Borr Drilling Limited

Good day and thank you for standing by. Welcome to the Board Drilling Limited Q4 2025 results presentation webcast and conference call. At this time, all participants are in a listen-only mode. After the speaker's presentation, there will be a question and answer session. To ask a question during the session, please press star 1 1 on your telephone. You will then hear an automated message advising your hand is raised. To withdraw your question, please press star 1 1 again. For the benefit of all participants on the call, please limit yourself to one question and a follow-up so that everyone is given an opportunity to ask questions. Please be advised that today's conference is being recorded. I would now like to turn the conference over to your speaker, Mr. Bruno Morin, CEO. Please go ahead.

Bruno Morin Good morning, and thank you for participating in Board Drilling's fourth quarter earnings call. I'm Bruno Morin. And with me here today in Dubai is Magnus Waller, our Chief Financial Officer. First, covering the required disclaimers, I would like to remind all participants that some of the statements will be forward-looking. These matters involve risks and uncertainties that could cause actual results to differ materially from those projected in these statements. I therefore refer you to our latest public filings. For today's call, I'll start with a review of Q4 and highlight key developments since the quarter end. Magnus will then review our quarterly and full-year financial results. I'll follow with a deeper look into the commercial execution, and we'll conclude with some comments on the business outlook. Let's get started. Before going to the results, I'd like to take a moment to recognize our teams around the world. During the fourth quarter, several of our rigs achieved noteworthy safety milestones. That includes the rig's idling grid, reaching six and three years LTI-free, respectively, and the rig's gun load and GERD reaching one year incident free. Additionally, we're proud to highlight that our rig Arabia III has received an award from Aramco's offshore department for the rig with the best safety score in 2025. These achievements underscore the team's commitment to safety, and I would like to take this opportunity to thank each member of board drilling family for their efforts. Now to the results. Our operational performance in the fourth quarter was solid. with technical utilization of 98.8% and an economic utilization of 97.8%. Fourth quarter operational revenues totaled $259.4 million. Adjusted EBITDA of $105.4 million came in line with our expectations, bringing full year adjusted EBITDA to $470.1 million at the top end of the guidance range. This performance underscored the resilience of our organization which navigated several headwinds in 2025 while delivering strong operational and financial execution. Our fleet contract visibility continues to improve as we reduce remaining open days. Recent awards and extensions have increased 2026 coverage to 80% in the first half and 48% in the second half, including the recently acquired rigs. Since our last quarterly report, we secured new commitments for seven rigs and expect further coverage gains in the coming months as we progress negotiations on multiple active leads. We believe the jack-up market bottom is behind us now, and we see fundamentals recovering gradually as demand increases. Most notably, in the Middle East, multi-year tenders are in progress for an estimated 13 rigs. In Mexico, we're seeing better visibility of payments and a more positive operating outlook. These improvements are being supported by financial measures introduced by the government, while at the same time, PMAX announced plans for a 34% year-on-year increase in upstream complex and reaffirmed its mandate to raise production. Overall, model jack-up market utilization remains steady at approximately 90%. As standards are awarded and available supplies absorbed, we expect market conditions to firm. Against this backdrop, we're pleased to have expanded our fleet to the accretive acquisition of five premium rigs from Noble. These rigs are highly complementary to our existing portfolio and well suit the capacity to pursue near-term opportunities. Integration is in progress and ahead of expectation. Looking ahead, market dynamics are setting the stage for improvements in the second half of 2026 and a recovering day rate and earnings visibility into 2027. But before I add color to this, I'll hand the call to Magnus to discuss our financial results.

Thank you, Bruno. I will now go into some details of the financials of the fourth quarter. Total operating revenues was $259.4 million, a decrease of $17.7 million, or 6.4% from Q3. This is mainly explained by 16 million decrease in day rate revenue, primarily due to rigs transitioning into contracts with lower day rates. The activity level in terms of total number of operating days stays even over the two quarters. A decrease in variable charter revenue explains a further 3.1 million decrease, primarily due to the grids and the contract and its planned transfer to a contract in Angola. These decreases are offset by 1.4 million increase in O&M revenue. Total operating expenses for the fourth quarter were 192.1 million, an increase of 13.2 million, or 7.4%, compared to the third quarter. The increase in cost was primarily due to 11.6 million increase in rig operating and maintenance expenses attributable to increase in personnel costs, accelerated amortization of deferred costs for the rig yield, and reimbursable expenses. For the quarter, we recorded a net loss of 1 million and adjusted EBITDA of 105.2 million. Looking at full year 2025, net income was 45 million and full year adjusted EBITDA came in at 470.1 million, a decrease of 7% compared to 2024. Moving into cash, cash increased by 151.9 million in comparison to the prior quarter and is primarily driven by the following. 34.8 million cash from operations, which is after 94.7 million of interest payments and 8.8 million of cash taxes paid. We spent 52.1 million in investing activities consisting of 36 million deposits for the five-rig acquisition and 15.9 million additions to jack-up rigs. And lastly, cash from financing activities was 169.2 million, consisting of 159.3 million net proceeds from the fund issuance, 80.3 million net proceeds from share issuance, net of issuance costs, offset by 70.8 million repayment of debt in the quarter. The company's cash and cash equivalents as of December 31st were 379.7 million. In addition, we had 234 million of undrawn revolving credit facilities, resulting in total liquidity of 613.7 million. It's worth noting after year end, we completed the five-rig acquisition from Noble and paid 174 million in cash consideration in January. The remaining consideration was settled by way of 150 million set of credits. We are very pleased with the five-week acquisition and the accompanying capital market transactions we concluded in December. We completed an offering of an additional $165 million of bonds during 2030, issued as part. In addition, we completed an equity offering, raising growth proceeds of $84 million for the same purpose. Both transactions saw very high investor interest and were significantly oversubscribed. In December, we also made the first steps to return to the Oslo Stock Exchange through a listing on the Euronext growth. The decision was made after seeing high investor interest from the Norwegian and European investor base, in addition to strong following by Norwegian sell-side analysts. We are planning on a full uplisting to the main list on the Oslo Stock Exchange in the first half of 2026. Then I'll pass the word back to Bruce.

Thank you, Magnus. We have been busy on the contract in front to start the year. Year to date, 2026, we've secured five new commitments, adding approximately 145 million to our backlog. Together with the two contracts we secured in December, this marks seven new commitments since our last quarterly report. I'm pleased to see both short and long-term commitments in this mix. Filling idle space in our 2026 schedule remains a key focus, while at the same time, we're mindful about positioning our fleet to capitalize on improving market conditions from late 2026 and onwards. I'll now spend time discussing the commitments we secured since the last quarterly report. In Americas, the run received a one-well extension with ENI in Mexico. The well has an anticipated duration of 75 days, keeping the rig on firm contract through March 2026. ENI remains a core customer of ours in Mexico and globally. Ongoing engagements leaves us reassured that we'll have more positive news soon for the run. Additionally, the ODIN secured a contract for two wells plus an optional well with an undisclosed operator in the United States. The campaign is expected to commence in July 2026 with an estimated firm duration of 120 days. As a result, the old one is now committed into November with options that could keep the rig utilized in the U.S. through mid-2027. Staying in Americas, today we announced a two-year contract extension for the New York in Mexico, keeping the rig committed into 2028. This extension highlights the strength of our business in Mexico, a market that remains critical to the jack-up industry. Moving to West Africa, the NAT secured work with ENI, keeping the rig busy through the end of these months. The RIGS is scheduled to move to Nigeria in early Q2 to commence its 11-month contract with Shell. In Asia, Brunei Shell extended the Saga contract by an additional five months. The Saga is now committed into April 2027 with an additional one-year option remaining available under the contract. In Thailand, the IDA secured a 75-day extension with PTTEP, extending its commitment into the second quarter of this year. And finally, in Vietnam, we have entered into a contract with Tan Long for the gun lot for a one-well campaign anticipated to commence in May. The well has an estimated duration of 70 days and should place the rig well to find follow-on work in the region. I remain proud of the continued contracting success, which is a testament to our strong customer relationship and ability to deliver reliable and exceptional operational performance day in and day out. Now looking ahead, As of today, our 2026 fleet coverage stands at 64%. With the inclusion of five newly acquired rigs, our coverage for the first half of the year currently sits at 80%. As a comparison, before factoring in these new rigs, this coverage figure would have been approximately 85%. Based on current customer engagements, we're confident that in the coming months, our fleet will continue to secure commitments and bring our contract coverage above 70%. On a full year basis, we see a pathway that allows contracting days in 2026 to modestly exceed the numbers of days achieved in 2025. In parallel, and as I noted by various industry analysts, tender activity is entering levels not seen since January 2023. According to information from PetroData, there are approximately 120 rig years on the tender and pretender phase for opportunities commencing within the next 12 months. And based on operator schedules, we anticipate that a meaningful amount of these will be awarded by mid-2026. Should these materialize, we believe that several of the awarded rigs will need to undertake lengthy contract preparations, leading to a boost in utilization from this year. Noting the strength of the tendering pipeline, coupled with current utilization levels, I remain optimistic that the foundation is set for a positive momentum as we progress to 2026. To close, I would like to reiterate key points around our 2025 execution and leave you with some thoughts on the business outlook. At the beginning of last year, we indicated that we were comfortable with consensus for full-year adjusted EBITDA that stood at $460 million. During the year, however, we faced unforeseen headwinds, including temporary contract suspensions and sanction-related contract terminations. We responded by leaning into the board drilling platform, which continues to be our competitive advantage. We filled the white space through close customer relationships, deep market knowledge, and our track record of safe and reliable execution. As a result, we delivered full year adjusted EBITDA of $470 million, which was at the top of our final guidance range. Further, in 2025, we took decisive action and complete a successful equity and debt transactions that strengthen our liquidity and position the company to pursue consolidation opportunities. Then in December, we announced the accretive acquisition of five premium jackups. We act opportunistically and bought these assets at an attractive price at a point in the cycle when demand is improving. We expect the transaction to be immediately accretive to adjusted EBITDA and to reduce our debt per rig. Looking ahead, we expect market conditions to continue improving to the second half of 2026, with ongoing dynamics supporting a clear recovery in day rates in 2027 and beyond. Our expanded fleet will provide us with scale and operational flexibility, providing more drilling to deliver long-term value to our shareholders. With that, I'll now turn the call over to Q&A.

Thank you. As a reminder, to ask a question, please press star 1 1 on your telephone and wait for your name to be announced. To withdraw your question, please press star 1 1 again. Once again, please press star 1 1 for any question and wait for your name to be announced. To withdraw your question, please press star 1 1 again. For the benefit of all participants on the call, please limit yourself to one question and a follow-up so that everyone is given an opportunity to ask their questions. Please stand by while we compile the Q&A roster. This will take a few moments.

Thank you. We are now going to proceed with our first question. And the questions come from the line of Scott Kruber from Citigroup.

Please ask your question.

Yes, good morning. Appreciate all the detail this morning. And the tendering pipeline boost is certainly encouraging. I'm curious on the outlook of the two acquired rigs that are idle, the SIS and the Frasier. Do you have any line of sight to securing contracts on those two?

Hey, Scott. Great to have you online. Thanks for the question. Indeed, great question. We are looking at a pipeline of opportunities for both rigs. What is interesting is, as I said in the remarks, I think the capability of these rigs is very well suited for the pipeline of tender that we refer to. At the moment, we feel quite confident that the SIF will have a contract for it in the coming months that will put the rig back into the operating fleet in relatively short term. In the case of Freya, I do think that it may take a bit longer. But as I said, the pipeline in the second half of the year continues to shrink. So I would think about that rate probably going to work sometime in the back end of 2026 or potentially early 2027, depending on the scope you define too.

Great. And apologies, I jumped on a minute late. So apologies, I missed this. But just thoughts on how EBITDA shapes up during the year consensus. It's close to 440 million. Just some initial thoughts on the achievability of that level of EBITDA.

Yeah, for sure. I think at this stage, it's still probably a bit too early for us to provide kind of a formal guidance. What I can share, as I said, is that the outlook continues to improve. And the team is working really hard to make sure that we do risk and cover the days in 2026. What I'll share, which is not far from what I mentioned during the last call, the outlook for 2026 right now seems to indicate that we should be able to achieve or we have a pathway to achieve a activity level in contracting days that is moderately higher than 2025. And when I say that, I'm referring to a 24-week to 2024 rig. with the noble acquired rates or the recently acquired rates being an upside to that. So I think that's the simple way to think. I think activity level will track slightly higher than it did in 2024. Now, let's see how the rates mature in 2026, particularly in the second half, and that should leave us in a position to provide better guidance in the coming quarters. Okay. I appreciate the power. Thank you.

I'll turn it back. Thank you, Scott.

We are now going to proceed with our next question. And the questions come from the line of Craig Lewis from BTIG. Please ask your question.

Yeah, hey, thank you and good afternoon or good morning and thanks for taking my questions. You know, Bruno, I did have kind of like a question. around what you're seeing in the Middle East. I mean, clearly, part of what drove the more recent softness in the market was You know, the laying down of rigs and just kind of a slowdown and overall Middle East activity kind of like, I guess there's been some rumblings about tenders coming to market force. It seems like some time now, any sense for when we could actually see some of these, you know, talked about tenders in the Middle East, actually, you know, not necessarily have the rigs start working, but when we could start seeing maybe some rigs be contracted around some of that.

Yeah. No, and thanks for joining, Greg. Very fair question. When we were talking about some of these tenders in the fourth quarter, in our November call, we were looking at that, anticipating them to be out. At the moment, the larger ones that we were expecting, including Aramco and KGO, are in progress. And in fact, KGO is in full tender evaluation from what we understand. and they are still in tender submission phase. So this is very actual, this is very real, very tangible. There are a few more prospects in the region that we've been expecting to come to the tender pipeline, including KJO, which is not yet fully developed, but that should come in the next couple of months, we would think. As I mentioned earlier in the call, the outlook at the moment, based on the conversations that we have had with the customers, is that they should be planning to award sometime around mid-year, maybe some a bit earlier, some slightly later, But by mid-year, I think that visibility will have formed quite nicely. So that's one of the reasons why we feel excited. That's a large volume of work coming from those senders. And it's probably worth to highlight that not all of it, but a portion of these requirements not only are large volume, but they require very specific technical capabilities. And we feel the fleet that we have, particularly with the recent acquisitions place as well, to evaluate. And we'll see. There are long-term vendors. For us, it's a very interesting body of work, but it has to make sense from a pure commercial standpoint as well. In any case, once that volume gets absorbed in the market, whether directly awards to us, let's see, or just to the peer group, it will put a lot of tightness in the market, which I think is what everyone is looking forward to.

Okay, super helpful. Thanks for that, Bruno. And hey, congrats on the noble acquisition, on those rig acquisitions. Clearly, know not transformational for the fleet but definitely gives you a nice boost you know it does look like we are at an inflection point or the cycle is turning and and and i guess what i'm kind of curious about is you know how you think about and is there room where the fleet is today to potentially acquire more rigs and and really you know i don't know how deep you want to get into that conversation but i am kind of curious around... I mean, it's not Keppel anymore. I guess they call it Seatrum. They still have some rigs that you know, I guess they're operating some, some jackups from, from, you know, previous orders from other customers. They have these rigs. Is there any kind of, is there any kind of, when could we see these rigs or, I mean, are they being, do you have any sense for if these rigs are being actively marketed for sale? And yeah, I mean, I guess that that's kind of it and kind of you know, and where we kind of think pricing is now for a premium rig.

Yeah, very good, Greg. Let me tackle maybe the question on the seat room rigs first. And you said rigs, but I understand that there's one of them that had been operating with Arunco before and was returned to the yard. I think the rest of them are either committed to BBCs or have been sold. I think it's probably fair to assume that that rate gets offered in the Middle Eastern tenders. It was a rate that was with Aramco before, and it has specifications and complies with the requirements. So I would expect that rate to eventually be offered in that tender. from experience, we know that the Singaporeans are not really in the business of selling rigs cheap and they probably see the market responding and they will have expectations. So I'm not sure if they get sold, but I do expect that there will be people looking at those rigs and trying to place them. Now, on the broader M&A picture, the answer that I have for you is probably not very different than what we said in a call in the last quarter. We have an operating platform that is very well recognized around the globe, including very well recognized by our customers. And that gives us a chance to look into M&A opportunities and see how we strengthen that platform further. For us, we continue to think about consolidation very selectively. It's not consolidation and growth for the sake of growth. We would have to look complementary to our fleet. And I think less likely to be looking at individual asset things. We want to see things that could potentially help us continue to transform and consolidate the sector. Now, we said it before with 24 rigs, and I have to emphasize again now with 29, we think we have a very interesting fleet size. We have scale in pretty much every key market around the globe. So growth is something that will look opportunistically. but I don't think it necessarily composes a core to our strategy. I think we have a good operational platform to do so if opportunity comes, but we'll look at that very opportunistically.

Super helpful. Thank you very much.

We are now going to proceed with our next question. And the questions come from the line of Frederick Steen from Clarkson Securities. Please ask your question.

Hey, Bruno, Magnus. Hope you are well, and as always, thank you for good prepared remarks. I wanted to dig a bit deeper into what's going on with the market at the moment, and I think we have a shared view that that it's exciting times, tenders are up, and utilization will likely point upwards as well. And on the back of that, I was hoping you could give a bit more color on how you kind of specifically see, you know, race development trajectory going forward, because typically there will be, I guess, first you'll see the tenders, then you'll see the awards, and then you'll see the day rates. So any color on when you think we'll see this higher activity level starting to, you know, really make an impact on bidding levels across the globe.

Thanks. Yeah, fair question, Frederik.

And what we have seen over the last, and we've been very open about it in the last few months, is that rates have been walking in most regions a bit sideways. I think in some regions like Asia, maybe a bit downwards a little bit, but it has been fairly contained. For us, the way we think about 2026 at the moment is utilization is obviously in the forefront, particularly for opportunities that we have that are short-term in nature, that helps us fill the gaps, help us de-risk the execution during the pandemic. Now, what is the date for the market to change? You're absolutely right. I think six years comes first. then rates come second. As we said, a large volume of the work that is in the tender pipeline at the moment is driven by the Middle East. We currently anticipate that these awards will start coming out during the second quarter, mid-year, thereabouts. And what is interesting, as I mentioned in the prepared remarks, is that Middle East tenders generally require a fairly lengthy preparation process for the rig. So it basically means that once we see awards coming through, those rigs are effectively out of the market a given month and until they actually can be deployed. So I expect that the pricing dynamic starts to progress once those standards conclude or shortly after those standards conclude, which would imply that we're looking at Q3 is when we'll probably have better visibility of those dynamics playing out. That's my best guess. As I said earlier, for 2026, name of the game for us is really de-risk the outlook, make sure that the fleet is occupied. I think 2027 is when we turn our focus again very sharply into economics and rates.

That's very clear. And just to follow up on that, and I guess you kind of partially answered it, but in terms of recontracting your fleet now, while I definitely appreciate that 2026 is a utilization game for you, Do you have any kind of strategy around what type of contract length you would kind of go for at the current time? Are you on short contracts to reprice that when the market starts accelerating again? Or do you still want to have like a baseload of longer term contracts even when they are available? And like a side question to that, since the current Middle East tenders are long in nature, and I would assume that you would be interested in some of them. Are there any changes to Saudi Aramco contracting terms, you think? Obviously, we're referencing suspension ability for the kingdom as we saw two years ago. Thanks.

Yeah. So let me break it down here, Fredrik. To your first part of the question, Yeah, with a 29-rig fleet, we obviously have to have a mix of short and long-term contracts. It's obviously important that we have a baseline of backlog. Clearly, as we have regions where day rates push closer to kind of cash operating costs, we don't want to be securing these contracts in the long term, and we're looking for opportunities to close gaps as best as we can. Some of the regions that the margins are still a bit more stretched and more interesting we're obviously more flexible in extending the duration of the contract a bit longer. And that depends a lot on the opportunities. There are regions that could be a bit more competitive at times, but certain tenders within that region that have particular requirements that are well suited for the fleet. And we look into how we optimize these things. So there's obviously a quite strong combination of factors playing out at the moment. Now, in terms of the second question on Aramco, yes, the tender is still ongoing, so let's see where we land. It does seem that in the tender documentation, Aramco has made some of the terms a bit more flexible, particularly some of the provisions around termination that were of a concern since the last round of suspensions and terminations. And they indicated some flexibility to discuss a few terms, mainly on a technical side, maybe not so much on a commercial side. but they do indicate some flexibility to discuss. So let's see how the tender progresses and where we land in that discussion. All right. Thank you very much. Have a good day.

Thank you, Frederic.

We are now going to proceed with our next question. And the question is from the line of Charles Olsen from Sidely Securities. Please ask your question.

Thank you. Good afternoon, Bruno and Magnus. A couple of questions for me, starting off in Mexico. You collected a bit called extra from Pemex or OPEX, if you will. You are obviously confident about more college regular payments coming from Pemex or Mexico this year. How should we think about this? And what's the current level of outstanding on your balance sheet?

Hey, Tru, thanks for the question. I thought we'd go through the whole call without a question from Magnus, so I'll let him tackle this one.

Thanks, Bruno, and Trus. So, yeah, as we said, we have come back to payments from Pemex has picked up over the past quarter, and we actually received around $46 million in total in the fourth quarter. So, we estimate we had around $90 to $100 million outstanding at the end of the quarter. in the beginning of January, received a further 23 million. So that is bringing the outstanding balance further down. So I think this is very positive to see. We see also peers of the companies reporting the normalization of collections. And the indications we have from Mexico is that it will continue into 2026 and that they're preparing for a new payment plan with the government to tackle 2026. So, I think we're positive about the development. I think also, as we noted in, I think, our previous contracting update, is that the contract extensions for the Galar and Gersemi include improved payment terms with our counterparty. So, we are guaranteed to have payments of operating costs within 45 days. no more than 180 days so outstanding variable tire so um so we are also improving on the terms towards our uh our counterparty thanks that's great to hear and i would expect those terms to be included on the the rig and the letter of intent as well no no truth i think that the rig that got extended right now continues on um the

historical contract structure, which is on a pay when pay basis. However, as Magnus pointed out, we do have encouraging signs that payments will reach a better normalization going forward.

Okay, thank you. Good to hear. On another topic, and obviously it's boring to talk about day rates, but it ultimately remains important, if you will. I mean, the spread seems to be very high at the moment. Obviously, Asia and the Middle East have been more competitive than West Africa. Are there other moving parts to think about? I mean, you talked briefly about terms you're discussing or are being discussed with Aramco, if you will, in terms of that tender batch there. How do you see that sort of progressing or moving elsewhere, the T&Is, if you will?

yeah yeah and i think the dynamics in our contracting is is always very fluid we're always kind of pushing and pulling on terms and conditions to the contracts of the customers um so it's uh it's normal to the cycle truths i would say that today um there's not a huge focus from our customers in trying to renegotiate terms i think that the terms are being fairly solid in a cycle so far. The discussion has always been a lot about rates. And as you pointed out, in some regions, there is a bit more competitive pressure, some other less pressures. Like if I look at regions like the North Sea, for example, they have very well-established frameworks for contracting. I don't think that we've been spending a huge amount of time revisiting provisions with the customers. Keep in mind that we very frequently are talking about customers that are repeat customers for Bohr. And we do have a well-established framework in this contract. So that takes a little bit of the pressure in negotiating terms, both on our side and the customer side. But inevitably, there's always a commercial push and pull of all the negotiations that mature to the cycles.

Understood. Thank you. And the final one for me, as we think about those rigs that you currently have, not secured any work for. I mean, the one which perhaps stands out a bit more than the other ones is the VAR. Should we think about that as probably the last one to find work, given that it's been sort of inactive previously or coming from yard, if you will?

Yeah, I think it's a fair statement, Ruud. I think that when I look at the pipeline and the things that we're pursuing at the moment, um in near term i would think or hope that we will have commitments for the healed and the sith um they've been operating until recently we have a pipeline of opportunity for them so that that's the most obvious movement in in the near future i i do think that the var and the freya are really they'll probably come a bit later probably kind of back into this year early next year with some focus on on some of the developments in the middle east that will likely create the catalyst to deploy those rigs. But that's probably a fair way to think about it.

Understood. Good stuff. Thank you, guys. Keep up the good work. Thank you.

We are now going to take our next question. And the questions come from the line of Joshua Jane from Daniel Energy Partners. Please ask your question.

Thanks for taking my questions. First one, I just wanted to follow up on Scott's question a little bit. As you talked about an asset that is sacked potentially coming back to work, how are you thinking about requirements from a return perspective in an initial contract to get a rig up and running today after it's been stacked? Maybe you could just elaborate on that a little bit.

Yeah, thanks, Joshua. And the answer to your question may vary a little bit from rig to rig. I'm thinking in our case, except for the VAR, all of the rigs either been working until recently or are rigs that would be rolling off contract. At this stage, we don't expect any meaningful capex in putting those rigs to work. The VAR would probably require a bit more, probably somewhere close to $5 million, $6 million, somewhere in that ballpark. So for the rigs that require little capex, the calculation becomes a bit easier and it's probably less a question of just off-the-gate economics and more a balance of the opportunity pipeline. We certainly don't want to have a rate going back to work to just work for a very short amount of time and then come idle again. It kind of defeats the purpose and it hardly ever generates sufficient economics. So balancing between feasibility of a pipeline and rate is obviously significant. But for the fleet that we have at the moment, the CapEx component, our reactivation component, is not a big factor because, as I said, these rigs have either been operating until recently or are rigs that are normally rolling off contract as we go along.

Thanks for that. And then I'm going to ask the Venezuela question, I guess, a little bit differently. Any thoughts on what you're seeing and hearing there in the region? And if things are calmer there or quieter, just given geographic proximity, does that further open up Trinidad, Columbia, and Guyana a bit more for the shallow water market? Maybe you could speak to that a little bit.

Yeah, and Trinidad has been a fairly busy jack-up market over the years. There's still some opportunities around that. Suriname, there has been a few opportunities in discussion. It's mostly exploration work, and some of it is a bit far in the future. Colombia has had some work in the past and has been quiet. I do think that as things calm down in the region, some of the operators may be a bit more compelled to go. Do I see a near-term large volume of requirements in the region? That's probably not the way I would put it. I think the moment you start getting a couple of jobs in places like Suriname and Colombia, then it starts to become interesting to see how you can put a scope together that supports a rig. Generally, it's a region that requires rigs with larger capabilities, which is obviously very interesting for our fleet, but I wouldn't think that is a large play.

Understood. Thanks for taking my questions.

Thanks, Joshua.

Thank you. That concludes the question and answer session. I want to head back to Mr. Bruno Morin for closing remarks.

Thank you. That concludes our call. Appreciate the interest in the company, and I look forward to speaking to you again next quarter.

This concludes today's conference call. Thank you all for participating. You may now disconnect your lines. Thank you.