Good morning, and welcome to the Liberty Oilfield Services fourth quarter and year-end 2020 earnings 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. Please note that this event is being recorded. 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 the company's 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 Pre-Tax 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 Pre-Tax Return on Capital Employed, as discussed on this call, are presented in the company's earnings release, which is available on its website. I would now like to turn the conference over to Liberty CEO, Chris Wright. Please go ahead. Thanks, Tom. Good morning, everyone, and thank you for joining us today to discuss our fourth quarter and full year 2020 operational and financial results. Wow. What a year for the world and our industry. I'm so proud of our team here at Liberty, weathering the storm of COVID impact with tenacity and strength and ending the year with determination and resolve in building a better company. We successfully navigated these challenges with the unprecedented sacrifice and commitment of the Liberty family. We enter 2021 with excitement as Liberty will celebrate our 10th birthday as a company. While we are very proud of what we have achieved in our first 10 years, we're even more excited about what the amazing group of people that make up Liberty are going to achieve in the next 10 years. 2020 marked a transformative year in our short history. We started the year in a frac market that was already struggling with pricing due to an oversupply of equipment and reduced completion spending. We rolled into the storm of worldwide COVID infections that led to a brief 25% drop in oil consumption by April of 2020 and oil dropping into the $20 a barrel range. Liberty reacted quickly and changed our cost structure to meet the new market reality. We worked with our E&P partners to plan a way through the crisis to make sure that we reach the other side with the strength to take advantage of an inevitable rebound. By our signing a deal with Schlumberger to acquire their OneStim North America frac completions wireline and Texas sand businesses in the summer of 2020, we are in a stronger position to capitalize on the nascent industry recovery. We have brought back frac fleets to work as our core customer partners restarted completions, and we ramped back up to 15.8 average active frac fleets in the fourth quarter. Most importantly, these fleets performed with a sterling safety record, and we set a company-wide operational efficiency records in Q4. This ramp-up represents a 68% increase from the third quarter and up from a low of 4.6 average active frac fleets in the second quarter. Revenue for the full year 2020 was $966 million, down from pre-COVID affected numbers in 2019 of roughly $2 billion. adjusted EBITDA for the full year was $58 million, driven by a relatively strong first quarter. Our fourth quarter revenue was $258 million, a 75% increase over the third quarter, driven by increased fleet count and the high efficiencies mentioned. Our fourth quarter adjusted EBITDA was $7 million, a $6 million improvement from the third quarter as frac activity continued to increase following an abrupt halt in completions activity in the oily basins during the second quarter. As we discussed in our April earnings call, our plan was to manage the balance sheet to cash neutrality during the historic COVID downturn. At year-end, our cash and cash equivalents were $68 million, over $10 million higher than at the end of the first quarter of 2020. We were excited to end the year closing on the acquisition of Schlumberger's North American pressure pumping business on December 31. We have laid the foundation for a new era of Liberty's leadership in technology and sustainability in the oil and gas industry. Our greatly expanded technology portfolio, breadth of operations, dedicated team, and historic Liberty focus position us to achieve even greater innovation and efficiency. We've had five weeks of engagement with our new team members as part of the Liberty family, and the enthusiasm is contagious. Both our legacy Liberty team members and new colleagues are already working together with a renewed level of excitement and dedication to delivering superior service quality and results in the field for our customers. We are excited to now have significant natural gas exposure as that activity is driven by a separate market with different cycles. U.S. natural gas demand dropped only about 2% in 2020, far less than oil demand. The global LNG market is strong right now, with prospects for 5% plus growth in the coming years. It is notable that even during a time of major transition, our new team members were able to drive strong fourth quarter sequential revenue growth of about 25% at legacy OneStim, a strong result. As we look ahead to 2021, we are excited by the opportunities ahead of us. We are still in the early innings of a recovery, but the clouds of COVID have begun to part and the global economy is on the mend. The rollout of COVID vaccines, fiscal and monetary stimulus policies around the world, and pent-up demand for goods and services reinforce a global economy that is on an upward trajectory. This provides the backdrop for continued improvement in energy demand, while controlled OPEC plus production, coupled with discipline among U.S. shale companies, is supporting oil and gas prices. This is reflected in a rising rig count throughout the fourth quarter. The number of total marketable frac fleets has declined significantly as the pandemic accelerated the pace of rationalization and cannibalization of frac equipment. As customer demand is shifting towards next generation technologies that support their emissions and efficiency goals, attrition of older equipment is expected to continue. Liberty's focus on reducing environmental impact since our inception with continued investment in technology through cycles, has allowed us to remain front and center with our customers in supporting this move by the industry, and moreover, deepening our partnerships during these challenging times. Operators are currently navigating through a time of industry consolidation, a changing political climate, and a commitment to keeping oil and gas production flat. Continued shrinkage of marketable frac fleets across the industry is a necessary part of moving the market towards balance. The current pricing dynamic remains challenging. Liberty is having many productive discussions with our customers to phase in modest price improvements throughout the year. Liberty was proactive in working with our customers as oil prices collapsed. That partnership works both ways. We believe the frac market will experience flat to slightly rising demand for frac services in 2021 based on current visibility into customer plans. Public operator demand is expected to be relatively level loaded, whereas private operator demand is more likely to be a bit backloaded. Against this backdrop, we enter 2021 with 30 fully staffed frac fleets working across all major basins except the Northeast. Liberty expects to maintain approximately 30 active frac fleets in the first quarter of 2021, with the potential of adding more fleets later in the year only if the economics improve. Increased efficiencies that lower our cost of delivery, coupled with a gradual modest rise in frac pricing, are the factors that can drive improved fleet profitability. We like our new mix of customers, including larger public and private operators with great assets, balance sheets, and most importantly, great people. It will take the right partnership and the right economics to add new fleets to the mix. Overall, we're off to a strong start to the new year. We are working hard to seamlessly transition our business into one thanks to the considerable efforts of our integration team. We are now a few weeks in, and the complementary customer partnerships, technologies, and business acumen across our teams has been an incredible value add. In the first few weeks of the year, we've had folks across all disciplines, notably operations, sales, and engineering teams, come together in our Denver offices, forming new relationships and finding new ways to collaborate and improve. It's been incredible. We now have new, highly complementary business lines to leverage greater control of the value chain, the capacity to move technology forward at a faster pace, our new digiFrac E-fleet on the horizon, and much more. Industry transitions take time, but we believe we're at the beginning of a new era in the industry, well-positioned with the right tools in hand. As we shared last quarter, it is the perseverance and enthusiasm of the team that sets the stage for Liberty to execute in 2021. I will now pass the call over to Michael to discuss our detailed financial performance, and then Ron will give a short update on the integration progress for operations and technology. Good morning. We're pleased to have finished the year on a positive note. Despite the immense challenges the team faced in 2020, our disciplined approach to managing the business was very effective. Frac activity improved meaningfully in the fourth quarter, and we were able to put more fleets to work faster than expected. The legacy OneStim business also saw significant improvement despite the inevitable disruption caused by the transition. We are so proud of the persistence and dedication exhibited by our legacy and new team members during the quarter, and we're excited to write the next chapter of our story as one united team. As we look forward, we believe we now have the right operations footprint in place for 2021. We currently plan on running approximately 30 deployed fleets in the first quarter and maintain those fleets during the year with some normal seasonal variation in the U.S. and Canadian markets impacting utilization in various quarters. I will talk further about our 2021 outlook shortly. For the full year 2020, revenue declined 51% to $966 million from $2 billion in 2019. Net loss totaled $161 million or $1.36 to its fully diluted share. Full-year adjusted EBITDA was $58 million, compared to an adjusted EBITDA of $291 million in 2019. Annualized EBITDA per fleet was $4.4 million, compared to $12.8 million in the prior year. Our adjusted EBITDA reconciliation now excludes stock-based compensation to more closely correlate to other industry reporting. Our focus in 2020 on managing capital expenditures was successful. We were happy to hit our target of positive cash flow from frac fleet operations during the last nine months of the year that were severely impacted by the pandemic. We were pleased to be able to reduce our full-year capital expenditures while continuing to invest in Tier 4 DGB equipment, our digiFrac E-fleet engineering and prototypes, and dual-fuel upgrades. All technology that is in high demand and investments in line with our philosophy of managing the businesses by focusing on superior long-term returns while maintaining balance sheet strength. For the fourth quarter 2020, revenue increased 75% to $258 million from $147 million in the third quarter. The increase in revenue was primarily driven by a 68% increase in active fleets and improved utilization as customers restored completions activity faster than expected. Net loss after tax decreased to $48 million in the fourth quarter compared to $49 million in the third quarter. Fully diluted net loss per share was $0.41 in the fourth quarter, equivalent to the third quarter of 2020. Results in the quarter were negatively affected by $11.1 million of non-recurring expenses, including transaction and other non-recurring costs of $9.4 million and fleet startup costs of $1.7 million. Fourth quarter adjusted EBITDA, which excludes non-cash stock compensation expense, increased to $7.1 million from $1.4 million during the third quarter. Improvements in adjusted EBITDA was driven by increased activity and utilization, driving higher absorption of fixed costs. General administrative expenses totaled $20.1 million for the quarter, including non-cash stock-based compensation expense of $3.5 million. Net interest expense and associated fees totaled $3.6 million, equivalent to the prior quarter. We ended the year with a cash balance of $69 million and a net debt position of $37 million. At year-end, we had no borrowings drawn on the ABL credit facility. Total liquidity, including $114 million of availability under that credit facility, was $183 million. As we laid out in our first quarter earnings call, we targeted managing the business to cash flow neutrality through the end of the year, we were pleased to be able to beat this projection. Given the considerable change in Liberty in the oilfield services market over the last year, I'd like to provide a preliminary view of our 2021 outlook. I remind everyone this is based on current macroeconomic conditions, there is significant uncertainty in the global economic outlook. As Chris pointed out, we are still in the early innings of post-COVID recovery. In the U.S., we expect a continuation of current frac activity levels through the first half, followed by potential gradual improvement in industry activity in the second half of the year, led by private operators, if the macroeconomic conditions are supportive. In Canada, we're anticipating normal seasonality with a stronger first quarter, followed by a seasonal recline in Q2, improvement in Q3, and a seasonal slowdown in Q4. We are planning to run approximately 30 average frac fleets during the first quarter, and we will evaluate changes to fleet deployments based on market conditions. We will add crews in the future only with a meaningful improvement in fleet economics. As Chris described, increasingly positive dialogue with customers suggests the frac market could see some modest price inflation as the year progresses. We believe there is a recognition amongst operators, and we work hand in hand with them to lower pricing during the 2020 energy crisis to ensure continuity of operations. Pricing at this level is unsustainable outside of the period of crisis management. We've had productive conversations with a number of clients and have plans in place to phase in modest price inflation during the year. With the OneStim acquisition, we have grown significantly, adding more frac fleets, the wireline business, and sand mines to the mix. We expect that general and administrative expenses in 2021 will only increase by high single digits from 2019 levels. We have increased our operating platform and will gain significant fixed cost leverage. Our first quarter will include approximately $10 million of non-recurring SG&A costs relating to the transition services provided by Schlumberger. Transition costs and services from Schlumberger will not continue after the first quarter. Capital expenditures are targeted in the $145 million-$175 million range for the year, and depreciation and amortization is estimated at approximately $240 million for the full year. Capital expenditures in the midpoint of range include maintenance capital of approximately $3.5 million per fleet, partially offset by the early stages of CapEx synergies tied to equipment slated for maintenance support. Annualized savings of approximately $1 million per fleet are expected to begin to appear in the second half of the year after our initial period of evaluation of the support equipment. We're also including approximately $60 million in technology investments, including digiFrac, dual-fuel upgrades, and Tier 4 upgrades. Lastly, approximately $10 million relates to the liberation and homogenization of our Blue fleets. Importantly, we have significant flexibility adjusting our capital spending targets depending on the market environment, and we plan to be free cash flow positive in 2021 while continuing to invest in the future. As we bring OneStim into the fold, Liberty is laser focused on building a business for the future where we are the partner of choice for people who run safe, sustainable, and productive operations. It is these efforts that will drive deeper customer partnerships and the superior returns we are known for. I'll hand the call over to Ron for a short update on the integration progress for operations and technology. We are excited to bring together two premier frac service companies, well-positioned to lead a technology-driven structural change in the industry. A change that is necessary from the viewpoint of our customers, suppliers, and investors. Our plan of execution is focused on three areas. Culture and leadership, technology development, and operational excellence. Right now, we're at the early stages, understanding what we're calling our Liberty Red and Liberty Blue teams are doing and why, and how we can leverage the best from each of the organizations. First, we've strengthened our leadership team to execute our vision with the combination of the Red and Blue heritage folks. These are the folks that will reinforce our culture of agility, idea generation, and empowerment, and drive collaboration across all our business lines to carry this business forward. Second, Liberty's history is rooted in the impactful utilization of real data and rigorous analysis. With our larger scale, we are now bolstering our knowledge base, representing a step change for innovation in the industry. We are creating a new technology leadership group to house all our innovation and engineering. This will accelerate the rate of development of our leading data-driven engineering simulation tools, leading-edge equipment design and technology development, innovation in ESG, and more. It is this collaborative model from start to finish that is key in driving value creation and the differential returns we've seen through our company's history. We were early movers in deploying dual-fuel capability, doing so in just our second year of business in 2013. We were an early field test partner for Tier 4 DGB and a strong advocate for this technology as a viable option for next-generation fleets to meet reduced emissions initiatives. We continue to see strong demand for this solution as we add this upgrade to much of our existing Tier 4 capacity. To further emissions and operational cost reductions, we are finalizing the testing of our proprietary engine idle reduction system. We expect to begin deployment of this system across our fleet a little later this year. The next step in our journey down this road of reduced emissions and improved operating performance will be our electric fleet. With electricity generated using natural gas reciprocating engines, the digiFrac platform will provide solutions to the challenges identified in many of the current iterations of electric fleets. In 2021, our digiFrac fabrication, field testing, and commercialization plans remain on track. We're working on integrating a fully electric process trailer, a combination blender and hydration unit, completing our power supply design and assembling a power generation system. In parallel with this effort, we will be completing the development and deployment of a next generation control system with fully automated pump operation for deployment across all Liberty fleets. As part of this initiative, we will also integrate the pump down control into the wireline system and ultimately into frac operations, allowing seamless oversight of these two integral operations on location. Third, from an operational perspective, we now have a much expanded software and technology platform. This will drive value by augmenting planning, execution, and equipment diagnostics with digital integration and automation. Our new larger organization takes greater coordination of all elements for managing our assets with the greatest efficiency, to where we invest dollars for the right equipment and technology, to how to best leverage our vertically integrated asset base and supplier partnerships. Our relentless desire to improve means that all processes are under the microscope. Along those lines, we have had great success in providing customers with both frac and wireline services, an area we know our legacy Liberty customers would greatly benefit from by streamlining our frac and wireline crews on site to shave extra minutes off the day. Every minute equals efficiency and translates to a lower cost of producing a barrel of oil for our customer and improved profitability for Liberty, the win-win we strive for. It has been an incredible start spending time with our red and blue teams across all of our basins. The eagerness and excitement from our teams is humbling. As we move forward, we'll come back to the street with the progress we've made. With that, I will hand the call back to Chris for closing remarks before we take your questions. Thanks, Ron. The future for frac services is leveraging scale for innovation with more data and technology, and empowering talented individuals to interpret and apply the analysis of this information to ultimately drive down the cost of producing hydrocarbons in the safest and most responsible way. As we enter our 10th year in operation, we are excited to lead a technology driven structural change in the industry. We are uniquely focused on extracting significant value from our acquisition by bringing together two of the leading technology centric service businesses in our industry, supplemented by an ongoing technology partnership between Liberty and Schlumberger. Early response to Liberty's acquisition of OneStim has been positive as customers are finding value in our technology leadership. Invention and creativity takes center stage in our industry. Liberty remains committed to the next decade of innovation as we were in our first decade as a company. We look forward to your questions. We will now- I'll turn it back to the operator for questions now. We will now begin the question and answer session. To ask a question, you may press star and then one on your touch-tone phone. If you are using a speakerphone, please pick up your handset before pressing the keys. If at any time your question has been addressed and you would like to withdraw your question, please press star and then two. At this time, we will pause momentarily to assemble our roster. The first question comes from Chris Vogel with Wells Fargo. Please go ahead. Thanks. Good morning. Good morning. I guess first to start off with a kind of high level question, we've heard the refrain, no fleets without pricing, I think since like the middle of last year. In practice, we've seen a lot of fleets coming to market at very low pricing thus far. Are there any factors that will be different going forward from this point in time compared to what we saw in the third and fourth quarter for the industry? Well, Chris, I don't think you've heard that refrain from us. Our goal when the pandemic hit was to work with our partners to keep our relationships strong and to get through the downturn, the oil price disruption, together with our partners. We made adjustments on the downturn to keep the economics to work for both sides. With an agreement to ramp things back up in a schedule that's actually been not much different than what we discussed and learned with our customers in April. To us, things have gone on plan. There's been no change. The key at the start is preserve the relationships, restart safe and efficient operations. As we mentioned, we had efficiency records in Q4, likely also for safety. Now we've seen an oil price recovery, and now we will see price recovery in our frac services as well. For us, things have gone as planned, on track. Okay, that's helpful. Thank you. Maybe to follow up on the pricing discussions, just curious if you can help us quantify how meaningful that might be and maybe translate it into how we should model gross profit per fleet or EBITDA per fleet going forward. Do you see any of these as kind of in the bag thus far? Is it going to be more of a slog as you get through the first half of the year? We have a good number of agreed price raises already. We have start dates or pad dates where these things will come in. Again, it's just always been a partnership dialogue with us. We moved down, we held for a while, and now we're bringing pricing back up. We have a good number of agreements already in place, and we expect over the next few months to have a good number of additional ones. I'm going to refrain from commenting on magnitudes and movements on gross profit. I don't know if Michael wants to add anything to there, but we got to let this play out as it goes. We feel pretty good about where we sit right now. Great. Thank you very much. On the pricing side, I think you'll probably start to see them slowly roll in from Q2 onwards. After that. Yeah, these were discussions we had as the crisis hit sort of Q2 of last year. As we say, we moved those pricings up with those clients in a planned fashion as we roll through the year. It's sort of incremental as we go through the year. Okay, great. Thank you. Thanks, Chris. The next question comes from Scott Gruber with Citigroup. Please go ahead. Yes, good morning. Morning, Scott. I want to stay on the pricing question, but ask a question related to incremental crews. Chris, you talked about the anticipated pricing on active crews. Is the magnitude of that price increase sufficient to add incremental crews into the market? Would you want to see something bigger or more of a step change in profitability before adding incremental crews? Scott, I would say yes. It's something additional to the agreements we have in place now. We have in place now the kind of partnership things we need to keep our customers generating strong returns and the returns on Liberty's invested capital to come back as well. Look, those have been very constructive dialogues. As I said, a number of agreements are completed. I think for us to stand up and hire new people and deploy another crew, that's a bar higher than what we're talking about so far. That's good to hear. Maybe just a little bit of color on 1Q EBITDA, now that you'll have the OneStim fleets in the fold. Now that you've closed the deal, how do you think about the timing to Libertize those crews and close the margin gap between the two sides of the business? I'll let Michael or Ron comment on that. Yeah. Scott, I think what you're going to see is a slow ramp-up. What we're calling our Liberty Blue Crews are very efficient. That is a nice surprise. We're going to get fixed cost leverage, sort of especially once we get past Q1. There's a lot of transition, sort of noise and costs, as far as until we transition onto our ERP systems and everything else, and we get to our true efficiency on the overhead side. There's a lot of work going on in the Q1 side for that. I think you'll start to really see that drop through to the bottom line from Q2 onwards. Then we'll start to see sort of more integration and sort of like that efficiency gap, any efficiency gap closing. One of the key things there is maybe not so much pumping on the day when they're on site, which is they're very impressive crews. Really a lot of it's around coordination and scheduling and reducing white space, which is one of the places that Liberty, our sales and operations team have excelled. Is the goal to close the gap by the end of the year? Is that possible? Correct. Yeah. That will be. I think yeah. Every customer, every fleet, every country, every basin has a little bit of a different flavor. Yeah, we would expect by the end of the year, you shouldn't really see any difference on whatever crew we're rolling out. It's going to be Liberty and Liberty all the time. Good to hear. Appreciate the color. Thank you. The next question comes from Stephen Gengaro with Stifel. Please go ahead. Thanks. Good morning, everybody. Two things, if you don't mind. One, just to kind of continue on that topic. I was trying to understand when you're looking at the fourth quarter, you mentioned record sand volumes pumped. I would assume that means pretty high efficiency. Are we looking at a pricing dynamic early in the year that's very similar to the fourth quarter? Is there any kind of efficiency gains that we could see early in the year, which would lift that EBITDA per fleet? Well, we did indeed have record sand throughput on our fleets, record efficiency across the Liberty fleet in Q4. Again, look, we'd love to see more margins then, but we know that's coming. For us, the key thing is the partnership with customers. Deliver safe operations and keep driving efficiency higher. There's always room to get better. Yeah, it was a pretty high bar in Q4. I'll let Michael talk about, there's probably incremental improvements in efficiency going into Q1. That's ambitious, but we'll probably achieve that. I think just the fixed cost leveraged over a larger platform is also helpful. Michael, anything you want to add? Yeah, I think so, Stephen. I think what you'll see is the heritage Drill Fleets pumped very efficiently in Q4. We didn't see much of that Q4 drop-off as we would because people were just starting to sort of ramp up completions. I would say that efficiency probably flatten, I would say, into Q1, as we see a little changeover in the calendars and the white space. I would say you probably won't see a lot of efficiency gains out of the combined operations in Q1, right? You'll start to see things change as we go through there. One of the things that you're going to see, we're going to leverage fixed costs. I think what we're going to be able to do is, as we go through the year into next year, do a fairly significant leverage down on R&M costs and some of those costs per fleet that we're looking at there. A lot of the technology innovations that Ron's team's sort of running through at the moment, that we're combining sort of best parts of what the historic OneStim team have been doing and the best parts of what we've been doing. I think we're going to see some pretty significant help there for the bottom line on both, on that side of it. The automation that Ron's doing, that I'll talk about later on, because you'll see more of that. We chat about that in May, really reducing the number of heads on site, being at the automated pumps, the reduction in fuel costs with the automatic idle. There's a lot of efficiencies that are coming. I really don't think you'll see a great deal of them in Q1 as we go through. You can imagine everybody's running at 9,000 miles an hour at the moment. You'll start to see those fall through, as we go through the year. Great. No, that's helpful. Thank you. The other one was on the digiFrac. Can you share with us sort of your thoughts on how the model ultimately works? What I'm thinking about is, who owns the turbines? Is it you long term? Do you think customers will pay for sufficient returns on that capital? Do you think there's another ownership structure of turbines down the road? Ron will take that. First and foremost, I guess most important to mention that we are not going to use turbines. We view a turbine as not only a challenge from delivering the lowest possible emissions footprint, but also incredibly challenging from a capital standpoint. You've certainly heard the numbers around what one of those costs to purchase and ultimately own. We're headed down a completely different path. We will be powering our electric frac fleet, digiFrac, with natural gas recip engines. Think 20-cylinder natural gas engine. They're commonly used in power generation right now. If you were to head out to an Apple data center, for example, and look behind that, what you would find is a 20-cylinder natural gas genset there. We're going to do the same thing. We believe we have an opportunity with that to deliver a meaningfully better emissions footprint than current iterations of electric frac fleets, and to do so at significantly better capital efficiency than we've seen in the past. Great. I can comment on the kind of the ownership model question there, Steven. I think you've probably heard us talk before. It is tough to think of that ownership model being separated out, right? The reality is, it's like the grid or any other piece of equipment that you own, right? You've got to get utilization to pay back that equipment. Now, we obviously sort of like the same way we are the same, we are the second largest frac company in the country. We are going to have the ability to own our power generation and keep it running 100% of the time no matter what customer it's working for. Because customers have downtime, right? They have issues go wrong with pads. They have changes. You'll see acquisitions where people have sort of like short-term slowdowns, et cetera. Now we can move that equipment around. It's got wheels. That frac fleet can move. I can generate a return on that capital investment that's continual. If people have tried to pitch this idea of a secondary ownership kind of rental, now the only way you can do that is if you've got significant other uses for that power, that you have a larger frac fleet. Think of Greco and their fleet, et cetera, of some of their power generation, small power generation. That you're accessing across a lot of different business lines and maybe a lot of different industries. That's the only way. We can guarantee that continuation of work, which means we're going to ultimately end up with the lowest cost of ownership for that power generation. I just don't think it really makes any sense doing it any other way. Okay. Great. I appreciate the color, gentlemen. Thank you. Thanks, Stephen. The next question comes from Sean Meakim with JP Morgan. Please go ahead. Thank you. Good morning. Morning, Sean. Chris, there's been a lot of talk about old equipment getting cut up. That's to your benefit as having a young fleet. Your contribution now is coming through this OneStim transaction. Across the industry, most of what's been cut up hasn't worked in a while. It seems like there's potentially an emerging bifurcation in the active market. Things are pretty sold out as far as e-frac and dual-fuel utilization across the industry. In that part of the market, we're seeing some capacity creep back in various ways. Maybe some piloting some new E-fleets, upgrading some Tier IV fleets to dual-fuel. I'm trying to get a better sense of your perspective around potential bifurcation in the active market between legacy fleets and next gen fleets. On balance, how should we think about a lot of nameplate capacity has gone away, but in the active market, we are still kind of letting some more horsepower creep in. I would love to hear your thoughts on those two emerging trends. Yeah, Sean, I would agree that the market is becoming bifurcated through a gradual process that's been going on for a while. As you know, Liberty was very early on, second year in business, building dual-fuel fleets. We probably had several years maybe even slightly frustrated. We had a lot of dual-fuel capacity, it was an effort to get customers to engage and use it. That mentality among customers has changed dramatically. That now I think everyone realizes, wow, lower emissions and lower emissions and lower cost. That makes sense. There's a little bit of extra logistics that need to be done, and we won't get into that today. Yeah, dual-fuel is becoming a more common thing that people want. Tier 4, certainly people at the highest bar want Tier IV equipment. That's. You can't upgrade an old Tier 2 engine to Tier 4. You can upgrade an old Tier 2 engine to Tier 2 dual-fuel, which is a great step in the right direction. For Tier 4 equipment, it's got to be Tier 4 horsepower that was built that way. It's going that way, and I would say, look, it's the bigger, stronger players that fleets are migrating towards more upgraded fleets. There's a lot of legacy horsepower and legacy players out there that are just less active in that space and not doing so much. I think as with the transformation to high-spec rigs, it will take some time, but it's definitely going on. No one's building old legacy equipment and people are, again, not maintaining all of it. They've combined, they had 10 fleets and they put them into seven fleets and they're removing parts. If they stop investing, maybe they'll be at six fleets a little bit later. We see capacity shrinkage around the marketplace. There's still a huge amount of traditional Tier 2 diesel fuel fleets running. They're not gone, there's just that equipment base is shrinking and the% of the market they are is shrinking as well. I think right-sizing the market takes some time, but the last 12 months have been particularly productive. I suspect we'll see quite productive this year as well. We'll end this year with meaningfully less deployable capacity for frac fleets, just because there won't be the investment levels to maintain the existing capacity. At the end of this year, we'll have less available fleets to frac and more fleets fracking. I think that progression is happening. I think that's fair. I appreciate that context. To touch on capital efficiency for a second, you're only about a month of looking under the hood, but I imagine your guys have been busy. You cited in the prepared comments, $1 million per fleet of maintenance capital savings from rationalizing the excess horsepower from OneStim. If we're running 30 fleets, $30 million a year, do you have a sense of how many years that can run or what kind of an update on the aggregate savings versus the initial shot in the dark that you provided us late in 2020? Yeah, I'd say that's Sean. I think the shot in the dark is still our best estimate at the moment. There's a lot of equipment out there. Yeah, I look at it as a bell curve, right? It's probably going to take most of the first half of this year to sort of come up with a plan, the efficiency plan of how we're going to do this. The majority of the savings will come next year on the capital side, and then some of it will slide into 2023. Think of it as a bell curve there. Roughly, when I put it together in a plan, I sort of go, half it's gonna come next year, maybe a quarter the second half of this year and a quarter of it in 2023. It may drag out a little bit further into 2023. That's where I'll go. Yeah, we're still in that general, that first shot in the dark that we had. ±$75 million, we think it'll help us on that. That's a good framework, Michael. Yeah, thanks guys. I appreciate it. Thanks, Sean. The next question comes from Ian Macpherson with Simmons. Please go ahead. Thanks. Good morning, team. Michael, does your CapEx envelope for this year include maybe at the high end or otherwise include the completion of the first digiFrac fleet in its totality? Or if you were standing up that fleet in the second half, would that be incremental sort of new build CapEx that could be above and beyond that? Yeah, the top eight does include it, Ian. Yeah, that'd be the building of the first digiFrac fleet. Good. Okay. I understand the reticence with more sort of specific guidance than what you've already given. You said an ambition would be to stay free cash flow positive for this year. We can certainly work backwards from your CapEx guidance, and we know what interest looks like. Could you point us towards anything with respect to cash taxes or working capital, harvest or build for this year that might help us to refine our EBITDA estimates for this year? I'd say very little cash taxes. Ian, so probably one move the needle on the cash side of it. Working capital will be a slight build, but not huge, right? This OneStim business came with some working capital that as part of the deal, the negotiated deal. There'll be a slight build. That will depend really on how the second half looks, right? If we stay in this kind of flat environment, macroeconomics doesn't improve, fleet economics don't improve, you'll be a relatively flat working capital area. I think we'll make some wins on inventory that'll offset some of the AR that will increase. If we see really pricing improve decently and we see a little more speedier adoption, you might see a bit of a working capital build, then you will see an earnings build at the same time. Right. Understood. Great. My other questions were answered, so I appreciate it. I'll pass it over. Thanks, Ian. Thank you. The next question comes from James West with Evercore ISI. Please go ahead. Hey, good morning, gentlemen. Morning, James. Chris, with Brent at $60 and WTI in the high $50s, certainly higher than I think most budgets were set for your customers, is there any talk at all of them kind of investing more this year? It looks to us like they're not investing enough to really even hold production flat at this rate. Are they starting to what they've announced, kind of reinvestment rates of 70% or 80%? Is that a signal that perhaps we could see a little bit better CapEx than perhaps we thought of a month or two ago? I don't think so, James. I have regular dialogues with our customers. Among the publics, I don't think we will see any change in plans. I think the message has been received. I think people realize, wow, we've had this awesome shale revolution, and none of the value accrued to the operators. Right. No, certainly for this year, and I don't think it fades much in the coming years either. No, I don't think we'll see any change in the development plans that the publics have laid out. Whatever oil prices do, unless they went really low, you would see a reining back in. We're not going to see new additional CapEx from the publics. Certainly, on the private side, it's a little bit different. Their oil prices and current economics impact decision making. There's a little more movement in plans for the privates. Even there, capital availability is not great. Nobody wants to stress a balance sheet. As cash flow flows up, I think you'll see a little more CapEx from the privates. We're already seeing a bit of that. Sure. Not huge. I agree with you. Current activity levels for the public sort of imply a little bit of a decline in production. Right through the year. Boy, efficiency and some upgrades. I don't know. If I was a betting man, I still suspect that exit rate production this December will be pretty similar to what December production was, that closing 2020 out. It'll be flattish this year. I don't think we'll be far off that. Okay. Fair enough. With respect to the Schlumberger technology portfolio that you now have acquired, are there certain technologies that stood out to you? You've had a month owning the assets and the IP. You obviously took a look under the hood as you were doing diligence. Are there certain technologies in that portfolio that are incremental to what you guys already had and could ramp your own efficiencies even further? James, I think there is. Even just on business processes. The more we look under the hood, it's like, wow, that's pretty cool. We've been cautious in saying too much about them because we've got to digest, understand it. We're planning to do, I think, Investor Day in May or something, where we'll have a longer presentation. We'll give a little more color into the technologies across from operations to business processes to ESG. We'll give a little more color or feel than yet. Yes, the surprises have been on the positive side as far as the technologies and the humans. One of the appeals to us of Schlumberger was that low turnover, long-tenured, higher caliber professionals in the company, and we haven't been disappointed. We're quite enthusiastic about it. Okay, great. Thanks, Chris. Thanks, James. Take care. The next question comes from George O'Leary with Tudor, Pickering, Holt. Please go ahead. Morning, guys. Morning, George. Welcome back to the calls. Thank you. Assuming pricing were flat from here, let's just assume. I know you mentioned there sounds like there's some increases on the come from some of your customers or partners in the field. Assuming pricing were flat from here, and given the 30 fleets that you guys anticipate running in the first quarter, just directionally, not asking you to quantify magnitude, but would fleet profitability, again, excluding pricing increases, excluding any noise associated with the OneStim transaction, would fleet profitability be better quarter-over-quarter in the first quarter from either a gross profit or an annualized EBITDA level, just given the increased scale? Or how would you frame that? We touched on it a little bit, but just looking for any incremental color you could provide. Yeah, George, we get significant fixed cost leverage, right? Our G&A really isn't going to go up horrendously at all, really not that much. When I think about the G&A heads that we added with this deal, we really added sales, right? You get a lot of fixed cost leverage. We're going to get a lot of, which is on the G&A front. We're going to get some of the district fixed overhead leverage, because obviously, we're doubling the size of our Permian business, right? Really not adding, you don't add the same amount of overhead When it comes to that, which I think is also very good. We're going to be, obviously, Ron's supply chain team are going to be buying twice the amount of stuff, and that's going to help with working with suppliers. I think that's a key thing. Yeah, as we get more and more into these, we sort of dig further and further into it, we will do actually see that. We'll also get sort of a little bit better utilization with the calendar, right? Again, it's sort of the larger you get in different areas, it means you're always going to have gaps, you're always going to have fleets moving around. As we work through the year, with the integration of these two fleets, which are going to be larger, you're going to be able to shuffle the fleets so you have less white space. Yeah, there's a lot of incremental benefits that come with that. I think a lot of the processes and procedures as we sort of be able to get more efficient as we go. I think adding the wireline business is a great complementary business. I think, again, that's a unique frac partner on the dance floor, and it's probably the largest portion of our third-party downtime. Ron could talk more to that, but if you shave minutes off a day, that's more revenue that you're gonna be able to bring to the table. The better understanding we have with pump down. We're already probably the largest or second-largest buyer of sand in the country by far. Now we have two Texas mines to help us balance some of that as well. All these things I think are going to come together to help, even without any pricing or any increase in fleets. We would see improvements as we go through the year. Great. That's very helpful, Michael. Just from a tendering perspective, you mentioned in the back half, it seems like some privates may add, at least best we can tell, activity was up in December, activity's up month-over-month in January, on the completion side. You can clearly see drilling rig count continues to grind higher. There's clearly some pricing discipline on y'all's part in not activating incremental spreads. From a geographic perspective and a tendering perspective, where are you seeing the lion's share of the shots on goal? Is it Permian activity increases, or are you seeing some activity increases potentially in the Haynesville? Where are people looking to add as we progress through the year? The Permian's certainly the biggest pond. Yeah. That's certainly the biggest place you'll see extra activity levels. The upside of the Haynesville was it didn't drop nearly as much. The Haynesville stayed reasonably strong throughout the year. It's definitely geographically advantaged for LNG exports, and as we see, those will set a new record this year, beating last year's record there. Not a huge increase in activity there. The awesome thing about shale gas is we can produce a lot of it. No, I don't think we're gonna see wild swings there. I would say that the flexibility in activity is more in the oil basins. If I could just color the comments, if you have one second. Interestingly enough, Liberty's always been sold out, right? We've had basins where customers have approached us over the years and said, "Hey, we'd really like you to bring your efficiency and engineering technology, your technology focus to our basin, to our country, et cetera." What we've done with this OneStim deal is expand that geographic basin, right? We started in the Haynesville, now we've got a large presence there. We're doing work in the MidCon. We have plug and perf operations in the Northeast. We have operations in Canada. The people that have been approaching us for years to come and help do some work with them in the Montney and Duvernay in Canada. Now we've got a base there that we can sort of do with that, especially once COVID gets over a little bit and we can actually get people across the border. You're gonna see some things there, I think, George, where you're gonna see some sort of potential once pricing comes back, the additional market for us to be able to take just by taking the Liberty of what that sort of Liberty Special Source that people have wanted and having an access to it in different basins. Thanks, Michael. Thanks, Chris. Thank you, George. The next question comes from Connor Lynagh with Morgan Stanley. Please go ahead. Yeah, thanks. I appreciate you guys squeezing me in. I'll keep it brief since we're at the top of the hour here. At a high-level framework, obviously, you've added pressure pumping, but there's the affiliated businesses, Michael, you're referencing wireline. There's the sand mines as well. I would imagine the incremental earnings contribution at today's pricing is pretty minimal, but could you give us sort of a framework to think about, relative to, say, 2019 on a per fleet basis or however you want to frame it? How much can you add to your EBITDA per fleet or your earnings power? Both from the just having incremental assets working, but then also the efficiency gains that you were talking about. I appreciate you might not be able to get super specific on the efficiency side, but would just love any thoughts on how we should think about that. Connor, it's really hard to comment at this point, it's just a little bit too early. I'd probably like to save that for the next earnings call. I'd say I think ideally we will get some. I think sort of being able to give those specifics would be better off done sort of once we've got a quarter under our belt and we can really see it. You've got to remember, this is all accounted for under Schlumberger and a lot of that's historical, their cost structure, et cetera. That's still sort of becoming clear. Let's put that off for a little bit. Not put too much addition in there at the moment. It will be positive. All right. Fair. Just one last quick question on a related vein then. The efficiency gains that you're talking about on wireline, that being a big portion of downtime, can you maybe help us think through how much of an uplift, how big of an outage is that on your "average pad?" If you guys were able to get it where you think is reasonable, how significant would that be? Over our past history, of course, we've tracked this since the beginning of our time. It averages today about six minutes per frac stage that we work on across our entire fleet. If you start to roll that up, obviously that varies a little bit by basin in terms of number of stages that we pump. If you think about it from that standpoint at a high level, that'll give you some sense of what kind of time we might be able to add over the course of a year. All right. Got it. I'll leave it there. Thank you. Thanks, Kevin. The next question comes from John Daniel with Daniel Energy Partners. Please go ahead. You guys, good morning. I just have really one question to follow on Sean's question, looking for a wild ass guess on your part, Chris. As you look at your customers, or just call it the E&P industry, what% of them actually care about lower emissions and what% of them are actually willing to pay for lower emissions? That's a great question. Look, I would say one thing I think, and John, I know you know this, but one thing I would say that's misunderstood about our industry, that the industry is dominantly people from rural areas that have lived on the land. I would say the concern for the environment has always been there in our industry. You're right. Right. Where are the incentives? Where is the drive for that behavior? It's definitely hampered right now in that the marketplace is so tough. E&P companies are hated by investors, and that definitely does swing a needle on cost above all else. The bigger players and a few of the, I would say, embraced players are willing to pay for it, but it's still a small percent. Everyone else wants it, but in today's world, they're more reluctant to make any meaningful trade-off for the cost of it. Yeah. We're sort of in the same boat too, right? We want to upgrade. I'd love to have all the leading edge fleets, that's a lot of money. Right. That's why I say this, things are trending the right direction, but it's not an overnight thing. John, I don't have an estimate any better than yours, but you make a very good point. Everyone talks the talk, and it's still a small minority today that'll pay for it. How would you characterize just the transition, Chris? We're eventually going to get there, right? Eventually, they're gonna have to pay for it, and it's the right thing to do. Is there a step change later this year, next year? I know we have no idea, but just your thoughts. John, I think it's so driven by oil prices and returns. I think that a lot of people say to me, "Boy, with customers with this discipline on investment, that must be really tough for you guys. They're spending less." My view on that is exactly the opposite. Right. The fact that oil prices have risen 25% since people set their budgets and nobody in the public world, and even the private world, isn't dramatic, that people don't want to change their budgets. We think that's a great thing, right? If people invest less and truly hold back, that's the thing that moves the needle on oil prices. You move oil prices to where they are today, and you take efficient operations, we're gonna see strong returns on capital by our customers. We're gonna see some respect and belief in our industry coming back from those returns. Right. That enables everything else. Everything else, like the dialogues we're having right now. Of course, no one wants higher prices, but we need a sustainable industry. We need partnerships that can keep getting better, and more price to us is necessary for that. Just to get return on our existing assets. We need a little more price on top of that to invest in new assets. I actually think, and you've heard me say it. Look, we've had a rough decade. I think the next several years for our industry are actually gonna be pretty good. Yeah. I think it's supported by commodity prices at base. I think that's going to lead to better returns across the value chain. Once you have better returns, the investment, the payment for lower emissions and better operations, that follows with it. Right I think we'll see a very different attitude for paying for lower emissions 12 months from now than we've seen the last 12 months. I could be wrong. That's my belief, John. Yeah. Well, my editorial comment is the technology seems to be here of making meaningful changes. Hopefully we'll see a rapid adoption. By the way, great LinkedIn video on The North Face, Chris. Thank you. Sure. Lifting up the industry. Thanks, John. I appreciate that. Okay. Take care. The next question comes from Tom Curran with B. Riley Securities. Please go ahead. Wow, good morning. That's dedication, guys. Thanks for still taking my question at such a late point in the call. I just had one technology question left. Curious, Chris, or Ron, whether you currently provide your customers with any ability to track and monitor in real-time and image all of the fluids involved in the frac slurry downhole. In other words, as the frac job is being executed, do you provide that ability to image and monitor the different fluids subsurface? If so, is it an ability you currently have in-house, or do you use a third party for that? Tom, that is an interesting question. As you probably know, Michael, Ron, and I, and a number of others in the Liberty team, spent the largest piece of our career developing fracture diagnostics, ways to measure how fractures grow and what they're doing. We have some of those technologies in-house. WellWatch is one we've talked about a lot that give us indirect measurements about how far away from well bores fluids are going. We've been looking at fracture diagnostic technologies, but it is not a standard. We run frac models, we obviously in real time are transmitting to our customers from satellite dishes our model predictions of where we think fractures are growing and where the sand is, where the fluid is. We do it on a predictive basis. We have some big picture far field pressure measurements to infer that. Certainly there's more that could be done there and with the right technologies and the right value proposition, yeah, I think you may see more of that from Liberty in the future. Just to be clear, Chris, you would expect to provide that in-house. Then just as a follow-up, what percentage of your jobs currently would you estimate involve some use of it? Well, the modeling, essentially all of them. WellWatch, the adoption of that is pretty rapid. That's ramping up at a good clip. It's still not half jobs, but that's ramping up pretty quickly. Micro seismic that we developed 20 years ago and tilt, we do have some of those on jobs. That's third party. That's a small%. Great. Thanks. I'll let you go before you lose your voice. Thanks, Tom. Yeah, I don't want to ruin everyone's Friday mornings, but we appreciate everyone's interest. This concludes our question and answer session. I would now like to turn the conference back over to Chris Wright for any closing remarks. Thanks everyone for your time today. I apologize us running over the one hour. We had expanded opening remarks due to the nature of the transaction we completed with Schlumberger. Thank you all for your time and interest in Liberty and frankly for your interest in this industry. Imagine if COVID had struck a world not energized by oil and gas. We wouldn't have vaccines now. We wouldn't have the ability to ramp up PP&E and to communicate and send resources all around the world. The world got hit a big blow, but thank God we had an oil and gas energized world to respond quickly. We look forward to tremendous progress continuing on that this year, and we look forward to talking to you after the first quarter. Have a great day, everyone. The conference is now concluded. Thank you for attending today's presentation. You may now disconnect.