Greetings, and welcome to the KLX Energy Services Third Quarter Earnings Conference Call. At this time, all participants are in a listen-only mode. A brief question-and-answer session will follow the formal presentation. [Operator Instructions] As a reminder, this conference is being recorded. It is now my pleasure to introduce your host, Ken Dennard. Thank you. You may begin.

Thank you, operator, and good morning, everyone. We appreciate you joining us for the KLX Energy Services conference call and webcast to review third quarter 2023 results. With me today are Chris Baker, KLX Energy's President and Chief Executive Officer; and Keefer Lehner, Executive Vice President and Chief Financial Officer. Following my remarks, management will provide a high-level commentary on the financial details of the third quarter and talk about its outlook before opening the call for your questions. There will be a replay of today's call, and that will be available by webcast on the company's website at klx.com. There'll also be a telephonic recorded replay available until November 21, 2023. More information on our access to these replay features was included in yesterday's earnings release. Please note that information reported on this call speaks only as of today, November 7, 2023, and therefore, you're advised that time-sensitive information may no longer be accurate as of the time of any replay listening or transcript reading. Also, comments on this call will contain forward-looking statements within the meaning of the United States federal securities laws. These forward-looking statements reflect the current views of KLX management. However, various risks and uncertainties and contingencies could cause actual results, performance or achievements to differ materially from those expressed in the statements made by management. The listener or reader is encouraged to read the annual report on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K to understand certain of those risks, uncertainties and contingencies. The comments today will also include certain non-GAAP financial measures. Additional details and reconciliations to the most directly comparable GAAP financial measures are included in the quarterly press release, which can also be found on the KLX Energy website. And now with that behind me, I'd like to turn the call over to KLX Energy Services President and CEO, Mr. Chris Baker. Chris?

Thank you, Ken, and good morning, everyone. Last night, we released our Q3 earnings, and we are extremely pleased with our third quarter performance. KLX maintained margins and generated incremental free cash flow despite a sequential 10% decline in rig count, a 7% decline in frac spread count and continued prolonged weakness in natural gas basins. As we report Q3, it appears the rig count is trying to bottom and natural gas prices have rebounded considerably which bodes well for future activity levels, including incremental gas directed activity into 2024. I'll go through the highlights of our third quarter before turning the call over to Keefer to discuss our financials in detail. KLX continues to focus on driving utilization and defending price to maximize margins and free cash flow. Our operations team has done a fantastic job all year adjusting their cost structures and maintaining pricing discipline. Overall, KLX continues to leverage its geographic and product service line diversification to drive results. Our more than 2,000 team members are well positioned across all major U.S. onshore basins to deliver our comprehensive portfolio of differentiated services and proprietary products. We believe the quality of our team and services allows us to capture a larger share of customer spending with outsized exposure to the largest, most active and best capitalized operators in the U.S. onshore market. For the third quarter, we had a revenue mix that was balanced both on a geographic and product mix basis. Geographically, the business was extremely balanced in Q3 with the Rockies generating 35% of revenue, up from 28% in Q2. The Southwest represented 35% of revenue, down slightly from 37% in Q2 and Northeast/Mid-Con represented 30% of Q3 revenue, down from 35% in Q2. We saw outsized contribution from the Rockies in Q3, driven by our…

Thanks, Chris. Good morning, everyone. As Chris mentioned, we reported quarterly revenue of $221 million, representing a 6% sequential decrease, which is lower than the 10% sequential decline in rig count. For comparison purposes, we reported third quarter 2022 revenue of $222 million, which was down only 50 basis points, which compared to the 20% year-over-year decline in rig count is a testament to the strength of our diversification strategy. The Rockies and Southwest segments each contributed 35% of Q3 revenue, led in the Rockies by our rentals, coiled tubing and tech services product service lines and in the Southwest, by directional drilling, rentals and coiled tubing. The Northeast and Mid-Con contributed 30%, led by pressure pumping, directional drilling and accommodations. Consolidated adjusted EBITDA was $36.7 million, demonstrating our ability to successfully maximize utilization, defend price and manage costs despite the much discussed rig count decline. Adjusted operating income for the third quarter was $17 million. Total SG&A expense for Q3 was $18.6 million. When you back out the nonrecurring cost, adjusted SG&A expense for Q3 would have been only $17.5 million or just 7.9% of quarterly revenue. We continue to run with one of the leanest overhead structures in the sector for diversified business and believe we can scale further while continuing to drive down G&A expense as a percentage of revenue. Q3 net income and diluted earnings per share were $7.6 million and $0.47, respectively. Adjusted net income and adjusted diluted EPS were $8.2 million and $0.51, respectively. Turning now to a review of our segment results. I'll begin with the Rockies. The Rocky Mountains segment third quarter revenue was $77 million, representing a 16% sequential increase and a 16% increase over the prior year quarter. Sequential increase in revenue was attributable to increased revenue across most product…

Thanks, Keefer. Before we wrap up, I'd like to share some additional details on our outlook and strategy. We expect a bit of slowdown in Q4 due to seasonality and budget exhaustion, but we believe the market activity is trying to find the bottom. As we look to 2024, we are confident the KLX platform is as well positioned as ever to ultimately benefit from increased customer activity and consolidation. Whether due to our lean cost structure, additional asset capacity or deployment of cutting-edge technology, the KLX platform has material intrinsic upside even in a moderately increasing market. As we enter the fourth quarter, we've seen consolidated rig count decrease an incremental 9% compared to a Q3 average of 649 rigs. WTI price is currently in the low 80s which is flat with the Q3 average and approximately 10% below quarter end, while natural gas price hovers around a very constructive $3.30. Our public customers have been incredibly disciplined regarding growing production and have leveraged the tremendous operating efficiencies afforded to them by their service providers to their benefit but ultimately, the strength of underlying commodity prices should drive strong returns for our customers and in return, additional service activity relative to Q3 2023 levels. Consistent with prior guidance, we expect full-year 2023 adjusted EBITDA to be in the range of $140 million to $150 million and expect that the business will continue to perform well due to our focus on crew utilization and pricing in order to drive margins and free cash flow. Given our revenue and margin expectations, combined with our CapEx guidance, we expect strong free cash flow generation in 2023 and continued strong free cash flow generation in 2024. As we look to 2024, there are several bright spots in addition to what we expect will…

Thank you. We will now be conducting a question-and-answer session. [Operator Instructions]. Your first question comes from John Daniel with Daniel Energy. Please go ahead.

Hey guys, thank you for having me. I guess the first one is on the frac side. If I heard you correctly, you said you've got the two and potentially a third getting in to the Mid-Con. Is that right?

John, you broke up a little bit, but I think you were asking if we set two spreads operating in the Mid-Con?

Yes. And then the third, I think -- I thought you said you had a third that might be going on. And I'm curious, just really your views on the Mid-Con. It tends to be more private than independent, if I'm not mistaken. And just what you're seeing from those operators right now?

Yes. Great question. So we do still have the two spreads and we had two spreads operating in the Mid-Con for all of 3Q. As you might imagine, we did have a fair amount of white space honestly, primarily due to drilling delays and we had a few clients that finished their programs early, really driven by completion efficiencies. So we elected to maintain staffing given incremental work in late Q3 and Q4. So we maintain staffing of those two spreads. Look, we're very accustomed. As you well know, the legacy routes of our business there on the pressure pumping side is really the Mid-Con and the Rockies. So we're accustomed to that customer base. We like that customer base. Spot pricing was down somewhat. But we really think that the contract we entered into allows us to baseload activity, drive efficiency gains and hopefully margins with limiting white space as we get into 2024. And to your last question on the third, so we do have -- still have the small spread in the Rockies where we're operating our cement business. That was very active in the third quarter. And I think what we made reference to in our prepared remarks was the base load and lack of white space. Depending on how the market plays out in 2024, we think sets us up well that if we elect to stand up the third spread, we'd be ready to do so, but we have not done that yet.

Got it. And then the last one for me because I got a bad connection, if you guys wanted to accelerate and bring on more of the electric wireline units, what are the lead times on those?

The lead times are volatile. It's what the lead times are. So it depends on the components. These two -- we were calling them two new units. They were completely refurbed from the ground up. Those were about six months. Latest Intel would be three to four months, but that's a moving number.

Fair enough. Thank you for including me.

Absolutely, appreciate the questions.

Next question is Steve Ferazani with Sidoti & Company. Please go ahead.

Good morning, Chris, Keefer, thanks for taking my questions. Good morning. I wanted to ask about the strength of margins in the Rockies. I know it's seasonally stronger. Trying to get your sense outside of seasonality, how sustainable those margins are? And I know the rig count didn't decline as much in certain areas as opposed to the gassier place. But the difference in how you're able to price in regionally in the Rockies versus Southwest and Marcellus?

Yes. Steve, great question. I think, look, as you well know, operating leverage is kind of like gravity. It always works, right? And that's what we saw in the Rockies this quarter. Candidly, we saw some of that last year. We've got a great team and a great presence in the Rockies and that really spans all the way through the Bakken, right? And so the reality is at this rig count and this activity base across most areas, operating leverage or negative operating leverage can really impact a given [indiscernible] or a given basin. And that's what we saw in the third quarter. We had more white space in the Mid-Con and the Southwest segment, especially around the Haynesville and the Eagle Ford than maybe we anticipated. Negative operating leverage dampered and put a damper on those margins, whereas in the Rockies, we saw a lot of activity, and we were able to redeploy some assets and mobilize some assets to cover off on additional work and see margin expansion with that operating leverage. The Rockies is also, to your point, more impacted by seasonality and weather. Last year in 2022, the Rockies performance in Q4 was stellar. It was as strong as I think we've ever seen it and that was really due to pent-up demand for our technical services and rentals business, in particular, especially on the production-oriented side of fishing, et cetera. And so look, we'll see how the fourth quarter plays out but we're very confident 2024 plays out exceptionally well in that business.

Great. And if I follow up on the Northeast/Mid-Con, I know it's only early November, so it's early to be having these conversations. But the recovery in natural gas prices, the sort of interest in the additional LNG export capacity that's coming, trying to get your sense in your conversations with customers so far, and I know it's early. With the new contract year, when are you expecting to see some sort of a pickup in those plays? And are you confident right now in a pickup in activity in those plays?

Yes. Great question. What I would say is there are two distinctly different markets still tied to the LNG story and natural gas story. Clearly, the Mid-Con and the Haynesville specifically, we've seen a lot of rig count roll there so operators have ducked more wells as we've gone through 2023. And we're definitely seeing a slight -- I'll categorize it as a slight pickup in completions activity in Q4, and we're having discussions in the Haynesville around rig adds in 2024. I don't think we see the same pickup in the Northeast in Q4 that we do in the Haynesville, partially just due to winter weather, seasonality, et cetera. But look, we're bullish when it comes to the natural gas outlook. We talked about this at your conference previously. 2024, if you look at the forward strip is highly constructive on the gas side, and we're hearing more and more positive feedback and outlook from commodities traders and others that 2025 is actually looking very strong at this point. So I think we've got some wind in our sale when it comes to the gas side of the business.

Okay, thanks Chris.

Yes, appreciate it, Steve. Thank you.

[Operator Instructions] Next question from David Marsh with Singular Research. Please go ahead.

Hey guys, thanks for taking questions. So just touching on the guidance. Previously, you guys had provided both revenue and EBITDA margin guidance. The last revenue guidance you had provided was a range of $900 million to $950 million for the year. Is that still a range that is achievable at this point?

So I think, David, I'll jump in and Keefer can jump in as well. This is Chris. Thanks for the question. What we updated in our prepared remarks was full year guidance. And so the full year adjusted EBITDA guidance and EBITDA and cash flow is what matters, right? So it's $140 million to $150 million. And so when you think about on a year-to-date basis, we're approximately $114 million. That guidance didn't really change on a full year basis over the last quarter, right? And so the midpoint of the full year is essentially equal to our prior guidance and consensus. So nothing's really changed there. We just didn't update the revenue number.

Got it. Got it. And then I guess as my follow-up, could you just -- Keefer, could you just give us a refresh on the credit facility? Where we're termed out to you right now? And any activity around that, that you guys might possibly pursue in terms of the extension. And with regard to the cash, I mean, are you -- do you guys look for opportunities to perhaps pay down that ABL a little bit to reduce interest expense in the interim? Or is there something particularly positive about holding cash, you guys able to earn more interest income from holding cash than when you're paying an interest expense.

Yes, good question. Happy to jump in here. I'll address your second question first, go a little bit out of order. As it relates to cash and uses of free cash flow, clearly, we think through optionality there. We're continuing to focus on reduction of net debt and building free cash. We're going to continue to evaluate opportunities to use cash in both organic and inorganic initiatives as we think about growing the business, and we'll continue to evaluate opportunities to pay down the ABL. At this point in time, we've elected to build cash. You can see from the face of the income statement, we are generating pretty substantial interest income today on our cash balance. So we're kind of more than offsetting the ABL cash interest cost based on the cash balance that we have today. But that is something that we do continue to evaluate. As it relates to the broader capital structure, we've got two pieces of debt paper out there. The ABL and the notes, both mature in the Fall of 2025. The ABL has a springer inside of the notes, but they mature roughly two years from today. So I think we're in a really good spot based on Q3 annualized results, LTM results. The business is performing exceptionally well. We've kind of more than grown back in the capital structure. Our net leverage ratio today is 1.3x. Moody's came out last week and upgraded our outlook to positive. So everything in that regard continues to head in the right direction but we still have two years of tenure left. Our call premium just dropped down to 102 and 78 as of November 1. And so I would expect over the next year or so, we're going to start to look harder around opportunities to refinance the capital structure of the business but we're just going to be patient and make sure that we execute a refinancing opportunity that makes the most sense for KLX and best positions us to continue to execute on our growth strategy going forward.

Thanks, Keefer. Thanks, David. So we've gotten a couple of questions since the call started via e-mail from some folks. Chris, you mentioned numerous benefits from the Oracle SRT. So can you elaborate more on that? I think people are interested there.

Sure, Ken. Appreciate the question. Look, our vision from the outset was to develop a next-generation smart tool that not only had performance benefits, but also inherent safety benefits as well as the potential to reduce string fatigue in coiled tubing as well as wear and tear on other asset components. The economic benefit of drilling and completion efficiency gains has largely accrued to the benefit of the operator while the increased cost of equipment wear and tear is candidly accrued to the detriment of the service company due to equipment cycle times, et cetera. And so the reality is it's paramount that OFS companies find ways to share in the efficiency gains to benefit margin across every service line that we operate in. And as we look at Oracle SRT, it really has the potential to extend coiled tubing string life, which is inherently margin-enhancing while also simultaneously bringing technology benefits to bear for the customer. And so we'll provide more benefits on the technology down the road, but we're really excited about the opportunities ahead.

That's good. We got another one talking about the -- longer laterals is kind of a buzzword today. What's your experience and expectation of continued adoption of the four-mile laterals?

Great question. And it's definitely in the news, and we see people setting records. We continue to see operators experiment with a whole host of lateral lengths and configurations. And while there's discussions and we're in discussions with operators on four milers, we believe that most operators are building their business to be really in manufacturing mode to drive efficiencies and find ways to improve ultimate recoveries of oil and gas in their wellbores. And in certain basins, the reality of the situation is four milers create incremental risk for operators where they would prefer other means to drive recoveries. So whether that lands all two, three or four milers, KLX is prepared to adapt and assist our clients with successful drilling and completion programs on complex wells. We recently were instrumental in the completion of a highly technical horseshoe well or actually two highly technical horseshoe wells in the Permian, which led to impressive results for that client. And so while depth records are nice, the reality is we're focused on serving our clients with consistent execution of highly technical wells while maximizing margins for our stakeholders over setting link records. That being said, look, lastly, KLX's diversified suite of products and services really allows us to address all of these distances as well as configurations.

We also got one talking about the outlook based on early customer guidance. It appears 2024 spending would be flat to slightly up year-to-year. If you want to comment on that?

Sure. I think -- look, there's been significant shape to 2023, just like there was in 2022 and we would expect some shape to '24 similar to Steve's question earlier in the call, just based off the constructive nature and forward strip on the natural gas side. So we would expect -- and from what we're hearing thus far, is slightly -- is flat to slightly up spending, which should ultimately lead to improved year-over-year results for KLX. And I think that's due to 4 specific points. We've got intrinsic upside in our incremental asset base, we have already talked about some of the high points of frac contract base loading, that service line as well as the introduction of additional Whisper series electric wireline units that we think we can deploy at attractive rates. And then lastly, further penetration of all the technologies we've talked about thus far, including our Gen 3 now rebranded dissolvable plug, the PhantM -- KLX PhantM Dissolvable.

Anything you want to add, Keefer before we -- looks like we're done with e-mail questions and people online -- on the call.

Yes. And just to follow up on the plug side. I think certainly, as you see this trend towards longer laterals, that's clearly going to drive a need for increased consumables per wellbore which ultimately is going to be a benefit for KLX suite of products and certainly our plugs business. As Chris mentioned, we announced the launch of our latest gen PhantM Plug. We've seen tremendous market response so far in the third quarter. So we worked with numerous leading operators across multiple basins where we've seen strong market adoption of our new plug technology. Customer feedback has been really strong to date. We did mention in the prepared remarks that our dissolvable plug sales were up north of 500% quarter-over-quarter. And based on October results, those strong plug sales have continued into Q4 and we would expect this trend to continue as we work into 2024 as well.

Yes, absolutely.

So that's it. Final comments, Chris?

Thank you once again for joining us on the call today and your interest in KLX Energy Services. We look forward to speaking with you again next quarter.

Thanks, everyone.

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