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spk03: Good day and welcome to the Neighbors Industries fourth quarter 2023 earnings call. All participants will be in listen-only mode. Should you need assistance, please signal a conference specialist by pressing the star key followed by zero. After today's presentation, there will be an opportunity to ask questions. To ask a question, you may press star then one on a touch-tone phone. To withdraw your question, please press star then two. Please note this event is being recorded. I would now like to turn the conference over to William Conroy, Vice President of Business Development and Investor Relations. Please go ahead.
spk01: Good morning, everyone. Thank you for joining NABOR's fourth quarter 2023 earnings conference call. Today, we will follow our customary format with Tony Petrello, our Chairman, President, and Chief Executive Officer, and William Restrepo, our Chief Financial Officer. providing their perspectives on the quarter's results, along with insights into our markets and how we expect neighbors to perform in these markets. In support of these remarks, a slide deck is available, both as a download within the webcast and in the investor relations section of neighbors.com. Instructions for the replay of this call are posted on the website as well. With us today, in addition to Tony, William, and me, are other members of the senior management team. Since much of our commentary today will include our forward expectations, they may constitute forward-looking statements within the meaning of the Securities Act of 1933 and the Securities Exchange Act of 1934. Such forward-looking statements are subject to certain risks and uncertainties as disclosed by neighbors from time to time in our filings with the Securities and Exchange Commission. As a result of these factors, our actual results may vary materially from those indicated or implied by such forward-looking statements. Also, during the call, we may discuss certain non-GAAP financial measures, such as net debt, adjusted operating income, adjusted EBITDA, and adjusted free cash flow. All references to EBITDA made by either Tony or William during their presentations, whether qualified by the word adjusted or otherwise, mean adjusted EBITDA as that chart is defined on our website and in our earnings release. Likewise, unless the context clearly indicates otherwise, references to cash flow mean adjusted free cash flow as that non-GAAP measure is defined in our earnings release. We have posted to the investor relations section of our website a reconciliation of these non-GAAP financial measures to the most reasonably comparable GAAP measures. With that, I will turn the call over to Tony to begin.
spk04: Good morning. Thank you for joining us today as we present our results and outlook. Adjusted EBITDA in all our segments exceeded our expectations in the fourth quarter. Daily margins in the U.S. lower 48 and international drilling improved. Our two technology segments once again performed well. As we forecasted, the industry rate count in the lower 48 declined modestly in the fourth quarter. Our major international markets were essentially in line with our prior view. During the quarter, we deployed three rigs in these markets. One was a new bill unit in Saudi Arabia. Leading edge pricing in the lower 48 was stable. This helped drive the increase in our daily rig margin, along with outstanding expense control. For the fourth quarter, adjusted EBITDA totaled $230 million. Our global average rate count for the fourth quarter declined by two rigs. All of this decline occurred in the U.S. Our drilling solutions and rig technology segments together generated EBITDA of $43 million, a record. As a portion of total EBITDA, these segments accounted for nearly 19% of the quarter, also an all-time high. Next, let me make some comments on five key drivers of our results. I'll start with our performance in the U.S. Daily rig margins in our lower 48 rig fleet exceeded our expectations. They increased by almost $400 compared to the third quarter. Daily revenue in the fourth quarter increased slightly. Daily expenses declined by more than $300. I am pleased with this performance. These results demonstrate our team's ability to execute at an impressive level in this market environment. Our reported lower 48 daily rig margin reflects the financial results of just our drilling rigs. The drilling solutions portfolio, NDS, generates significant margins on top of that. I'll discuss this in more detail in a few moments. Now I'll discuss our international drilling business. Daily margin in this segment increased by nearly $900. This result exceeded our expectations. During the quarter, we stood up three rigs. We restarted two in Colombia. Another new build rig in Saudi Arabia also started up. With these additions, we have now deployed the first five of the ongoing international startups that I detailed last year. Margins increased in Saudi Arabia, where our SANA joint venture operates 48 rigs. This fourth quarter improvement resulted from the contribution from new bills deployed during the third and fourth quarters of last year, plus strong operating performance across the entire fleet. Let me add a few more comments concerning the new build program in Saudi Arabia. The fifth rig started in the fourth quarter. The second tranche of five rigs is currently under construction in the Kingdom. We currently expect the first of this group to spread during the current quarter. Two of the remaining four rigs should be deployed by the third quarter of 2024. The last two rigs of that tranche are expected to spread in early 2025. We expect the first unit of the previously awarded third tranche to start around mid-year 2025. The outlook for the balance of our international business, both in the Middle East and in Latin America, remains quite positive. Three of the four total rates we were awarded in Algeria should start this quarter. We see prospects to add additional rates in a number of international markets. These include Kuwait and Algeria in the Middle East and elsewhere in the Eastern Hemisphere, in Argentina and Latin America. Let me finish this discussion on the international business with a few comments on the recent news out of Saudi Arabia. The Senate currently operates 48 rigs there. Of these, 40 work in gas and the balance in oil. Contracts for the oil-directed rigs have recently been extended for a four-year period. With the Kingdom's focus on developing the natural gas resource, we are very comfortable with our position there. As to the new bill program, This was contemplated well before capacity expansion plans in Saudi Arabia. The new bill program is also a key element in the Kingdom's Vision 2030 plan. As such, we are confident in the program's future. Next, let me discuss our technology and innovation. Revenue grew sequentially in all three portions of MDS's business, on neighbors' lower 48 rigs, on third-party lower 48 rigs, and in international markets. The international business recorded the strongest growth, with revenue up 13% sequentially. Revenue grew in the lower 48, both on neighbors and third-party rigs. I would like to stress, NDS grew faster than the rig counts in both of these market segments. Our NDS EBITDA increased by 13%, which beat our expectations. This performance represents the highest sequential quarterly progress in all of 2023. From a product line perspective, casing running and performance software drove NDS's growth. Next, I will detail the value that NDS generates in the lower 48 market. The average daily margin in the lower 48 from our drilling and drilling solutions businesses combined was over $20,000 in the fourth quarter. Of that, NDS contributed more than $3,900 per day. This significant incremental margin contribution, a quarterly record, comes with limited capital spending. The returns on capital in NDS are the highest in our company. In the fourth quarter, penetration of NDS services increased on neighbor's rigs in the lower 48 to nearly 7 per rig. Once again, we saw growth in our SmartSlide directional steering system and our SmartNav directional guidance software. These installs were up 19%. The casing running job count also grew significantly, up 17%. As shown by the fourth quarter results, our multi-pronged growth strategy for the MDS portfolio is proving successful. Looking ahead, we see increasing interest globally across product lines, particularly for our advanced technology solutions. Next, let me make some comments on our capital structure. With the proceeds from our recent debt offering, we redeemed the notes that were due in 2024 and 2025, pushing our next maturity to 2026. As we look ahead, our first priority for free cash flow remains reducing net debt and improving our credit ratings. I'll finish this part of the discussion with remarks on sustainability and the energy transition. Our energy transition initiatives, as you know, focus on improving operational efficiency and reducing emissions intensity. These technology solutions once again contributed visible margins to our rig technology segment. The most impactful is our PowerTap module. This unit connects rigs to the grid. In the fourth quarter, we had 24 modules running. More than 20% of those were on third-party rigs. In addition, two units are in transit to Argentina. These two are the first power top units incorporating a frequency converter for the international market. We have eight more units under construction, including two destined for the international market, one more for Argentina, and the second for a large market in the Middle East. Our energy transition portfolio continues to gain traction. We are encouraged by the emerging opportunities internationally, complementing those in the U.S. on both neighbors and third-party rates. Geopolitical events in the Middle East interest rates, and lingering inflation concerns all make for the continued elevated volatility of commodity prices. In this environment, the operator response has been to restrain ambitions and exercise capital discipline. It is understandable why operators are looking at mergers in this environment. The near-term effect of recently announced mergers is yet to be fully determined. Notwithstanding this uncertainty, international prospects, particularly those driven by NOCs, remain very attractive. Our geographical position is unique in the global land drilling industry. It enables us to capture international growth. At the same time, we are positioned to capitalize on any emerging growth in the U.S. Next, I will discuss the pricing environment. Our fourth quarter results for the lower 48 reflect continued stabilization of leading edge market prices. I want to reemphasize the rates for our highest spec rigs exceed all of the pre-2023 market highs. Our focus in the lower 48 market remains profitability, while we stay committed to delivering superior value to our customers. As such, we continue to demonstrate the value of our technology portfolio with MDS. As I mentioned, in the international market, we have committed seven additional rigs in 2024. This growth should provide substantial uplift potential to our earnings. We believe there is room for additional rig deployments in the Eastern Hemisphere and Latin America. I will discuss these in a few minutes. We surveyed the largest lower 48 clients at the end of the fourth quarter. Our survey covers 17 operators, which account for approximately 46% of the working rigs at the end of the quarter. During the fourth quarter, consistent with the prior survey's results, this group added more than 10 rigs. The latest survey indicates this group's year-end 2024 rig count will be essentially in line with the year-end 2023. More than half of this group signals no change. The balance indicates minor additions or decreases. We believe that, with the uncertainty in commodity prices, customers remain cautious about their plans for 2024. Our plan for our lower 48 business this year fully contemplates the current environment. We continue to focus on maximizing free cash flow while we look for opportunities to put additional rigs to work. Our view of the international market is bullish. With the international additions already in hand, we would increase our international rig count by almost 10% by the end of 2024. We expect our segment revenue to grow by low double digits and our EBITDA margins to expand. Next, I will share some of our notable recent highlights and accomplishments. First, NDS was selected by a very large operator in the Middle East to install NDS's advanced rig control and automation system of five working rigs. The multi-round award process was competitive. This award marks the first rig automation project in this market. It is notable the neighbors were chosen to lead this effort. Second, we commenced operations in Arkansas to drill wells supporting lithium production. Exxon Mobil selected a neighbor's Pacex rig for this project. Third, another of our Pacex rigs was awarded for the year by one of the largest operators in the Permian for the second consecutive year. Competition for this award came from rigs operated by six other drilling contractors. Next, we are now providing support to a drilling contractor in Libya under a recently signed technical services agreement. Under the agreement, we are providing expertise but have no capital at risk. In addition to these highlights, I want to mention the notable agreement between Nabors and SLB. Together, we will collaborate to scale automated drilling solutions for operators and drilling contractors. This integration of both companies' platforms expands the breadth of drilling automation technologies available to customers. It also increases their flexibility to utilize existing rate control systems from either neighbors or SLB. And to wrap up, the SPAC sponsored by neighbors closed the previously announced business combination with Vast Renewables Limited. The combined company trades on the NASDAQ exchange under the ticker VSTE. Let me finish my remarks with the following. We are encouraged by our operational performance as we close out the year. Looking ahead in 2024, we see significant opportunities both in our global markets and for our advanced technology solutions. Now, let me turn the call over to William, who will discuss our financial results.
spk05: Thank you, Tony, and good morning, everyone. Fourth quarter financial results surpassed our expectations, with EBITDA for all segments increasing sequentially. In the U.S., we managed to maintain our lower 48 daily revenue at the strong level we achieved in the third quarter. while our operational expenses decreased meaningfully following measures to reduce our field overhead. Consequently, our daily margins improved materially rather than decreasing as we had anticipated. International drilling benefited from increased income in Colombia and Saudi Arabia, together with disciplined cost control across geographies. Drilling solutions deliver strong results, well above our expectations, bolstered by year-end sales of casing running tools as well as robust deployments of our software and data offerings. For rig technologies, we believe an upgrade and recertification cycle is developing as global rig count increases. The segment also over-delivered with strong year-end shipments of rig components, together with higher than expected equipment rentals and sales of spare parts. In addition, the margin mix of our revenue contributed favorably to the healthy port quarter result for the segment. We expect the first quarter drilling activity in the lower 48 market to improve over fourth quarter levels, though at somewhat lower average pricing. We also anticipate that the international growth we have experienced should continue throughout 2024. Although we are forecasting positive trends for our drilling solutions and rig technologies to persist in the first quarter, we will miss the impact of the seasonal year-end equipment sales. For the full year 2023, Revenue from operations total $3 billion. This compares to $2.65 billion for 2022, a 13% improvement year-over-year. NDS and rig technologies led the way, with both delivering 24% growth. Our drilling rig segments also grew significantly. Lower 48% improved by 15%, while international increased by 12%. For the fourth quarter, Revenue from operations was $726 million, or 1% below the third, a slight decrease reflecting a decline in U.S. average rate count. This, in fact, was partially offset by strong increases in drilling solutions, as well as incremental rate count in Colombia and Saudi Arabia. Revenue for a U.S. drilling segment at $266 million was down 11 million, or 4%. This decrease reflected a 3.4 rig reduction in our lower 48 rig count. Daily revenue of $35,800 was up slightly versus the third quarter. Revenue from our international segment of $343 million remained essentially in line with the prior quarter. In Saudi Arabia, we successfully deployed the fifth new build rig and improved operating efficiency. In addition, Two rigs restarted operations in Colombia. Revenue from this incremental activity was offset by a reduction in low-margin reimbursables in certain geographies. Revenue from neighbors doing solutions grew sequentially by $4.2 million, an increase of 6%. Despite lower recount in the lower 48, NDS demonstrated resilience by continuing to add third-party revenue and expanding its presence in international markets. Compared to the third quarter, NDS increased lower 48 third-party revenue by 8%, and international revenue improved by 13%. RIG Technologies' revenue decreased by $2.2 million, or 3.5%, primarily due to lower capital equipment sales to the neighbor's fleet. Nonetheless, we experienced a material increase in third-party high-margin RIG components, rental, and spare parts sales. Full year 2023 EBITDA reached $915 million, increasing by 29% from $709 million in 2022. This growth was spread across all of our segments. The improvement was primarily driven by significant daily margin expansion in both our drilling businesses and rig count expansion in international markets. NDS and rig technologies also contributed meaningfully. Combined, these two businesses grew EBITDA by $43.6 million in 2023, a 38% improvement year over year. For the fourth quarter, total adjusted EBITDA was $230 million, $20 million higher than the third quarter, and 9.6% improvement. All of our segments contributed to the growth. Despite decreased lower 48 activity, U.S. drilling EBITDA increased by $1 million, or 1%, compared to the prior quarter. This improvement was driven by the M400's maintenance-related downtime in the third quarter and higher daily margins in the lower 48 market. Lower 48 drilling rate EBITDA decreased by $1.2 million, or 1.2% sequentially. Average recount of 70.3 declined by 4.6%. Average daily rate margin of $16,240 was almost $400 higher than the prior quarter on a moderate increase in daily revenue and a $300 per day reduction in operating expenses. The leading edge price environment continues to hold steady, and our efforts to limit costs are proving effective. For the first quarter, we project our average daily rate gross margin at approximately $15,300. The expected sequential reduction reflects repricing of renewals as rigs roll to new contracts. During the fourth quarter, our rig count was 70.3 on average, and we exited the quarter at 74 rigs. We anticipate a high level of churn during the first quarter. Consequently, despite an underlying favorable trend in activity, we expect rig count in the first quarter to average between 73 and 75 rigs. On a net basis, Alaska and the U.S. offshore businesses performed better than we anticipated. In the fourth quarter, the combined EBITDA of these two operations was $18.7 million, an increase of $2.2 million. EBITDA rebounded following third quarter planned maintenance on our M400 rig in the Gulf of Mexico. The strong offshore results were partially upset by year-end maintenance on two Alaska rigs. Combined EBITDA for Alaska and US offshore should increase between $1.5 and $2 million in the first quarter, driven by a rebound in Alaska activity and partly offset by a one rig drop offshore. International EBITDA increased by $9.4 million and 9.7% to $105.5 million. Average rig count and average daily growth margin improved largely driven by the additional three rigs deployed, as well as by operating expense reductions and improved operational performance in Saudi Arabia. For the quarter, average rig count increased by 2.4 to 79.6 rigs. Average daily gross margin came in at $16,650, up almost 900 from the third quarter. We project international average rig count in the first quarter to increase by approximately two rigs, driven by new-build startups in Saudi Arabia and the commencement of our contract awards in Algeria. For average daily gross margins, we are targeting between $16,100 and $16,300. The anticipated sequential decrease, as compared to the fourth quarter, reflects potentially higher startup costs for several rigs during the first quarter. Drilling solutions adjusted EBITDA grew by 13.4% to $34.5 million in the fourth quarter. Gross margin for NDS was 52.4%, up from 51.2%. We continue to see increased market penetration, particularly in third-party rigs and in international markets. Internationally, NDS grew EBITDA by almost 10% sequentially. In the U.S., casing running and performance software drove robust growth. We expect first quarter EBITDA for drilling solutions to come in between $30 and $31 million, primarily driven by the absence of seasonally high equipment sales. NDES daily gross margin for the lower 48 was $3,912, up 15% from the prior quarter. Our combined drilling rig and solutions daily gross margin reached $20,151, a 4.7% improvement. It is worth highlighting the NDS growth year-on-year. Comparing to full-year 2022, NDS EBITDA increased by over 30%. NDS EBITDA contribution to neighbors as a whole also increased, while gross profit margin widened. RIC Technologies generated EBITDA of $8.8 million, a 22% increase versus the third quarter. This growth was primarily related to high-margin year-end capital equipment shipments, rentals, and spare parts sales. I would also like to point out that our energy transition business has started to contribute meaningfully to our RIG Technologies EBITDA. We expect RIG Technologies EBITDA in the first quarter of $5 to $6 million. Now turning to liquidity and cash generation. Overall, our 2023 EBITDA was historically strong. It is true, however, that last year we had a significant EBITDA shortfall in our US segment, driven by the market, And in Saudi Arabia, we delayed new bill deployment. Notwithstanding these shortfalls, totaling nearly $200 million in EBITDA, we still generated $111 million in free cash flow. Other factors did affect our free cash flow in 2023. Our capex for the year at $553 million was higher than we had forecasted by about $70 million, most of the variance coming from Saudi Arabia. In addition, we incurred capital expenditures from incremental international awards that required significant upfront investment spent well before the corresponding EBITDA generation. Also, we purchased our operating base in Baca Muerta, Argentina, as our activity in that basin continues to expand. Interest expense was also higher than we planned, with rates increasing sharply during the year. Finally, working capital, rather than being a tailwind, actually increased in the second half of the year as clients held on to their cash for longer, likely driven by the higher interest rate environment. In terms of capital structure, we remained busy during 2023, addressing our debt maturity profile. During the year, we completed capital market transactions for a total of $900 million. Late in 2023, neighbors issued $650 million of senior priority guaranteed notes, due in 2030. During January of this year, we retired $630 million of our near-term debt maturities, mainly our 2024 convertible debt and our 2025 senior unsecured notes. These transactions extend our next debt maturity into 2026. Free cash flow totaled $52 million for the fourth quarter. This result includes an increase in capital expenditures versus our projection, and working capital headwinds. CapEx of $124.5 million in the fourth quarter fell by 32 million below the level of the preceding quarter, but it was significantly higher than our target, mainly in Saudi Arabia. This amount included investments for the Sanaa New Build program of $42.9 million. for the first quarter of 2024 we expect capital expenditures of approximately 170 to 180 million dollars including 50 million for sun at new builds this should be the high water quarterly mark for the year we will refrain from providing annual free cash flow and capex guidance at this point we're currently considering a total of eight additional international tenders in conclusion the fourth quarter had many positives First, our EBITDA rebounded close to the levels of the first half and was significantly above our expectations. Second, the lower 48 was higher than we expected and very strong price and cost performance. We are seeing increasing rate count in that market with stability in leading edge pricing. Third, international rate count increased and margins were also significantly stronger than expected, almost $900 over the prior quarter. Fourth, NDS was strong on international and third-party sales with our gross margin profitability expanding. Fifth, great technologies also grew with signs that an upgrade recertification cycle is commencing and with encouraging performance from our ET business. And finally, I can say that the future bodes well with double-digit international revenue growth expected in 2024 and a base being built for further lower 48 recoveries. This improved drilling environment and further progress on our market penetration strategies should also continue to drive improved results for drilling solutions and rig technologies. Although at this point we will not provide annual guidance, we expect lower 48 rate count to recover throughout the year from the 2023 quarterly average. Our full year 2024 average should end up somewhere close to our average for the full year 2023. International average rig count should increase by somewhere between 7 and 10 rigs, depending on timing of deployments. We also expect drilling solutions and rig technologies to increase significantly as compared to 2023. And during 2024, we expect to deliver a significant sequential increase in free cash flow. And of course, we are planning to allocate this cash generation towards reducing our net debt. With that, I will send the call back to Tony for his concluding remarks.
spk04: Thank you, William. I will now conclude my remarks this morning. As we look ahead, we see significant opportunities. As mentioned previously, we have in hand seven big startups in 2024, which, combined with partial year startups in 2023, will yield sizable EBITDA contributions in 2024. Looking ahead, we still have in our pipeline additional opportunities, which we are evaluating. Those markets include Algeria, Kuwait, Argentina, and one more rig in a market in the Eastern Hemisphere. That totals eight rigs in these markets. On top of these eight, we have committed orders for seven more rigs in Saudi Arabia in 2025 and 2026. Altogether, these add up to 15 incremental opportunities on top of the seven committed rigs for 2024. We believe it is imperative to use our strong geographical position to take advantage of these favorable market opportunities. The Navis portfolio is uniquely positioned to take advantage of multi-year contracts with attractive returns in international markets. Ultimately, when combined with the prospects for our NDS business, this is one of the most attractive environments we've seen in years. This concludes my remarks today. Thank you for your time and attention. With that, we will take your questions.
spk03: We will now begin the question and answer session. To ask a question, you may press star, then 1 on your touchtone phone. If you're using a speakerphone, please pick up your handset before pressing the keys. If at any time your question has been addressed and you would like to withdraw your question, please press star, then 2. Our first question comes from Kurt Haliak with Benchmark. Please go ahead.
spk06: Hey, good morning, guys.
spk05: Good morning. Good morning.
spk06: Thanks for that thorough assessment. So, hey, Tony, I'm really curious in the context here, right? It looks like there's this continued growth wedge between, you know, international and the U.S., and you kind of laid out how you think things are going to run, right? So when you think about the opportunities outside of Saudi, right, there's always been seems to have always been, you know, some things that kind of get in the way that, you know, impede, you know, timing or startup or something along those lines. So, just kind of curious on how you think about that with respect to that 7 to 10 rate increase that you're thinking about through 2024 and, you know, what could be some of the risk factors, again, outside of Saudi?
spk04: Right. So, Let's break it down first. So just to put it in context, because you mentioned outside Saudi, in the last half of 2023, we actually added five rigs internationally, one in the UAE and two in Colombia, in addition to the two new builds in Saudi Arabia. So that's how we closed out the year. Then for this year, as I mentioned, we have seven rigs, which three are for Saudi and four are for Algeria, actually. And Algeria is a market we've known real well. CanRig has a great presence in that market as well. Sonatrack and the state drilling companies are actually a big customer as well of CAN rigs. So we have a good infrastructure, so we're pretty confident in our ability to get out there. And as I said, these three new bills, three of those four, we're expecting to hit this first quarter. And I think the organization has been looking at this for a long time, so it's well loyal to address that. So that's seven rigs committed for 2024. clearly, and that's locked in. And then as I said on the call, we have an additional, we have an additional committed orders for seven rigs. This is not just, I may be misspokenly calling them opportunities. There are actually seven more rigs committed by Aramco for 2025 and 2026. So when you add those together, that means over the next two years, with a little bleeding over, depending on timing, for that seventh of the new bills into early 2026, you've got 14 rigs going there The organization on the Saudi side, we've actually reinforced that organization really well. We've added some people from Houston over there to help them with all the stuff that's been going on, and we have a pretty good feeling now that we have our arms around scaling up what's needed to make sure that it's all successful, which then has led us to reorganize for the rest of the company to focus on some of these key markets that you're referring to. So let's talk about those other key markets. Those key markets, remember, if you go back to my conference calls, Last quarter, I listed off about 10, 12 markets, and those markets today still have about 50 tender opportunities, okay, 50 tender opportunities. And what we're doing now is we're trying to streamline our focus in our slide deck on the website. I think it refers to 12 opportunities. But I would say in my remarks I refer to eight. So really it's eight of the short list of 12 that we're focused on. And one of the things we're focused on when we do that is obviously what you just said to make sure that we actually can deliver from an execution point of view. So these selections will be both a function of the economics as well as our ability to make sure we get it on board as much and as quickly and as efficiently as possible. That is all part of our logic in evaluating the stuff right now. But I think The big message here is I think we have a unique geographical position and portfolio. I mean, we're the only one that has such a balance between a huge percentage in the U.S. and internationally, and we want to exploit this position as much as possible, taking advantage of what everyone has recognized as a clear secular uptrend in international. So that's the thinking that helps you.
spk06: No, that's really helpful. Now, the second element of the question, and, right, you referenced the quarterly survey that you do with – E&P companies. And again, if I heard you correctly, you referenced that those companies would effectively exit 2024 flat with year-end 2023, which from this point would effectively represent no change in overall drilling activity. However, you referenced that you expect your rig count in 2024 in the U.S. to average the same as it did in 2023, which by math, would infer you're going to add anywhere around, you know, 8 to 10 rigs between now and your end. So, question is, are you displacing other contractors if the overall rig market is not expected to grow?
spk04: Right. So, let me put it this way. We get paid for doing better, right? So, that's what we have to do better. And I think one of the things in this market that goes sideways is the operators now, you're not as excited about things. And so, everyone has a is going to be focused on improving what they're doing. And so that means technology, and that means also maybe upgrading your service providers. So I think with the churn going on, I think it will provide us an opportunity, and some of our big competitors as well, to upgrade the position. And that's what we're referring to. That's what we intend to play into, because we think there will be that opportunity. If you listen to the guys that have recently done the big acquisitions in particular, The good news is that those acquisitions show that there's long-term value in the US, and they need to make money. And it's all power to them to make money, which is good for us. But the benefit to us is that with this consolidation stuff that's going on, that means they're going to turn to the bigger players to help execute that. And that's hopefully what we're going to plan on playing to. And then if you listen to the remarks of some of the CEOs of these companies, The next leg for really them getting their economics going is to better technology, better technology on the wellbore as well as intelligent completions. And so we think we have a unique portfolio that will help us address both of those things with our drill view technology, et cetera, that we have. And also along the laterals, to the extent that you have one super major really buying into that, others haven't yet got there in large part because they don't have the acreage to do it. But neighbors is unique in terms of our capacity to do that. I think today, I don't want to say that it's not true, but I think we do have the longest lateral out there. I think it was something like 32,900 feet for Exxon. It was the total measured depth. I think the lateral was like more than 22,000 feet. And so our top drive and the rest of our equipment is really poised to handle that racking capacity and other things. So that's what gives me some confidence. Now, obviously, I need the market to break well. I need some breaks to get that number, but We're setting that, that's the objective for the management here to try to make that happen. But you're right, it's a heavy lift and I don't want to, you know, but we're putting out there, that's our aspiration for the year to try to gain in that fashion. Does that make sense to you?
spk06: No, that's great. And that's a fantastic color. Thanks, Tony.
spk03: The next question comes from Derek Podheiser with Barclays. Please go ahead.
spk07: Hey, good morning, guys. Appreciate the comments around Saudi's recent announcement. I understand that it should not affect your new build program. But what about from what we heard as far as potentially slowing down existing activity? Would there be a threat to the cadence of your rig deployments and how you previously got around one a quarter and had the first three charges awarded? But is there any threat that that could get stretched out from where you stand today?
spk04: The short answer is no, but let me give you some reasons why I get there. So let's put everything in context here. There's 210 land rigs working in Saudi and 87 offshore rigs. The conventional oil and gas account for 73% of the market. The unconventional accounts for about 10% of the market, and there's 22 unconventional rigs working today. Now, in process today, right now, is awards by RAMCO for 2024 and 2025 for 20 additional rigs. And you've heard some other people announce some awards that may be playing to that. Those 20 are in process, and we have not seen any sign that any of those changes are going to be impacted. And the reason for that is twofold. Again, I can't predict what really is going on there, but our impression is there's a growing domestic consumption that natural gas is needing to solve for, and then, of course, the attraction of having a burgeoning export market. And those two things are not affected by the capacity issue you've heard about. Now, Sanit currently operates 48 rigs, and more than 75% of them are gas-directed. And in fact, this year, the only two rigs we have up for renewal are two gas-directed rigs. So for this year, we're looking pretty good. The new build program that you referred to, of course, was done back when we did the joint venture more than five years ago. And it's part of a longer-term industrial policy for the kingdom, part of 2030. And those long-term policies are sort of like, you know, act of God. Once they're in place, they're hard to move. They're like dirt barges. So I really don't see things changing. Will it affect some cadence? Yeah, I'm sure over time, depends on what happens, that it could be some cadence about whether it's four rigs or five rigs, which is the target per year. That could get affected, but we have not heard anything. We haven't heard anything that affects any of the rollouts so far at all. So today, as you know, we have five rigs, new bills, that are on the ground working. We have 45 to go. Our view is that this is an unparalleled growth opportunity that we're just beginning to see the fruits of. And we think, you know, when realized, you know what the numbers are, this thing could, you know, approach $500 million in EBITDA just from these incoming rigs when all 50 of them are on board. So it's a huge thing that we're playing to, and that's why we're spending the capital to do it, which obviously is truly into our free cash flow. You know, we spent quite a bit, a little bit more than planned for this year because of timing issues. But we think it's a play in a unique market, and we have a very unique position that we need to take advantage of and exploit as much as possible. And so we're really happy that Aramco has been part and parcel, has been a great partner along the way. And as I said, we haven't seen any second guessing of this at all.
spk07: Great. I appreciate all that detail. That is very helpful. Just switching over to the U.S., so you talked about the dynamic of repricing your rates lower down to current market rates, which is putting some pressure on your first quarter margins. You've also talked about how current rates are remaining steady. So maybe just expand on that churn as your higher price rigs go down to the current market rate. And maybe when should that spread narrow from what you see in your blended average versus where we are in current rates? And then maybe talk about contracting versus spot exposure across the fleet today.
spk04: Well, let me start out and say, yes, I think our guides for the first quarter does reflect some continued churn and the current market pricing. Let me first comment by base and just give you a feel for the market. Maybe that makes sense. West Texas, I would describe the rate of churn as high and activity level is down. South Texas, I would call the churn low and activity flat. East Texas, I'd call the churn medium, activity down. Northeast sites call that low and activity flat. And North Dakota, I'd say low, but activity flat. But neighbors, because this position actually has had some upturns there. 44% of our rigs are in West Texas. And so that does affect the overall thinking in terms of, you know, we've got to be concerned about churn given that market today. And that's why you saw the numbers where they are. I think there's two positives in our numbers. The first is that our customer impact has shifted more to public operators from last year. So year end, this year, we're exiting around 72% of our client base is public versus 61% before. And then the second point is our gas rig count change mix has changed. It was 30% in early 2023, and we're down to 14% today. So I think our guidance reflects the fact that to deal with that and to maintain a disciplined approach on selection of the jobs and pricing and find customers is also important. you know, that we can share our journey to on technology as well, technology deployment, which, you know, is key to us realizing, you know, even better returns. And as you know, when you measure us for returns, you got to make sure you add the NDS margin per rig to the base drilling margin. When you do that, NDS margin, this last quarter is 3,900, and you add that to the margin for over $20,000 per rig, which I think is pretty good in this market. So the goal is to, you know, try to maintain... maintain our outperformance and to try to select customers that play into those factors I just talked about. Does that make any sense?
spk07: It does. And then maybe just quickly on the narrowing of your blended revenue per day and then just where the current spot is. And just as we think about the churn through the year, how is that going to narrow maybe how wide it is now? I'll let Ben give you more color.
spk05: So I think the latest contracts that we are signing are somewhere a couple thousand dollars in terms of revenue per day beyond where the blended average is. Now, we do have a ton of contracts that are locked in already. I would say 30% have a lot of term on them remaining. So the other 70% are basically... exposed to where the leading edge day rates are over the next six months or so. So average, that's why we are forecasting a reduction in about $1,000 per day in the first quarter. At this point, we're not ready to look at the second quarter, but we think that prices have steadied and we are even managing to get leading edge prices in some cases that were higher than the prior contract. So, you know, we think we're in a good situation right now, but undoubtedly, you know, because of our revenue per day, and in fact, the fourth quarter was a bit of a surprise to us on how well we managed to renew our contracts and maintain the day rates at a pretty high level. But we do think we'll see some deterioration in the first quarter. And we would hope that the second we see some stability for the average day rate or the average revenue per day. So that's, we're seeing the narrowing happening sometime and crossing over, I guess, sometime in the second quarter.
spk07: Okay, great. Appreciate all the detail, guys. I'll turn it back.
spk03: The next question comes from Waqar Saeed with ATB Capital Markets. Please go ahead.
spk00: Thank you for taking my question. My question relates to free cash flow, and that's the number one question I'm getting from clients right now. You're not giving guidance for free cash flow for 2024. Is that because you're not sure of any additional contract wins internationally or anything on what's driving the reason or what's the reason behind not providing guidance?
spk05: Well, we're not providing guidance. I'll address that first because, you know, it's still very early in the year and we do have a very meaningful amount of contracts that are being negotiated, and vendors outstanding, as Tony mentioned. And those can have a significant impact on EBITDA, but also on CAPEX. So before we get the outcomes of those contracts, we feel it's a bit premature to go out on a free cash flow for the year. But if you're referring to the fourth quarter also, you mentioned that some clients are asking about it. What I'm focusing on is that our underlying cash flow generation for CAR was very strong from our operations. In fact, the underlying cash flow was strong and remains strong. Now, we did have some unplanned items that fell in the fourth quarter. So if I focus just on the fourth quarter, the biggest shortfall was really working capital for CAR. I mean, and that was about $50 million versus what we forecast. The working capital was higher. $40 million of that was our accounts receivable. We were planning to reduce our accounts receivable inventories for the quarter, but those increased in the fourth quarter, mostly in worse collections than we targeted. So the US was the main driver, but it was not the only one, by the way. We really have had a tougher time in the second half of this year collecting from our customers. I do suspect that interest rates have something to do with this. Nonetheless, it is true we need to adjust to this environment and find a way to bring this DSO down. And we are planning to do that to bring their DSO back to the records we had in the first half. So I think that was the largest shortfall. CapEx was also an issue this quarter, about 30 to 40 million more than we targeted, all of that in Saudi Arabia. I think about 30 million of that was really legacy rigs In Saudi Arabia, we will have about 20 rigs going through their four-year recertification. In Saudi Arabia, that's a massive undertaking because it's not only the rig but all the related equipment. A lot of equipment after four years needs to be replaced, refurbished, and upgraded. So we are preparing for that, and we have ordered required components to make sure we minimize the downtime related to this certification process. So I think AFEs for these specifications are about $1.5 million per rig per car. So we had expected our suppliers to get this material ready at the beginning of the first quarter. But based on our client schedules and requests, we had to move up some of the deliveries of these items. And that hit us pretty bad in the fourth quarter. So that was the lion's share of the capex hit. Again, that's something that we would have had to absorb anyway. So it's not like an extra incremental capex. but it did hit us in the fourth quarter. And you may remember that we issued senior notes in November. So between fees and some carry on the cash for a bit more than a month, we had an extra cash outflow of about $15 million or so for the fourth quarter. So basically, if you add all that up, it's about $100 million shortfall, but half of that is really accounts receivable. And that's where we, and inventories, and that's the area of focus for us for 2024. So we do have to get better at adjusting to the customer's attempts to keep their cash. And we have a plan for materially reducing our inventory. So we expect those to have a very positive impact in 2024. I hope that answers your question, Wakar.
spk00: Thank you for that great detail. It's very helpful. Just on 2024 CapEx, are you prepared to provide just the bookends and, you know, the kind of range? And I'm sure it's a pretty wide range because reactivations can be quite costly internationally. But maybe a broad range of if you don't get a contract, what it could be. And if you get additional, then, you know, where it could go.
spk05: We are, you know, we have our board meeting today and, I mean, starting today until Friday. Okay. So we're going to, obviously, these are important items right now because, as you well know, you know, CapEx and free cash is very important. It's a very important topic for us, as you well pointed out. So until we have the board blessing on what we can actually focus on and what they're going to basically give us the green light to go for, I think giving some sort of very wide range, you know, like a range that's 50, 60 million dollars different is not very useful at this point. So I think we're going to, I'll just say that we expect our CapEx to be a bit higher next year than it was this year. That's all I will say at this point. So that's it.
spk00: Thank you very much. Really appreciate it. Thank you. Thank you for the detailed answer. Appreciate it.
spk04: The only other comment I'd add to this, Makar, is that if you look at our free cash flow for the year and you add back the in-kingdom rates, which is really a new-build program investment, together, that amount of free cash flow that we generate this year I think is really a remarkable total number. it really shows the strength of the portfolio, what we do have here as a company. So I'm pretty proud of that, that we actually can do a new bill program, that no one's doing a new bill program of the size that we're doing here at all. And so the fact that we can do that and still chip away at debt and do other things, I think, is a distinction that we have uniquely given our portfolio. So that's the other thing I'd add.
spk00: Thank you, sir. Thank you very much.
spk03: The next question comes from Arun Jayram with JP Morgan. Please go ahead.
spk02: Yeah, good morning. Gentlemen, I appreciate the fact that you don't have a board-approved budget for 2024, but the CapEx commentary was helpful. Tony, you mentioned 7 to 10 incremental international rigs that you expect by year end. Can you give us maybe a little bit of a flavor of of the type of rig that you expect to deploy, and what type of capex do you see on those reactivations and upgrades? Are these rigs that are already located internationally, or are you moving some capacity from the lower 48?
spk04: The seven rigs that I'm talking about, four that are in hand that you're going to see, the four are in Algeria, which are existing rigs with upgrades, and the three of those are... in-kingdom new bills. The in-kingdom new bills have a ticket, you know, more than $50 million a pop, and the other ones are upgrades, and there's upgrades of rigs that are on-site in Algeria. They're not being brought from the U.S. And so when you look at the size of those rigs, they're not equal to the average size of the good rigs in Saudi Arabia. So when you actually look at blended margins, We are having some change in mix because the Algeria rigs are a little bit smaller rigs, 1,500 horsepower rigs. They're a little smaller than the other rigs that we have. Therefore, when you look at our margin for the first quarter that we're talking about, there's consensus there is some change in mix and timing that affects margin as you work all the numbers through. But those rigs do not include anything from the U.S. There's no upgrades required from the U.S., which, again, is unique. unique to us because we have rigs in the international market already.
spk05: So we did dial in a slight reduction in margin in the first quarter. Because we're going to have like seven rigs coming in, we took a little bit of a cautious view on deploying those rigs and the amount of uptime we're going to get at the beginning until those rigs are fully operational. So there is a little bit of that included in the forecast for the first quarter.
spk02: Got it. And maybe just one follow-up, Tony. One question that's come in, as you do deploy the Sunod new build as part of the JV, are these take-or-pay contracts, and what kind of contract commitments do you have on those? Because you are investing capital there.
spk04: Yep. These are 10-year contracts, six years take-or-pay, and a four-year renewal option. It's a four-year guaranteed renewal, basically. So they're 10-year contracts.
spk02: Great. Thanks a lot.
spk04: That's what's unique about everything I'm talking about. No one has that kind of contract, six years with a four-year renewal guaranteed 10-year contract.
spk02: Great. Thanks a lot.
spk03: This concludes our question and answer session. I would like to turn the conference back over to William Conroy for any closing remarks.
spk01: Thank you all for joining us this morning. If there are any additional questions, please follow up with us offline. And Dave, with that, we'll end the call there. Thanks very much.
spk03: The conference is now concluded. Thank you for attending today's presentation. You may now disconnect.
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