maintenance CapEx of between 150 and $200 million for the full year. In addition, we are targeting an estimated $100 million in growth capital focused on fleet upgrades and mine optimization, we believe maintenance CapEx will be approximately $3 million to $4 million per fleet per year in the stimulation services segment. In addition, the property production segment is planning to spend approximately $30 million to $50 million in total capital expenditures for the year. We will remain disciplined with our capital allocation plans and focus on allocating capital where it can achieve the best return on investments. Operating cash flow was $42.7 million.
During the fourth quarter, working capital was reduced by approximately $10.5 million. While we continued to manage our receivables and payables. In addition, we saw a $35 million reduction in inventory, and we remain committed to utilizing our inventory on hand and expect to see continued reductions in 2024, particularly as we prepare to deploy fleets. Despite these inventory reductions, we expect total working capital to increase through 2024 as we seek to deploy additional fleets increase efficiencies and so more sand.
Total cash and cash equivalents as of December 31st was $25 million, including $6 million attributable to Flotek total liquidity at quarter end was approximately $103 million. Borrowings under the ABL credit facility ended the quarter with $117.4 million at the end of the fourth quarter, we had approximately $1.1 billion of debt outstanding, majority of which does not mature until January 2029.
Our primary objective in the near term remains generating free cash flow for delivering the balance sheet. Everyone within our organization is laser-focused on operational execution efficiencies and providing best-in-class service to our customer. We believe this focus will improve our relative positioning within the market and lead to improved results in 2024.
That concludes our formal remarks. Operator, please open the line for questions.

Question and Answer Session

Operator

(Operator Instructions)
Luke Lemoine, Piper Sandler.

Luke Lemoine

Hey, good morning, Matt.
With reactivating 10 fleets, it looks like you're probably displacing some competitors. Can you talk a little more about just kind of market structure, how you're attacking this? And as you see it right now is 10 reactivations about the right number? Or is the goal to eventually work back up to 45 fleets?

Matt Wilks

Yes. So we've added 10 and the majority of those have come in the first quarter. And so there's a there's only one or two that was actually in Q4 that we added and we expect to end at some point in this year, around 41 42. And if the market's there, we're going to go ahead and take it to 45 and get full utilization across the platform.

Luke Lemoine

Okay. And then on you cited your February pumping hours, setting a record yet at the 10 fleets where you talked about getting EBITDA per fleet back to $20 million to $25 million annualized, just kind of within the stimulation segment, is this where you guys currently are or when do you see this transpiring this year?
Not to put a specific date on it. We're not quite there yet. But we expect to be there in the first half.

Matt Wilks

Okay. And then maybe just one quick one on I know you're not disclosing your fleet count, but just kind of trying to triangulate this roughly in 4Q? Were you kind of maybe in the mid 20s and now you're in the mid 30s. Thanks, Greg. Okay. All right.

Luke Lemoine

Thanks, Matt.

Matt Wilks

Thank you. Thank you.

Operator

Alek Skylar, with Stifel.

Good morning, everyone, and thanks for taking my question. So just to start us off here. Just kind of following up on the prior question line, if you could just on the 10 fleets, the reactivated. I was just wondering if you could comment on sort of the pricing dynamics in the market as of overall supply and demand and what you're seeing given where gas prices have been doing or et cetera?

Matt Wilks

Yes. I think I think the top line, the market is it's flattish. And so we're coming in. We're adding fleets in an environment where where there's not an increase of active fleets in the market so that that is that is have an impact on top line. But the utilization and absorption of costs and reducing our per unit costs across across the business far outweighs any concessions we make on the top line, and we expect that trend to continue as far as cost.

Got it. Appreciate the color. And then just shifting gears to the proppant segment. Just wondering if you could comment on the current spot pricing for frac sand. And I guess just kind of your exposure to that market, given your comments on contracting year to date QUARTER.

Matt Wilks

I'll defer to Matt Zinn on this one.

Ladd Wilks

We're still seeing spot pricing in the in the 20s, depending on the market up into the 30s and some other segments not necessarily the Permian, and we continue to see some exposure to that market. But our focus is continuing to grow. Why are long longer term supply term agreements with customers and have a minimal exposure to the spot market.

Yes, I'd appreciate it. If I could just squeeze one more. And I was just wondering if you could provide some additional color on your 24 free cash flow expectations and any kind of target think about the leverage ratio exiting the year on services?

Matt Wilks

I don't want to guide too aggressively, but we expect to generate a tremendous amount of free cash to pay down debt. And it's not unreasonable for us to be able to cut our our debt in half this year.

Got it. I appreciate the color. And with that, I'll turn it back.

Operator

Arun Jayaram, JPMorgan.

Arun Jayaram

Good morning, gentlemen, I wanted to see if you could give us a sense of the type of pricing concessions? And did you yield caught relative to the leading edge in order to improve the utilization from the beginning of the fourth quarter? And thoughts on Could this what has been maybe the reaction to from your peers from some of your market share gains and could this do you worry that this could have a maybe a destabilizing impact on the level of pricing discipline that we did observe in the industry last year?

Matt Wilks

Morning, room. I really don't care what it does to our competitors. I don't spend a lot of time thinking about them. We're doing what's right for Pro frac. We're taking market share. We're not going to hold up pricing to their benefit and cede market share to do it. We're taking our market share back and I don't really care what it does to them. What I like what it does for us.

Arun Jayaram

Got it. Got it. And Matt is Ladd mentioned a target to get to $20 million to $25 million in EBITDA per fleet, but we're just trying to do to think about our modeling on the next couple of quarters. Where do you think you're at from from a profitability perspective as we sit here today, as we sit here today, high 10s, I think, okay, so mid to high 10s then in before this half in, we expect to be in that 20 to 25 range. Understood. Understood. Then Magnus, I think the biggest driver for it is cost absorption and utilization rates diluting diluting our cost per unit.

Ladd Wilks

Right, right. And then just maybe, Matt, your perspective what are the recent things that we have seen as we've seen, call it, five natural gas companies, Cotara just become staggering TT. and CNX. now pulling back on CapEx. Could you talk about some of your just natural gas exposure today and just maybe potential impacts to the frac and profit side of it?

Matt Wilks

The businesses? Yes, we've got about a third of our business exposed to gas markets. And we just we don't have a crystal ball. We don't know when the gas market's going to come back. We don't know how deep or wide this this gap is going to be. But we're committed to these basins and we are big believers in the demand drivers that are coming later this decade. So we're staying committed to our our customer base. They're staying committed to these basins and welcome a huge increase to duck inventory and then hope for an improving commodity.
Thank you.

Operator

Dan Katz, Morgan Stanley.

Eight, thanks to morning and maybe just another one on the property business. You guys have kind of touched on some of these points already, but just wondering if you can expand at all on on some of the drivers that are contemplated in the with utilization upside that you guys flagged and, you know, in terms of will it be internal or external a particular basin for a lot of potential customer types and, you know, tailwind from more proppant per well from a well design perspective. Just wondering if you could give us any more color on on the drivers of data.

Matt Wilks

I think it's 65% to 75% utilization target both later this year? Thanks.
We continue to see improved demand on our Permian assets specifically and increasing utilization there. And it's a combination of third-party and internal. What the focus right now is making sure that all of our customers are provided great service and great product, and we're continuing to focus on those areas in South Texas and the Permian are the greatest utilization drivers for increase.

Ladd Wilks

Great.
Thanks. Appreciate that color. And then I'm apologies if I missed this, but but wondering if you could give us an update on e-frac kind of what your nameplate capacity is now. I mean, those fleets are working on what what and our four were from the newbuilds that were that were maybe whilst last year? And also more broadly, what plans are for Avon or dual fuel upgrades maybe in your 2024 budget?
Thank you.
Yes, fuel efficiency continuing to be a major theme in the in this industry. And it's a it's become a really strong demand driver for us. We're not at full utilization on our equally, but expect to be this year. Again, this goes into how much operators spend on on on diesel. We've been able to eliminate as much of that cost as possible and grow margins alongside it. So that everybody wins. I'm sitting on the E fleet front. We expect to be fully utilized this year, working with operators. They're very interested in a turnkey solution. That's everything from gas power gen along with your E fleet. And so we've begun to find a high degree of success in bundling that as a turnkey solution and expect that to get us to full utilization this year.
Great. All makes sense and appreciate the color. Thanks a lot. I'll turn it back.
Thank you.

Operator

John Daniel, Daniel Energy. Please proceed with your question.

John Daniel

And again, thanks for having me, Matt, in the press release, when you know the big step-up in the pumping hours in January and February. Is that a function of just less white space on the calendar? Or is there something from a job design, which is letting you get more hours per day for both it's more associated with calendar efficiency. I mean our crews are amazing. We get out. And regardless of customer type, we're easily pumping 2020 plus hours every single day that they have available to pump. But the question is, is that 18 days per month or is it 28 days per month?

Matt Wilks

Right. And so going in working with customers on their program, making sure that we're aligning our interests with the right customers. And when you look at our revenue per pump hour, we recognize that we have to be a little bit more competitive with customers that can give us 28 or 30 days a month pumping. But what we see from getting more pump hours per month and the dilutive effect on our cost structure, it's more than worth it for us to come in and provide some some top-line concessions.

John Daniel

Okay. So I'm trying to translate here. It sounds like you would think you've got a better customer mix today than maybe four to five months ago.
Is that fair statement?

Matt Wilks

But we love all of our customers. But as far as customers that can give us a high percentage of pumping days per fleet. It's the highest it's ever been. This is the highest account. This is the highest calendar efficiency that we've ever seen from our customer base.
Okay. I got another one here, and this is not meant to be I got your question, but when you talk about full utilization later this year, are you assuming the US working frac crew count for the whole industry is growing or is this more increased market share?
So when you look at the industry, I think we suffered from our from our own failures in 2023. And we come in we've come into 2024 with a deficit of our own that when we overcome that deficit from we'll outperform our peer class just from from stabilizing the business to where it should have been the whole time. And this we expect this to happen regardless of what the total market does.
All right. And then one final one for me is probably more for Matt on the sand side. But can you speak to any RFPs inquiries in terms of not looking for price point here, but just the level of inquiries for sand, maybe back half of the year out of the Haynesville mines, are they starting to talk about that or is it too early?
We're constantly talking to our customers about their timing. I don't know that there's necessarily an RFP season for that regions, so to speak. But we are closely aligned with all the major operators in that basin, and we're talking to them regularly about their upcoming programs and where they think their activity may shift based on gas.
Okay. Fair enough. I'll leave it that. Thanks for including Thank you again.
Yes.

Operator

Tom Curran, Seaport Research Partners.

Tom Curran

Thank you for joining the call from. Great to know you a little bit better at opening question for you. Could you share some color on the nature of where the CapEx spend will be going for Alpine this year when it comes to your own budget, we evaluate all our CapEx based on improving utilization. We're lowering cost structure, so improving reliability or lowering the cost of manufacturing. So that's our key focus is where our demand is and where we can lower cost or improve reliability. So the places that we have growth opportunity are where we're going to have the most banks.

Lance Turner

Yes, got it. And then when it comes to utilization, could you tell us one where you exited the quarter at utilization wise and then to go from there to, let's say, north of 70%, what do you expect the split to be between internal feeding that Pro frac expected active fleet ramp.
And then third party sales again in the ramp from where you exited utilization wise to, you know, climbing north of 70% like you're targeting approximately two thirds of the ramp is external customers and a third of the ramp is internal just rough numbers. We continue to see strong demand based on our footprint in the Permian with large operators that have drilling programs, completion programs that spread across the basin, and we continue to see strong demand as well.
It's out to those customers about their operation and at this point, Matt, would you say, you know, you've got all that demand in hand in whatever different forms might exist contracts, you know, our dedicated acreage carrying mutual interest, whatever the nature of how you've secured that demand, you have it. And it's just a question of executing from here on the third-party side, we have yes, we have line of sight and we're currently negotiating supply agreements as we speak, have an assumption on a certain percentage of those being executed goes into that number. And then we'll execute like we have for years and years.
Got it.
Okay.
Thanks for taking my questions.

Operator

Thank you. Our next question comes from the line of Don Crist with Johnson Rice.

As end of your question Morning, gentlemen, just one question from me.
I remember from past conversations that the utilization of the sand plants was somewhere in the 50 ish percent before you acquired performance.

Matt Wilks

Is that a pretty good kind of bogey to start with and kind of where do we think it's going to go, you know, year over year as we kind of ramp towards that 65 to 75 plan?
Yes, our historical utilization of our mines has been around that 50%. And we as we've become more focused on third party agreements, that's where the ramp comes from.
Right. So we should expect somewhere in the 50% year over year kind of bogey for modeling purposes?
Correct.

I appreciate that everything else has been answered. Thank you.
Thank you. And this concludes our question and answer session. I would like to turn the floor back over to management for closing comments.

Matt Wilks

Thank you, operator. And the takeaway today is that we are aggressively focused on growing value for us for all stakeholders. And we have a plan to get it done, and we look forward to sharing our successes in the coming quarters as we increase utilization and drive improved results. We look forward to speaking with you again on our next call.

Operator

Ladies and gentlemen, thank you for your participation. This does conclude today's teleconference. You may disconnect your lines and have a wonderful day.