Welcome to the Liberty Energy Earnings Conference Call. All participants will be in listen-only mode. [Operator Instructions] After today’s presentation there will be an opportunity to ask questions. Please note this event is being recorded. I would now like to turn the conference over to Anjali Voria, Director of Investor Relations. Please go ahead.

Thank you. Good morning, and welcome to Liberty Energy's first quarter 2024 earnings conference call. Joining us on the call are Chris Wright, Chief Executive Officer; Ron Gusek, President; and Michael Stock, Chief Financial Officer. Before we begin, I would like to remind all participants that some of our comments today may include forward-looking statements reflecting the company's view about future prospects, revenues, expenses or profits. These matters involve risks and uncertainties that could cause actual results to differ materially from our forward-looking statements. These statements reflect the company's beliefs based on current conditions that are subject to certain risks and uncertainties that are detailed in our earnings release and other public filings. Our comments today also include non-GAAP financial and operational measures. These non-GAAP measures, including EBITDA, adjusted EBITDA and adjusted pretax return on capital employed are not a substitute for GAAP measures and may not be comparable to similar measures of other companies. A reconciliation of net income to EBITDA and adjusted EBITDA and the calculation of adjusted pretax return on capital employed as discussed on this call are available on our Investor Relations website. I will now turn the call over to Chris.

Thanks, Anjali. Good morning, everyone, and thank you for joining us to discuss our first quarter 2024 operational and financial results. As we enter the fourth year of what appears to be a durable cycle for North American oil and gas production and development activity, consolidation across the energy industry is pushing larger companies to seek technical solutions and expertise to drive value creation. Liberty's strong first quarter results demonstrate the continued benefits of leading the industry in technology innovation, service quality and investment in talent. Over the last year, the operations team delivered our highest combined safety performance and average daily pumping efficiency in Liberty's history. Our 32% adjusted pretax return on capital employed for the 12 months ended March 31, 2024, represents the continuance of our history of strong returns. I'm proud of the continued outstanding results our team achieved during a period marked by softening industry activity trends. Exceptional operational execution and deep customer engagement drove strong first quarter revenue of $1.1 billion and adjusted EBITDA of $245 million. We generated strong cash flow and distributed $42 million to our shareholders in the first quarter. Since July 2022, we have now distributed $417 million of cash to shareholders through the retirement of 12.5% of shares outstanding plus cash dividends. We remain focused on generating strong returns and free cash flow. We are pairing investment in profitable growth initiatives that increase our competitive advantage with a robust return of capital program. We are leading a generational shift towards low emissions, capital-efficient natural gas-fueled technologies. Our comprehensive solution from critical power generation to the CNG fuel supply supports our digiFleet deployments and uniquely serves our customers in their development of oil and gas resources. Furthermore, a growing demand for power from AI-driven data centers and reshoring of industrial and…

Good morning, everyone. We started the year delivering solid first quarter results, fueled by a concerted effort to deliver a superior reliable service to our customers. By focusing on meeting the increased complexities of our larger growing E&P customers, we've been able to mitigate the challenges of a softening industry demand during the last four quarters and deliver a strong return on and return of capital. A more sophisticated customer base requires tailored solutions that are best served by technology investment, scale and integration, and we have aligned ourselves with these customers by meeting and exceeding their growing demands. In the first quarter of 2024, revenue was $1.1 billion compared to $1.1 billion in the prior quarter. Our results were flat with the prior quarter, in line with our expectations and as our pumping efficiencies and integrated services offset lower sand and other consumable prices and market headwinds. The first quarter net income after tax of $82 million compared to $92 million in the prior quarter. Fully diluted net income per share was $0.48 compared to $0.54 in the prior quarter. First quarter adjusted EBITDA was $245 million compared to $253 million in the prior quarter. Frac markets have softened since the height of late 2022 and early 2023, but now appear to have stabilized since late last year. Our first quarter results were relatively flat with the fourth quarter, in line with our expectations. General and administrative expenses totaled $53 million in the first quarter and included noncash stock-based compensation of $5 million. G&A decreased $2 million sequentially as prior quarter performance-related compensation was modestly higher than the current quarter. Net interest expense and associated fees totaled $7 million for the quarter, relatively in line with $6 million in the prior quarter. First quarter tax expense was $26 million,…

We will now open the line up for your questions. The first question comes from Roger Read with Wells Fargo. Please go ahead.

Yes. Thank you, everybody, and congrats on the quarter. I'd like to just follow up on the issues of pricing. We did see a competitor say they wanted to go grab market share. You've obviously got a lot of things that will push back against that, the better fuel pumps and everything like that. But I was just curious how that market dynamic is working here.

Yes. Good morning, Roger. Look, the industry conditions probably peaked about 6 quarters ago in the fall of 2022. And it's really just because that's when the fleet count peaked. And the fleet count has sort of gently moved down since then. And if the fleet count is going down, you've got incrementally negative pricing pressure. This is compared to any other downturn. This has been a very slow, very modest gradual pullback. And I would say that pricing pressures are in line with that. They've been modest and gradual. And there's much more in choosing who you're going to use than just price, right? It's quality and technology and way of doing business. So as we've said, there is very modest pressure on pricing, but I would say not meaningful. And we're probably near a bottom in fleet count activity. I don't know that it moves up meaningfully, but when it does start to gradually move up, we'll see sort of pricing pressure modestly in the other direction. So for us in the Liberty world, the pricing story remains relatively boring.

That's good. And then kind of following on your comment there. I mean, at some point, gas prices recover here and we get more activity in the gas regions. Any indications from any of your customers kind of where we are in that process or maybe what they need to see to start going the other direction? Is it a change in production? Is it just price driven? Is it synced up with the LNG export increases?

Yes. I think customers are pretty thoughtful about that, and there is a constant dialogue about that. But I think, yeah, I think customers need to see that prices have firmed that, that export volumes demand actually is pulling upward at a meaningful rate. And that they've got some comfort that the next 12 or 24 months, prices are going to be much more constructive than they look today. So that's not imminent. That increase in gas activity, it could be as early as the end of this year. It might not be till next year.

Okay. Appreciate it thank you.

Thanks, Roger.

Our next question comes from Stephen Gengaro with Stifel. Please go ahead.

Thanks. Good morning everybody. Two for me. One is just a clarification. I think, Michael, you mentioned the second quarter guide for revenue. But you also said -- I think you said low double-digit EBITDA growth as well. I was just -- I wanted to ask how we should think about sort of incrementals in general, if you don't want to apply it directly to the second quarter because this -- I would think EBITDA will grow faster than revenue, but just curious your thoughts on that.

Yes, I did say low double digits, kind of a similar growth on EBITDA versus revenue. Yes, I mean, as we move forward, there is some change in mix as you go through this process. We're helping our clients as they are moving back to Liberty sourcing some of their consumables, sand and chemicals, which have a lower margin pass-through than service revenues. Service revenues is relatively service pricing relatively flat, and that's sort of where we get to that so the 25% to 30% incrementals.

Great. And then the second question I had was, when you think about -- and I'm sure you guys have done some of this math, you think about current U.S. oil production levels and you think about frac activity and drilling activity, where do you think we stand as far as industry activity versus what's needed to hold production at current levels?

That's a fine balance. My guess is the activity level today is probably consistent with flat U.S. oil production. I know we saw a big decline in January. I think that's monthly fluctuations. But we're certainly not at an activity that will meaningfully grow U.S. production. Probably activity today is flat on oil production. And look, if prices stay where they are, you're going to see a little bit of incremental activity from privates later this year. And are we ultimately going to end the year with some modest production growth, probably.

Okay. Great. Thank you.

Thanks, Steven.

Our next question comes from Stephen Gengaro with Stifel. Please go ahead. I'm sorry, Neil Mehta with Goldman Sachs. Please go ahead

Good morning team. A really solid Q2 guide. I guess my question was really focused on the back half of the year. And as you think about the back half versus the first half, to be kind of in that flattish territory versus last year of EBITDA, there would be a ramp. And I think there are a lot of reasons, I think we do ramp in the back half. So just be curious on your perspective team on some of the drivers in 2H versus 1H.

Yes. I mean what I mentioned is oil prices. If oil prices stay where they are, I think we'll see more activity from private operators in the second half of the year than the first half of the year. I would say for the larger publics, flat -- pretty flat activity going forward.

Yes, you're going to get the roll off of Canada. We've already seen the drop in the gas basins. I think that's already baked in. And that's where we see to get to that flattish guide for the year.

Okay. All right. That is helpful. And then we didn't talk about return of capital yet. So I just love your perspective, the business is starting to generate real free cash flow, balance sheet in good shape. So how do you think about returning excess cash to shareholders? And what are other calls on that cash, including the potential for bolt-on M&A?

Yes. Those are decisions we discuss, debate, wrestle with every day. We have a strong core business and key for us there is competitive advantage. We've got it every day, not last year, not last month, every day, we've got to deliver a better service quality than our competitors. And that's humans, that's training, that's culture, that's technology, that's investment and all those things. Obviously, we've got this larger scale transition to gas burning activity. I think we've pretty much laid out a plan for that. We're probably at the peak level of that right now. So as you go into future years, we'll continue to invest in new technologies, but the investment in the frac fleet probably gradually rolls down in the coming years. We've got this new LPI business that's quite exciting, but we're going to go at a slow and measured pace this year in this new business line. Right now, it's about nailing the technology and the execution of delivering on-site oilfield electricity to run our operations. And then, of course, maybe the most compelling investment we have, although we have to balance it is to buy back our own stock. We've got a very strong return on capital, an incredible competitive position. We still trade at a single-digit price to earnings ratio. So yes, of course, we're intrigued by that and don't see that likely changing in the coming quarters. But it's always a balance between all those things. We've always got to keep the business so that we have a strong competitive advantage and a bright future ahead of us. We can't ever just look -- just this year, we should only do this -- so to us, it's always balancing opportunities today and the outlook for the future.

Thanks again, team.

Our next question comes from Luke Lemoine with Piper Sandler. Please go ahead.

Hi, good morning. Chris, you talked about digiPrime, just the fuel consumption there versus Tier 4 DGB. But could you just also talk about maybe the first six fleets in the field, how those have been performing? And then Michael, I believe you said number seven is coming later this quarter, if you're still kind of going to 10 fleets by year-end are fleets eight, nine and 10 already allocated to customers?

They are. They are. As we've said since the start, the interest there is large. The interest is larger than the amount of fleets we can build. So yeah -- but yes, those fleets through the rest of this year, we know who they're going to and where they're going. So those plans are in place. But digiPrime is a very different technology. So we love the idea. The early operations, I would say, are great, but it's brand new. There's little things. Oops, yeah, got to change that. So we're tweaking the design or whatever. But the pumps that are out there, yeah, the performance is impressive. The power density, that super high thermal efficiency. So you're actually not just burning gas instead of diesel but less gas. So I think [indiscernible] around there. Ron, do you want to elaborate or comment anything on that?

I think you covered it well, Chris.

You got to come visit someday. We'll take you out to one.

Okay. Absolutely. Thanks guys.

Thanks, Luke.

Our next question comes from Arun Jayaram with J.P. Morgan. Please go ahead.

Good morning, team. I wanted to see if you could shed a little bit more light on the sequential double-digit sequential topline outlook for the second quarter versus 1Q. I'm trying to get a sense of if you're going to kind of dissect the drivers of that growth between more efficiency or pumping hours on existing fleets, you've obviously added a couple of digiFleets I think in 1Q and also between LPI. Just help us think about what's driving the sequential growth?

One thing is just calendar, right? At the start of the year, you got weather, you've got people with different plans with programs. So probably the single biggest thing is just a fuller, more robust calendar. I'll let Michael add -- so are these other factors, but I think that's the biggest one.

Correct. We had very, very strong pumping efficiencies, and we expect that to continue or as it always does, slightly improve, especially as we get into the better weather. And then as Chris said, you're putting that over a stronger calendar with less whitespace days, you have a little move, obviously, with the technology, which is helpful on the price side of it, offsetting. And then you've got that being offset by, to some degree, as we look and we help our clients save money on sand and consumables and that general market price on those sands has come down, which has been very helpful to our clients. So it's a balance of all of those things Arun.

Fair enough. Chris, we get a decent amount of questions on LPI. So I was wondering if you could just give us a sense of how big that business is your future growth opportunities for that segment? And maybe talk a little bit more about the LAT or the Liberty Advanced Technology, which you talked about earlier in your prepared remarks.

You bet. I mean, look, LPI today is relatively small business. Today, it's about building. It's about building infrastructure team, technologies, understanding systems. What does LPI do today? It delivers natural gas to our on-site electric generation to power our digiFleets and also the dual fuel fleets and of course, digiPrime fleets. And it doesn't supply nearly all of those fleets today. So this is early stage in that business. But I think it's got -- as you've heard us say, just tremendous, tremendous growth opportunities. But key to securing that growth is securing the technology, the operations and the supply chain. The inbounds we get now for just needs for electricity. I mean, it's just we -- and look, I've been outspoken about this for many years. We have followed very poor policies in this country for our electrical grid, and we fragilized our electric grid with constant demand. Demand has grown very slowly over the last decade. And even with very little demand growth, we've driven prices up, reliability down and now that that grid and those policies are colliding with rapid growth in demand for electricity. So this is going to cause some bumps and struggles for our country. I wish it wasn't, but LPI will be -- we'll see tremendous business opportunities in providing firm, reliable, affordable natural gas generated electricity. So the future of LPI is tremendous. But is it a big business today in Liberty? No. But will it be a big business in the future? We think it will. And LAT is super exciting as well, and I'm going to let Ron tell you a little bit about what it is and why we're doing it.

Yes. Look, from -- probably from going back to six years now, I guess, 2018, we made a pretty conscious decision around getting into some vertical integration around manufacturing capacity. That started with our ST9 acquisition and a decision around bringing in-house the ability to control the design and ultimately manufacture and assembly of a pump. As we fast forward to today, we're in the middle of this transition to next-generation equipment. We control the design of digiFrac from the ground up. We've done the same with digiPrime. And it makes sense for us now to control that entire packaging process and particularly the engineering design and control of that in-house. And so LAT a very conscious decision for us to do exactly that, which is to be able to take -- the feedback we're hearing from the field, the input from our customers, opportunities we identify for even advancing the technology beyond where we are today -- implementing that in our engineering design and then handling some amount of that packaging internal to our organization. We still have some great third-party packagers out there that have been partners for a long time. We'll continue to work closely with them as well, but we're going to do some amount of that baseload work internally and particularly retain control over the engineering, design and innovation in that side of things.

Great. Thanks.

Our next question comes from Scott Gruber with Citigroup. Please go ahead.

Yes, good morning. A question here. With Waha Gas turning negative, I'm just curious whether you have any frac contract set up where you supply the fuel costs such that you can directly benefit from negative gas prices or is the benefit to Liberty mainly indirect the rate resiliency for e-frac and dual fuel, that lower negative gas prices provided and growth opportunities for LPI. Just kind of wondering how the benefit flows to Liberty.

Yes. Today, it's indirect. Today, we don't capture the benefit of that. But will we in the future, you bet we will. And think of it even outside the oilfield. We're going to sell electricity. Gas is going to be an input cost, and we're going to sell it in different places and different setups with different commercial arrangements. So yes, we're excited by that. But right now, that benefit -- well, that benefit goes to our customers, but of course, they also have the downside of selling gas into that market. So no, today, we don't benefit from that. But it, of course, is just a further tailwind of why it just makes more sense when you can do it to power large industrial machinery with natural gas instead of diesel. Diesel is an awesome fuel that powers the world and it will for decades to come. But when you've got infrastructure and when you can bring gas and you can take large machinery and powered on gas versus diesel. It's just cheaper, more abundant, lower cost, lower pollutants and lower greenhouse gas emissions.

Got it. And then I wanted to circle back on your comments regarding private potentially picking up activity later in the year. Is that mainly just kind of a function of time with privates need to accumulate more cash following the rebound in oil or is there a egress factor here, particularly in the Permian, do you think privates wait for Matterhorn to start up and see better egress for natural gas out of the basin?

Well, look, it's a bit of a combination of all of those, but I do think Matterhorn matters because -- look, in the Permian, incredible basin, but it's a lot of pretty gassy production. So oil drives economics, but gas matters too. So yes, when we get more pipeline capacity and there's value or less negative value from gas, definitely in addition to oil prices, that will further improve economics of drilling. And look, we're not expecting some huge surge or increase in activity. But on the margin, if you were a private operator, would you be more likely to produce later this year than earlier this year. If oil prices were similar, yes, definitely later this year is going to be a better decision.

That make sense. Thanks, Chris.

Thanks. Yes, good guestions.

Our next question comes from Derek Podhaizer with Barclays. Please go ahead.

Hi, good morning, guys. I wanted to go back to LPI. You talked about the opportunities outside of oil and gas, looking specifically at the AI data centers. Could you help frame this market opportunity for us? And how you think about that potential earnings power over the medium term? I mean will we be talking about decade-long PPAs, just more stable earnings. Just a little bit more how to think about that AI part of the business.

Yes. It's going to be a different business. But key for us, it's going to take the same expertise and the same technology we're developing today. That for us has always been the excitement of this. We're not taking a flyer on some crazy idea. We have always thought for our frac operations it's just essential to control the power of your fleet. And so for us, we're building that infrastructure to deliver fuel, generate electricity and run our operations, but we've known from the start that, hey, by developing that expertise and that ability to power our own fleet, of course, we can do all sorts of different things with those. And look, it's early on. These are -- we're in dialogues now. But this year is mostly about developing the technology, the expertise and the delivery of that remote electricity to our frac fleets. It's not outside oil and gas, that's not a 2024 thing. We probably see the start of that next year. But to your original question, yes, are they going to be some larger projects? Are there going to be some more stable many, many year contracts, yes, there will be. And so to us it's development expertise that helps our core business that will always be a key part of our core business. But yes, it's going to give us a leg up and an entree into a marketplace that just -- that is struggling already with the dearth of power. You've got customers for your data center or for your industrial operations, but it's hard to get affordable near-term additional power to any industrial activities in this country. We should not be in this situation, but we are, and we're going to be in this situation for years, many years. So for us, yes, we should probably give more color later. But yes, it will be a long-term, a little bit more -- probably a fair amount more stable leg of a high return profitable business for Liberty.

Understood. That's helpful. Switching back over to frac. Just want to think about the fleet count for the remainder of the year. And maybe just the interplay of adding additional digiFleets. You talked about six going to 10, retiring Tier 2 diesel fleets, I think you guys had 100 Tier 4 diesel fleets being upgraded to the dual-fuel DGB -- and just getting a sense of what's going towards incremental fleets versus replacement fleets. So just your overall view of high-grading the fleet mix as we work through the year and how that may help the ramp that you're expecting in the back half of the year?

Yes. Today, it's all about replacement fleets. We're not adding new fleet capacity into the marketplace as it is today. And in fact, we don't have any plans to for later this year. So this is about replacing existing equipment with next-generation equipment that has a lower operating cost and a higher profitability. Ron, do you want to add anything or comment on that, but it's definitely not about going from six today to 10 digiFleets, that's not four new fleets going to the marketplace. That's zero new fleets going into the marketplace.

Got it. Great. Appreciate the color. I’ll turn it back.

Thanks.

Our next question comes from Marc Bianchi with TD Cowen. Please go ahead.

Thank you. I wanted to first clarify on the EBITDA outlook for the year to be flat. Should we be taking that message as a literal comment? So you did $1.2 billion of EBITDA in 2023. Is the expectation that it's $1.2 billion in 2024 or could it be down 5% to 10%, and it's still sort of is close enough to being flat that it would qualify for that statement?

We've been very specific flattish, Marc, flattish. So yes, so yes. So no, it's not saying it's a little flat, $1.2 billion to $1.2 billion. No, it is going to be flattish so kind of within the rounding area that you discussed.

Got it. Got it. Okay. And then that still would imply some improvement in the back half. And it sounds like from what you're saying, there's a bit of what we just talked about with the digiFleet deployments helping some sort of customer-specific things helping and maybe a little bit of help from higher oil activity or maybe that's not the case. If you could just kind of clarify what the macro outlook is in the back half that's driving your results.

Yes. And so we've talked about Q2 versus Q1. Q3 historically is probably the best quarter of the year. I don't see any reason to expect that to be different this year. But yeah, that's why our guidance is flattish. We don't have a crystal ball. We don't know what will go on in Q4. We don't know specifically Q3. But if the activity stayed flattish where it is today, for us, we still have from internal improvements in our business and cost efficiencies and new technology deployment, we can still grow EBITDA in that environment. And typically, you face somewhat of a roll down in Q4, we probably see a little of that this year, but probably not so much because activity today is sort of flat production at best. So I think activities -- if there's a bias to change in activity six or 12 months from now, it's more likely to be up and down. But that's why our guide was sort of, oh, we're just flattish. We don't have a crystal ball for the end of the year. But in the current existing marketplace, how would Liberty perform, annual EBITDA would be flattish compared to last year.

Yes. Makes sense. And then, Michael, just one more on the free cash for the year, could you just talk to what we should be thinking of from a conversion of EBITDA perspective? Because first quarter looked like you had a pretty big working cap headwind. And I think earlier in the last call, you said you would expect that to be flat for the year. But just if we could talk about it in kind of how many dollars of EBITDA ultimately convert into free cash would be helpful.

We don't give those details. Things move around. But yes, you always get a build of working capital in the first quarter because of kind of Q4, the last 6 weeks is always the lowest part of the quarter and the opposite spectrum. We will see with growth in revenue, obviously, growth in topline, you're going to see a slight usage aside sort of build in working capital in Q2. You're going to see a kind of a release of working capital in Q4. So yeah, as we said over the course of the year, working capital will be about sort of flat for the year. But I mean, those free cash flow numbers are not quarterly driven. They sort of -- they have some little bit of sort of up and downs with it.

Okay. Thanks very much. I’ll turn it back.

Thanks, Marc.

Our next question comes from Keith MacKey with RBC Capital Markets. Please go ahead.

Thanks. Good morning. Just wanted to start out with customer consolidation, I didn't really hear that as a factor in the outlook. But certainly, there is a lot of rig activity that is subject to consolidation, particularly in the Permian. And we have noticed a slight downtick in rigs that are associated with consolidation versus the overall Permian rig count. And so certainly, they have to run the businesses independently before the deals close, but not necessarily the way they would have if there was no deal. So can you just talk about your exposure to customer consolidation and any potential impacts, positive or negative that you could see from the upcoming consolidation?

Look, your comments, I think are correct. There's been a continual consolidation at some pace the last 12 or 18 months, probably still continues. It does lead to incrementally a little bit less activity. That's probably why our production run rate today is that flattish, where last year we grew nearly 1 million barrels a day or over 1 million barrels a day in total liquids production. So a little bit lower activity. There'll be an offset of that, of course, because noncore assets are going to be sold off and new privates or existing privates will get bigger and it will fill a little bit of that gap, not happening today right now. But the bigger customers, bigger, more sophisticated customers on balance, that probably benefits Liberty, that's a better match for us than probably for most of the rest of the marketplace. So in these cases, we're much more likely to be more concentrated with the buyers than the sellers in those deals. So yes, it's been a small headwind for the industry and maybe a very small tailwind for Liberty.

Okay. Thank for that. Just maybe a little bit on Australia. You talked a little bit about the entry into the Beetaloo Basin. Can you just talk about where you are in that? I think some of the equipment was maybe getting ready to get transported. So just an update there would be helpful. And do you see this as really a one-off opportunity or are there other potential international opportunities that you might be looking at as well?

Look, we've been pitched about international opportunities almost as long as we've been a company. So the interest in having Liberty's engineering prowess in addition to horsepower and equipment and all that, the interest in that international market has been strong. Our view in the past has always been we're super loyal, and we move slowly. So we're in a basin like we're going to stick with our partners in that basin. We tend to have very sticky customers. We've slowly moved to other basins as we build more capacity or existing customers have pulled us there. So we've been more gradual in doing those things. But the [indiscernible] sort of checks two boxes. One is the gas in place is enormous. It's this tremendous gas basin that hasn't produced any gas yet, but could and should and when we talk about -- and you can read about it in Bettering Human Lives, the fastest-growing energy source on the planet over the last 12 years, by far, is natural gas. That likely continues in the coming decades as well. So Beetaloo is a huge resource base -- Australia itself is having struggles with domestic gas prices and gas supply and the projections there show things getting tighter. So there's a need for that gas there in Australia, you're right near the South Asia and Southeast Asian markets for it. So it's a big upside. And with the rollout of digiTechnologies, we've now -- we're bringing in new fleets, and we don't need new capacity. So we've got fleets going out the other side that we can retire or in the case of Beetaloo where we could send a fleet to Australia. And we've got good partners there, and I think we're levered pretty nicely to upside in that basin. But it's small. That's a multiyear thing for that to become meaningful, but could it become meaningful? I think we think it could. I'll let Ron update you a little bit more about like what's going on timing-wise and how that's going. But it's an exciting new opportunity for us.

Yes, just a quick update there, Keith. So we isolated a fleet of equipment, identified the assets that we're going to head over there. They've gone to a central facility for us. They are basically done their refurbishment program at this point in time, making sure that, that fleet is ready to operate in a relatively remote environment. So as we wrap that up, that fleet will ultimately move down to the Gulf Coast, and we'll have that loaded on a boat sometime here in the middle to latter part of Q2, and it will find its way to Australia -- should arrive there in early maybe mid-Q3. And then we'll have to work our way through customs and whatnot there before we have that on the ground and ready to work, but that's where we stand today.

Okay. Thank you very much.

Thanks.

Our next question comes from Waqar Syed with ATB Capital Markets. Please go ahead.

Hi. So we saw the data from EIA and North Dakota Oil and Gas Commission. It shows that completion activity in North Dakota Bakken was down about 24% quarter-over-quarter in Q1. And also in Wyoming, Colorado area, it was also down about 22%. Did you experience declines in work in those areas? And how do you see that kind of changing in Q2 and going forward?

Yes, absolutely the case. The Bakken historically has a very meaningful winter downturn and absolutely did this year as well, as you just pointed out in that data. So absolutely, the reduced activity in the Bakken in Q1 and also some reduced activity in Wyoming and Colorado. So yes, that data is true. I think we'll see -- yeah and that activity will rebound a little bit for the quarters for the rest of the year.

No. So that's a pretty big change in activity. How would the incrementals behave as a result? Wouldn't that be a pretty strong tailwind to incremental margins as that happened in Q2?

Well, the other thing is all of our assets are on wheels. So when activity declines in Bakken there's just less fleets working, we drive those fleets elsewhere.

Yes. That’s it. Thank you very much. That’s all I had.

Yes. Thanks Waqar.

Our next question comes from Saurabh Pant with BoA. Please go ahead.

Hi. Good morning, Chris, Ron and Mike. Maybe I want to start on the efficiency side of things. Like you noted in your press release, in your comments over the past 12 months, efficiencies have been really strong, right? And the obvious question is how much running room do we have, right? But as a follow-through on that, how much of the incremental efficiencies do you think come from pumping companies like yourself? And how much of that do you think is in the hands of the E&Ps, the operators in terms of maybe logistics or just the way they design the jobs and line up the supply chain? If you can just talk to that a little bit.

Yes. It very much requires both sides. You're on location. It's a dance between wireline and frac and your customer and logistics and supply chain and operations. It's also I would say one of the advantages Liberty has had. If you deliver the best quality, you get -- you can work with the best customers. So it is absolutely a coordination of all of those. And I'll turn it over to Ron, who's certainly been a leader in the engineering, innovation, the way to think about this and to find the opportunities to move progress.

Yes. Obviously, we continue to work on that. You saw we made progress -- incremental progress each and every quarter, one after the other. And so that's a credit to the operations team to our technical development team as we continue to find ways to understand more and more about how our equipment is operating to be proactive around things that could move the needle could put us -- could help us deal with some downtime. We're finding ways to identify those and react to them before they happen. And so that's a credit to the whole operations team out there. There's still opportunity there. We continue to find ways to move the needle on that. But the low-hanging fruit has gone a long time ago. These are going to be modest incremental improvements as we continue to take equipment to the next level, even as you think about digi, our next-generation technology, the time between overhauls on these gas engines look meaningfully different than it does on a diesel engine. As we automate the operation of the pumps, we can ensure increased longevity of components out there. So less time required for maintenance as we have worked closely with partners around things like hot swap technology, the ability to get a pump in and out of the red zone without having anybody step into place there around zero time between moving from wireline to pumping on a wellhead, strong partnerships as Chris mentioned over the E&P side of things, but also with other service providers out there that are bringing supportive technology to the table. And then also for us, of course, speaks to the vertical integration we continue to work on as we work on improving our logistics platform, the introduction of LPI and removing that reliance on third-party for natural gas, all of those sorts of things from an integrated services offering help us to ensure the highest possible efficiencies on location, and we'll continue to try to find little ways to [indiscernible] a bit more in that quarter-after-quarter.

Right. Right. No, that's very helpful. And then just one unrelated one. I'm just thinking about the medium-term, not just the very short-term, but I think as I remember correctly, Chris, Ron, you talked about 90% of your fleet being gas-fired by the end of the year. And some of your competitors have talked about similar numbers, not exactly 90%, right, but a large majority of the fleet being gas-fired. How should we think about that if we think a couple of years out from now and a lot of the working fleet at least maybe not the total inventory, but the working fleet is gas-fired? At what point do we think about more gas-on-gas competition versus just displacing diesel like we are at this point?

Absolutely. But we talk about fleet technology a lot. That's a positive development for the industry. It lowers cost and all that. But it's not determinative. A fleet is in a good fleet or a bad fleet based on what it burns, that's just one factor. The single biggest factor by far and away is that humans running that fleet, the quality of operations, the quality of the supply chain. We don't talk too much about this, but we've had certainly multiple examples where a Liberty diesel fleet is displacing a 100% gas burning fleet. And it's just for quality of operations and people. Customers just -- it's not just the fuel it takes. That's just one factor. It's mostly about humans and service quality. And so yeah, that is a spec but not the spec.

And I would maybe go a step further than that and say it's also important to remember that not all gas fleets are created equally. There are significant technology differences between the opportunities out there to consume gas. We have been very, very specific about the technologies we have chosen to invest in and deploy in the field, both in digiPrime and digiFrac around ensuring that the gas burning technology we deliver in the field is the highest efficiency, lowest fuel consumption and as a result, lowest emissions footprint on location. That's not true for all gas burning technologies.

No, I think that makes sense. Execution often tends to be the unsung hero. And then, Ron, I think you talked about that on the LAT side as well, right, so it makes sense. Okay. Thanks. I’ll turn it back. Thank you.

Thanks, Saurabh.

Our next question comes from John Daniel with Daniels Energy Partners. Please go ahead.

Hi, guys. Thanks for including me. Just, Chris, given the demands for power over the next basically decade, how far out are you guys having to place orders for content on your equipment and for LPI?

Supply chains are tricky. Supply chains are tricky. There's a lot of dialogue going on about that. I probably -- I won't comment on any specifics there, John, but you do identify a real issue. It's -- there is not a surplus of such equipment.

Okay. Do you -- and I don't know if you can answer this, but I'll ask it anyway. Is there any risk that the major OEMs pivot and allocate more product to data centers directly to the detriment of oil and gas?

That's happening today. That's happening today. It was one of the reasons, John. As you know, we've held this belief of what's going on with the electricity market for years. So when we got into building our digiFleets, it was -- if we count on a third party that's going to do that, a third party is not necessarily an oil and gas company, if the market switches and they can drive all those things over to data centers or for manufacturing thing -- but no we're at the mercy of a business that's not ours. And we just decided that was a risk we didn't want to take.

Okay, make sense. Thank you for [indiscernible]

Thanks, John. Take care.

This concludes our question-and-answer session. I will now turn it back to Chris for closing remarks.

Thanks, everyone. In early February, we released our comprehensive report Bettering Human Lives 2024 that covers energy, climate change, poverty and prosperity. I spent many weekends and evenings writing this report. But what I'm most proud of was not written by me. It was the words in the letter from Anne Hyre, the Executive Director of our newly formed Bettering Human Lives Foundation. The BHL Foundation is the culmination of our studies into the world's biggest solvable problems and our passion to play a meaningful role in changing the lives of millions. Anne's letter says it best, and I will read the full text now. Despite significant cultural and geographical differences among countries in Sub-Saharan Africa, the scenes outside the window as I drive from town to town are remarkably similar and all include women and girls standing in lines at water pumps, walking in groups in search of firewood and cow dung and carrying heavy loads of firewood and water filled buckets, whether in Malawi, Burkina Faso, Ethiopia or Kenya, I pass clusters of homes and see women cooking amidst harmful smoke from open fires that are fueled by wood or cow dung. We are in the year 2023. How is this acceptable? I feel so disheartened that the daily lives of women and girls in many lower-income countries continue to be filled with tedious physically demanding and often dangerous task of collecting fuel and water for cooking, cleaning, laundry and heating homes. I am a nurse midwife and I've spent 30 years working to improve quality health services for women during pregnancy, childbirth and the postpartum period. For 25 years, I worked primarily in Southeast Asia, where access to energy and economic growth contributed to visible progress in improving health and quality of life. For the past five…

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