Good morning, and welcome to the Cactus Q1 2019 Earnings Call. My name is Marcella, and I will be facilitating the audio portion of today’s interactive broadcast. All lines have been placed on mute to prevent any background noise. For those of you on the stream, please take note of the options available in your event console.

At this time, I’d like to turn the show over to John Fitzgerald, Director of Corporate Development and Investor Relations..

Thank you, and good morning, everyone. We appreciate your participation on today’s call. The speakers on today’s call will be Scott Bender, our Chief Executive Officer; and Steve Tadlock, our Chief Financial Officer.

Also joining us today are Joel Bender, Senior Vice President and Chief Operating Officer; Steven Bender, Vice President of Operations; and David Isaac, our General Counsel and Vice President of Administration. Yesterday, we released our first quarter earnings release, which is available on our website.

Please note that any comments we make on today’s call regarding projections or our expectations for future events are forward-looking statements covered by the Private Securities Litigation Reform Act. Forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control.

These risks and uncertainties can cause actual results to differ materially from our current expectations. We advise listeners to review our earnings release and the risk factors discussed in our filings with the SEC.

Any forward-looking statements we make today are only as of today’s date, and we undertake no obligation to publicly update or review any forward-looking statements. In addition, during today’s call, we will reference certain non-GAAP financial measures.

Reconciliations of these non-GAAP measures to the most directly comparable GAAP measures are included in our earnings release. With that, I will turn the call over to Scott..

Okay. Thanks, John, and good morning to everyone. I’m pleased to report strong first quarter results having delivered top line sequential growth of nearly 14% and all-time revenue highs for all three of our business lines. Our growth significantly exceeded the trajectory of the U.S. land rig count, which was down 3% sequentially and U.S.

completions activity. During the period, average U.S. market share in our products business, which we define as a percentage of onshore rigs followed, increased from 27.8% to a record 29.1%.

Further, we generated attractive margins despite lower commodity prices at the start of the year, rising costs associated with Section 301 tariffs and the strength in Chinese currency in response to reduced trade tensions.

In summary, revenues increased 13.6% sequentially, adjusted EBITDA increased 10.4% sequentially and adjusted EBITDA margins were 37.2% in the first quarter. I’ll now turn the call over to Steve Tadlock, our CFO, who’ll review our first quarter financial results.

Following his remarks, I’ll provide some thoughts on our outlook for the near term before opening the lines for Q&A.

Steve?.

Thanks, Scott. Q1 revenues at $159 million were 38% higher than the equivalent period last year and 14% higher than in the fourth quarter of 2018 as Scott mentioned. We reported record revenue for all three of our business lines despite the broader sequential decline in the U.S. land rig count.

Product revenues, which include consumables used in both drilling and production, were $87 million, 47% higher than the equivalent period in 2018 and 10% higher sequentially.

The product gross margin of 39% was 170 basis points higher than Q1 2018 and 320 basis points lower sequentially due largely to the more fully realized impact of Section 301 tariffs and changes in FX rates, as Scott mentioned. Rental revenues were $39 million, 32% greater than Q1 2018 and 23% higher sequentially.

The increase was attributable to continued investments in our asset base and demand for a differentiated equipment during the quarter as our customers’ budgets reset in January. Field service and other revenues in Q1 were $34 million, 25% higher than Q1 2018 and 14% higher than Q4 2018.

Higher sequential revenues were driven by an increase in billable hours for our work tied to both drilling and completions activity and the recovery from the seasonally impacted fourth quarter. The movement year-over-year is due to an increase in billable hours as the follow-on effect of our products and revenue growth over this time.

Field service revenues represented approximately 27% of combined product and rental-related revenues during the quarter, in line with expectations. SG&A at $12.7 million for the quarter was $3.6 million higher than Q1 2018 and $2.2 million higher than Q4 2018.

The sequential increase arose primarily from higher stock-based compensation expense and increased professional audit and tax fees. The majority of the increase compared to 2018 was due to additional payroll expenditure and other costs associated with becoming a public company.

We would expect SG&A in 2Q 2019 to be roughly flat sequentially with stock-based compensation expense slightly under $2 million per quarter for the remaining nine months of 2019.

Depreciation and amortization expense during the quarter totaled $8.9 million, up $6.6 million sequentially, and we would expect similar sequential increases for the remainder of 2019. Net income at $48 million increased from $39 million in Q4 2018.

This included $1 million in costs associated with the March follow-on offering as well as an income tax benefit of $8 million. You’ll recall that our income statement reflects a net income attributable to the noncontrolling interest owners and public owners of Cactus, Inc. First quarter adjusted EBITDA was $59 million.

This was 38% greater than the equivalent period last year and up 10% sequentially. Adjusted EBITDA for the quarter represented 37% of revenues, which compares to 37% in Q1 2018 and 38% for Q4 2018. We reported a total tax benefit of $1 million during the quarter, which was inclusive of a specific $8 million tax benefit.

In conjunction with the March secondary offering, we released a previously booked valuation allowance and recorded a tax benefit related to the realizable portion of the associated deferred tax assets. Our public ownership averaged 52% during the quarter.

At the end of the quarter, our public ownership was 52%, which should result in an effective tax rate of approximately 15% barring further changes in our public ownership percentage. Internally, we’d prefer to look at adjusted earnings per share as it eliminates the impact of changes in public ownership throughout the quarter.

It assumes the public entity held all units in our operating subsidiary, Cactus LLC, at the beginning of the period with the resulting additional income tax expense related to the incremental income attributable to Cactus, Inc.

With fully diluted shares outstanding of approximately 75 million and an effective tax rate of 24.0%, our adjusted earnings per share this quarter was $0.49 per share compared to $0.45 per share in Q4 2018, an increase of 9%. We estimate that adjusted earnings per share in Q2 will have an effective tax rate similar to Q1 of 24.0%.

Our cash position increased by $17 million during the first quarter to $88 million at March 31. For the quarter, operating cash flow was $34 million, and our net CapEx spend was $14 million.

Additionally, we spent $2 million on finance lease payments in the quarter and repurchased about $2 million worth of shares associated with a restricted stock unit vesting event in February following the 1-year anniversary of our IPO.

Net working capital increased by approximately $20 million during the quarter, broadly in line with the increase seen in revenues. While accounts receivable increased by $16 million sequentially, DSOs remained in the low 60s.

We continue to receive product from China in January that had been purchased in anticipation of possible year-end tariff increases. Net working capital at the end of the first quarter, expressed as a percentage of Q1 annualized revenues, was flat compared to December 2018.

And while the rate is still higher than historical norms, we would expect to see further reductions as the year progresses. Our full year 2019 capital expenditure expectations are unchanged as we still expect to spend in the low $60 million range.

This includes $45 million to $50 million for growth capital on our rental business with a significant portion going toward our new innovations. That covers the financial review, and I’ll now turn you back to Scott..

So thanks, Steve. Further increases in wells drilled per rig and larger pad sizes continue to benefit our business. That said, the U.S. land rig count has moved lower thus far in the second quarter.

While our rigs followed, is likely to decline quarter-over-quarter, we believe our Q2 product revenues may be relatively unchanged based on preliminary results through April.

Looking to the latter part of the year, we are cautiously optimistic regarding modest increases in overall drilling activity from Q2 levels as crude prices have now stabilized at levels above $60 per barrel particularly following the decision to cease Iranian oil waivers.

We have noted renewed interest from private operators, while our larger publicly traded E&P customers are broadcasting capital spending discipline while exerting pressure on suppliers more consistent with the $50 per barrel price environment.

And point of fact, our market share gains during the quarter can be attributed to an increase in activity from private and preexisting customers in a declining rig count environment. Market share gains were recorded despite limited progress with the majors.

On the rental side of the business, our customers have maintained their level of completion activity thus far during the second quarter, while we’ve expanded our market penetration with the majors.

We expect to maintain rental revenue in Q2 despite the declining rig count environment as we’ve seen increased demand for higher pressure, large-bore valves already reflected in our 2019 CapEx budget.

Regarding the commercialization of our new completions initiatives – our innovations rather, on-site performance has exceeded expectations, and we’re confident we’ll surpass our previously indicated year-end revenue projections.

While we’re still in the early stages of deploying these assets in the field, our customers have already witnessed tangible efficiency gains, leading to an increase in stages per day on location. Interestingly, pressure to perform in the aforementioned $50-odd per barrel budget environment has enhanced interest in these products.

CapEx for these new innovations specifically will be largely spent during the second half of the year, although we are attempting to bring this forward given demand. Field service, which is driven by both product and rental activity, witnessed its typical first quarter rebound following the slower holiday season.

Going forward, we’d expect revenue from this business to remain in the 26% to 28% range of our combined product and rental revenue. Regarding tariffs, the impact of Section 301 tariffs that were set at a rate of 10% on products imported from our wholly-owned foreign manufacturing subsidiary in China was more evident during the first quarter.

There may be some small residual effect on margins during the second quarter, but we’re confident there’ll be no additional impact post Q2 and we expect minimal further currency effects. In summary, we expect revenue in the second quarter of 2019 to be at least as strong as our record-setting first quarter.

We do not expect meaningful changes in overall margins, although a slight decline in product may be largely offset by gains in rental.

In anticipation of questions about capital allocation in light of our increasing cash position, I can confirm we reviewed no suitable M&A opportunities to date, and our Board has made no decisions regarding dividends or a potential buyback program.

We remain firmly focused on safety execution, producing attractive returns on capital and generating a significant amount of free cash flow. So with that, I’ll turn it back over to the operator, and we can begin our Q&A session.

Operator?.

[Operator Instructions] Your first question is from the line of Tommy Moll [Stephens, Inc.]. Your line is open..

Good morning and thanks for taking my questions. .

Good morning Tommy. I wanted to start on the theme of capital discipline, which has come through loud and clear from the E&Ps recently, and you mentioned how the value proposition for the new rental products fits into that.

And I wonder is the pitch to customers on a per well basis you spend fewer dollars in addition to an efficiency gain? Or is it more just on the efficiency side?.

Yes, Tommy, it’s the latter..

Okay.

But did I hear you say correctly that even in the current capital austerity environment for some of the E&Ps that the uptake on those new offerings has actually aided?.

Yes. It is because there’s increased emphasis right now on reducing NPT..

Okay. Got it. And then your commentary on the rig count, I think, syncs up pretty well with what some of the land drillers have been saying a couple – in recent days have come out and pretty clearly called 2Q the bottom. I wonder if you have any visibility into your existing customers planning.

You indicated that if crude holds and we get into the back half of the year, maybe you’d see an uptick in the rig count.

Are you having any conversations with existing customers at this point about what their internal planning might look like? Or is it still too early to know?.

Yes, Tommy, I’d say it’s probably a little bit early, although we have pretty good visibility in terms of our wellhead business through the next – certainly through Q2 and probably into Q3, although things can change.

The comment about optimism really probably addresses more – first, we got a couple of customers indicate they might loosen their belts a little bit if crude prices remain high, but also we’ve seen a significant increase in inquiries from privates. And privates, as you know, are about 40% of this market. So it’s a very significant player.

It’d be – despite capital discipline, which as I mentioned, all of our customers are preaching the fact that oil is in the $60, $65 range gives me some optimism that we’ll see some rebound by the second half of the year..

Great. Thank you. I will turn it back..

Your next question comes from the line of David Anderson [Barclays]. Your line is open..

Scott, I was hoping you could talk about your business from more of a medium- to longer-term perspective, which I think you’d probably prefer to do anyways.

As you think about planning out over the next, call it, two to three years, I know you’re doing a little bit of manufacturing expansion right now, moving some things around, opening – adding a little – freeing up some on the wellhead side. But how do you think about, say, U.S.

completions market in terms of, say, the number of wells that are going to be needed to drill annually over the next several years just to keep production flat? These decline rates are really starting to pick up.

But if you think about trying to scaling up your business and kind of planning around this, kind of what are some of your baseline expectations? If you can just kind of walk me through your thought process as you think about kind of the next two to three years..

Well David, it’s, I think, more about our business specifically than I do about the industry in general. We have – we still feel like we have lots of headroom in our completions side of our business. So I guess I’d say two things. I believe the completions side of the business in general is going to grow faster.

And I believe because of our low market share relative to our drilling market share, we’re going to see additional, I think, tailwinds from that.

So as we plan from perhaps 2021, I think you’ll probably see we’ll rely upon our Suzhou facility to maintain adequate capacity in terms of the wellhead, and we’ll begin to look at perhaps greater emphasis in the U.S. on being able to maximize utilization of our rental assets.

So if you were to go – you were kind enough to visit our Bossier City facility and you saw it was quite busy. Most of our branch locations are similarly quite busy.

So while there’s no roofline expansion for this year, I would anticipate, looking at 2020, we’ve got a couple of branches that probably could use some expansion just to handle the volume of what I think is going to be some fairly attractive completion work..

So it’s less on the manufacturing capacity that you need to build out.

It’s going to be more in the service center side and kind of that – kind of hand-to-hand stuff that maybe you do differently than your competitors?.

Yes, David. That’s correct..

So Anadarko is one of your customers, which of course is in the process of changing hands..

I didn’t – we don’t talk about....

You didn’t hear that? Yes. Okay. Agreed. No, I wasn’t going to do it to my customer. I was actually more getting in the line of that when a customer – a knee-jerk reaction is going to be, hey, they’re going to lose share.

But the other side of that would be this is also an opportunity to work your way in with that new customer and maybe another customer base. And I know some people – one of the questions is how do you break into the majors on the wellhead side? Do you see this as an opportunity? Because it seems to me – the product itself speaks for itself.

This would seem to be a great opportunity to kind of showcase that product to try to get into that.

Is that how you view that? Or maybe can you talk about maybe some of the challenges that you face with some of these other types of customers that maybe have a different procurement process than, say, your normal customer base?.

Well, without getting into specifics, I would say that our success rate in winning customers is fairly high if we can get out on the trial. And heretofore, our ability to get our equipment out on a trial for majors has – we’ve not had much success in that regard.

So to the extent a major purchases, one of our customers uses our equipment, I think the trial issue will be behind us. And again, if the past is any indication of the future, we do extremely well with trials in comparison to our competitors.

Does that answer your question?.

Absolutely does, perfectly. Thank you..

Your next question comes from the line of George O’Leary [Tudor, Pickering, Holt & Co]..

[Indiscernible]. Thanks for taking my questions guys. I just want to start off, as you guys look to grow the business and I think in your area where you have the most line of sight to growth is, it sounds like, is still on the rental side and the completions side.

Are there any basins where you feel like you’re spending more time trying to grow there? Or is it more of a customer-specific conversation and you’re sort of basin-agnostic?.

Yes, it’s the latter. We follow a customer, really not the basin..

Got it. And then I realized customers are looking at trying to limit nonproductive time as they’re trying to reduce their cash and maximize their cash flow.

What specific issues are they – just thinking about your existing customers, what specific issues today are they looking for you to help solve? What are the pinch points as you see them today?.

You mean – I’m going to set aside drilling because I think we’ve spoken about that to a great extent, but it shouldn’t be taken for granted, George, either because once you’ve saved a day or so in rig count, it’s a very difficult thing to walk away from.

So I think we’ve continued to mention that we see most of the nonproductive time related to a frac location, where there’s a great deal of confusion, a great deal of multiple suppliers working.

So if you just think about the time spent rigging up frac equipment, when you go on location, you have the pressure pumpers, you have wireline companies, you have the zipper manifolds, if they use that, you have the frac trees, you have all the hardline. All of it takes time.

All of – any – it takes time, it produces an opportunity for safety issues and nonproductive time. And then as we go to simultaneous operations, you see the activity in moving from well one to well two to well three and back to well two and back to well one. So think about all that movement that takes place between wells.

And then think about, I guess, thirdly, all the maintenance that has to take place on a frac location and that’s maintenance to – you all know starts with the pressure pumper, but there’s a lot of maintenance that goes on with the pressure control equipment, the zipper manifolds and the frac valves.

So those are the areas that we’re trying to address..

Great. [indiscernible]. Thanks guys..

Your next question comes from the line of Scott Gruber [Citigroup]. Your line is open..

Yes, good morning..

Hi Scott, how are you?.

Well. You guys had a good quarter in rental, particularly from the top line perspective. It sounds like you’re making further inroads with the majors.

I’m just curious, why not a better outlook than just flat in 2Q on the top line for rental?.

Scott, that’s a good question. Yes. A lot of our increase during the quarter – this is the same old story, was very large-bore, very high pressure valves. And our product mix has changed in 2019 in comparison to 2018. And we’ve been caught without sufficient assets in that particular category, which we did see coming.

I wish we’d seen it come in a little bit earlier. So a significant part of our noninnovation-related CapEx is directed towards the higher pressure, large-bore valves. And higher pressure, I mean 15k. A lot of work right now. You know the areas where 15k fracture taking place basically, the SCOOP/STACK in the Delaware.

So those assets will begin to come in sometime at the end of the second quarter and the third quarter, by which time, we should see some help. So right now, we’re a little bit capacity constrained..

Understood. And then it sounded like there was some transitory and mobilization cost weighing on the rental a little bit in 1Q.

How much was that and does that roll out in 2Q, before we pass that in 2Q?.

I would say, Scott, that probably contributed 100 basis points to 150 basis points to our reduced margin. We really fought cold weather in the first quarter. I don’t ever – I try never to blame performance on cold weather, but maintaining this equipment in cold weather is a challenge, particularly in January and maybe part of February.

So we spent a lot more money to ensure this equipment has uptime. And then we – because of the lack of adequate supply in 15k equipment, we were shuffling it all over the country..

Got it..

So we’ve not – I got the better position, I think..

Got it. Maybe if I can just squeeze one more in. You’re getting questions on the potential for capital return this year.

Do you think that will happen before year-end? And just your updated thoughts on the process, when is that appropriate? And what’s your latest thoughts on the method?.

If we don’t see an opportunity to deploy our cash in a responsible manner, I think we’ll do something by the – make some announcement by the end of the year..

Got it. Thank you very much..

Your next question comes from the line of Chase Mulvehill [Bank of America Merrill Lynch]. Your line is open..

Yes, good morning, gentlemen..

Good mornig..

I wanted to kind of try to dial in 2Q a little bit on the products side. Maybe if you can kind of help us understand where your market share ended the quarter and if you expect that to kind of sustain that level that you ended the quarter or expect that to grow in 2Q..

Chase, I always expect it to grow, so we do. We’re always chasing work. Our market share is about – you’ve got it now – I haven’t looked at it this week, but it’s pretty much flat with the last figures that you saw. So we do a lot of business with the large E&Ps. Most of their broadcasted reductions have already taken place as far as we can tell.

So we think that for our less active customers, they’re going to remain fairly flat. We might lose another rig or two. But as I mentioned, we’ve seen a pretty significant uptake in privates and – although we don’t really talk about them a lot, they’re an important part of our business..

Right Okay. That makes sense.

And if we think about market share kind of towards the end of the year, internally, do you have a market share target or a target that you’d like to share with The Street?.

We do have one internally. I would not like to share it with The Street..

Does it start with a three handle?.

Chase, Chase..

All right, I’ll move on. On the product margin side for 2Q, you said margin’s down.

Can you just walk through kind of what’s contributing to the margins being down in a kind of flat revenue environment, and then how much should we think about margins being down in 2Q?.

First, I’ll ask what contributes to that, it starts pretty much with tariffs and ends with tariffs. So we’re going to see the – we think we’ve seen pretty much the full impact of the tariffs rolling through our inventory, but we were expecting we could see another 100 to 150 basis points, after which you’ll see the full impact.

I don’t know if you saw the paper this morning.

There’s talk about rolling back that 10% 301 tariff on the $200 billion tranche that was announced last – I think it was last July, wasn’t it, folks?.

Yes..

So it looks like there’s going to be some compromise on tariffs. I think the last thing we saw was the 25% on the Section 232, might remain in place. But the next $200 billion, which is the area of most concern to us might roll off. So we’ll have to see how that plays out..

Okay, right. That’s some positive news there.

Last one, you talked positively about the privates and inquiries, are you seeing most of the increase in inquiries from privates on the completions or the wellhead side?.

Wellhead..

Awesome clarity. Turn it back over. I appreciate the color..

Your next question comes from the line of Marshall Adkins [Raymond James]. Your is open..

Good morning guys..

Good morning..

So you guys have been kicking everyone’s butt on share here on the wellhead side. At some point in time, I would think your competitors respond.

Are you seeing any response from them in terms of legitimate competitive solutions to what you guys provide?.

Marshall, I think, I probably said before, I think that without patting ourselves on the back too much, I think that we probably raised the benchmark in the industry. I think everybody’s products today are better than they were a couple of years ago. And some of that clearly is a response – in response to our market share gains.

So yes, we have a big target on our back and their products are getting better. I think that if you had a chance to, maybe, go through our plant, you’d see that, that really is a – well, it’s a very important part of our business. The execution part of our business is really important.

So it doesn’t do you any good to have the greatest product in the world if you can’t show up on location on time and if you can’t install it and test it without problems.

And so while we talk about innovations because it’s a lot easier, I think, for our audience to grasp, I cannot overemphasize the importance of our unique supply chain and our ability to make a delivery when we promise. And then on our staff of field service techs, we’ve got, I don’t know, 350-or-so scattered around the U.S.

who perform every single day. So that’s just part of the equation. Look, Cameron’s got outstanding equipment. I don’t normally like to mention competitors, but you’ve got – we’ve got some very, very good competitors out there with great equipment. I just feel like we’re much better focused on this business..

Right. Well, your results certainly bear that out. Let me shift gears over to the rental side. You’ve been commercializing – the process commercializing a bunch of these new frac innovation products. You’re going to be, I presume, putting a lot of money into those here in the back half of the year.

Are you ready to tell us? I know you guys haven’t really been wanting to be too forthright in terms of what you’re doing.

But at what point in time will we start to see exactly what that is and how that’s going to be additive to the rental business?.

Marshall, you’re going to see it the last possible time..

Afraid you’d say that..

Well, the fact is I am – some – when people ask what keeps me up at night, the two things that keep me up are safety, concerns and competitors. And the last thing I want to do is open this up to our competitors. And they’re going to see it increasingly and I just don’t intend to help them..

Let me come at it in different ways. It does – I heard earlier, and just maybe correct me if I’m wrong, but it seems like you’re, maybe, a little bit ahead of schedule that it’s progressing extremely well. Maybe update us on timing when you think these things will start to hit, if you could.

I know you mentioned a little bit earlier, but just a little more color on that..

Okay. Marshall, they’re in the field right now. The problem is we don’t have enough of them to move the needle. And we’re not going to have enough of them to move the needle until the third quarter. That’s the problem. It’s not a question of acceptance. It’s not a question of demand. It’s not a question of the value proposition.

Right now, we’re doing everything we can to bring forward the receipt of these goods. So I’m going to stand by our earlier comment that you need to look at Q3 and Q4. And we mentioned an exit rate of, I think, 20% by the end of the year. I think that we’re going to surpass that..

Right.

And are there bottlenecks in terms of manufacturing? Is that just more just the whole process where by the time we get into next year you’re going to be blowing and going on and putting more of this stuff out in the field?.

Yes, it’s manufacturing bottlenecks, Marshall..

Guys thank you very much..

Yes..

Your next question comes from the line of Martin Malloy [Johnson Rice]. Your line is open..

Good morning..

Hey Martin..

Just on the manufacturing side, I think you’ve got two new CNC machines coming online relatively soon at Bossier City.

Do you have other plans beyond that to add capacity?.

Joel?.

Just in terms of headcount capacity right now, in terms of machine tools, these two will give us the additional capacity we need right now to continue to increase the rework and the amount of rental assets we put back into the field..

Okay.

And then on the rental side, as you’re able to leverage your field techs and your infrastructure on the field over the medium to long term, how should we think about that in terms of the impact on margins on the rental side?.

Well, I mean, obviously it would increase because we don’t really need a whole lot more footprint, although I did make mention of the fact that in 2020, we have a couple of facilities that just flat need expand – roofline expansion because of the volume of goods, but there’s a high degree of incremental margin contribution from the rental business.

Yes. And utilization, frankly. The degree to which we better utilize our assets clearly because of the – we have a fixed amount of depreciation for those assets, has a significant impact on our margin profile..

Great. Thank you..

[Operator Instructions] Your next question comes from the line of Kurt Hallead [RBC Capital Markets]. Your line is open..

Hey, good morning everybody..

Hey Kurt, how are you..

Hey, I am great, great, thanks Scott. So Scott, just wanted to maybe circle back on the context around the dynamics where you have a pretty significant opportunity to penetrate with the major oil companies as they get larger in the Permian.

Just kind of curious, as you think through that dynamic, do you have a specific time frame as to when you’d like to kind of crack that code and how far along you might be in potentially making that happen?.

Yes. I’d like to have cracked it last September..

Fair enough.

But in all honesty, is there any particular dynamics where the major oil companies really are not that interested in your value proposition? Or is there some insights you might be able to kind of provide us on how these majors might be different in terms of their decision-making process vis-a-vis the independents? And over time, you’ve had experience, you sold in the majors before, so just kind of looking for some additional insights on how things are proceeding there..

I really – I can’t really forecast when or even if I’ll know. I’m just as optimistic as I’ve ever been, and we’re working just as hard or harder than we ever worked. But I really – I don’t think I could opine on when the timing of that breakthrough, if any, will occur. Having said that, I’m pretty happy with the results of the company so far.

And there’s a lot of low-hanging fruit out there in terms of multi-rig players. But then we’re not doing any work and they’re also on our target. So we’re not really – if you look at our list of target accounts, clearly, the majors are on there, but there are an awful lot of large E&Ps that are also on that list..

Yes. That’s all fair. And maybe from a – as we think maybe longer term as well and maybe a question for Stephen on this, Steve Tadlock.

When you think about the optimal capital structure and you think about where you’d like to reside in terms of return on capital and other return metrics, can you give us some insights on how you’re going to mapping that out?.

Well, I think – I mean, honestly, I think we’re doing a pretty good job. We’re over 30% return on capital employed. We would look at our – and that’s over a long time horizon. So the recent years have been better than that. So we’re always kind of scrutinizing everything we do to make sure it’s got a very high return on capital.

And that’s why you don’t see us making acquisitions that don’t make sense and spending money on rental that’s not highly utilized, so....

Okay. Thank you..

There are no further questions at this time. I’ll turn the call back over to the presenters..

Thanks, everyone, for joining, and we look forward to speaking with you on our next earnings call..

Thanks, everybody. Have a good day..

This concludes today’s conference call. You may now disconnect..