Flowco Holdings Inc. (NYSE:FLOC) Q4 2024 Earnings Call Transcript

Flowco Holdings Inc. (NYSE:FLOC) Q4 2024 Earnings Call Transcript March 18, 2025

Operator: Good morning. Welcome to Flowco Holdings Incorporated Fourth Quarter and Full Year Fiscal 2024 Results Conference Call. Today’s call is being recorded, and we have allotted one hour for prepared remarks and Q&A. At this time, I’d like to turn the conference over to Andrew Leonpacher, Vice President, Finance, Corporate Development and Investor Relations at Flowco. Thank you, sir. You may now begin.

Andrew Leonpacher: Good morning, everyone, and thanks for joining us for Flowco’s fourth quarter and full year results. Before we begin, we would like to remind you that this conference call may include forward-looking statements. These statements, which are subject to various risks, uncertainties and assumptions, could cause our actual results to differ materially from these statements. These risks, uncertainties and assumptions are detailed in this morning’s press release as well as our filings with the SEC, which can be found on our website at ir.flowco-inc.com. We undertake no obligation to revise or update any forward looking statements or information except as required by law. During our call today, we will also reference certain non-GAAP financial information.

We use non-GAAP measures as we believe they more accurately represent the true operational performance and underlying results of our business. The presentation of this non-GAAP financial information is not intended to be considered in isolation or as a substitute for the financial information prepared and presented in accordance with GAAP. Reconciliations of GAAP to non-GAAP measures can be found in this morning’s press release and in our SEC filings. Joining me on the call today is our President and Chief Executive Officer, Joe Bob Edwards and our Chief Financial Officer, Jon Byers. Following our prepared remarks, we’ll open the call for your questions. With that, I’ll turn the call over to Joe Bob.

Joe Bob Edwards: Thank you, Andrew, and good morning, everyone. It is my pleasure and an honor to welcome you to our first investor call as a publicly traded company. For the benefit of the group and, in particular, all of the investors on the phone with whom we have not met, I’d like to begin the call with a little bit of Flowco history and an overview of our operations and position in the energy market. Flowco was formed in June of 2024 via the merger of three private companies, Estis Compression, Logistics, and Flowco Production Solutions. Each of these three companies was formed over ten years ago and has built market leading positions in the production optimization sector of the domestic oilfield service market. Each company has also demonstrated a culture of innovation, a customer focused approach to problem solving, and an emphasis on investing in strategies that produce consistent high rates of return on investment.

This common culture and a shared vision for the future led to the merger and importantly has guided our integration efforts. By far, the easiest part of our integration was choosing a name for the combined company. The name Flowco not only is the name of one of our notable brands, but it also perfectly describes what we do every day. We help our customers flow their oil and gas wells more efficiently and economically. Flowco participates in the production phase of the industry, which is much more stable than either the drilling phase or the fracking phase of the oilfield service market. Our revenues are derived from oil and gas company nondiscretionary OpEx rather than their CapEx. More broadly, our results can be traced to the absolute levels of oil and gas production in the United States as well as the number of actively producing oil and gas wells themselves rather than the number of active drilling rigs or frac spreads.

We sit at the critical path of operations for our energy company partners. And quite simply, if our equipment is not working properly, our clients’ wells do not produce to their optimum level. We are proud to offer a range of solutions that work for the entire lifespan of the well, which in most cases is more than 20 years. Our company is organized and managed through two operating divisions, Production Solutions and Natural Gas Technologies. Production solutions includes our artificial lift products, which help oil and gas operators produce their wells after drilling and fracking operations are completed. Our products include a mixture of surface equipment and downhole products, which are designed and installed based on specific well production data.

We enjoy market leading positions in high pressure gas lift or HPGL, conventional gas lift, and plunger lift applications, and we count among our customers some of the largest and most well capitalized oil and gas companies in the world. Next, our Natural Gas Technologies division provides our market leading vapor recovery solutions deployed at surface production locations for the entire life of the field. Our proprietary equipment and patented technologies provide operators with a safe and highly profitable method of capturing methane vapors that would otherwise be flared or vented to the atmosphere. These vapor recovery solutions provide some of the most impactful environmental benefits to operators, while also providing high value economic returns, especially in today’s current natural gas price environment.

We help our oil company clients capture and sell hydrocarbon molecules that would otherwise be seen as a waste product. Our GAAP financials reflect a healthy mix of equipment rentals and product sales. At a high level, our equipment rentals are comprised of short term and long term rental contracts on over 4,300 active systems across our fleet and include systems that provide high pressure gas lift, conventional gas lift and vapor recovery applications. Our equipment sales are comprised of downhole equipment associated with conventional gas lift and plunger lift applications and to a lesser extent the sale of certain types of surface equipment packages. We service our diverse customer base with a dedicated workforce of approximately 1,270 employees through a network of field service locations located in every major US shale basin.

We also have a vertically integrated supply chain based in the United States, which provides a competitive advantage while providing flexibility and stability in periods of geopolitical uncertainty. In 2024, we increased pro form a revenue 10% versus 2023, while U.S. oil production increased 2% to 3%. This growth was achieved almost exclusively on an organic basis by investing growth capital to fund expanded offerings primarily in high pressure gas lift and vapor recovery, our two fastest growing business lines. Based on identified customer demand, U.S. production outlook, and current industry activity, we expect 2025 to be another year of profitable growth with a similar level of growth capital deployment compared to last year. More on this from our Chief Financial Officer, Jon Byers, later in our presentation.

Finally, as we optimize and grow our business following the IPO, we will continue to market across our various solutions to our 300 plus customers and look for ways to cross collaborate. Our singular focus on production optimization and an emphasis on continuous technological innovation across our product lines sets us apart from our competition and should lead to increased market share gains over time. So with that, I’ll turn the call over to Jon Byers, our CFO, who will take you through our 2024 results. Following his remarks, I will make a few closing comments and then open the lines for Q&A. Jon?

Jon Byers: Thanks, Joe Bob. Before reviewing some of the key financial metrics and results for the fourth quarter and for 2024, I’d like to provide a few reminders on our historical financial information given the combination of Flowco, Logistics and Estis in June of 2024. For clarity, note that any financial information presented prior to the June 20, 2024 business combination reflects only the historical performance for Estis. Financial information in the third and fourth quarters reflects the financials for the consolidated entities. For those looking for pro form a financials for the first nine months of 2024, I would refer you to the pro form a financials on Page 25 of our January 16th prospectus. Finally, note that our 2024 financials are presented for our operating subsidiary, which was a privately held pass through entity for the entirety of 2024 and therefore incurred no federal income tax.

Turning now to our financials, in the fourth quarter, we reported adjusted net income of $28.8 million on revenues of $186 million. Revenue was down approximately 1.8% quarter over quarter as expected for reasons I’ll discuss in a moment. Fourth quarter performance was in line with our expectations and was a result of the strong execution of our Production Solutions and Natural Gas Technology business segments, where we saw growth in both adjusted segment EBITDA and adjusted segment EBITDA margins. Fourth quarter Production Solutions revenue was $113.3 million with adjusted segment EBITDA of $49.9 million, an increase of 1.5% and 5.2% respectively from the third quarter. Adjusted segment EBITDA margins increased roughly 150 basis points quarter-over-quarter.

The increase in all metrics in the segment were the result of higher operating leverage combined with a slight shift in revenue mix change towards our surface equipment business unit from downhole solutions. Fourth quarter Natural Gas Technologies revenue decreased 6.5% to $72.7 million in comparison with the third quarter. The decrease in revenue was expected and was primarily attributable to the completion of a large customer project within the Natural Gas Systems business unit in the first half of the quarter. Utilization of our vertically integrated manufacturing for third party sales is returning to normal levels after several above average years. While revenues decreased, adjusted EBITDA grew 4.5% to $27.8 million over the same period for the segment with adjusted EBITDA margins up 400 basis points due to strong performance of Vapor Recovery, which offset the impact of the decline in revenues from Natural Gas Systems.

Overall, consolidated fourth quarter adjusted EBITDA was $73.8 million, which was roughly flat compared to the third quarter with adjusted EBITDA margins increasing by roughly 50 basis points. Notably, absent the $3.9 million of costs associated with standing up our public company infrastructure, adjusted EBITDA would have seen growth on a quarter-over-quarter basis, highlighting the strong underlying performance of our business segments. On capital investments, the majority of our fourth quarter investment of $35.4 million was directed towards growing our surface equipment and vapor recovery rental fleet given the attractive payback periods and returns on capital employed. While we plan to provide an annual adjusted return on capital employed metric going forward, today we’ll share our fourth quarter annualized adjusted ROCE, which is approximately 20%.

When calculating adjusted ROCE, we make adjustments for amortization and intangibles associated with the merger transaction given our merged entities were combined and not acquired. We define adjusted ROCE as operating income plus amortization divided by total assets minus goodwill and intangible assets and minus current liabilities. As Joe Bob mentioned, we anticipate a similar level of capital investment in 2025 as in 2024, mostly dedicated to our rental fleet, as we are achieving incremental returns in excess of 20%. These significant capital investments in our rental fleet will lead to a progressive increase in profitability into the second half of the year. Shifting to a few notes on corporate costs and reporting going forward, as I mentioned previously, we had $3.9 million of costs associated with the establishment of our public company infrastructure in the fourth quarter.

This is primarily professional services and headcount additions related to our IPO, which we will continue to build out in 2025. Also following the completion of our IPO, we’ve become a federal and state income taxpayer and anticipate a blended tax rate in the low to mid-20% range. Both the corporate cost and the increase in taxes will impact comparability in subsequent quarters. Turning to our balance sheet and liquidity, we’re very pleased with our strong financial position following our successful IPO in January. Importantly, we utilized most of the primary proceeds from the offering to pay down borrowings on our revolving credit facility. As of March 14, 2025, borrowings on the revolving credit facility were $195.7 million with a borrowing base of $723.5 million.

We had availability under the revolving credit facility of $527.7 million. We’re working to integrate the businesses post-merger and expect a near term increase in working capital in the first half of 2025. As we’ve stated before, we’ll be thoughtful and maintain tight capital discipline when considering any future investments. On the capital allocation front, as noted in our press release, we are considering the initiation of a small sustainable dividend to return capital to shareholders over time. In summary, the business delivered solid performance in 2024, ending the year with the fourth quarter in line with our expectations. As Joe Bob mentioned, we saw 10% pro form a revenue growth in 2024 versus 2023. Reviewing the EIA production data, this compares to only 2% to 3% growth in U.S. oil production over the same period, illustrating our thesis that our business can grow in a relatively flat production environment.

As we continue to collaborate with our customers, we’re seeing new opportunities to grow our partnerships and business every day. On high pressure gas lift, we’re seeing increased orders with multiyear contract terms as customers further prove out and realize the significant benefits of our technology within their operations. In vapor recovery, we are uncovering new opportunities as more midstream customers are recognizing the value in capturing and selling methane emissions from their operations. As a result, our expectations for 2025 as we laid out during the IPO are unchanged as we continue to execute against our strategy. Back to you, Joe Bob.

Joe Bob Edwards: Thanks, Jon. As we’ve highlighted this morning, we accomplished a tremendous amount in 2024 and absent any significant unforeseen changes in the market, 2025 is setting up to be another strong year for Flowco. Turning now to guidance. For the first quarter of 2025, we expect adjusted EBITDA of $74 million to $78 million. Before I open up the call to Q&A, I want to acknowledge and thank a number of people that have been instrumental in our success and vital throughout the IPO process. Our advisors, the lawyers, bankers, consultants, and other people that work so incredibly hard to help us prepare the process and guided us through investor meetings and pricing. Thank you for your impressive work in helping us execute our very successful IPO.

To our private equity sponsors at GEC, White Deer, and Genesis Park, Your unwavering support over the years is much appreciated. We look forward to many successful years of partnership in the next phase of Flowco’s journey. For our customers, thank you for supporting each of our industry leading brands through our merger last year and your ongoing support as a combined company operating under the Flowco banner. And importantly, to my Flowco employee family, including the large number of Flowco employee owners, Thank you for your friendship, thank you for your trust, and thank you for your partnership. Together, let’s continue to innovate and build upon Flowco’s position as a pure play provider of production optimization solutions to the oil and gas industry.

We accomplished a tremendous amount together in the last 12 months, but there’s a lot of work still to be done. Lastly, to our new investors who made our IPO a reality, thank you for the confidence you have placed in our management team and the trust you have bestowed upon us to manage your investment in Flowco. We will work tirelessly to earn that trust every day and vow to never take that support for granted. We look forward to working with you along with our covering analysts, and I look forward to seeing many of you tonight and tomorrow at the Piper Sandler Conference in Las Vegas. So, with that, I’ll turn it back over to the operator for Q&A.

Q&A Session

Operator: [Operator Instructions] And our first question comes from the line of Arun Jayaram with JPMorgan.

Arun Jayaram : Good to see your report this morning. Just general questions we’ve been getting from the buy side on Flowco is quite a bit has changed since the IPO in terms of the macro environment with some tariffs as well as the potential resolution of the Ukraine-Russia conflict. So I guess our broader question, we heard the commentary on 1Q guidance essentially in line at least with our forecast. And Jon mentioned that your overall expectations are largely unchanged from the IPO commentary. But I did want to see if we could dig into 2025 as a whole, just in the context as we have seen some softer forecast from your OFS peers and just general commodity price uncertainty for upstream operators?

Joe Bob Edwards: Yes, happy to elaborate, Arun. Look, a lot has changed since we went public roughly, what, six weeks ago or so. But at the same time, a lot is the same, right? Our story is the same. We are levered to production volumes, not the vagaries and volatility associated with drilling and completion expenditures. Commodity prices certainly matter, geopolitical events certainly matter. But what I am optimistic about is the durability of The U.S. Shale business. And, we’ve gone from 5 million, 6 million barrels a day, ten years ago to where we are today leading the world. And with the consolidation that’s taken place among our customer base, the outlook seems much less volatile. I think the customers that are prosecuting the shale developments today are taking a manufacturing approach.

They’re taking a multiyear view. And so, I’m encouraged by where we sit within the industry today. Certainly, things like tariffs being put on and off inside of a matter of days make it really hard to operate. But I would highlight actually our domestic supply chain as a defensive mechanism against volatility in the tariff regimes, and also the fact that we don’t rely on far flung supply chains for critical materials. Everything is sourced here domestically. We maintain our own ability to ramp up and ramp down our growth capital expenditures because we control our destiny through our manufacturing facility. So, look, in a world that has undoubtedly become a little less stable, I like where we sit.

Arun Jayaram: Great. Thanks for that. And my follow-up is just kind of on margins. You guys had strong margin performance, call it 150 basis points of margin expansion in Production Solutions sequentially and over 400 in Natural Gas Technologies. Could you give us a sense of how you think about margin progression over the balance of 2025?

Joe Bob Edwards: Yes. Look, the margin progression is really a function of, I’d say, two things, obviously, mix and pricing. And the mix shift in our top-line revenue, Arun, is trending more toward rental, less toward sales. Product sales come at a lower margin than equipment rental. So, I think you’ll see margins continue to bleed higher, and that’s just as a result of our growth capital investment in our surface equipment fleet across high pressure gas lift and vapor recovery systems.

Operator: Our next question is from the line of Lloyd Byrne with Jefferies.

Lloyd Byrne : Hey, good morning, Joe, Bob, Jon, team. I was wondering if you guys could just comment on administration policy and then how that impacts the VRU. Is there anything in the IRA or waste emissions that would change the nat gas tech trajectory going forward or the VRU?

Joe Bob Edwards: Yes, Lloyd, good to hear from you. Thanks for the question. And it’s something obviously we track closely. Let me remind everyone what we do and why it matters and why we’re not particularly concerned about the volatility that this new administration is introducing to this sector. Our vapor recovery systems are deployed by oil companies to capture highly profitable molecules that were previously seen as waste product, okay. And the presence of natural gas handling capability at the wellhead as well as natural gas takeaway capacity out of, in particular, the Permian has led to this type of product, our vapor recovery system at these large pads that are being brought on. These are standard equipment nowadays. The equipment deployment is highly profitable, virtually at any gas price, but at today’s gas price in particular, gas with a four handle on it actually, feels a lot better than down in the 2s where we were a year ago.

The, the Inflation Reduction Act, enacted by the Biden administration did have a waste emissions charge in it, which was scheduled to come into play in 2025. We saw that. We continue to see that should it should it actually survive as a tailwind on top of the economic benefits that our vapor recovery systems provide. Because with waste emissions charges comes effectively taxation on operators, and so that would just increase demand for products that would eliminate fugitive methane emissions like vapor recovery systems. So, to the extent those get rolled back, that does not impact at all the financial viability of our product. In many ways, it makes what we do a little less murky, because we then have a level playing field without any sort of government intervention.

So, we’re going to continue to keep our head down and offer the industry’s leading solution in that area and our customers hopefully will continue to support us in deploying more units over time.

Lloyd Byrne: That’s great. Thanks. And let me follow-up too with, I think maybe as Jon mentioned that VRU is finding incremental customers in the midstream. Can you just talk about the potential there or the potential to take it to other pieces of the oil infrastructure as well?

Joe Bob Edwards: Yes. So, historically, our business has been built on the back of upstream operators, utilizing this technique to capture vapers at central gathering facilities, okay. So, very much a system, a business model that was built in and around upstream facilities operations, okay. Obviously, as you move further down the natural gas delivery system, you have various points of methane potential methane leakage all along pipeline systems, compressor stations, even all the way down to where gas is either being consumed or liquefied for export. We’re looking at that entire value chain today as additional end market demand centers. In particular, the midstream space, largely the pipeline operators that have lots of concentration of emissions around certain points in the delivery system as a next leg of growth for Flowco.

We think that some of the largest operators in the U.S, Pipeline Operators in the U.S, will see value in this sort of technology deployment, and we’re talking with all of them. So, I hope to see some positive news on that sometime during 2025.

Operator: The next question is from the line of Derek Podhaizer with Piper Sandler.

Derek Podhaizer: Hey, good morning guys. Welcome to the public markets and the call. Congratulations. I just wanted to dig into maybe about your customer base with HPGL. So obviously you talked about a little bit, Joe, but we’ve seen that wave of E&P consolidation. Maybe could you talk to how that impacts Flowco and the adoption of HPGL? And then maybe how we should think about incremental or new customer adds for 2025? So just some thoughts around your customer base for HPGL specifically.

Joe Bob Edwards: Yes. So, let me start at a high level, Derek, and remind everyone kind of what we’re talking about and what we’re looking at. So, the Rystad, which is, I think, one of the better research groups out there, sizes the North American or excuse me, the U.S. onshore, artificial lift market at roughly $6 billion to $7 billion. Okay, and only half of that market is serviced by Flowco, okay? So that’s high pressure gas lift, gas lift traditional gas lift and plunger lift. The other half is serviced by ESP and rod lift, okay? So we happen to be in and among the faster growing sectors of artificial lift, and we’re really, really happy to be market leaders in each of the forms of lift that we actually offer our customer base.

Our high pressure gas lift offering in particular is our fastest growing offering. We were pioneers in developing this technique alongside a couple of oil company clients, and we enjoy a market leading position, and a customer base of sort of everyone that you would know. And what we have done to build that business, Derek, is what we’re going to continue to do to expand it. And that is we’re going to push the technical envelope in terms of what the system can do, where it’s applicable, how it can actually expand on what it’s good at, which is producing high flow shale wells in really tough situations, lots of sand, lots of gas. These are areas and operating environments where ESPs are not comfortable, right? So, we’ll continue to push that operating envelope every day, okay, through technology development as well as through just good old trial and error with customers.

And the customer base, is sort of who you would expect. It’s the technology leaders in the U.S. onshore, okay? We count among our customers the 60 largest and most financially secure oil companies in the U.S. but we have over 300 customers as a company. So, we continue to go to the customers that are not users of HPGL and tell them the benefits of it, specifically against DSPs. Now, we built a heck of a mousetrap, if you will, with an HPGL, but I want to be very clear that there’s a big market out there for ESPs where HPGL is not the right technical solution, okay? We think that, today, we have pushed the envelope enough to where we can penetrate roughly 40% of the total available market for ESPs and HPGL. There’s going to be a sector of the market, Derek, where an ESP is always going to be the right solution, okay, conventional reservoirs, water floods, areas where they just you don’t have the flow rates that an HPGR requires to actually be deployed.

So, we’re going to continue to look at that market. We’re going to continue to look at our solution and how we can expand it and, get after one customer at a time to try to have additional penetration.

Derek Podhaizer: Great. No, that’s good color. I appreciate that. This question might be for Jon, but just wanted to talk about the free cash flow outlook or maybe the moving pieces as we look into 2025. Obviously, you said similar CapEx year-over-year increase of working capital in the first half. Maybe if you can break it down how we should think about growth versus maintenance CapEx and then maybe the conversion rates from EBITDA down into free cash flow for 2025?

Jon Gatlin: Yes. So we’re not going to give any full-year guidance. I think everything is still in line with the expectations that we kind of we had laid out in the, in the roadshow.

Operator: [Operator Instructions] The next question comes from the line of Philip Jungwirth with BMO Capital Markets.

Philip Jungwirth: Yes, thanks. Good morning, guys. Wondering if you could discuss the eGrizzly unit, which you called out in the press release, first electric multi well high pressure gas lift unit and just what’s the opportunity set here and what are the benefits to customers from either an electric motor or multi well model, which in this case is both?

Joe Bob Edwards: Yes. Hey, Phil. Thanks for the question and good to hear from you. So you know this, but just to level set for everybody. A compressor can be powered by either electricity or natural gas fired engine, right? And we have a mix of both throughout our fleet. And as we developed the high pressure gas lift capability, we developed both the ability to deploy compression, and our technique of high pressure gas lift via either an electric motor or a natural gas engine. And the technique was developed for one wellbore, okay? So, one point of compression, one wellbore. Yes, one unit, one wellbore, okay? Over time, through technology development, we learned how to use one point of compression to lift multiple wellbores.

And we first deployed that capability with a natural gas fired engine, and then over time developed the ability to provide that solution with an electric motor. So, it’s going to be fit for purpose for places where operators have embedded power infrastructure. They have the ability to actually utilize an electric fired compression unit, and we’re just in the early days of rolling that out and we’re getting good customer reception as we do so. But it’s going to be customer by customer based on power availability, and also obviously the size of the well pad that they’re bringing online.

Philip Jungwirth: Okay, great. And then wondering if you could also talk through the company’s vertically integrated manufacturing operations and supply chain logistics and just how does this help you reduce execution risk? And then anything to note in terms of inflationary pressures across the key components and how that’s managed?

Joe Bob Edwards: So, we’ve manufacture all of our equipment in the United States. We really have four centers of excellence Kilgore, Texas, El Reno, Oklahoma, Lafayette Louisiana, and Houston, Texas, where we manufacture everything from downhole components to surface equipment packages. The critical components that we have, Philip, are sourced from domestic sources largely. Those domestic sources, of course, have their own supply chains, some of which have some international exposure. But as we think about tariff exposure, as we think about supply chain risk, we’ve all lived through situations where the risk on both of those are way higher, okay? I think we have a little bit of an embedded benefit among around two fronts. Number one, we can ramp up and ramp down capital investment very quickly based on the fact that we control it all in house, okay.

We estimate at any given time we have about six months of capital at risk in our delivery schedule, okay? Number two, we think that our competitive our competitors, where it’s a competitive technology or a similar technology sourced overseas, we think our competitors have more exposure on the tariff front, okay. So, we think that in a very dynamic market, we sit at a place that’s pretty comfortable and we like where we sit.

Operator: The next question is from the line of David Smith with Pickering Energy Partners.

David Smith: A lot of good questions have been asked already, so I’ll go in a different direction. Given your history of successful M&A as well as the lower valuations we’re seeing across at least the public OFS space year to date, wanted to ask for any color on how you’re thinking about potential acquisition opportunities or whether you’ve seen any meaningful changes in the asking levels across the private space?

Jon Gatlin: Yes. Look, this business, I think is very well positioned to be a market leader in one market niche, which is the ability to handle production, the ability to sustain production, the ability to work with oil and gas companies to increase and maintain production with innovative technologies. Importantly, we don’t offer every unique technology to every oil company on the planet, right? So, there’s a big world out there, David, as you know, and we’re constantly on the lookout for innovative technologies, like minded management teams that see the world the same way we do, customer focused technology oriented businesses. M&A has always been part of our strategy. The business was really formed via M&A and combining three companies that that checked all those boxes that I just mentioned.

And yes, we have an M&A pipeline. It will be part of our strategy. As we said on our roadshow, and I want to repeat now, we want to get through today. We want to get through the ability to report earnings and then certainly M&A will be part of a process. I also want to be real clear though, we are fortunate to be traded at a — what I think is a very nice, attractive valuation level. It can never be high enough. And you’re right, you’ve alluded to it, David. The M&A markets are significantly below that. We are going to be very disciplined with capital, okay? We are a returns oriented management team. Our board incentivizes us, and we’ve all built our careers around being good stewards of capital. So, as I said on the road, I’ll say it again here, just because something is accretive to earnings doesn’t mean it’s accretive to returns.

And we want to do returns accretive M&A in areas that make sense. And if we can find situations like that with like-minded management teams, we’re all in.

David Smith: I really appreciate that color. I guess the only related question I have is, if you could please remind us on your comfort level around the leverage, particularly with that M&A question in mind?

Jon Gatlin: Yes. We really like where our balance sheet sits today. We’ve got plenty of availability. We also are not — we understand financial engineering and the ability to utilize leverage to drive returns, but none of us are excited to try out the limits of that. We are envious of other balance sheets that have less leverage than us, but we’re going to continue to be prudent, David. We’ve lived through enough of this industry to know that leverage can really get you into hot water and none of us are looking forward to getting that getting into that boat.

Operator: [Operator Instructions] At this time, I’ll turn the floor back to Joe Bob Edwards for closing remarks.

Joe Bob Edwards: Excellent. Well, thank you all. Appreciate, you tuning in. Look forward to seeing you all in the weeks to come. Appreciate it.

Operator: Thank you. This will conclude today’s teleconference. You may disconnect your lines at this time. Thank you for your participation.