Greetings. Welcome to the KLX Energy Services Second Quarter Earnings Conference Call. As a reminder, today's conference is being recorded. At this time, I'll turn the conference over to Ken Dennard, Investor Relations for KLX Energy. Ken, you may now begin.

Thank you, operator, and good morning, everyone. We appreciate you joining us for the KLX Energy Services conference call and webcast to review its second quarter 2025 results. With me today are Chris Baker, President and Chief Executive Officer; and Keefer Lehner, Executive Vice President and Chief Financial Officer. Following my remarks, management will provide commentary on its quarterly financial results and outlook before opening the call for your questions. There will be a replay of today's call that will be available by webcast on the company's website and will also be a telephonic recorded replay available until August 21, 2025. More information on how to access these replay features was included in yesterday's earnings release. Please note that information reported on this call speaks only as of today, August 7, 2025, and therefore, you're advised that time-sensitive information may no longer be accurate as of any time of the replay listening or transcript reading. Also, comments made 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, 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 risks, uncertainties, and contingencies. 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 be found on the KLX website. And now with that behind me, I'd like to turn the call over to Chris Baker. Chris?

Thank you, Ken, and good morning, everyone. Thank you for joining us today. I'm pleased to report that consistent with what we outlined on our last call, KLX had a relatively strong second quarter, outperforming the market backdrop. Our results demonstrate that we are executing in line with our game plan, driving efficient operations and controlling costs even as the sector wrestles with persistent commodity price volatility and softness in oil rig and frac spread counts. For the second quarter, we reported revenue of $159 million, up 3% from Q1 and adjusted EBITDA of $19 million, up 34% from Q1. Revenue increased meaningfully in our Rockies and our Northeast/Mid-Con segments, which more than offset the sequential decline in the Southwest. Adjusted EBITDA margin improved materially, up 260 basis points sequentially to 12% despite the U.S. land rig count being down 7% and frac spread count being down 14% over the same period. We experienced meaningful margin fall-through on this revenue increase as a direct result of our focus on maximizing utilization, driving a very efficient cost structure, and leveraging KLX's strong reputation for differentiated completion and production services across all key U.S. onshore basins. Our performance was driven by the execution of our operational initiatives, including cost focus, asset rotation, holding the line on pricing where possible, taking market share where profitable, and leaning into higher-margin PSLs. As we alluded to on our Q1 call, the second quarter saw significant strength and sequential improvement across our completion and production portfolio, including technical services, coiled tubing, and accommodations, among others. Our team in the field did an exceptional job managing headcount and sharing personnel across districts in response to the inevitable white space that is pervasive in this market where our customers' completion plans are constantly changing. Recall, in general, more than 50% of our revenue occurs post the frac job. Therefore, white space due to customers taking completion holidays, especially in the Permian, makes staffing extremely difficult. Incredible teamwork and alignment across our organization allowed KLX to maximize labor utilization and drive improved adjusted EBITDA margins. The macro environment remains challenging given OPEC+ production increases, tariff policy overhangs, recession risk, and rig count volatility. Yet as we've shown, our diversified portfolio, strong customer alignment, and diverse geographic footprint continue to drive relative outperformance where and when it counts. Q2 revenue and adjusted EBITDA per rig were $286,000 and $33,000, respectively, which were 8% and 172% ahead of our results in Q4 of 2021, the last quarter with a similar rig count to today. This demonstrates our materially improved market share and positioning within the industry since 2021. Now let's look at our geographic results. The Rockies was 34%, up from 31% in Q1. The Southwest represented 37% of Q2 revenue, down from 42% in Q1 and the Northeast/Mid-Con was 29%, up from 27%. Rockies completion PSLs made significant contributions to the quarter-over-quarter improvement in top line and margin led by coiled tubing, tech services, and other completion services. The Rockies benefited from a return to normalized seasonal operating levels and a favorable shift in revenue mix, which we expect to largely continue into the third quarter. The Southwest battled through customer-initiated breaks with completion holidays driving white space in Q2 due to commodity price volatility, especially within our frac rentals, wireline, and flowback PSLs. Margins saw some compression versus Q1, mainly due to cost absorption associated with the previously mentioned white space and stand-up costs associated with our thru tubing business but remained in line with 2024 averages, which we expect to continue into Q3. Northeast/Mid-Con benefited largely from improved completion activity over the first quarter. The segment experienced a 12% revenue increase sequentially and more than doubled its adjusted EBITDA and adjusted EBITDA margin over the same period. You'll recall this segment was impacted by unforeseen white space in Q1. We expect further improvement in both revenue and margin in Q3. By end market, drilling, completion, production, and intervention services contributed approximately 16%, 56%, and 28% of Q2 revenue, respectively. Finally, as a follow-up to the evolving tariff landscape, our strategy remains the same: pass along increased costs where possible and adjust sourcing to mitigate short- and medium-term risks. With that, I'll now turn the call over to Keefer to review our financial results in greater detail, and I'll return later in the call to discuss our outlook.

Thanks, Chris. Good morning, everyone. As Chris mentioned, Q2 2025 revenue was $159 million, a 3% sequential increase. Consolidated adjusted EBITDA was $18.5 million with a 12% margin, up from 9% in Q1 2025, demonstrating strong cost discipline and improved utilization and was in line with last quarter's guidance. Total SG&A expense for Q2 was $18 million. Backing out nonrecurring items, adjusted SG&A expense would have been $15.1 million, a 12% reduction versus prior year Q2 and an 8% reduction versus Q1 2025, reflecting the full benefit of the cost structure changes we executed in early 2024 plus some additional savings in the first half of 2025. We have remained lean from an overhead perspective and expect adjusted SG&A expense to hover in the 9% to 10% of revenue range for 2025. Moving to our segment results. The Rockies posted a strong sequential rebound with second quarter revenue of $54.1 million, operating income of $3.3 million, and adjusted EBITDA of $10.4 million. Sequential revenue and adjusted EBITDA increased 13% and 55%, respectively, driven by a return to normalized seasonal operating levels and a favorable revenue mix that combined to drive a 500 basis point increase in segment margin sequentially. In the Southwest, revenue, operating loss, and adjusted EBITDA were $58.8 million, negative $1.7 million, and $7.2 million, respectively. On a quarterly basis, Q2 revenue decreased 10% sequentially with EBITDA down 38%. Permian rig count decline led the U.S. onshore market lower, declining 9% sequentially. Permian customers reduced activity and took extended completion holidays, which drove lower utilization and increased white space versus the first quarter. Additionally, start-up costs and some transitional friction weighed on the quarter as we work to expand activity within certain completion PSLs. For the Northeast/Mid-Con segment, revenue was $46.1 million, operating loss was $1.3 million, and adjusted EBITDA was $7.2 million. The sequential increase in revenue of 12% and adjusted EBITDA of 167% were largely driven by higher utilization across the vast majority of our completion PSLs, corresponding reduced white space, and targeted expense management across the geo segment. All of this combined to drive a 900 basis point increase in segment adjusted EBITDA margin, and we expect further margin improvement into the third quarter. At Corporate, our operating loss and adjusted EBITDA loss for the quarter were $9 million and $6.3 million, respectively, which improved 27% and 14%, respectively, from last quarter as we've continued to reduce overhead and fixed costs. Now turning to our balance sheet, cash flow, and capitalization. We ended Q2 with $16.7 million of cash on hand and reduced restricted cash from $8.1 million in Q1 to only $600,000 as of June 30. Restricted cash is currently being reduced further to $55,000 in Q3. We ended Q2 with approximately $65 million in liquidity, an increase of 13% from Q1, including $16.7 million of cash and cash equivalents and $49 million of availability on our revolving credit facility, including $5 million on an undrawn FILO facility. Total debt as of June 30 was $259 million, including $213.7 million in notes and $45 million in ABL and represents a 1% decrease compared to Q1 levels. We are in compliance with both our net leverage ratio and CapEx covenants as of Q2. Our bonds require a 2% annual mandatory redemption paid quarterly, and we continue to make these payments, but we did pick $7.1 million of interest in Q2, and we will evaluate future PIK versus cash pay decisions based on market conditions and company leverage and liquidity. And just last week, we elected to pay a portion of Q3 interest in cash. Even with the PIK interest in Q2, we were able to reduce total debt by $2.3 million versus the prior quarter. Moving to working capital. As of June 30, we had $46 million in net working capital, which decreased almost $14 million sequentially, and our DSO and DPO normalized to 61 days and 51 days, respectively, both in line with longer-term historical averages. We will continue to proactively and prudently manage working capital as we navigate the current market. CapEx for Q2 was $12.7 million gross and $11.1 million net of asset sales. Spending was focused on maintenance of our pressure pumping, coiled tubing, and accommodation fleets. As of June 30, we had accrued CapEx of approximately $12 million and $2.2 million of assets held for sale, including a property sale for $1.8 million that closed in early August. Looking ahead, we have taken measures to curtail second half spending, and we expect gross CapEx for 2025 in the range of $40 million to $50 million and net CapEx between $30 million to $40 million. To reiterate our financial objectives, as we advance through 2025, we expect cash and liquidity to improve, supported by our ongoing focus on efficient capital allocation, strategic asset deployment, and proactively managing our debt levels to minimize cash interest costs. Our team's deep experience navigating sector cyclicality enables us to proactively identify and implement additional measures aimed at continuous cost structure refinement, optimizing our asset footprint, generating sustainable free cash flow, and maximizing financial flexibility. I'll now hand the call back to Chris for his concluding remarks and more color on our outlook.

Thanks, Keefer. The broader market environment remains volatile, and visibility continues to be opaque, but we are confident that our focus on operational discipline, balance sheet flexibility, and proactive risk mitigation will allow us to successfully navigate the remainder of 2025. Looking forward, Q3 is expected to be the strongest quarter of the year, maintaining a consistent pattern seen in prior years and showcasing our strong positioning with leading customers across the entirety of the U.S. onshore geographic market. We are again targeting a sequential quarterly revenue increase of low to mid-single digits on a percentage basis with continued margin expansion. Despite the noisy macro, this outlook reflects strength in KLX's underlying business, recent awards from key customers across our core PSLs, certain customers' completion programs restarting from Q2 breaks, and continued strong operational execution, leading to enhanced profitability alongside measured top-line growth. As we look ahead to the second half of 2025, we remain optimistic about the long-term fundamentals for U.S. natural gas as well as the positive implications for KLX. Our significant presence in gas-focused basins positions us well to capture incremental activity as new LNG export capacity ramps over the next 12 to 24 months. On a quarter-over-quarter basis, we saw a 25% increase in our dry gas revenue, but we are still 40% off of the gas-driven quarterly revenue highs we saw in Q1 of 2023, illustrating that there's ample room to grow. We remain committed to deleveraging our balance sheet by appropriately allocating capital on a disciplined and prioritized basis, driving free cash flow, and pursuing strategic value-accretive M&A opportunities that support our growth. Plus, our improved debt structure provides the ability to act quickly when compelling opportunities arise. Although the current market backdrop and our share price create added complexity to potential transactions, we continue to view our business as fundamentally undervalued. Notably, since our March refinancing, a number of potential M&A targets, including some previously reviewed in 2024, are reengaging. The current rig count environment raises urgency amongst many OFS providers on the need for consolidation where the market is challenging, both operationally and financially. We continue to believe that meaningful consolidation is necessary for the sector and are ready to capitalize on opportunities that advance our position. In summary, as we enter the second half of 2025, we are confident in our ability to execute our strategy and navigate what is a dynamic and volatile market. Our scale, diversified offering, broad geographic footprint, and strong customer relationships position KLX to capture share and continue to drive results. We appreciate the dedication and contributions of our employees, the partnership of our customers, and the ongoing trust and support of our shareholders. With that, we will now take your questions.

And the first question is from Steve Ferazani with Sidoti & Company.

This is Alex on for Steve. So maybe just to start from us. I know you're guiding for low to mid-single-digit sequential revenue growth in 3Q, which would be typical seasonality. Any concerns about hitting that number given the continued decline in rig count?

No, look, it's a great question. I think we talked about what underpins our guidance last quarter. I think if you step back and look at Q2 specifically, I think we had a relatively strong quarter relative to the macro background. But if you really dig in and look at Q2 on a monthly basis, we really had 2 out of 3 solid months. April was weaker than May and June, and that strength exiting Q2 and what we saw in June is a big part of what underpinned our Q3 forecast. But as you look at the Q3 guidance specifically, I think rig count is factored in. What's essentially not factored in is unexpected white space from customers. That being said, we saw a number of operators restart completion programs post some 2Q holidays that they took. And our current schedule and our current 90-day outlook suggests all 3 months of the quarter should be base loaded. We've also had some near-term wins with multiple clients in multiple basins that went through off-season or off-cycle RFQs post completing their integration programs associated with recent M&A, and we should benefit from that incremental work as well.

Great context. And I know you just touched on this a little bit, but maybe we could expand on opportunities in gas basins and specifically, any increased inquiry activity in the Haynesville or the Marcellus? And just geographically, where do you see the best opportunities over the next 6 to 12 months?

Yes, it's a great question. Look, we talked about it in the prepared remarks. We've seen rig count ramp about 12 rigs from the bottom in the Haynesville. Our Haynesville revenue increased about 25% quarter-over-quarter. And so the way I would think about those 2 basins, the Northeast has been fairly stable for us. And I would say that in a positive light. Q1 was fairly strong. Q2 continues to hold there. The Haynesville activity continues to ramp. And my prior comments around winning RFQs, we've definitely seen some opportunities where we've won some incremental work going into the second half of the year. We're still off the highs of Q1 of '23 when we think about the overall gas exposure and revenue coming out of those 2 basins. So I really think it speaks to the opportunity we have on the revenue level to continue to grow as gas rig count continues to expand along with completions activity.

And then just one more from us. Lower CapEx and reduced working capital certainly seems to be supporting the balance sheet. So just a question, given the ongoing weakness, how are you thinking about cash flow in the second half and any potential further asset sales or cost cuts? I know you kind of alluded to some opportunities in the prepared remarks.

Yes. Alex, this is Keefer. I'll jump in on cash flow. To your point, we didn't give an explicit guide on free cash flow for the second half of the year. But with that said, we did generate almost $12 million of unlevered free cash flow in the second quarter, and we saw liquidity increase almost $10 million sequentially. So we have guided clearly for Q3 to be up from a top line perspective as well as from a margin perspective. So I think clearly, that's driving higher quarter-over-quarter EBITDA for the business. From a working capital perspective, Q3 is going to be slightly more intensive than the second quarter was. There's a couple of things driving that. One, obviously, an incremental increase in revenue; and two, there are 3 payrolls in the month of July, and there are no 3 payroll months in the second quarter. So those 2 things combined to drive marginally higher working capital intensity at least in the third quarter, but some of that will likely unwind in the fourth quarter. Thinking through the other building blocks of free cash flow, if you just use kind of the midpoint of our full year net CapEx guide, it would imply about $15 million of second half net CapEx. Based on current accruals, I think it's safe to assume that there's going to be some shape to that with Q3 capital spending being higher than capital spending in the fourth quarter. So put all that together, I think to reiterate what we said in the prepared remarks, we do expect liquidity/cash to continue to improve as we navigate the second half of 2025.

Next question is from the line of John Daniel, Daniel Energy.

Chris, in your prepared comment, you touched on what I took as elevated M&A discussions. What would you say is the driver of that? And do you think that the people that you might be speaking with have more realistic valuation expectations?

I think the driver of it is somewhat capitulation. Look, the reality is some of the smaller service companies are really struggling in this environment where they perhaps don't have the SOPs, the safety initiatives, etc., to work for some of the blue-chip majors. And so maybe the first time in a long time, we're seeing a bifurcation of performance. And I think some of the smaller guys are really struggling in certain basins. Whether there's capitulation on price and value is very much TBD, but we are definitely seeing deal flow and a bit of capitulation where people are coming back, asking to come to the table and see if the art of the possible is there.

Okay. And then you just touched on the SOPs. That was something that some field guys shared with me a couple of weeks ago on a trip. I'm just curious, does that apply to all of the various OFS service lines? Or are there certain ones that are maybe immune from that? Can you just elaborate on the significance of that?

I think it's highly significant when you think about the blue-chip majors that have been the primary drivers of the wave of consolidation we've seen over the last couple of years. So when you think about those names, their HSE requirements, their SOPs, consistency of performance in the field is very, very important. Are there operators? And are there certain service lines when you talk about non-pressure control surface rental equipment or otherwise that don't have those requirements, light plants, other things? Sure. There's leniencies there, especially when you get to some of the smaller private operators. But when you're talking about pressure-related equipment, coil tubing, frac, etc., yes, I think you have to have all the appropriate levels of procedures in place to work consistently for the larger operators.

Okay. You've been in this industry for a long time. Do you think that the enforcement of these regulations has significantly changed compared to what the major companies may have done five to seven years ago?

I believe if you recall our Q1 call from last year, we mentioned a few operators completely halting operations in certain basins and districts for a month. This reflects their commitment to doing things correctly. There has indeed been a significant change. While there will always be exceptions in the field, overall, I think we've seen a notable shift in the approach, aligning with the 80/20 principle.

Got it. Okay. The last one for me, just on the gas markets. And I know visibility sometimes is limited in this space, but would you expect a less severe seasonal impact in Q4 this year in the gas markets than maybe prior years? Or would you just say normal at this stage?

It's a good question. We continue to engage with our clients about how they are managing the current strip. A couple of weeks ago, the strip was significantly stronger than it is now. However, they don't appear to be losing confidence. We are still seeing more rigs coming into the Haynesville along with additional completion crews, so it doesn't look like there will be substantial budget exhaustion in the fourth quarter for the Haynesville. The Marcellus and Utica may be slightly different because activity seemed very strong on a seasonally adjusted basis in the first quarter this year and has remained stable in those plays, showing little growth but a lot of consistency. The concern is whether that stability and the quick start in Q1 might lead to some budget exhaustion in Q4. We haven't heard about that yet, but it's certainly something we need to monitor.

This now concludes our question-and-answer session. I'd like to turn the floor back over to management for closing comments.

Thank you once again for joining us on this call and your continued interest in KLX. We look forward to speaking with you again next quarter.

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