TechnipFMC Stock

Hello, everyone. Thank you for joining us, and welcome to the TechnipFMC Third Quarter 2026 Earnings Conference Call.

[Operator Instructions]

I will now hand the conference over to Matt Seinsheimer, Senior Vice President, Investor Relations and Corporate Development. Matt, please go ahead.

Thank you, Matt. Good morning and good afternoon, and welcome to TechnipFMC's Third Quarter 2026 Earnings Conference Call. Our news release and financial statements issued earlier today can be found on our website. I'd like to caution you with respect to any forward-looking statements made during the call. Although these forward-looking statements are based on our current expectations, beliefs and assumptions regarding future developments and business conditions, they are subject to certain risks and uncertainties that could cause actual results to differ materially from those expressed in or implied by these statements.

Known material factors that could cause our actual results to differ from our projected results are described in our most recent 10-K, most recent 10-Q and other periodic filings with the U.S. Securities and Exchange Commission. We wish to caution you not to place undue reliance on any forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any of our forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise. I will now turn the call over to Doug Pferdehirt, TechnipFMC's Chair and Chief Executive Officer.

Thank you, Matt. Good morning and good afternoon. Thank you for participating in our third quarter earnings call. Total company revenue in the period was $2.9 billion. Adjusted EBITDA was $636 million, with an adjusted EBITDA margin of 22% when excluding foreign exchange impacts. We generated free cash flow of $470 million in the quarter. Our quarterly results demonstrate continued strength and consistency in our execution, and I am proud of what our team has accomplished.

We recently achieved several operational milestones, all further strengthening our track record of client success in advancing offshore projects. In Suriname, we continue to make strong progress on the Grand Margo project with the delivery of critical subsea equipment ahead of schedule. Together with Totel Energies, we are helping to bring Suriname's first offshore development closer to production through early collaboration, standardized engineering, and delivery certainty. In August, we delivered the first Subsea 2.0 tree for Chevron's Gorgon Stage 3 project. This is the first tree delivered under Chevron's 20-year Subsea 2.0 frame agreement with TechnipFMC. During the quarter, we were also recognized at the 2026 Petrobras Best Suppliers Awards, receiving orders in 3 categories: flexible pipe installation, subsea wellhead systems and ESG governance. The awards recognize both our technology and execution performance, reinforcing the differentiated value we deliver to our clients and the strong governance standards that underpin our operations.

I want to specifically highlight the flexible pipe award. As this marks the fifth time we have received this recognition, demonstrating a proven track record of operational excellence. And most recently, we celebrated the manufacture and delivery of the 200th subsea tree for ExxonMobil in Guyana. With our Subsea 2.0 platform, enabling greater standardization across multiple projects. Together, these examples highlight the discipline that drives our execution. The collective efforts of our global team ensure that we continue to perform at a very high level. delivering projects not only on schedule, but in many cases, ahead of schedule, giving our customers greater confidence in sanctioning offshore projects. Turning to inbound orders. We announced 3 subsea awards for the quarter. We secured multiple contracts to supply flexible pipe systems, the first for Azul Energy and Angola, and the second for Petrobras in support of multiple pre-salt fields in Brazil.

We are well positioned for such awards as our industry-leading flexible solutions and ongoing industrialization efforts enable us to deliver greater efficiency, consistency and predictability around project timing and performance. We were also awarded an integrated contract from Petronas for the Limbayong project, their first deepwater project offshore Malaysia. This greenfield development will benefit from both our Subsea 2.0 configure-to-order platform and iEPCI execution of the entire Subsea scope, reducing project cycle time on this fast-track development. Notably, Limbayong was one of 3 iEPCI projects awarded to TechnipFMC in the period. Inbound orders in the quarter totaled $2.1 billion. In addition to these projects, we continue to enhance our customer relationships through collaborative partnerships. We recently finalized a strategic collaboration agreement with Petronas that establishes TechnipFMC as Petronas' strategic deepwater development partner, embeds our iFEED to iEPCI integrated delivery model, strengthens executive-level engagement and creates opportunities for growth across multiple projects and countries over the coming years.

The collaboration deepens our long-standing relationship and extends well beyond the scope of a traditional frame agreement. And just last week, we announced a memorandum of understanding with BP under which TechnipFMC will be the preferred strategic supplier of 20K systems for BP's Paleogene program in the U.S. Gulf. This exclusive agreement builds upon our proven 20K technologies and the experience gained through collaboration on BP's initial Paleogene developments, Kaskida, and Tiber. These new agreements exemplify our focus on client relationships and reinforce our commitment to deeper collaboration. Moving to the outlook. We remain optimistic about the durability of the subsea market. We have high visibility in offshore activity where we see a sustained resurgence driven by a record level of deepwater projects, which significantly improved economics and a shift in operator capital toward prolific, high-quality offshore reservoirs. This outlook is reflected in our Subsea opportunities list, which has increased for the 9th consecutive quarter and highlights an opportunity set that has grown 25% and over the last 2 years to $32 billion when using the midpoint of project values.

Let me now close on a few points. First, we are a technology company that has fundamentally changed the way we execute and deliver for our customers. Our unique operating model improves project economics while reinforcing customer trust and confidence in our delivery capabilities. Next, client recognition and new collaboration announcements further reinforce the value of customer engagement. Deeper collaboration drives even greater success for trust and shared goals create a clear path to direct awards. These relationships become increasingly more valuable as clients adopt a portfolio approach to offshore development. optimizing opportunities across their entire asset base rather than simply advancing individual projects. And finally, improving project economics and greater schedule certainty are attracting capital flows to offshore development. At the same time, energy security is prompting operators to diversify their investment opportunities while consuming nations are looking to diversify their source of supply.

Additionally, there is a near-term requirement to replenish diminishing stockpiles. Increased exploration is likely to follow, expanding activity in established regions while opening new markets in countries that have never produced from offshore basins. This is all driving a robust pipeline of opportunities. And if we extend our view to include 2027, we expect Subsea orders over the next 5 quarters to be at least $14.5 billion. Let me be clear, the Subsea order step-up is here. This momentum should also lift the quality of our inbound orders with substantially more Subsea 2.0, iEPCI and direct awards expected in the year ahead. We also believe the step-up in 2027 marks the start of a sustained wave of activity that will extend beyond the end of the decade. I will now turn the call over to Al to discuss our financial results and importantly, our outlook for Subsea in 2027.

Thanks, Doug. Inbound in the quarter was $2.3 billion, driven by $2.1 billion of subsea orders. Revenue in the quarter was $2.9 billion. Adjusted EBITDA was $636 million when excluding a foreign exchange loss of $9 million. Turning to segment results. In Subsea, revenue was $2.6 billion, a 5% increase versus the second quarter. The sequential revenue improvement was driven by increased project activity, specifically iEPCI projects in Indonesia and Brazil, as well as increased services activity. The revenue increase was partially offset by lower project activity in Norway.

Adjusted EBITDA was $612 million, up 6% sequentially due to strong execution and higher project and services activity. Adjusted EBITDA margin improved to 23.5%, the highest quarterly margin achieved to date. In Surface Technologies, revenue was $296 million, an increase of 7% from the second quarter. The increase was driven primarily by higher activity in the Middle East along with higher completion activity in North America. Adjusted EBITDA was $53 million, an increase of 7% sequentially. Adjusted EBITDA improved due to higher activity in the Middle East and North America. Adjusted EBITDA margin was 18%, essentially in line with the second quarter. Turning to corporate and other items. Corporate expense was $29 million. Net interest expense was $4 million and tax expense was $104 million. Cash flow from operating activities was $531 million, with capital expenditures totaling $61 million in the quarter. This resulted in free cash flow of $470 million.

We repurchased $320 million of stock in the third quarter when including $20 million of dividends Total shareholder distributions were $340 million. Cash and cash equivalents was $1 billion. We ended the quarter with a net cash position of $645 million. Turning to fourth quarter guidance. For Subsea, we expect seasonal impacts to our fourth quarter results, with revenue declining mid- to high single digits sequentially. Adjusted EBITDA is expected to decline approximately 250 basis points to 21%. For Surface Technologies, we anticipate revenue and adjusted EBITDA margin to be in line with our third quarter results. Moving to our full year outlook. We are making the following updates to our guidance. We are increasing subsea revenue to a range of $9.6 billion to $9.8 billion. We are increasing free cash flow guidance to a range of $1.45 billion to $1.55 billion. And we are reducing the full year effective tax rate to a range of 25% to 27%.

With this update, we are increasing our expectation for total company adjusted EBITDA to approximately $2.22 billion for the full year, excluding foreign exchange. All other guidance items for the current year remain unchanged. Now let me take a moment to focus on next year. As Doug commented earlier, we have high visibility in offshore activity, which supports our expectations to inbound at least $14.5 billion of Subsea orders over the next 5 quarters. And importantly, this visibility puts us in a good position to provide an early view of Subsea financial guidance for next year. For 2027, we are expecting subsea revenue to be in a range of $10 billion to $10.4 billion, with adjusted EBITDA margin in the range of 22.5% to 24%. And we will provide the remainder of our 2027 financial guidance with our fourth quarter earnings.

In summary, our team continues to execute well. Both total company revenue and adjusted EBITDA margin improved sequentially. And with today's update we have now increased our expectations for total company adjusted EBITDA for the full year. Free cash flow for the first 9 months of the year improved $1.2 billion. We have distributed $1.1 billion to shareholders through dividends and share buybacks, representing 86% of free cash flow, already exceeding distributions made in all of 2025. Lastly, we have provided an early view of our 2027 Subsea outlook, reiterating our expectation for growth in Subsea inbound, revenue and adjusted EBITDA margin. When using the midpoint of the 2027 guidance ranges, we expect Subsea adjusted EBITDA to increase more than 10% year-over-year. This reflects continued strength in operational execution with incremental margin for Subsea approaching 50% in the coming years. Operator, you may now open the line for questions.

[Operator Instructions]

Your first question comes from the line of David Anderson with Barclays.

Doug, I hope my communication is okay. I'm traveling at the moment. I want to ask you about the $14.5 billion in terms of the next 5 quarters. Is the macro, what we're looking at today, is that an influence in terms of the timing of those projects in terms of either the fourth quarter or next year? Just curious, from your standpoint of kind of how your customers are thinking about the macro and how much that's influencing the actual? Or do you have such line of sight that, to a certain extent, it's irrelevant?

Sure, Dave. Good morning and we can hear you just fine. So the macro environment, as we're all dealing with is quite fluid at this point in time. In terms of its impact on our outlook or the timing of the outlook, there's no direct correlation, Dave. As we pointed out in the prepared remarks, it is driving some changes in customers' behavior where they are looking to diversify where they do their projects. and spend their capital and also consuming countries are looking to pursue their own reserves where possible and where applicable and also to diversify their source of supply. And this is what's driving a lot of activity in the offshore.

We've got a tremendous amount of inbound in terms of commercial inbound at this point working with clients to unlock new opportunities all around the world. So the timing issue in the $14.5 billion is really just a fact of what's going to fall within the calendar year of 2026 and what could tip over to 2027. In particular, we have 2 large -- 2 to 3 very large projects that we are just in the final stages of concluding. Expect those to conclude by year-end, but they could tip into the new year, but I wouldn't tie it to the macro, Dave.

I'm just curious, as we look before -- in the past, you -- I think on the prior call, you had talked about kind of more greenfield, larger greenfield projects next year. Curious on the complexity of those projects. And some of this brought up on another call. I was talking about the complexity of offshore projects and how that changes. Is that, I don't want to -- the iEPCI model, for the most part, I don't want to characterize this the wrong way, but tends to be kind of on the smaller side. As you go into larger projects, are they getting more complex? And by extension, does that mean there's more FTI revenue per tree, however you want to talk about it? And is that accretive to margins? Just kind of curious how to think about that trend.

Sure. So the complexity of a greenfield versus a brownfield is typically just around the geology -- from a subsea point of view and from what we do, we're somewhat agnostic if it's a greenfield or a brownfield or the location of it. I mean, it may change between oil reservoir and a gas reservoir, the type of tree system that we use, but our 2.0 configure-to-order architecture applies across the board. So where the greenfield comes in is just less knowledge that you have about the topography of the seabed, maybe less knowledge you have around the soil conditions. And clearly, less knowledge you have about the reservoir itself.

And that's why you see greenfield projects sometimes take a little longer to move forward because customers are diligently making sure that they understand the complexity of the geology that they're dealing with in the subsurface. But from our point of view, it doesn't make a big difference, Dave, with our customers moving towards a portfolio approach, both in greenfield and brownfield, as we pointed out last quarter, An example of that would be Equinor, how they're approaching their additional work that they're doing in the brownfield activity on the Norwegian Continental Shelf, where they're doing groups of projects at a time where we were very successful and very appreciative of the work we're doing with Equinor.

So for us, we can get the leverage in a brownfield as well as in a greenfield. And so one is not necessarily more interesting than the other, and both are ramping up because clearly, the shortest path to first oil was a brownfield development. Therefore, it tends to have the highest project returns, at least in the near term. So those are being pursued as vigorously as now many greenfield opportunities around the world.

Your next question comes from the line of Mark Wilson with Jefferies. Please go ahead.

Excellent results, again, congratulations on that. Alf, I would like to ask on one of the last comments you just mentioned talking about an incremental margin on Subsea approaching 50% in the coming years. Could we give a bit more detail on that? Are we talking about Subsea 2.0 awards iEPCI. And goodness me, it sounds very incremental. Some details, please.

Yes. Thanks, Mark, for the question. So first of all, I don't think I commented on that this was beyond 2027, I think I specifically commented on' '27. But nevertheless, it's something that we are proud of in terms of what we are able to deliver. And it always starts with the quality of our backlog. And what we have done is continuously through 2026. As you can see from our continuous raises of revenue guidance, we have continued to demonstrate our ability to execute on this backlog. And we're doing so with increased throughput.

And when the throughput increases, we are also able to expand margins. So that's part of what you're seeing is really the underlying fundamentals of our quality of backlog, but our ongoing industrialization of our company. So whenever we have revenue increase year-over-year, we expect to have an outsized ability to expand our margins. And yes, that is through many different aspects, including increased mix of Subsea 2.0, iEPCI as well as making sure that our service business grows at least in line with our overall business. And all of those factors combined is what gives us the confidence to come out with this guidance at this point in time and indeed imply a 50% incremental margin into '27.

Could you talk about the capacity limits within that throughput, Alf. I think you've got 3 major producing manufacturing facilities around the world. What kind of utilization are we speaking to in that guidance? And then I'll hand it over.

Yes. No. Clearly, one of the things that we have focused on in our model over the last -- operating model over the last couple of years is to be 2 things: capital-light as well as focusing on throughput rather than keep on thinking about what incremental CapEx do we need. We build our business down days around creating constraints and thereby driving our thinking for how you can solve problems within the existing footprint rather than automatically defaulting to capital expenditures. Sure, are we investing in certain technologies that will enhance the automation and the throughput of our facilities? Yes, on an ongoing basis.

But that's also where we have talked about before that we have demonstrated that, for instance, the Subsea 2.0 order can go through our manufacturing plants at a 2.5x what a normal 1.03 could do. These are the things that we continue to see demonstrate to ourselves on a daily basis as well as keep on investing in for the future. And with that said, at this moment in time, no real concerns for overall capacity.

Your next question comes from the line of Arun Jayaram with JPMorgan Securities LLC.

Doug, my first question is I wanted to see if you could talk about what you're doing on accelerating cycle times. You mentioned kind of the Suriname project with Total. I was wondering if you could maybe elaborate a little bit on what's driving that? Is that just the shift to 2.0? And perhaps I'd love a mini update on what you're doing in terms of industrializing the installation process? Any updates on that would be helpful.

Sure, Arun. Thank you for the question. So what I was talking about on the GranMorgu project in Suriname was the delivery of some of the critical equipment, including the trees ahead of schedule -- this is a new market. This is the first project that's ever been done in that market. We have a track record of being very successful in entering into new markets and being the pioneer to bring Subsea into those markets. As a matter of fact, an impeccable track record. And this is just another example of that.

So it's about doing business the right way. It's about being on the ground in Suriname, knowing the people, knowing the support network that we have there, building the relationships early on. And then yes, the shift to Total energies to our Subsea 2.0 standard configurable product allowed us to have the deliveries not only on schedule but ahead of schedule, something that, quite frankly, is just very difficult for in the past for any subsea company to do. But certainly something that we are uniquely doing today, which is delivering projects ahead of schedule on even shorter cycle times than what has typically been done in the past.

So this all falls under the relentless pursuit of reduction of cycle time, Arun and something we continue to be very focused on.

Got it. My follow-up, Doug, I wanted to talk a little bit about your inbound order commentary. The company had previously indicated confidence in delivering $10 billion of inbound orders in calendar '26. Is that still a good target? I know you mentioned 2 or 3 large projects that are still trying to get to the finish line. Is -- maybe just comment on that. And I guess the question is if there is slippage in that $10 billion target, is that just driven by just the timing of these contracts contracts that you thought you'd win?

Sure. So Arun, the short answer is yes, but I'll give you a little more color. It is 2 to 3 projects that awards that we're just going through those final stages. We're not -- I couldn't say with confidence coming on the call that they were going to land within the calendar year. They are still more likely than not going to land in the calendar year, delivering the approximately $10 billion of inbound for 2026. Just wanted to be realistic given the fact that the end of the year is fast approaching. And if they slipped into the following year to make sure that they were being properly accounted for in our inbound guidance, hence going to the $14.5 billion for the 5 quarters, simply an issue of timing.

Your next question comes from the line of Alexa Breno with Goldman Sachs.

We just wanted to ask at the early '27 color is very helpful. Could you help just frame it from a regional perspective? Where are you seeing opportunities across maybe Africa, North Sea, et cetera? And how should we think about it in that framework?

Yes. So good morning Alexa and team as well. The -- if we look at it geographically, it's -- we had said that there was -- the last decade was really being driven by South America. It was going to continue to be very strong, and the next decade will be driven by Africa and I would say largely that, that is still the case. So we'll see a tremendous amount of awards coming from South America, both Brazil Suriname, obviously, Guyana. So there's lots of activity going on, also some activity, potential activity in some neighboring countries, which may not hit in '27, but could hit beyond '27 and then you also have kind of the whole region between the northern part of Guyana and Venezuela, et cetera, that could get interesting, probably beyond 2027.

So South America remains a critical focus for us. We wish Petrobras continued success in their exploration that they're doing in the equatorial margin which is a different region than the pre-salt in Brazil and could be quite prolific as well. So lots of reasons to be -- continue to be excited about South America. Moving towards Africa. I mean it's just -- it's robust. It's robust in West Africa. It's robust in East Africa, and we're going to see continued activity in North Africa as well. So those regions are all regions that we are targeting and pursuing in our opportunity list as you can see that we publish and would probably therefore also be reflected as inbound opportunities at the same time.

Important, as I mentioned earlier, to mention the NCS or the Norwegian Continental Shelf, it continues to be quite robust by multiple operators that continue to move projects forward as they help supply energy security for Continental Europe. And then we talked about Asia, I think on the last couple of calls, we said, keep an eye out for places like Indonesia, and that's really coming to fruition now. But we have multiple tendering activities, and we are actually performing multiple projects in Indonesia at this time. And then Australia, Australia is a major LNG producer and exporter and they will be going through multiple rounds, including, as we mentioned in our prepared remarks, the Chevron Gorgon Stage 3 project, which is all brownfield projects to supply gas to the existing LNG infrastructure in Australia.

So a long answer to say that it really is heating up around the world. It really isn't region-specific. I want to throw in the Paleogene, I would be wrong not to in the U.S. Gulf. It continues to surprise to the upside in terms of activity. And we also made a note in the prepared remarks about a very important relationship and agreement that we signed with BP to be their exclusive provider for the 20,000 in the Paleogene. So really, it's ramping up. Geographically, it's ramping up quite broadly.

That's very helpful. And then just a follow-up. As we look at the projects that are entering backlog today versus work being executed, can you give any color on how commercial terms or pricing are comparing? And then how should we think about margins thereafter?

No, it's an important question, Alexa, and I will -- I'm happy to share with you that new work or the inbound that we're putting in the backlog is accretive to the backlog margins. This is really because of the work that we're doing to help our customers be successful by reducing cycle time, improving their project economics, which allows us to share in a portion of that economic value that we create. So it's a true win-win.

Your next question comes from the line of Scott Gruber with Citigroup.

Doug, you mentioned that the step-up in Subsea orders is here. I'm curious whether that step-up that you see into '27 and we'll ignore the timing issues around year-end. But is that volume step-up within the ballpark of what you would have expected at the start of the year? Or has that gotten better given the macro backdrop? I'm asking because earlier this week, an offshore driller suggested they hadn't seen much of a cyclical response yet. So I'm wondering your perspective on that and whether the secular trend is really going to dominate here and the macro will help essentially extend that trend rather than add a material cyclical element to the order cadence. So just curious your thoughts on that.

Sure, Scott. As I've said in the past, I'm not a driller, I don't drill. So I don't want to speak on their behalf. And I've also made it a point to emphasize as has proven to be the case, we're a leading indicator when you look at the offshore and the deepwater. Our projects are typically awarded 1 to 2 years before the drillers get a tender or get an ITT. So just keep that in the back of your mind. But to more specifically answer your question, I do see this as a structural change. I don't see this as a cyclical change. It's not being driven by any particular event.

Yes, as I pointed out, due to some of the geopolitical events that are happening around the world, it is driving customers' choices of where they spend their capital, and it's also driving host nations or the consumers to decide where they acquire their energy from. So I do think that there's an attribute of that embedded, but I certainly don't think that that's the primary driver. This is a structural change that we've been talking about for years. It was coming. It's a result of the ability that we've been able to demonstrate through iEPCI and Subsea 2.0 to be able to help our customers improve the economics of offshore developments. And it's not just the upfront economics, it's the delivered economics.

Often, the upfront economics worked on paper, but what was delivered was often over schedule and over budget. We have a consistent track record of delivering on schedule or ahead of schedule, giving our customers the benefit of accelerated time to first oil and improved project economics. So in other words, their confidence in moving their capital towards the offshore is back, and I don't see it moving -- I don't see it changing as a result of any other geological play that's out there in the world today. And it's really because the best reservoirs, barring some reservoirs in the Middle East are offshore. And those are the ones that they have access to. So you have high-quality reservoirs with very solid economics. You just needed to know that you could work with companies that shared the commitment to delivering these projects on time and at the economic -- and at an economic rate that made them successful. This is why you see our customers buying behavior changing.

The fact that 80%, 8-0, 80% of our business is being direct awarded to our company. It's not going out to a competitive tender. The fact that our customers are booking us multiple projects at a time, not just one, but today's project plus tomorrow's plus the next day's project, because they want to ensure that they have access to the innovation that we're driving in the subsea industry, all supported and important to say by the way that we work. And we were very, very pleased to receive the award we received from Petrobras identifying us as their top ESG company that they work with. How you do business is as important as what you do. So look, this is, as we're calling it, a sustained wave of activity. It's just where capital is flowing. And the capital is flowing to the offshore for economic reasons. It's flowing to the offshore for energy security reasons, and it's flowing to the offshore because our customers have confidence that we can bring these projects to completion for them in a positive way.

I appreciate the color. It makes a ton of sense. And my follow-up is on margins for next year. Is there much benefit from the next phase of the iEPCI 2.0 initiative, the SERP portion? Is there much benefit from that hitting in the in the '27 margin guidance? Or is that still kind of more to come?

Scott, I'm smiling, Scott, because I thought this question was going to come up a lot earlier in the queue. So thank you for bringing it up. And look, I am actually going to pivot back to Mark's question earlier, when he acknowledged the phenomena, well, I think in his own words, I think he said strong performance in terms of a 50% incremental margin. That's something you don't expect in the industry from the companies that you follow and Alf explained why that was your follow-up is a perfect follow-up to that question because I will tell you in that 50% incremental margin, we're not counting on the iEPCI 2.0 contribution. So imagine that. Imagine you just imagine that, Scott. So it is more to come.

And I'm not saying that we won't see some of -- we won't be talking more about iEPCI 2.0. Obviously, we'll continue to provide updates I can tell you it's moving very well. We continue to have strong success in the testing that we're doing and in the field trials that we're doing. So it's moving in the right direction. But no, we did not embed that and I'm not saying that would necessarily be upside to 2027. But as you look at 2027 and beyond, that's a whole another wave of margin contribution that you're not -- that we are not experiencing today.

And as importantly, and I always like to talk about a win-win. It's a whole another wave of cycle time reduction that our customers aren't experiencing today. So they're going to win because we're going to continue to drive down cycle time simplify the complexity that remains in the nonindustrialized portion of the subsea offering, which will be addressed in our iEPCI 2.0 offering, giving them much improved project economics and allowing us to continue to share in the value in that economic value that we create.

Well, thanks. And every once in a while, we do see 50% incrementals. We just don't see people sustain it. for multiple years. So congrats on that. And I'll turn it back.

Your next question comes from the line of Josh Silverstein with UBS.

Maybe just sticking on the margin front here, really strong margins of the past 2 quarters. outside of normal seasonality, is there some sort of expected big drop off in the fourth quarter? Or is there some sort of margin headwinds or mix change? Because it seems like you're already trending to the bottom half of the 2027 guide just based on the normal seasonality.

No, you shouldn't read too much into this. This is normal seasonality. We -- in the fourth quarter, we experienced a lower activity in -- particularly in places like the North Sea. We do take our vessel portions of our vessel fleet into maintenance and dry docking. And those things affect utilization, but it's actually timed with the fact that there is lower activity going on. So that is really the main reason of why you're seeing this. And there is nothing specifically pronounced about it more than that activity is going on in the fourth quarter.

Got it. And then you guys have specifically highlighted kind of a customer shift towards this portfolio-based offshore development approach. You talked about the Petronas collaboration, the BP MOU there. Where are you seeing customers adopt this portfolio-wide development versus the individual projects? And how does that change your kind of view on visibility in pricing and market share?

Josh, I would say -- I would put it this way. I think every client is thinking about it. Not every client has a portfolio right? Clients have different sets of opportunities. So it's maybe more applicable for some clients than others. And I think every one of them is considering it, just I can say that because of the discussions that we're having with them. It's really -- it's applicable anywhere where they have the visibility in the portfolio within their own scope of assets to be able to approach the market in this way. So you see it in mature basins. Because there tends to be more assets available within those mature basins. But then you also see it occurring in emerging basins, like the Paleogene is in the emerging basin.

So there, you had BP take a very proactive approach. We're seeing it in greenfield and brownfield, again, pointing to Equinor on the Norwegian Continental Shelf, who's doing it with their brownfield portfolio. So it really is, and we have clients that are doing it not just within 1 basin because of Subsea 2.0 being a configure-to-order or more standardized product, we have customers who have multiple assets in multiple geographies approaching us in a portfolio approach across geography because the core of the Subsea 2.0 configure-to-order system is standardized, so they're able to do that. So this -- the technology is enabling this type of buying behavior. But I also think our performance is enabling this type of buying behavior because a customer is not going to entrust you with multiple projects in the future if they don't think you're going to perform well on the project you're going today.

And if we're being honest with ourselves, the industry didn't have a great track record in the past. And when you're still in a 1.0 world and still doing work the old way, you haven't transformed as TechnipFMC has, it's hard to be predictable in your execution performance. It's just hard. You're in a bespoke world. You have -- you're doing many, many first articles. It's really, really hard to have that level of consistency. So I think it's a combination of the customers' behavior, their asset base and their behavior, our performance and our technology that is enabling this approach. But I will tell you, it's very favorable for both parties. And again, we believe in a win-win. We don't believe we have to win at our customers' demise. And it's important for us that our customers continue to win because we want offshore to continue to be strong.

Your next question comes from the line of Marc Bianchi with Cowen. Please go ahead.

Thank you. Doug, appreciate the expectation for the step-up here in the orders. If I look at the year-to-date orders, they've trended, I think, below certainly what we would have expected, perhaps what you were expecting. Is there anything you can point to thematically that was maybe affecting some of the order conversion over the course of this year that you see changing? I don't know one thing I have in mind is, obviously, there's this war going on and maybe folks are dragging their feet a bit. But just anything thematic that you would point to?

No, Mark, actually, if you go back, I guess, probably about a year ago now, back in 2025, we said that 2026 was going to be a bunch of smaller awards. And just think about it statistically, a bunch of smaller awards, harder to predict the exact timing of those awards. So really, it's just been a timing issue. You see it in our -- again, this quarter, 3 [indiscernible] awards, but $2.1 billion of inbound. So lots of unannounced awards, which just means there's been a lot of smaller awards.

I think last quarter or 2 quarters ago, I pointed to the fact that 2027, we were going to start to see some of the larger orders really through the end of the decade, and those are shaping up as I was responding to Alex's question earlier. So -- it was really just a mix of the type of opportunities that we've been chasing. The team has been working really hard. We've been very successful. It's just a bunch of smaller awards and therefore, they tend to spread out a bit more on you.

Okay. And then the other one I have is on looking at 27% and the subsea revenue guidance, it's about a 5% increase. And I'm curious that makes perfect sense, just given the backlog scheduling you have. But I was wondering about the services piece of that because I think over the past couple of years, you've said that's going to grow in line with broader subsea revenue, which is kind of like a double-digit rate. Is services still growing at that double-digit rate in the '27 outlook that you provided?

So again, I think at this point in time, and we'll obviously be able to provide further updates as the year goes on. But I think it's I think it's a reasonable assumption to continue to look at services growing kind of in line with the growth of the overall segment at this point in time.

Your next question comes from the line of Victoria McCulloch with RBC. Please go ahead.

I guess my question actually is a good follow-on from that previous one. Because when you look at the contribution that services has been that have certainly taken, I guess, got some highlighted in today's results. How does the magnitude of the contribution and the margin profile of the services contribution compared to where you expect to be 12 months ago?

Good question, Victoria. I don't know that it's much different than what we had expected. We have a -- it's an OEM model as you know. And so we have a lot of visibility into our services profile. It is more of a book in turn than a backlog business, but it's still -- because it's an OEM model, we service our equipment. We have standard maintenance programs for that. So we're able to predict it fairly well. So I don't know that there's anything necessarily unusual. We did see, for instance, a strong pickup in our well intervention business in the third quarter.

So that's something that could be -- that we could potentially see more of as we move forward, where customers are really trying to optimize their existing wellbores. And the way that -- one way they can do that is with a drilling rig. The other way is to use one of our service vessels to be able to do that. So we are seeing an uptick there. But I wouldn't say anything that particularly stands of Victoria. It's a very good, very solid, very sustainable and a strong margin contribution business for us and one that we continue to invest in and grow.

Your next question comes from the line of Derek Podhaizer with Piper Sandler. Please go ahead.

I know you've been talking about this throughout the course of the call, but maybe if this is a nuance, but something that picked up on in the release was you talked about the strength extending beyond the decade with this wave of activity. And I feel like previously you've talked about straight towards the end of the decade, again, maybe pretty nuanced. But could you help unpack that comment for us, just a reflection of the continued momentum that you've seen over the past 2 years? Or again, has anything changed recently to extend your visibility beyond the end of the decade?

Thank you, Derek, and look, the biggest thing that is driving our confidence to make that -- and you're right, it was a pivot in terms of the terminology that we've been using is the portfolio approach. I mean, a project today is going to be delivered sometime just prior to the end of the decade. So when you're talking about a portfolio approach and where customers are buying multiple projects in series from us, another way of saying that is beyond the end of the decade. So that's what's giving us greater confidence.

And as I mentioned a couple of times on the call, we are seeing customers potentially reconsider the allocation of their capital and looking at offshore, both from the ability to be able to replenish reserves, the economics that are there now and the certainty that we are providing them as mentioned earlier, as well as wanting to have maybe a more diversified distribution of their capital geographically. And we're also seeing host nations really driving to pursue their own hydrocarbon reserves for their own energy security. You see that a lot in Asia as an example. We mentioned an award from Petronas in Malaysia. We talked about Indonesia earlier on the call et cetera.

So it's kind of -- it's a combination of those things, Derek, that are just making it increasingly visible to us that this activity we're either booking beyond the end of the decade already or we see a clear path to do so. And I'm going to go all the way back to Scott's comment, this isn't the best we can do. We still have 2/3 of our subsea infrastructure or the subsea project that we've not industrialized yet. That's what we're working on. That's what we'll be called iEPCI 2.0 that's going to bring a whole another wave of improvement in economics for our clients and for TechnipFMC.

That's great and very helpful. And I know you've are been asked about the iEPCI 2.0, I just mentioned and get. I think the other upcoming catalysts that you leave a little breadcrumbs for us is around your partnerships with some of these startups that are looking to move markets from the onshore to the Subsea. Just wanted to give you an opportunity if there's any updates there? Or still this is more of a stay-tuned event?

No, that's clearly happening today. And there was a couple of articles recently. I don't want to comment on them because they were in the media, but I don't know that they were necessarily press release from the client. But they're out there in the public domain where there are independent operators that are coming to TechnipFMC and a direct award as a result of our iEPCI and our Subsea 2.0 offering and their belief, again, that we will continue to drive this industrialization and innovation for the industry as we go forward.

So as mentioned previously in years past, our total client mix was between 9 and 12 clients a year, and we now service anywhere from 30 to 40 clients in any given year. And that market, they continue to expand the market as well as they bring fresh capital into the market.

We have reached the end of the call. I'll now turn the call back to Matt for closing remarks.

Thank you, Matt. This concludes our conference call. A replay of the call will be available on our website beginning at approximately 3:00 p.m. New York time today. If you have any further questions, please feel free to reach out to the Investor Relations team. Thank you for joining us. Matt, you may now end the call.

This concludes today's call. Thank you for attending. You may now disconnect.

Over the last 4 years, TechnipFMC has been far and away the best story in energy services. Trading at under $10 of stock is now up almost 8x since the period when Upstream spending globally has been flat. They did it by establishing itself as the premier offshore equipment company, reshaping the subsea market and integrated offering, an iEPCI approach to transform the industry and structurally lowered costs for the deepwater development.

The market has recognized the rarity of capital equipment company having higher orders revenue and margins concurrently. And this window looks to be open for several more years. My pleasure to introduce Mr. Doug Pferdehirt, who's been CEO of TechnipFMC since 2016. Thank you, Doug.

Thank you, Dave.

So Doug, a year ago, you sat here with the wind clearly at your back. Stock's now had quite a run since then. Expectations are sort of a different animal today. Can you think about managing that shift from being kind of a story that was sort of an interesting niche story to kind of really establish yourself as a leader in there. How are you sort of approaching that now in terms of those expectations? Do you change anything here? Or do you just continue the same way you've been going? Or does it require a different approach?

Sure. So I am not sure what you're feeling on your back right now, Dave, but I'm feeling the same amount of wind or perhaps a bit more. Just to play off of your -- the first part of your question. Really, a year ago versus today, a whole lot of things have come together. So I would say we feel more wind at our back today than we did a year ago. We've certainly proven more, both in terms of the market, the shift of capital flows to the offshore, our continued high level of execution and our ongoing development and extension of our offering through our industrialization journey.

Honestly, it feels really, really good right now. We're obviously singularly focused on execution and making sure that we continue to execute at a very high level. The team has done a tremendous job over the past year of delivering these projects, not on schedule but ahead of schedule, building further credibility, which leads to our customers putting more trust and confidence in us, and that's most reflected by the fact that 80% of our business is now direct awarded to our company.

So never sees any sort of a competitive environment or a bidding environment that's direct awarded. And that's hard to achieve. And it's certainly something we're focused on every single day to ensure that we continue to deliver to our clients' expectations. So yes, there's higher expectations from the market. There's higher expectations from our clients, and there should be. But rest assured, nobody puts more pressure on themselves or feels -- puts a higher expectation on themselves than the 22,000 women and men at TechnipFMC.

So over those last 4 years, your orders have been kind of around that $10 billion level have been growing, yet FIDs have been going down all at the same time. Can you just help us understand a little bit how that math works for FTI? Is it just this direct award approach? Is it iEPCIs? Is it all of the above? How can investors sort of understand that?

Yes. No, I think to really appreciate kind of the composition of the inbound is you have to start with looking at the market position. So we have over 50% of the world's installed base on the seafloor. We have massive, massive amounts of equipment, but also very advanced equipment that is sitting anywhere from a few hundred meters to up to 2 miles deep in the ocean. So this is where no person can go. So it's all very, very advanced materials. It's all controlled by advanced automation and control, some of the most advanced automation and control in the world today. We partner with NASA in terms of our control systems. And then it's all manipulated by either resident robotics or remote robotics.

So you've got this combination of things going on, managing not just a single piece of equipment, you have to appreciate what we're putting down there is -- it would look like a gathering system. I mean, there's all sorts of different things on the seafloor that we put to ensure that the hydrocarbon can be developed both economically and safely over 25- to a 30-year lifetime in a very harsh condition. You're obviously in a saline environment, controlling wellbore fluids versus a very cold ambient temperature on the seafloor.

So it's exciting. That gives us a somewhat of a like an annuity, not only from our Subsea services business, which is now a $2 billion business, OEM model. We service 100% of our equipment. We get these 20- to 30-year service contracts. But also as customers look to add incremental production or add incremental wells because we have such a large presence, that is typically direct awarded directly to our company.

So what you've seen is a very, very resilient amount of activity that hasn't been dependent upon large project FIDs. There have been some in that period of time. But to your point, not the same cadence as we had experienced previously or will experience over the coming years through the end of the decade.

So I thought -- and leading into that, I thought on your last call that probably the most important thing you had talked about was the outlook for next year and that we're now seeing large greenfield awards. What's changed in your view? What -- that seemed to me kind of an important distinction.

Well, the big change and the reason that I made that comment on the call was the question was about what gives you the confidence to be able to call an inflection in your inbound through the end of the decade. I mean, not a lot of companies are in a position to do that. Well, we have -- we have visibility that is really unique in that we have these long-term partner relationships with our clients that are exclusive in nature and allow us to have access to information 1 year, 2 years in advance of it becoming public knowledge or knowledge in the public market because we're working with them. We're helping -- we start as an architect. We're the architect, we're the builder and we're the service company. We're all of those now post the merger.

So in the architectural phase, just as you would, if you were building a home, you start that years or more before you engage the contractor to actually build or construct what you want to construct. So we are privileged to be and honored to be in that position where we're sitting there as they're looking at different assets, potentially where they're going to invest their money and how they're going to invest their money and with whom they're going to invest their money and being at the table obviously gives us insight and a significant advantage.

So from that, we have visibility that, quite frankly, is unique. And we haven't always had that as a company. We've built that over time. And certainly, we're in a very privileged position as we sit here today.

In addition to that, what we offer to our customers is unique. No one else offers to the market what we can offer to the market. So as a result of that, they're seeing a benefit. The benefit that they see is a reduction of cycle time or acceleration of time to first oil. And that's a big driver because offshore projects are longer cycle projects. And if you can accelerate the time to first oil, you can significantly improve the project returns.

In addition to that, what they're looking for is certainty, certainty in the outcome. If you're going to make a large capital investment personally or through your company, you want to know the result. You want to know you're working with somebody who's going to deliver to the standard that you've agreed to. That's who TechnipFMC is, and we've proven that time and time again. This has actually changed our customers' behavior.

In the past, they would secure one project at a time. because they kind of wanted to see how the company would perform on that project before they commit an additional project. Our customers are now moving towards a portfolio approach. They're actually coming to TechnipFMC and saying, here's my portfolio, here's opportunities. How about looking at these next 3 jobs? So in calendar terms, we're looking at stuff well beyond 2030 today. And our customers are committing work to us well in advance of that project that we're currently working on. And we're seeing this both in greenfield developments as well as in brownfield development.

You talked about that portfolio approach in brownfield. I'll get to that in a second. I was kind of curious with more greenfield projects out there, does that change the competitive dynamics at all just because it's more like I would assume that more of these projects will be out for bid, whereas you've talked about direct awards being like 80% of your amount or something. How does that change? Or does it?

No, it really doesn't because the relationships we have with our customers are not specific to greenfield or brownfield, new projects or extension of existing projects. They are relationships between 2 companies. So be it a greenfield or a brownfield, if we're in an exclusive direct award relationship, which we are with many of our clients, -- and there will be more of those going forward. We're obviously building those relationships every day. It's irrelevant if it's a greenfield or a brownfield environment.

The exciting part about the greenfield FIDs coming now through the end of the decade, it's obviously a significant volume of work on top of this very strong and stable activity that we've had around the brownfields. Now you're layering on top of that the greenfield developments. And there's many reasons why that's happening. But one thing for sure is the intensity of the conversations and the cadence of them wanting to move projects forward is increasing significantly.

That cycle time. Is that your big advantage, do you think, in all these -- like are you -- maybe you don't know, but I'm just curious, are you like promising to deliver like a year ahead of your competition from what you can gather?

Yes, but it's not a promise. It's what we're doing. So they're experiencing that. So it's kind of -- they look at and they just say, this is real. And this is different. I mean we are a different company than we were in the past. And they're looking at this and saying, "I can have first oil 9 months earlier." When they talk to you, that's important, and it's obviously important to their company and also to the host countries in which they're working. So it's something that's very real. It's something that's proven.

The exciting part for us is we believe we can reduce cycle time further. And that's within the company, we talk about the relentless pursuit of reduction of cycle time. Why is that important? It is the only scenario I have been in my entire career where you're in a win-win situation, your customer wins and you win. That's -- I don't know of any other situation. Certainly, I haven't been in many different activities in this industry where you've been able to be in that scenario.

We've proven that the customer doesn't have to lose for you to win or vice versa. You get out of the supply and demand and you get out of the big swings on return on capital through cycle, we're eliminating all of that. We're a high-performing company with a high return on capital, and we're showing that, that can be sustainable. Why? Because we've identified what's important to them, which is cycle time. That's important to us because that means we're getting a lot more throughput our existing infrastructure. So we're not having to spend more to grow. And on top of that, we're obviously able to benefit from a higher portion of the economic value we create as a result of that.

So a true win-win situation. The key to that, Dave, is we have identified and are confident that we're only 1/3 of the way there. For all the hockey guys. So it's just the first period intermission or baseball into the third inning. But that's where we are. We still have 2/3 left to go which is going to drive significant -- further significant improvement in cycle time, and we will obviously be a beneficiary of that as well.

So I would imagine you would say that first 1/3 is probably has a lot to do with Subsea 2.0. So if I go back in the prior cycle, there were some instances, we had some execution problems here and there. This seems to kind of solve a lot of those issues on the execution side. You're now talking about a new technology, kind of a new initiative, which you're sort of teasing to the audience and maybe you could tease a little bit more, if you don't mind. I'd be really curious, is this that next part of it on that other 2/3, how much is that playing into that next 2/3? Is that what you're aiming for?

Yes. Let me try to be clear on this. So the first third, as I'm talking about, was done before the merger. So before the merger, FMC Technologies, as we were at the time, focused on the seafloor exclusively, equipment on the seafloor. And we started working on that 4 years before the merger. As a result of the merger and one of the reasons for the merger, other than being the only end-to-end solution with the integrated or iEPCI offering, was also the other products.

So everything on the seabed needs to be connected to the surface of the water, and that's done through rigid pipe, flexible pipe umbilicals and risers. So all that needs to be done. And all of those products is what came to us as a result of the merger with Technip. And what we've done now is we've taken the same proven playbook that we did on the seafloor, we've marketed it as Subsea 2.0, and we're going to expand that across the rest of the offering.

In addition to the water column, you have to get all of this stuff on to the seafloor connected and commissioned, call that installation. So that's the other 1/3. So there's the 1/3 of the water column, the 1/3 of the installation, meaning there's 2/3 left to work on, which was a result of the merger. And that's why I'm quite excited is, we have learned a lot from the first 1/3. Our level of confidence in delivering the second 1/3 is far greater than it was the first 1/3 and the first 1/3 is working today. And you can see the impact that it's having on our customers first again, improving their project economics, but also it's impacting us favorably.

We will carry that through the next 2/3, hence, the relentless pursuit of reduction of cycle time. We believe there's significant runway left with those other 2/3, and we will benefit as we have in the first 1/3. So just think of it as it's proven, it's established, it's somewhat of an industry standard now, it's what leads to a lot of our direct awards because of how differentiated it is. But that's just the equipment we're putting on the seafloor. Do the same thing for the rest of the products and the installation services, I think we have a huge opportunity ahead of us, Dave.

So what excites you the most about this? Is it the ability to reduce that cycle time and therefore, get more orders? Is it more on the margin side of what you can do for your own margins? Is it both? Is that another win-win that you...

This may sound strange, and I've never actually said this, but I'm going to say it. What gets me excited is eliminating waste. If you go through this lean journey, and I've been on it now for 5 years, it wasn't easy for me to change. I was not a lean guy going into this. It is -- you have to change who you are as a person, you have to change the way that you manage the company and you have to change the culture of the company. We've done that.

Then you get this absolute loss of patience for waste. Waiting for the elevator to go up and down drives me crazy because that's unproductive time. I'm not picking on the conference. I love the conference. But everything I see in life now is under this lens of waste. It drives my wife crazy. We can't enjoy dinner anymore. But everything is around this lens of waste. You've got 22,000 women and men who do it better than I do. I mean they are more passionate than I am about it. When you unlock that magic, that's what gets us excited.

So when I look at the other 2/3, you know what I see, Dave, I see waste. Now the industry doesn't see it because it's the way we've always done it. It's okay, Doug, there'll be higher oil prices. It's not okay. Let's change the way we work. We've proven that in the subsea equipment. It's been hugely beneficial. We're going to do the rest for the other 2/3. And I'll admit it openly on an open mic. There's a lot of waste in the way subsea projects are done today, and we're going to drive the waste out of it.

I want to go back to the brownfield opportunities. That was another thing that kind of really came out on your call, you talked about is brownfield portfolio management, not something I've ever really thought about much. How big is that opportunity? It sounds like that's a real durable part of the orders going forward. Do you expect that to be a durable growing part of the business?

I think it's durable, and I think it will act as an accelerant, if you will, Anybody who has offshore floating infrastructure today on average, it's only producing at 60% of its nameplate capacity. It's not because they overbuilt or overspecified. It's because wells naturally decline over time. The good news is offshore wells decline at a very modest rate, 3% to 4% per year, unlike the shale that declines at 30% to 60% over the first 2 years. So very different, but it still declines.

So after 10 years of producing offshore, you're in the range of about 60% to 70% of the nameplate capacity because your initial production is your highest level of production. So you have to design the facility for that highest level of production.

The best thing you can do is look for in your portfolio of all the little additional reserves around your infrastructure and look for ways to tie those back. That's typically called the brownfield side of the business. But it's hugely economically valuable because you don't have the high capital cost of the floating infrastructure. And honestly, somebody's got to drill the well and we do the rest because we can do all of the infrastructure, tie it back, produce it in a very short period of time.

This is a business that used to take 28 months on average. 28 months on average to tie a well back to the existing infrastructure. Today, we're doing it at 14 months on a steady basis. And as I said earlier, as we address the other 2/3, which is not efficient today, there's no reason we can't drive that to a far lower number. I'm not going to commit to anything on the stage because we're still working on it. And then you start to say, well, this is pretty short cycle. We're talking months, not years to tie back and offshore wells producing 20,000 -- up to 50,000 barrels a day depending where you are in the world and you're tying it back for very little capital cost.

So this whole portfolio approach is our customers opening up to us and saying, here's my host. Here's my reservoirs around the host and they call them stranded reservoirs. They're not -- they're not physically stranded. They just don't quantify the capital investment of their own host because of the size of the reservoir, but they're still meaningful. It might be 4 wells. It might be 8 wells, but they're still meaningful and can be tied back to that host facility.

Is that U.S. Gulf Norway? Is that the larger...

Well, by definition, it would be where the most offshore infrastructure exists today. So -- but it's the U.S. It's the North Sea. I mean, okay, the U.K. can or cannot participate, but they have lots of infrastructure. Certainly, Norway is today, but it's also West Africa. And you'll see some of our clients who are thinking differently today and really looking at recovery rates They'll actually be accelerating. We'll still be doing greenfield developments for them in certain areas, and they'll start to do brownfield tiebacks, if you will, of brownfield activity at the same time. So it's definitely a focus.

I think we have a few questions here for the audience. We're going to -- if you use your little polling devices there. A few quick questions just to get some perspective. So which region do you expect to see the most growth in 2027? This isn't necessarily an offshore specific name. So Middle East, offshore, deepwater?

I can only choose 2. I fully acknowledge I'm biased. But look, I think the Middle East will see the rate of recovery in the Middle East. Latin America, a lot of Latin America is offshore. So I actually -- and I know it's not exclusively offshore.

Audience agrees with you.

But a lot of the Latin America activity is actually in the offshore domain as well. Okay Sorry, Sorry, you had me on a roll.

No, you're doing good, though. All right. So deepwater FIDs is something we talked about earlier today, we see a total of about $70 billion in '25. '26 on track for $100 billion. Where do you see '26 FIDs going? Kind of down a little bit, flat, up?

I'll get your answer later. There you go. All right. Do we have one more, I think, on there?

No, that's it. I just had those 2 questions. So your margins have moved up meaningfully over the last couple of years. I attribute a lot. Obviously, the Subsea 2.0 has really helped us. I think you've talked about further room to run here. Can you talk about what are some of the drivers? Is it more throughput? Is it the new technology? What do you think are going to be the primary driver of margin expansion over the next 2 or 3 years?

Yes. It's -- just look at the response of the questions. Clearly, the confidence in the market is going to drive overall activity. We talked about these greenfields coming back. We haven't even had the time to talk about emerging markets. There's a bunch of emerging new basins that are likely to FID over the coming years that's going to also contribute. But we like to focus, again, lean, lean, lean. We like to focus on what we can do ourselves, what we control, right? Love the market growing. It's a good thing.

I think we are a positive influence on that by, again, reducing cycle time, improving project returns while giving our customers certainty and confidence in sanctioning their projects, but really focusing on what we can do. That's that remaining 2/3. It's just that elimination of waste. It truly is a compelling opportunity and we know how to do it, and we will do it.

I know Matt is dying to give us our 2027 margin, but we'll have to hold up on that.

But I want to ask you kind of one last question. I'm curious about what we've been seeing in Southeast Asia over the last. It seems like over the last quarter or a lot of talk about offshore, not just from you but from other service companies have talked about Southeast Asia as being kind of a market that's inflecting in offshore. At the same time, if you look at what's going on in the Strait of Hormuz, there's no 1 region more impacted by this. Just a coincidence? Or are we already starting to see that sort of transition that shift into more offshore and the diversification of supply and that whole thinking on energy security. How are you thinking about that?

I think, Dave, it's undeniable to say that everyone's not going back and looking at their portfolios, certainly consuming countries that were dependent upon -- particularly heavily dependent upon any particular region around the world and maybe deciding that it would be better to be a bit more diversified. The first place to look is at home. What potential do you have? So I don't know -- I can't recall everything I talked about. But in Indonesia, we see a burst of activity in Indonesia and obviously supplying gas for domestic consumption but also for LNG.

Clearly, there's been an accelerated pace in Indonesia. You should expect -- I would expect to see Malaysia under Petronas, start to really look at their own opportunities. They've mainly been producing from shallow water today, but they do have deepwater reservoirs. And I think that would be a great sign in terms of people's focus and confidence, Australia, et cetera.

So I do think -- or we are experiencing a higher level of interest in commercial activity in Asia Pacific than we would have forecasted or expected. You can decide yourselves what's driving that. But there is -- it's undeniable, the level of commercial activity that we have going on in Asia Pacific now is far greater than I would have anticipated.

Fair to say when you look out to '27, a larger portion of that would be Southeast Asia than you probably would have expected 12 months ago.

Yes, I would agree.

Doug Pferdehirt, TechnipFMC. Thank you very much.

Thank you. Thank you all.

[Audio Gap] chair and Chief Executive Officer.

Thank you, Matt. Good morning and good afternoon. Thank you for participating in our second quarter earnings call. I'm pleased to share with you another strong set of financial results, driven by robust execution across the entire organization. Total company revenue in the period was $2.8 billion. Adjusted EBITDA was $601 million with a margin of 21.8% and when excluding foreign exchange impacts. We generated free cash flow of $488 million and distributed $440 million through dividends and share repurchase, delivering on our commitment to return the majority of free cash flow to shareholders.

Now moving to Subsea orders. We achieved $2.5 billion of inbound in the quarter, including four announced awards. Much like greenfield developments, Clients are now applying a portfolio approach to brownfield expansion opportunities to improve outcomes across multiple projects. These projects leverage the significant infrastructure investment already in place as clients look to prioritize their most economic opportunities.

By developing projects utilizing a consistent methodology and standardized solutions, TechnipFMC can help reduce cycle time across the portfolio of assets, significantly improving overall economics and helping clients advance projects more quickly. VAR Energy's recent iEPCI awards for the Ophelia and [Goa Nord] projects in the North Sea is a great example of this approach. We will utilize our integrated model across multiple fields through coordinated portfolio execution to help deliver first oil within two years. In the quarter, we were also awarded Subsea production systems by Equinor for a portfolio of subsea tiebacks, leveraging our standardized solutions we can deliver these projects with scheduled certainty and lower cost for Equinor, which has plans to develop a total of 75 subsea projects on the Norwegian continental shelf over the next nine years.

Looking ahead, we will continue to benefit from a resilient and expanding offshore market. We see a strengthening order trend in the second half of the year, providing us with confidence in achieving $10 billion of Subsea inbound in 2026. Our Subsea opportunities list once again stands at a record level, providing a robust pipeline of opportunities for projects that will extend beyond the end of the decade.

Our visibility is further enhanced by deeper client collaboration and earlier engagement that bring TechnipFMC into the project development process much earlier than ever before. In the quarter, we signed an integrated global collaboration agreement with a long-standing partner, which builds on the principles that have made our iEPCI integrated commercial model successful, combining early engagement, field optimization, and execution capabilities within a single framework.

The expanded collaboration engages TechnipFMC up to a year earlier in the project development cycle before critical subsea architecture and investment decisions are made. The global model will extend beyond individual projects, enabling optimization at the portfolio level. for also providing greater visibility into future development opportunities.

In Subsea, we consistently demonstrate our ability to execute at a very high level. This has brought certainty back into subsea projects giving our clients greater confidence in moving forward with final investment decisions. We expect this will drive further strength in capital flows to offshore markets. In Surface Technologies, our execution continues to support margin improvement in 2026 despite lower revenue versus the prior year. Here, our strategy has been to focus on the right customers in the right geographies and with differentiated technologies where we can achieve higher returns.

In the Middle East, our Surface Technologies team was recently recognized by ADNOC. For our significant role as a local manufacturer and partner within their in-country value program. This program is central to the UAE's plan to redirect significant investment into the local economy in the years ahead. Being a recognized partner positions TechnipFMC well as the program expands and reinforces our commitment to growing alongside ADNOC, and the UAE's industrial ambitions. This is a visible endorsement of the investment we have made in the country and the trust they have placed in our people and local operations.

Let me close on a few points. I'm extremely pleased with our second quarter results. The strong financial performance in the period clearly demonstrates the solid momentum in our execution, thanks to the dedication of the 22,000 women and men of TechnipFMC. This gives us the confidence to raise our full-year expectations for total company EBITDA.

Our order outlook for Subsea remains robust. And with a book-to-bill above 1 in the quarter, we see a strengthening trend in order activity in the second half of the year. We also reiterate our expectation for a step-up in inbound orders in 2027 and extending through the end of the decade. This growth will be supported by iEPCI, Subsea 2.0 and Subsea services, much of which will be direct awarded to our company. And as our clients move toward more collaborative approaches to develop their offshore portfolios, we will leverage our iEPCI execution model and our configurable solutions to drive further efficiencies and higher capital returns for both our customers and TechnipFMC.

I will now turn the call over to Alf to discuss our financial results and importantly, our strengthened financial outlook for the balance of the year

Thanks, Doug. Inbound in the quarter was $2.7 billion, driven by $2.5 billion of subsea orders. Revenue in the quarter was $2.8 billion. Adjusted EBITDA was $601 million when excluding a foreign exchange loss of $19 million. Turning to segment results. In Subsea, revenue was $2.5 billion, a 13% increase versus the first quarter. The sequential revenue improvement was driven by increased project activity, particularly iEPCI projects in the North Sea and the Mediterranean, partially offset by lower activity in Africa and the U.S. Gulf.

Adjusted EBITDA was $577 million, up 31% sequentially. The due to strong execution and higher project activity. Adjusted EBITDA margin improved to 23.2%. The -- in Surface Technologies, revenue was $276 million, a decrease of 3% from the first quarter. The decrease was driven by reduced activity in the Middle East due to the ongoing conflict. -- and lower activity in North America. This was partially offset by strength in other international markets. Adjusted EBITDA was $5 million, an increase of 1% sequentially. The -- adjusted EBITDA improved sequentially due to strength in international markets despite the revenue decline in the Middle East.

Adjusted EBITDA margin was 18.1% and up 70 basis points from the first quarter. Turning to corporate and other items. Corporate expense was $26 million Net interest expense was $4 million and tax expense was $114 million. Cash flow from operating activities was $548 million, with capital expenditures totaling $60 million in the quarter. This resulted in free cash flow of $488 million. We repurchased $420 million of stock in the second quarter when including $20 million of dividends, total shareholder distributions were $440 million. Cash and cash equivalents was $992 million. We ended the quarter with a net cash position of $590 million.

Moving to third quarter guidance. For Subsea, we expect revenue and adjusted EBITDA margin to be in line with the second quarter. For Surface Technologies, we anticipate revenue to increase mid- to high single digits sequentially with an adjusted EBITDA margin of approximately 17.5%.

Moving to our full year outlook. Beginning with Subsea, we now expect both revenue and adjusted EBITDA margin near the top end of their respective guidance ranges. For Surface Technologies, we now see revenue closer to the low end of the guidance range with adjusted EBITDA margin just above the midpoint. We continue to expect corporate expense of approximately $120 million.

With these updates, we are increasing our expectation for total company adjusted EBITDA to approximately $2.19 billion for the full year when excluding foreign exchange. And finally, we now see full year free cash flow tracking towards $1.45 billion, which is the high end of our guidance range.

In summary, we delivered strong second quarter financial results with Subsea margins exceeding 23%, helping drive total company adjusted EBITDA to $601 million, excluding foreign exchange and free cash flow expanding to $488 million. We returned $725 million in total shareholder distributions in the first six months of the year, which equates to 95% of free cash flow.

Given our long-term expectations for the company's financial performance, we continue to see share repurchase as an attractive use of free cash flow. We have increased our expectations for total company EBITDA for 2026. And lastly, we remain confident that in 2027, we will grow Subsea inbound revenue and adjusted EBITDA margin.

Operator, you may now open the line for questions.

[Operator Instructions] Your first question comes from the line of Derek Podhaizer with Piper Sandler.

I guess maybe, Doug, let's start with your opening comments around the brownfield opportunities that you're seeing. You talked about delivery of first oil in 2 years brownfield or step-outs. I know previously, you've talked about electrification of the brownfield being able to step out that radius 4x more than typical hydraulics. So -- is that what you're seeing now? Or is that still an opportunity in the future? Maybe just some more comments around the brownfield step out and potentially electrifying these operations as you move forward?

Thank you, Derek. So in these peer cases, they're not necessarily enabled by the all-electric solution, but what we are seeing is our customers scour their portfolios, looking for marginal fields or brownfielter tiebacks, all somewhat synonymous opportunities because in this case, the host facility exists, which allows them to really through a single contract with us because of our fully integrated offering be able to deliver a very short cycle project and accelerate time to first oil.

What's exciting is and where the behavior has changed is in the portfolio approach. We saw this and talked about this in prior quarters in greenfield activity where customers are coming to us and through discussions working with us not only on a current project, but on future projects tying in and leveraging that consistency of approach and our unique iEPCI and 2.0 capabilities.

So we're now seeing that spill into the behavior in the brownfield markets, and we gave two examples of that, both with Var Energy, which is a great example as well as with Equinor that are looking at a portfolio approach. So multiple projects under a single portfolio approach. That will allow consistency, greater certainty in scheduled delivery and shorter cycle times that has a vast improvement to the clients' project returns and economics and obviously benefits us as well. So that's very exciting.

The opportunity that lies ahead is exactly what you said, growing the brownfield market. How do we grow the brownfield market is by being able to in an efficient, short cycle and economic way tie back from further distances from the host facility. And with the all electric solution, we now can go and increase that radius around the host facility by 4x and hence, reach a much greater feel -- a much greater opportunity set in terms of marginal fields and tieback opportunities. In that case, we've done a lot of work with the all electric system. We have many electric systems deployed around the world, and we're really now working with our clients to look for those greater opportunity set. But as you said, that is a future opportunity for us and one that will further grow the brownfield market.

Great. That's very helpful, Doug. Thank you. And then I guess, next, you've talked about collaboration with your customers starting in the development life cycle. A year earlier, obviously, it helps your visibility, which you've already went over in your prepared remarks. But maybe operationally, could you help maybe expand on that comment? I mean what's the benefit for you operationally the benefit for the customer operationally? And how does this translate whether it's in time to first oil or overall earnings profile, the power there. Just maybe some more color around now moving up in the development cycle by a year with your customers.

Derek, this is an all of the above. And the reason why it is, is being at that table because when we say a year earlier, we're now -- in the prepared remarks, I referenced -- this is well be for any traditional contractor would be invited into the discussion well before even decisions around which type of subsea architecture might be used. So we're going in as a trusted consultant or a trusted adviser, trusted partner, they're inviting us to the table because they see the value that we bring, they want us to be part of that conversation. And by being part of that conversation, the objective for the client is to be able to further accelerate time to FID, so faster time, shorter cycle time to FID.

And then from our point of view, it's not only securing that project and having the visibility and in many cases, as a direct award because of that proprietary nature of our relationship, but it also means delivering a shorter cycle time projects. So within the company, we have the saying that we all live by every single day, which is the relentless pursuit of reduction of cycle time. That's the unique capability that allows us to win while at the same time, our customer wins. So this increased earlier engagement is really, really critical and is giving us a level of visibility and insight that we've never had as a company.

Your next question comes from the line of Arun Jayaram with JPMorgan. Please go ahead.

Doug and team. Doug, I was wondering if you could talk a little bit about the trajectory of orders that you expect this year and how you see the inflection point in orders playing out in 2027. On a year-to-date basis, you've booked $4.4 billion of subsea orders book-to-bill of just below 1. So wondering if you could discuss expectations for the back half and perhaps give us some insights on your pipeline of direct awards that may not be on the Subsea opportunity list.

Sure. So clearly, there's momentum, as you pointed out from the first quarter into the second quarter and further momentum expected in the second half of the year. We see a clear line of sight to the $10 billion target for 2026. What we're seeing is a lot of smaller projects. If you recall, even in the first quarter, very few announced projects, we did have four analoged projects this quarter, but it's a lot of smaller projects. What you see in 2027 is the inflection and the return of some very large greenfield opportunities, which will not only drive the total opportunity -- the opportunity set as we published and we pointed out in the prepared remarks, is now achieved another record level and increased again this quarter, largely driven again by those greenfield-type projects.

So that will just get further strength and confidence in 2027 and what we have referred to and are fully committed to a step up of orders in 2027. So it's a bit of a mix question in terms of the type of projects in 26 versus the type of projects in 2027. 2027 will be larger projects, more greenfield opportunities 2026 being more of these marginal field tieback brownfield opportunities, some greenfield opportunities as well, but customers are really, really focusing on getting these shorter-cycle projects out the door as fast as they can. And that's where we have the natural ability to be able to help them do that.

And that's why I can confirm that our proprietary list of opportunities that result in direct awards to our companies, to our company, some of which we obviously announced this quarter is growing and is a very healthy set of opportunities and one we will continue to benefit from as the company moves forward.

Great. My follow-up, I was wondering if you could give us any bread crumbs on your SURF 2.0 initiatives, where are you in terms of your efforts to industrialize the other 2/3 of a subsea project, the installation, the water column, any bread crumbs you could share today?

Sure. So just for the entire audience, Arun, I'm going to maybe reference it slightly differently. When we talk about Subsea 2.0, so far, we've been talking about -- that's the industrialization of all the equipment that sits on the seabed. And that's something that happened many years ago in our company and that we're benefiting from today. So if you look at what is currently called Subsea 2.0, which is again the equipment on the seabed, about 80% of our new orders are coming -- are now Subsea 2.0. So the market has entirely embraced this new architecture, and it represents about 50% of our revenue. So you can obviously see the upside that we have from the further conversion of that 80% of orders into revenue.

When we talk about what's left, I'm going to ask all of you, we're going to try to deviate the gaming architecture a little bit. It's really about industrializing the iEPCI. So it's really about making the iEPCI 2.0 because remember, the iEPCI has three components. It has -- which sits on the seabed -- it has all the things that are in the water column, the umbilical risers flow lines, fiber optics, telecommunications, electric -- all -- everything that's within the water column. And then it's the installation of all of that kit.

So it's really three different elements. So if you think about it that way, as we go from the Subsea 2.0 seabed, configure-to-order architecture and we move to a fully industrialized iEPCI 2.0, the upside is significant because those last 2/3, the water column and the installation have yet to be industrialized. So think about it as going from Subsea 2.0 to iEPCI 2.0, and that is where we will get and that will be another major, major change to not only our company, but to the way that the industry operates.

I will tell you this, I spent most of the quarter working on this. And we are getting some very, very exciting results. We continue to -- I'm trying to give you the bread crumbs you asked for without saying too much, but know that it's a major focus of mine, we've made quite a bit of progress in our understanding of some of these disruptive technologies and processes that will become part of iEPCI 2.0 in the future.

Your next question comes from the line of Victoria McCulloch with RBC. Please go ahead.

Thanks very much for your time. So if we could start on the Subsea EBITDA margin. As we look into the second half of the year, I guess, in the context of what you've delivered this quarter, can you give us a bit of an understanding how the split comes from delivery on project phasing versus fundamentally a structural step-up in higher quality contracts and the proportion of the entire I guess, revenue and the EBITDA that you're seeing being delivered from the business right now?

It's a great question. And obviously, there's a lot of market momentum out there. We are in a unique position as we have discussed before in terms of the relationships with our clients. But I will tell you this, we focus a lot more on those, as you would say, as you mentioned, those structural changes because we don't want to do this for today. We want to do this for a very long time. and we want to continue to be very successful.

And again, when I say successful, it's our clients and TechnipFMC. And I think we're kind of unique in that manner. We're not selling fixed assets. We're not a commodity we are a technology company. So we're looking for ways to ensure that our customers are successful while we continue to be successful at the same time. So what we put most of our focus on are those internal changes to both our operating model as well as what we just talked about going from Subsea 2.0 to iEPCI 2.0, continuing to benefit from the better, the greater efficiencies we have in our manufacturing, the shorter cycle time, which frees up more assets, which is why you don't need to be building or buying assets right now.

You need to be becoming much more efficient. That's how you're going to drive higher returns and create a sustainable model going forward. So we very much focus on those internal elements that are really changing who we are as a company and the way that we operate.

I'll pass it over to Alf to add some more color.

No, just to complement what Doug said. So in all what he just said, when you specifically look over the evolution of first half, second half and onwards, it is very much a gradual improvement, right? Because these things are realized as we keep on taking on new backlog with iEPCI and 2.0, but also starting to mature all of our industrialization processes. So it's really hard to kind of pinpoint that it's a step up in any one quarter. It's a gradual improvement that we're seeing through our backlog as we're experiencing really in demonstrating strong execution.

Sure. I'll just add to Alf and say, it's not only a gradual improvement in the second half. But as Al said in his prepared remarks, we're already committing to 2027 improvement.

Yes. That's really helpful color. Just on the tender pipeline, it's great to see it grow every quarter and the color that you gave on the projects added and have been awarded. We don't know there are some sticky projects. These are not your projects but sticky projects that whether it's the economics or the offtake that become challenging to see sanctioned and reach that FID for the company. When you look at your addressable contracts that you see in the second half of this year and into next year, how much of that $30.5 billion is still kind of sticky and dragging a bit? And maybe could you use the iEPCI. Let's put it that way.

Well, thank you for that endorsement. I'm looking at the opportunity list as you just mentioned, we -- let me use a different word for sticky. We certainly know that some of these projects have lived on this list a bit longer than anyone originally anticipated. I will tell you, I think everyone will be surprised that we'll start to see some momentum in some of those projects. Some of those projects indeed the economics will be solved by iEPCI 2.0. We certainly would be proud to be -- if we could do that for our clients. But of course, there's always local challenges or reservoir challenges or partnership -- or partner challenges between different operators. So it's very hard to predict exactly when projects will FID, but I actually think the probability on this list over the next 24 months is greater than it's ever been.

Your next question comes from the line of David Anderson with Barclays. Please go ahead.

So you were talking about how the orders are sort of shifting in from 26 to 27 shorter -- more brownfield, shorter-cycle projection towards larger greenfield projects next year. Does that imply that we should see -- I would assume that means we've seen more -- many fewer direct awards, and it should be a lot more competitive tenders. Can you talk about the dynamics a little bit of that? I know a lot of the margin expansion has been structural, but there's obviously pricing is a critical factor here. Can you sort of talk about that? We haven't really seen this type of market in quite some time. So how are you approaching this obviously, some of your competitors have been pretty aggressive on certain projects we've seen lately.

Sure, Dave, and thanks for the question. So first of all, I wouldn't necessarily draw the conclusion that it would be -- well, almost -- I will say this. I would not draw the conclusion that it will be less direct awards in 2027. And remember, we've already announced some pretty substantial greenfield direct awards throughout the history of a number of our iEPCI projects and our direct awards -- so I wouldn't draw that conclusion. But just speaking more broadly to the 20% of our business that does -- we do compete in competitive tendering, remembering that 80% of our business is direct awarded to our company. So on that 20%, I think, Dave, the right approach is discipline. Keep in mind that we have certain obligations and making sure that those obligations are met and achieved. You all know the competitive landscape. It's rather concentrated. I think is maybe the word to use. So look, I think I set a very matured, disciplined companies in a market that's growing.

And so we will be selective. We will focus on those projects where we believe to Victoria's question earlier, where we can use our magic and our differentiation to help unlock the potential. So then if it's a competitive tender, it kind of really doesn't matter if we're tendering something that is uniquely different than what the competition has because of their lack of capability or technology differentiation. So Yes. The market will be what the market will be, Dave.

Again, as I said earlier to an earlier question, we very much focus on what we can do to create value for our clients and ourselves at the same time. And often that will lead to a direct award because of the differentiated nature of our offering.

So Doug, maybe we could take a little bit of a step back. I'm just curious how you're your customer conversations that go on. I'm particularly wondering about how do your customers make capital allocation decisions in this kind of market with all this volatility and obviously, the conflict going on. Where does off-store fit? Is offshore now becoming a bigger part of that? Do you think the shift capital allocation towards more offshore for a variety of reasons. Is that part of the reason why you're seeing 27% looking -- seeing a step up there?

So Dave, I don't want to speak on behalf of my customers. So I'm just going to give you my observations based on behaviors that I'm seeing in the industry. I would absolutely say that Subsea is becoming a more strategic consideration for our clients because of the geographical diversity that it offers, i.e., if you want geographical diversification, there's only one way to get it. There's the two poles, which is North America and the Middle East, and then there's offshore. And so I think, clearly, countries, NOCs as well as independents and IOCs are looking at their exposure in their portfolio and when they look at their risk analysis, I do believe that geographical diversification has always been part of that, but it may be a greater consideration. And as it's a greater consideration, it will most likely drive increased levels of focus on offshore assets.

Keeping in mind that the reservoirs are exemplary. It's never been an issue of the quality of the rock. It was an issue of economics, and it was an issue of project certainty. Our clients demand certainty the offshore industry for decades did not deliver certainty.

TechnipFMC has brought certainty back into our clients. It's given them the confidence as they move forward and look at their offshore, their broad offshore portfolios where they can actually move, diversify their project opportunities around the world. At the same time, and we've talked about this on prior calls, it's not just the traditional customers. We are seeing new entrants in the offshore at a rate that I had never experienced in my career. So many, many new offshore operators taking on deepwater subsea projects. Humbly, I will say they make only one phone call. because there's only one company that can deliver them everything from the architectural phase or the front-end engineering through the manufacturing, delivery, installation, commissioning and life of field service contracts of up to 30 years through a single entity and a single contract in Net TechnipFMC.

Your next question comes from the line of Mark Wilson with Jefferies.

Doug, your comments about industrializing i.e., iEPCI and iEPCI 2.0 is fascinating with the water column and then the installation side of things. My question, therefore, would be that in terms of the water colon and insulation, a big variable in that is whether we've got flex pipe or there is welded rigid pipe. Is there, therefore, an iEPCI 2.0 vision that covers both of those? Or does it require one of those two technologies to really outweigh the other to deliver that vision of iEPCI 2.0?

Sure, Mark, and thanks for switching over to the new nomenclature as quickly as you did. I honestly appreciate that. So look, when we look at iEPCI 2.0, it will solve the vast majority of the market's requirements and it will not be dependent upon 1 specific type of one specific type of pipe or installation, i.e., flexible or rigid, but it will be a game changer. Let me explain. It will be something that has never been done before. And it will be very unique.

And I simply can't say more mark because it would not be to my benefit to do so at this stage. But what we have under development is substantial. It's the most excited I've been in my career. And again, it will change the industry. So yes, it will be agnostic to the type of to rigid versus flexible as we have historically thought and we'll cover both, but in a very differentiated way. We look forward to it.

My follow-up would be to ask regarding the margin. I think 2Q is is the highest group margin since the demerger. You guided to the second half and unchanged broader EBITDA. But you've spoken before to they're still being levers that can be pulled within EBITDA. And we note subsea now over 23% margin. So just if you could just speak to the the outlook there versus the projects and the backlog you have.

Well, we've consistently improved the opportunity set in our backlog by obviously working off some of the old legacy backlog, very little remains. We continue to replenish it with higher quality backlog, not just in terms of necessarily the margin associated. But with the quality of the work that we will be performing, i.e., the ability to be able to consistently deliver ever better projects as we move forward because of the quality of the backlog.

I do want to take this opportunity just to emphasize because I know it didn't come across in all of the early reports, but we're raising guidance. So I want to make sure everybody acknowledges that. We had a substantial beat this quarter, and we raised well beyond the value of the beat. So it is -- so total company EBITDA, we took to $2.19. That's a substantial increase. So I just want to make sure that, that comes across to the audience so that, that gets accounted for appropriately. In terms of the margin in Q2, Al's already referenced that he expects a similar margin for Subsea in -- and I don't know, Alf, is there anything else you want to tell...

Just overall to make sure to understand that for both segments, we expect EBITDA generation to be stronger in the second half than in the first half.

Your next question comes from the line of Marc Bianchi with TD Cowen.

On the iEPCI 2.0, how long do you think it will take before we start to see this becoming a meaningful part of your inbound and of your backlog?

Thanks, Mark. And again, thanks for picking up on the new nomenclature, I'm loving it. So we're just being a little bit -- it's not that we're not telling you the answer. We are still going through Concept Select. We are doing experimentation as we speak. I will tell you that was a big part, again, a big part of my focus on this past quarter, and I'm excited is I don't want to say too much. But if you put the two together, it gives you a little bit of an indicator. The exact timing, I don't want to put a stake in the ground yet -- that will come in time. But we wouldn't be talking about it now if it was in the distant future.

Okay. Okay. On the order outlook for the remainder of the year, you mentioned the smaller projects or maybe the difference is smaller projects this year, greenfield projects next year. Does that translate into maybe fewer press releases as we sort of track the performance over the back half of the year. These are smaller things that might not qualify? Or is that not the right takeaway?

No, I think that's fair, Marc, and I appreciate you making that observation because I wouldn't want people to be concerned, if you will, about a lack of press releases or announcement, we saw what we've delivered in the first half, and there really wasn't a significant amount. So it is a lot of smaller projects. But again, these are very meaningful projects for our customers. and very meaningful projects for ourselves. But yes, that's a fair point. I wouldn't focus too much on just a number of press releases. We remain confident in delivering the $10 billion to be inbound.

Your next question comes from the line of Scott Gruber with Citigroup.

Yes. Good morning. Maybe coming back to the macro, Africa has received a lot of attention in terms of the development pipeline. I've been thinking more recently about Asia Pacific just because the region has been hard hit by the energy crisis. And even before that, there seemed to be an interest in picking up activity. Maybe if you can dig into the region a bit more from India to Southeast Asia, down in Australia. What are you seeing in terms of the development pipeline there? Has that taken a step higher with oil prices? And what's the outlook for gas development across the region? I just imagine that, that's progressing in a positive fashion kind of given the power demand growth trends. Just some more color on Asia Pacific will be created?

Sure, Scott. And I absolutely believe your intuition is validated. We're seeing that both in the behavior from the governments as well as clients within the Asia Pac region. One, at a government level, they are looking to secure capacity beyond their traditional sources. And that doesn't mean there's anything other than that. They are out going around the world, negotiating contracts to diversify their supply.

At the same time, they are taking a second look at their own resources or resources within the region that they could invest in. And I think it's a combination of both. So it's maybe not necessarily in their territorial waters, but it's in the region. So from a gas -- you mentioned gas from a gas point of view, the best example of that would be Indonesia.

We see a significant amount of activity for our company as well as tendering activity more broadly in Indonesia. We see more and more neighboring countries, wanting to be part of those projects, those developments. We know there's large gas project opportunities in Australia. And Woodside is obviously doing everything they can to move those projects forward, and we would be delighted and honored to continue as a partner with them on future projects. And then in Malaysia, Malaysia continues to look at deepwater opportunities. Again, it's mainly been a shallow water developments in Malaysia, and they're looking more and more at deepwater developments, an area that we have partnered closely with Petronas in the past in that region.

So -- and there's other activity in other countries within Asia, but I would say those are the -- those are the highlights and absolutely tie into your thoughts as far as increased activity, both because of gas and supply of gas, but also potentially because of wanting to have a little more control over their future.

I appreciate that color. And then just turning to the surface business, orders downtick during the quarter, the $220 million -- a little bit more color just beyond that? Anything to read into it? And then kind of outlook for orders in the second half of the year?

Sure. So when you look at surface and you look at their orders, Well, let's just look at the business, where the orders really come from that feed the backlog are really from the Middle East, right? So the North America business, more or less a book and turn business. So that kind of resolves itself on a quarterly basis. So when you look at things like backlog or inbound, it is really about the Middle East.

An important thing to remember, we signed a 10-year contract with ADO and several years ago. I think Q4 2021, if I recall Yes, else confirming. So it's been quite some time ago, and we're working that off, right? So that doesn't get replaced because you work it off over time. until the next big contract. So that's just a natural dynamic that you're going to see in the surface backlog. And in terms of -- but the activity remains very strong and in the UAE.

And as indicated earlier, we just received the recognition and award from ADNOC that we were very proud to talk about. In terms of our work with Saudi Aramco in the Kingdom, we continue to be very active in terms of our manufacturing. There's been some modification and some service activity from time to time, but we remain very active and full utilization of our manufacturing plant in the Kingdom. We do anticipate additional orders from Aramco in the second half of the year.

Your next question comes from the line of Caitlin Donohue with Goldman Sachs.

I just wanted to touch on the services business within Subsea. What are your expectations for that business over the next couple of years, especially as we are seeing a little bit more of this order step-up into 2027. What are your expectations around the growth that we could see there?

Sure, Caitlin, I'm happy to take your question. And thank you for asking. It is absolutely a crown jewel of the company. It is an important business. It is probably the most consistent business. I think of it kind of as an OEM model. The assets that we deploy are very high end. They almost always use automation and control and robotics. These things are very, very deep in the ocean, obviously, cannot be intervened with by man.

And therefore, it's very, very advanced automation and control and robotics, some of the most sophisticated, quite frankly, in any industry. So these things do require inspection maintenance and repair, from time to time, our customers do have to intervene, not because of our equipment, but because of the wellbore. The wellbore is dynamic, right? So the flow is always changing.

The type of fluid is always changing. Day 1, it may be oil and day whatever it may be 90% water. Or you may have gas breakthrough or you may have asphalt in scale buildup, all sorts of things happen down hole, it's a very dynamic environment. And whenever they need to intervene, they will call us and we will typically help them with the intervention either by performing the intervention from one of our intervention vessels or if necessary, and they need to actually pull the completion because there's a downhole failure of one of the pieces of the downhole equipment, which we don't provide, then they would require a rig to do that, but we would still need to come out and help them be able to access and remove our equipment from the wellhead.

So it's -- I guess what I'm trying to explain is this is a business that from the time you receive the work and from the time you deploy the assets on the seabed, you've now got a 20, 25, 30-year life of field services contract that is very predictable that because of the nature of it, it is a very it's very accretive to our company, and it's something that we put a lot of time and focus on ensuring that we have the ability to continue to grow and expand that business. The best way to grow and expand the business is to grow and expand your installed base on the seabed.

As I explained, it's an OEM model. I think it's well established that TechnipFMC has been successful and continues to be successful. And so when we talk about direct awards, they all come with these life of field services contracts associated with them. So up until now, the growth rate of the Subsea Services business has somewhat been in line with the growth rate of projects. And that's very much a result of just how fast the company is growing on the project side. But there is a point in time, and I'm not suggesting it's anytime soon. But theoretically, there's a point in time to where the growth of the project revenue will slow down, but the services revenue will not slow down as a result of that because, one, you have a larger installed base; two, you'll have equipment that's continuing to age and that will just drive more and more activity for our services business.

So it's a business we're very proud of. It's a business we put a lot of focus and attention into and 1 that we expect to continue to grow and make a stronger contribution to the company going forward.

That's helpful. And then just my follow-up, I wanted to touch on seeing these larger greenfield orders coming in, in 2027 relative to 2026. I know FDI has pretty high line of visibility into the latter years of the decade. Interested on if this is a trend that you expect to continue seeing some of these larger orders coming in post 2027? Or if this is more of just a 2027 call right now?

No. Thank you for clarifying. It is absolutely post 2027 through the end of the decade.

Your next question comes from the line of Saurabh Pant with Bank of America.

I wanted to quickly follow up on something that we touched on, I think we Scott was asking the question on gas and Asia. I want to focus just on the gas part of it, more, Doug. I think I'm seeing more and more gas projects show up in the pre-FID pipeline. And of course, Asia is part of it, but we saw the first fiber project in the East and that get to FID, the krona project, right? So just big picture, what does more gas in the mix been for SPI? And then related to that, what does that mean for your subsea processing opportunity? I'm thinking separation and boosting, is that something that would probably see higher demand on the back of just more gas projects?

Interesting question. Let's first talk about the gas demand. So I will tell, if you look at the subsea FIDs, the liquids demand has actually remained quite strong. That doesn't mean that the gas demand is not -- gas opportunities are not growing, as you pointed out. and I'll get to that in a minute. But the liquids remains very, very strong, and but a lot of that is being driven by the activity that's going on in South America.

As we look at gas, Yes, we talked about Indonesia. We talked about Asia more generally, Indonesia, Australia, just to name a couple. But you're right to point out also the Eastern Med, a significant large projects ongoing and future opportunities in the Eastern Med. There's also a significant amount of gas activity going on in the Norwegian sector of the North Sea, which will continue to be a key from an energy security, a key reliable source of gas into Continental Europe.

And then we see other gas developments and gas opportunities as we look around the world, some in the northern part of South America and elsewhere. So yes, I see a shift -- it has not been as pronounced as I would have expected at this point in time, but it is continuing to move in that direction. And then your question about gas versus oil to TechnipFMC, we're somewhat agnostic.

Here's probably the biggest difference on it, let's just say, on a per unit cost gas is better for us. Gas equipment is -- tends to be much more demanding. The velocities that these wells -- the velocity of the gas flowing through our equipment is staggering for anyone to even imagine. And you always have to realize it, it's not just dry gas that comes out of the reservoir. And again, it could have some liquids. It could have some solids and at a very high velocity. It requires some very sophisticated equipment.

So I would say it really differentiates those who can and cannot provide that type of equipment. But over the life of the field of the project, I would say oil reservoirs tend to lead to more services activity. So it's a little bit of a trade-off and a bit of a wash over the life of the field, but probably more upfront in terms of the upfront capital cost when it's associated with the gas development on a per unit basis.

Right, right. Now that's a fantastic color, Doug. Then just a quick, I know Arun was talking about giving some breadcrumbs on SURF 2.0, which became iEPCI 2.0. I want to go back to that that line of thinking. I'm just trying to think from an operator perspective, Doug, because like you said, your aim is to reduce the cycle time, improve the economics of the deepwater projects, and that's how everybody succeeds, right? So if I think about it from an operator perspective, as you partner with them, -- what are they trying to solve for in your effort to industrialize the water column, the installation part of it, what is the biggest pain point? And what would they love for you to do? And how will it benefit there?

Quite simply, the relentless pursuit of the reduction of cycle time. It gives them certainty. It allows them to do more projects. And at an ever-improving economic rate because of their project returns improve because of the accelerated time to first oil. And obviously, all of those things benefit TechnipFMC as well.

We have reached the end of the question-and-answer session. I will now turn the call back to Matthew Seinsheimer for closing remarks.

This concludes today's conference call. A replay will be available on our website beginning at approximately 3:00 p.m. New York. If you have any further questions, please feel free to reach out to the Investor Relations team. Thank you for joining us.

Lauren, you may now end the call.

This concludes today's call. Thank you for attending. You may now disconnect.

All right. Nice crowd. Welcome to day 2 of our 11th Annual Energy Conference at JPMorgan. Delighted to have TechnipFMC, Doug Pferdehirt, who's the CEO, to present. I think we were discussing last night, FMC has been at all 11 of our conferences. So thank you for your continued support of the conference.

Well, thank you, Arun. Thank you to JPMorgan for having us, and thank you to everybody in the room and those that are attending via the webcast.

Yes. Doug, before we begin, I was wondering if you could just give the generalists in the audience today, just a quick snapshot of the company and what you do within the energy services landscape.

I'll do my best, Arun. It's hard to do it. And in short -- if you really look at the history, I think it'd make a great Netflix miniseries one day. But in the shortest way possible we brought certainty back into offshore projects, which is giving our clients greater and greater confidence in moving forward in FID-ing investments in the offshore.

We're doing this in a period coupled with new technology that we're bringing as well as a new commercial model that we're bringing into the market, which is allowing us to drive down the breakevens offshore while breakevens are increasing in other areas where our clients could be making an investment.

As a result of this, we see ever-increasing capital flows moving into the offshore domain, which is growing the market at a time that's very favorable to TechnipFMC given the uniqueness of our offering and the changes in the competitive landscape that are very favorable to our company.

Great. Doug, you mentioned a little bit about offshore being a bright spot within the global spending picture. We're seeing a lot of deepwater FID activity across the U.S. Gulf, Brazil, West Africa. How would you characterize the current offshore spending environment as we move through the year? And what is the setup as you think about the back half of the decade?

Sure. So look, the market has been growing for some period of time. If you just look at it over the last 2 years, we publish on a quarterly basis, the outlook for the offshore subsea developments those projects that are likely FID within the next 24 months. So it's a 2-year look ahead. That data set has grown 30% over the last 2 years. As we sit here today, we're actually seeing a further inflection in the growth rate 2027, beyond -- through and beyond the end of the decade. So I would call it robust today but growing.

Great. And could you highlight what you're seeing in some of the emerging basins beyond, call it, the Golden Triangle, places like Guyana, Suriname, Namibia, Mozambique, and trying to paint the picture of the deepwater market, not just kind of concentrated in the Golden Triangle.

Sure. And it's an important question because earlier, you were asking about growth through the end of the decade. All the growth that I've referenced thus far is really coming from the Golden Triangle or the traditional offshore oil and gas basins around the world. So it really hasn't been supported by the growth of some of those emerging basins on top of that. So as we look forward through the end of the decade and beyond, is really where we start to see the contribution in a meaningful way from some of those emerging markets as well.

Keep in mind, we have seen progress in Suriname where Total Energy did sanction the first project there, GranMorgu, which we are performing for them under our iEPCI model with Subsea 2.0. So we're very excited about that. We do -- we are tendering in Namibia today. So we do anticipate the potential for an FID this year, certainly next year, if not this year.

Guyana, I still think, as an emerging basin and even though what ExxonMobil there has done is exemplary. It's never been done before in a very short period of time in 1 decade, they took a country that was not producing to over 1 million barrels a day now on the pathway to 2 million barrels a day. It's just been astonishing. We're honored to be ExxonMobil's exclusive partner, and we performed all of the work for them in Guyana.

So Mozambique, we're performing projects there for both ENI as well as for TotalEnergies. Mozambique is very interesting being it's a gas market and the access to the Asia Pacific market for the gas. So the emerging markets are contributing, but they'll contribute an even greater portion as we move towards the end of the decade. And there's a few we didn't even talk about beyond that list, and I think we'll start to hear about in 2030 and beyond.

Yes, maybe Indonesia is a place that we've been hearing some things about, correct?

Indonesia has been quite active. There will be other activity, I believe, in East Africa. There will be other activity in Asia, and there will be other activity in South America that we haven't even talked about.

Doug, we had one of the biggest supply shocks since the 1970s. You liaise with a lot of your customers, a lot of NOCs, a lot of large majors, independents, what has been the reaction from your customers? And how does this -- how do you think this influence deepwater activity?

So before the war, there was already this shift, as I referenced in my opening remarks, the shift was already underway. Certainly, as a result of this, there are several different dynamics at play here, the buyers or the consumer. So let's just be specific and say maybe the Asian countries, they themselves are looking for alternative supplies. When they're looking for alternative supplies to maybe not be so leveraged on any 1 particular region, they're typically going to other producing countries, most of which are producing from offshore.

So clearly, when we speak to our clients, they're getting interest in contracts now from buyers, other countries for their commodity. So they're looking at potentially increasing their capital expenditures in their offshore projects to be able to feed that -- I'm going to call it an increased demand. It doesn't mean that the global demand is being increased. It means that the selection of that it's really diversifying their supply into other regions, which will largely be driven by offshore.

The other thing that we're seeing is individual countries themselves, looking at their own oil and gas reserves. And what could they do to strengthen their independence, maybe not to be truly energy independent, but to be able to at least have a greater local supply within their own control. So when you speak of Indonesia earlier, clearly, we're seeing an increased demand in the country like Indonesia. So there's a few different dynamics at play.

And then I would say just for our global customers, they're looking at their portfolios and they're looking at kind of risk tolerance for different regions for different activities. And perhaps that could also result in them diversifying some of their spend from one region to multiple regions as a result of what we've all just experienced.

Let's talk a little bit about Azul and on the company, the inbound order trends, FTI has consistently been delivering call it, $10 billion per annum of inbound Subsea orders. You mentioned that your Subsea opportunity list is up 30% or last couple of years or so. And perhaps there may be an inflection point in orders as we think about 2027. Could you maybe elaborate on what you're seeing on the inbound order front?

Well, you back me into the corner, Arun. I have no choice but to confirm that we would also expect to see an inflection in our order rate in 2027. Clearly, just given the strength of the market, the increasing size of the market, our position within the market, our unique offering and our forward visibility that is quite unique with our customers.

Keep in mind, we are also the offshore architects. So we start at the architectural phase, then we go through the manufacturing, the delivery, the installation, the commissioning. And then we have a long life of field services contract, typically 20 to 30 years, OEM-type model, associated with the services over the life of field of that project. So if you add all that up, we're typically involved in the project for 30 to 40 years from inception all the way through the finalization of the economic production from that reservoir.

So because of that, we have a seat at the table very, very early, and it gives us a great degree of visibility into likely FIDs and decisions that are being made. Because of the uniqueness of the offering which we call iEPCI or an integrated project, where we do everything from, again, architect to life of field services.

Our ability to be able to do that also leads to a lot of direct awards, meaning awards that never go out to a competitive tender. That is a unique visibility that we have into the market and a high degree of certainty because we're working together with the clients to make those projects economical.

So when you add all of that up and that visibility that direct awards and the unique positioning that we have along with the growth of the market and an ever-increasing competitive landscape, it puts us in a position where we can say with confidence that we expect an inflection in our inbound order rate in 2027, above the $10 billion run rate that we have reconfirmed for this year.

Doug, you mentioned something last night that I found interesting is that when you became CEO, you felt as though your biggest competitor was U.S. shale in terms of the cost curve. And can you talk about how Subsea projects were done 10 years ago versus the industrialization you've pushed into the segment and talk a little bit about your Subsea 2.0 offering.

Sure. Often, we get I'm very competitive. Our company is very competitive. And often you get focused on another company, and you lose sight of what's really meaningful. What's really meaningful is the capital flows and the confidence in the offshore market. And we had lost that over a decade ago, the performance of our company as well as all the other companies in the sectors was poor if we're just being very blunt and very honest.

Poor, meaning we typically delivered projects 1 year late. Not 1 day, not 1 month, not 1 quarter, 1 year late, which would destroy the project economics for our customers. This was offset by a very high commodity price, but it also meant that the breakevens offshore were approaching $80 a barrel. $80 a barrel. At that point in time, Arun, we reflected within our company and realized that this was not a sustainable path. An ever increasing commodity price is not a good strategy for our company. So we decided we need to focus on what really was wrong with the industry, what we could humbly do to try to influence a different outcome and build a very different company as a result of that.

So that started on the innovation side, where we looked at the way that we were delivering projects over a decade ago. And our customers were telling us what to build, exactly what to build. So they were giving us specifications that were unique on every single project. So we never had a repeat order even from the same client. So from client Project A to their same client project B, they would have a completely different set of specifications. This led to -- or this leads to a very inefficient process and a very fragmented supply chain. These things would ultimately end up in waste, rework, cost overruns, delays on projects and would affect the overall project economics. So at that point, we sat back and we said, "how could we do this differently?" And we didn't come up with it on our own. We just looked at other industries.

And the industry that you would think is far away from what we do for a living, but we were quite enamored by the way that they were working their process was the automotive industry. So we started working closely with Toyota in the Lean Institute and started to try to figure out how did they take a process that was engineered to order or the specifications were unique and differentiated to something that was incredibly efficient. And the answer was we needed to move from an ETO world, engineered to order to a CTO world, configured to order.

So today, when you go on and you order your automobile from whomever you prefer, you don't get to tell them how to make the engine. You don't get to tell them what alloy to use in the frame. This is what our customers were doing. It wasn't adding any value, but this is how they were approaching the market. And we were -- it was the way the industry operated. It wasn't our client's fault. We enabled this. So what the automotive industry does now is you have a set of drop-down menus. In the end, they deliver you an automobile. It feels like they made that automobile just for you. In reality, they've made 1,000 or 10,000 of that configuration. But more importantly, when you hit order, they don't have to do any engineering. There's no first article. It goes straight into assembly and test.

So if you put that into the context of our business, where we have come up with what we call Subsea 2.0 which is this configurable architecture on the seabed, our customers now work from an iPad. They work from an app. Within the app, there's a set of drop-down menus. Instead of saying 2 doors or 4 doors or automatic or manual transmission, it says 5,000, 10,000, 15,000 or 20,000 psi, 250, 300, 350 or 400 degrees fahrenheit. But it puts those functional requirements that they need, which then go into a configurator and outcomes, the type of equipment that they need.

At the moment they order that equipment, it goes straight into our assembly and test, which reduces 9 to 12 months of detailed engineering because if you change 1 spec, if you just want to change 1 thing by -- phase it by 12 degrees different than the last piece of equipment, it's 9 to 12 months of engineering because you have to go back through every single line item before you can start the machining or the manufacturing of the equipment. So this has really allowed us to shrink the cycle time which is critically important to improving the offshore project economics and bringing greater certainty to the outcome.

So that's really what Subsea 2.0 is all about. It's been hugely successful. The market has embraced Subsea 2.0 in a meaningful way, and it continues to provide great value to our customers through reduction of cycle time and great value through us through greater efficiencies within our organization.

Doug, can you talk a little bit about -- so that's the subsea or the equipment piece, what are you doing in terms of providing solutions when you give an integrated project or your iEPCI kind of framework?

Yes. Thank you for asking. So first, we needed to address the architecture, which was Subsea 2.0. After we did that, we sat back and we said, is this enough? And it was meaningful, and it was certainly going to improve the economics. But what we realized was at the time customers would have somebody build the equipment and somebody do the installation and the connection of the equipment.

So the equipment sits on the seabed. It's typically -- it could go back to shore, but it's typically connected up to something that's floating on the top of the water, most likely -- or most of the time, it's called an FPSO. But it's something that is floating on the top of the water. But everything on the seabed needs to be connected back up to that object through the water column, which, keep in mind, could be hundreds of feet to 2 miles deep in the water column. We work really, really deep on the bottom of the ocean. So that has to be connected with pipes for the fluid to flow through. It has to be provided electricity through cables. It has to have telemetry through fiber optics, down lines or chemical injection lines. It's a very complicated system to support that equipment on the seabed.

Remember how deep we are on the seabed. This is all with advanced electronics. This is designed for a 20 to 30 year life. So you're putting high-end automation and control and robotics on the sea floor in a saline environment, to work for 20 to 30 years. This is really high-end automation and control technology that we have within -- and competency that we have within our company. So when we did -- when we looked at it, we realized that if we brought those 2 together, -- and our customers no longer bid those as separate work packages, there were things we could do to integrate those connections -- again, fiber optics, power cables, chemical downlines, flow lines to connect to that equipment back up to the surface as well as the way that we would install all of that onto the seabed and into the water column.

That led to the concept of the iEPCI or the integrated offering that led to the merger of FMC Technologies with Technip creating TechnipFMC to remove the redundancy to remove those unnecessary interfaces. On an average project, if you do it in an integrated way, you will remove 30% of the hardware required by removing unnecessary interfaces. We don't have time to get into all that, but it's a meaningful number.

We're putting massive amounts of equipment on the seabed to be able to remove 30% of that, and to be able to do that in a much more efficient way is why our customers are also embracing the iEPCI. So if you put the combination of the integrated offering, which is unique to our company, with the architecture, the Subsea 2.0, which is unique to our company, it's why we've had the tremendous success and customer acceptance that we've had in the market.

And how do you quantify that? 80%, 8-0, 80% of our business is direct awarded to our company. It never goes out to a competitive tender because our customers see the value, and we are in a situation where our customers win while we can win. We're not in the typical relationship where there's a winner and a loser, either the customer or the supplier based on supply and demand. We have a very different way that we treat our customers. We ensure that our customers are winning every day, and that's through the relentless pursuit of reduction of cycle time.

Every hour, every day, every month that we save on cycle time and accelerate time to first oil, dramatically improves their offshore project returns. And we deliver these projects with 100% certainty, 100% certainty on time, on budget every time. Meanwhile, we're able to benefit because, again, we're getting those greater internal efficiencies. We're reducing that 9 to 12 months of required engineering and we're able to drive much greater operating performance within our company.

In a typical Subsea 2.0 versus a typical 1.0, we can move 2 to 2.5x the volume through the same roof line in a 2.0 world than in a 1.0 world. We're not stopping and starting, building something for the first time. We really now have achieved flow. We're not done because I know that sounds like we've accomplished a lot, and perhaps we're at the end of the story. It's important to recognize we're not done. What we have done so far is only about 1/3 of the overall equipment and the overall installation activity that we do as a combined IECI project.

So think about everything we've just said and the benefits that we've received from that differentiation, we're only 1/3 of the way done. We have 2/3 left to do, which we're actively working on today to get an overall system that will be even shorter cycle time than what we can do today.

Yes. Could you maybe elaborate? Because we've highlighted as the next big catalyst for the stock is the industrialization of, call it, the installation process. We've -- I think the market is calling it SURF 2.0 and maybe give us a sense and maybe give some breadcrumbs on how that process is going?

Sure. So this nomenclature SURF, which is subsea Umbilical Risers and Flowlines, it's kind of old nomenclature the way the industry used to look at the equipment on the sea floor was considered SPS, subsea production systems. The water column and the installation, or the vessels, was considered SURF or Subsea Umbilical Risers and Flowlines. We destroyed that by putting it together and calling it iEPCI, right? But it's fair that the industry still sometimes thinks about SPS and SURF.

Everything that I talked about in terms of the Subsea 2.0, the industrialization or the configure to order the automotive model, we've only applied to the seafloor so far. So as part of the merger, we got the capability of the water column umbilical riser flow lines, flexible pipe as well as the installation capability. That's what we're working on now. That's the remaining 2/3.

We have done -- we have made tremendous progress going through a very disciplined approach, learning from how we performed on the Subsea 2.0 seafloor to look at the rest of this 2/3 and what we can do differently. I will tell you, it is dramatic. It will be game changing, not only for ourselves but for the industry. But I'm going to stop there. Arun, I'd like to go further, but we are deep, deep, deep into the concept select. We are deep into really proving out some of these concepts and the impact that some of these concepts will have I will personally though, I will tell you, I am extremely motivated and extremely excited and believe the impact of what we have left to do will be greater than what we've done so far.

More importantly, our customers believe that, and our customers want that. And that's what's going to continue to drive down the breakeven in the offshore, continue to make it more and more attractive and continue to drive more capital flows offshore.

Great. We have ExxonMobil, who's going to follow you. So that's a big customer as well.

A customer, we're honored to be partner with.

Great. Let's shift a little bit to financials a little bit. You've guided to $9.4 billion of Subsea revenue, 21.5% EBITDA margins, not going to ask you about the quarter, but just generally how are things kind of progressing from an execution standpoint and your belief in terms of continuation of margin growth as the cycle continues?

So speaking of the -- so the Subsea guidance for 2026, as is being referenced by Arun, I'll just be brief. We're going to deliver. As we look forward beyond 2026, already back in February, February of 2026, we already made the statement. I'll reaffirm it today with an even greater level of confidence. We're going to deliver growth in inbound. We're going to deliver growth in revenue. We're going to -- and deliver growth in EBITDA in 2027. So we're a backlog company. We have great visibility. We have an ever-improving quality in our backlog. And I can say with a high degree of confidence, we will continue to grow into 2027 as well.

Great. Doug, one of the favorable things about the business model is you spit off a lot of free cash flow from the business. You have a net cash position at $540 million. Your EBITDA, the free cash flow conversion has been very, very strong, I think, 65% or so. How do you think about the right level of cash to manage your business. We're a bank. We don't want you to get too much cash to start competing with us, but how are you thinking about the right balance sheet leverage of the company? And maybe comment a little bit on your cash return framework.

Sure. And look, thank you for asking. It's starting to be somewhat taken for granted. But if you look at the work that we have done to improve the balance sheet and liquidity of the company, at the same time as all these other innovative things that we're talking about, mergers, et cetera, we're super proud of where we are. We are financially extremely strong. As you mentioned, we're in a net cash position. We don't have any debt really coming due until quite a few years out, and we have obviously the capacity to take that out. It's a small amount of debt. So in a very strong position.

We continue -- like everything we do at the company to look for ways to optimize the performance of the company. That includes cash generation, and that also includes the way that we use that cash. What's really important when you think about the cash generation of the company from everything that we just said, growing inbound, growing backlog, growing revenue, growing EBITDA margin and EBITDA is obviously going to generate more and more cash. The question is, are we going to be good stewards of that. And I hope we've demonstrated that. And I sit here today and can reconfirm that.

We are not a conglomerate. We are a pure play. We don't just buy things for the sake of size or bolt-on acquisitions. We are very focused in what we do. Our M&A landscape has no white space. We've done the big strategic moves that were required. We continue to invest in technology, particularly around material sciences and automation and control, and we will continue to do so. But nothing that is going to be a huge generator or a huge use of that cash. And internally, we're growing the company at a level of CapEx that only requires about 3.5% to 4.5% of revenue, and we're typically on the low end of that and growing the company.

How are we able to do that? We're able to do that through this drive this relentless pursuit of reduction of cycle time. We talk about how it helps our customers. That's most important to us. But it also helps us because if I take 9 to 12 months off of the engineering required on a project, I have 9 to 12 months more capacity in engineering to do other things. If I can do 2.5x through the throughput of my manufacturing facility, I don't have to spend any additional capital to grow the company to build more manufacturing.

And it's this way of thinking differently, which is not the way things have traditionally been done in our industry. Traditionally, if you were in growth mode, you spend capital, you spend, spend, spend, then you overspend, then maybe you don't have the level of activity and there goes your returns. We are a returns-focused company. We're very proud of what we've been able to do. Our ROIC is achieving levels that have not been achieved historically, and we have a pathway to continue to drive those even higher being very good stewards of the way that we use the cash within the company.

And finally, because I just -- the clock just hit 0, 0, 0. It's important to understand with the cash that goes beyond that, we are delighted to return to our shareholders and we have done that in a meaningful way. Over 70% of that free cash flow generated.

Great. Doug, we're out of time. Thank you so much.

Thank you. Thank you all.

So let's start. Good morning, everybody. Thank you very much for being here. So welcome at the SDC conference. I would like also to thank you very much, Doug for the heart, Chairman and CEO of TechnipFMC to be here. It is a great honor to have you on the scene, Doug. Thank you very much. And maybe on a more personal way, I would say it's also a big pleasure to have you. Doug and I have been knowing each other for now 11 years. So it come back to 2016, 2017, the Technip, FMC merger.

At that time, you were Chief Operating Officer of legacy FMC Technologies. And maybe at the time of the merger, where you're asking yourself like at some stage, charges the goal. how can I run a company in a country with as many as 246 different types of cheese. It's a good question. Years after years, there have been ups and downs. -- but the vision became reality, and TechnipFMC started to massively outperform the sector starting in H2 2022. So the -- I would say the skeleton of this discussion is going to be very simple. The past -- in fact, the past, it will be a little bit of a present the present and the future. Now let's start.

Also, 1 point, if you want to raise some questions, there is a crude and all the questions should pop up on my iPad. This is a theory, but my friend and colleague, Bob Racket told me that it is working. So I think it is the case. So Doug, thank you very much. So let's start by the past. And when I'm saying the past -- how do you view the current cycle compared to the previous ones in plural, how do you view it on Berry to the 2005 2013 cycle, what are the differences? Are there some common features what has most surprised due in this current up cycle.

Thank you. Thank you, Gil. Thanks to Bernstein for having Technip to be part of the conference. Thanks to the many familiar faces and some new faces in the audience here today. We appreciate you being here. And to those on the webcast, thank you for dialing in. So I got to go back to the Dogan quote. It's tough to follow a quote like that. I didn't know we were going to be talking about cheese. And I'm not sure that Dugald have been excited about the approach that we took. So we took the 250-odd different cheeses and made them into a single configure-to-order product line.

Our cheese manufacturing would have been very different in the end, and I'm not sure my French friends would have approved of it, but a very unique approach and somewhat of a fitting quote considering the challenge that we had at the time. So let's talk about that cycle. And you'll hear me say this a lot. We are in the midst of as a structural change -- and part of it being a cycle is becoming, I think, less and less obvious. And I think more people are beginning to really realize there is a structural change going on, a structural change, not just in power demand, but a structural will change, particularly in the offshore power generation.

And that's what is -- it's really starting with the offshore, which is where we're seeing the benefit of that. But if I compare the 2, honestly, they couldn't be more different. There's far more differences than similarities between the 2. And if I had to just pick a couple of examples, we could talk about the fact that in that cycle, '05 to '13, '14, companies like ourselves were winning and our clients were losing. That is not sustainable. That is what leads to a cyclical business.

So we made a decision that was not obvious at the time, which was we were going to create an environment to which we could win, whilst our customers could win simultaneously. Now when you go back to the last cycle, the challenge of doing that was item #2. The industry had a fixed asset mentality, a fixed asset mentality, which meant supply and demand, which meant cyclicality.

We induced the cyclicality because as thinking about our businesses as fixed asset businesses, we would raise prices, raise day rates, raise costs as a result of an improved environment, i.e., demand when demand outstrips supply, and we would "take advantage of that scenario. Well, I learned early on in my career, your customer is always smarter than you, and no customer is going to allow that to perpetuate very long.

So very quickly, they'll swing that around by reducing demand, which puts the pricing leverage back on their side of the table. So point number two, the structure of the business just was not able to deal with that. And then the third really fundamental change that's occurred between the last period of time. I'm going to -- I don't like the word cycle, obviously, the last period of time and now is the competitive landscape. It is completely different. We didn't exist, we did not exist in the last cycle. Now let me be clear, Technip as a stand-alone company existed, FMC Technologies as a stand-alone company existed, but Technip FMC did not exist. So think about that.

So those are some really major changes that truly differentiate what we're experiencing today from the past. The fourth and final aspect that was a major change was the attractiveness of the capital to flow to -- for our customers to flow their capital to different areas. And if I go back to that period of time, the challenge really wasn't the offshore environment.

It was the fact that the U.S. shale was attracting the capital because the U.S. shale was presumed to have better economics and certainly had better predictability. So in that past period, because of those kind of aspects that I just pointed out, offshore projects were high risk. Offshore projects had a lot of uncertainty. And because of that, when our customers had an opportunity to flow their capital investment to another what appeared to be more attractive investment for them, it flowed to the U.S. onshore.

So around that period of time, we had a bit of a breakthrough moment where we realized our competitor was not another public company or a private company. Our competitor was simply the access to capital. So we had to make offshore attractive again. We need to make offshore economic again, and we needed to make the offshore -- put the confidence back in by bringing the certainty of the outcome back into the offshore -- that led to several changes in the company, which we can get into, if we would like.

And -- well, first of all, the creation of TechnipFMC, the investment and changing the way of what we do and how we do it, which has allowed us now to be in a scenario where we attack cycle time every single day. We call it the relentless pursuit of cycle time. So we have taken the offshore economics and improve them substantially by reducing cycle time. We have brought certainty back into the offshore projects, meaning it's delivering them on time, on budget. So now the economics offshore have improved dramatically, while the economics in the U.S. unconventionals continue to be quite challenged.

And as a result of that, the capital flowing to the offshore, we're benefiting from that differentially because of what we have created is unique in a very different competitive landscape than we had during that last period. So that's just a little bit of the overarching story behind it, and then we can get into the elements, if you would like.

So globally, maybe to put further color to what you just said. Let's go back to June 2014 just before the oil price crashed. At that time, the breakeven price for deepwater oil was circa $65, $70, probably more or less the same for U.S. shale oil. And basically, the breakeven price for deepwater projects went from $65, $70 per barrel in June 2014 to below $35 now. .

So the question, which obviously comes to my mind, is in this dramatic decline in this breakeven price. A big part comes from yourself, possibly as well from, I would say, from the fact that reservoir deep offshore reservoir were very prolific. Is it possible maybe to strike a balance between, I would say, general mature nature and what you bring to your customers?

So let me start with, I'm a reservoir engineer. So I love mother nature, and I love that Mother Nature put a lot of the hydrocarbon offshore. That's just the fact. The most prolific reservoirs other than the Middle East are offshore, period full stop, by any definition, permeability, porosity, Dorsey's law, you can follow anything you want to follow, oil in place, barrels in place, the -- it is just fundamentally better than other areas of, again, of investment for our clients.

So when you think about the equation dollars per barrel, it's never been about the denominator. It's never been about the barrels. Go back to what I said earlier. It's been about the cost of extracting those and the certainty of that investment. So back in that period in 2014, there was actually a report that was published. That said offshore projects were being delivered on average on average of 1 year late and on average of 100% above budgetary costs. That's not sustainable.

As again, as I said earlier, our customers are always smarter than us. That's the right approach to take in business. So they recognize that. So we were in a period where their offshore project economics were deteriorating because of execution and performance, whilst the providers on the service side, things are great. They thought things were great because they were seeing backlog, they were seeing backlog growth, revenue growth, margin growth. But in reality, they were setting themselves up to fail. And I was part of that. I'm taking responsibility for that.

So somebody had to do something different. We chose to be at somebody. There was no certainty that it was going to be successful, but we decided to radically change the way offshore would be developed in the future. That started by taking an equipment manufacturing company, FMC Technologies and merging with an installation company, Technip, had never been done before.

Our customers always bought the equipment from someone and had someone else install that equipment. And they sat in between and manage that interface, which often led to most of the delays these projects that were being delivered on average of a year late was largely due to that interface. -- because there's a lot of synergies and there is a lot of value between he or she who makes it and he or she who installs it, if they have aligned interest.

In a non-integrated project, there is no aligned interest. It's actually the opposite. You make more money by causing hardship and hard ache on the other provider, which the client gets punished by in the form of variation orders. So what we said is, look, let's be the adult in the room someone needs to change the game.

So we created TechnipFMC with the idea that our clients could now through a single contract work with the architect because 2 years before that project ever is discussed publicly or Cs FID, we're designing the architecture. So you can work with 1 company to go from the architectural phase, through the equipment manufacturing phase through the installation commissioning on the seabed and very importantly, through a life of field service contract, which is an OEM model that is typically a 20- to 30-year service contract, one provider. That's the decision we made.

That's what led to the creation of TechnipFMC on the 17th of January 2017. And here we are almost a decade later, as you pointed out earlier, still as the only integrated offshore provider, creating a very unique scenario for us and probably the one statistic that I would ask you to remember that really creates the investment opportunity for you, which is 80% of our business is direct awarded to our company never goes to a competitive tender.

Because as I said earlier, we have created a scenario where our customer wins at the same time that we can win. So we do that by that relentless pursuit of the reduction of cycle time we have taken up to 1 year off of a 3-year project for a big new development for an existing development where we're just adding additional infrastructure. What used to take 26 months, we can do in 14 months. You can call us, we can do the architecture design, we can manufacture, we can install, we can commission, and we can have it producing within 14 months on the seabed.

That is a huge benefit to our clients, cause of the quality of the reserves, not only in terms of the production, but also in booking those reserves, which is important when they talk to you in the investment community as how they are sustaining the growth of their company by identifying and booking additional reserves. So that's kind of how this has all played out. It's dramatically different than it had been in the past.

As long as we continue to focus on the relentless pursuit of reduction of cycle time, as long as we continue to make those economics much more attractive offshore, the capital will continue to flow. And we've seen that. The point that -- the one data point maybe that you didn't mention, Guillaume, is the breakeven cost in the U.S. unconventionals has gone up, has almost done the opposite. It's gone from the $30s to the $70s, whereas we've gone from the $70s to the $30s. And it is sustainable as long as a company like TechnipFMC continues to drive change, technology and innovation that will continue to reduce cycle time. And I am confident that we can continue to do so.

Thank you very much, Doug. So let's jump in the present. So in the current environment, so we understand that I would say the structural shift towards offshore continues and is going to continue, that the structural element. However, given the increase of the price of the commodity, there is likely to be, I would say, a short-term up cycle in North America, probably over the next 12 to 18 months.

How would you view those two first, the long -- I know you do not like cycles, but the long structural trend towards offshore and the short-term likely increase in U.S. insurance?

So it's a fair question, but let's just start with the facts. We have not seen that yet. Correct. But there's been a phenomenal environment from a regulatory perspective. There's been a lot of incentive for that to occur, and it hasn't occurred. So one must step back and say why. Now look, I'm not pro or anti anything. I obviously have a bias to the offshore, but we also operate and do work on land, and we do work in the Permian Basin and other places in North America. So it's not us versus them, but I just think we have to look at the facts. We have not seen that occur.

There is something very telling there. If you step back and you look at the environment for investment and the fact that the investment did not follow, I think, one must ask themselves why. Number two, I think you pointed out very -- I think in the way you asked the question lies the answer. I think if we see that, it will be cyclical, and it will be very short cycle.

So yes, I think that the U.S. unconventional becomes that short-cycle cyclical barrel, but the structural change is the offshore and will remain the offshore. And again, that has to do with everything we've talked about thus far. And the fact that if you're chasing reserves and if you're trying to add more proven undeveloped reserves to your balance sheet, those big barrels, thanks to mother nature, as you pointed out earlier, happened to be offshore and will continue to be offshore.

So let's continue with the present. So at the beginning of the year, early 2026, the outlook for offshore was very constructive and was about to reaccelerate probably in H2 2026. So question I would like to ask you, you mentioned during the previous earnings call that what we are saying in April 2026 was already true in February 2026. However, could we say, to a certain extent that the conflict is nonetheless going to translate in a new reacceleration, a stronger than previously expected reacceleration and or towards an even longer cycle when we look over the next 3 to 7 or 8 years ahead. .

So yes -- and yes, but it's not a cycle. It's a structural change, but it will continue to support that structural change. So yes and yes is the short answer. The -- we have seen this transfer of capital flows from the U.S. onshore to the offshore some time ago. We had experience that this buildup. We published what's called the Subsea opportunity outlook, it's every quarter, we publish that.

It's a view of projects that are likely to reach FID or the final investment decision within the next 24 months. That list has grown quarter on quarter on quarter, that list has grown 30% over the last 2 years. It is at a record level in terms of the size of that Subsea opportunity list, which is at $30 billion today and continues to have a lot of support.

So -- we have definitely seen that. And that was all pre the wars actually and certainly pre the Middle East conflict that we're now experiencing.

When we -- if I answer the question slightly differently, what has been the reaction to that? Yes, clients are looking at ways to accelerate their production particularly in regions that are more less impacted. Let me use that word, less impacted. And again, if you can take an offshore development and call us and have us do the architectural phase, the manufacturing phase, the installation phase, commissioning, producing on the seabed in 14 months, that's pretty attractive. And can be some pretty substantial reserves that can be booked to the balance sheet as well as production that can be converted into revenue for our clients.

So we're seeing quite a bit of that, and that normally occurs in the more mature regions where there's already a lot of infrastructure and a lot of subsea development. But we're also seeing more and more conversations around, let's just say, rebalancing their risk profile. Just as you and your companies have a Chief Investment Officer that looks at the risk of the portfolio, we have enterprise risk management, and we look at risk within the investments we make as a company. Our customers do the same thing.

So they now have to say if we're going to invest that capital in a region that may be less stable, we had rated it historically versus where we are today, that may shift some of that to other regions. And again, just because of where that energy source is, which is offshore as we've indicated here a few times, you could see that accelerating developments in the offshore areas outside the areas that are in conflict today.

So the transition is obvious among those new regions. I think there is a region which really starts to be on the spotlight. It is Africa. So Namibia is probably accelerating as I think Total Energies now wants to move quite quickly with Mopin project. So maybe we've talked about history. Let's talk a little bit about geography. What should we know on what are, I would say, the interesting moving parts according to you in Africa as of today. .

Okay. So I got to give a shout out to my friends in South America first because I think it's warranted and will continue to be a major driver and then we'll move to Africa, if you don't mind. So really, the last decade has been about South America, what has occurred in Brazil, not just by Petrobas, but by Petrobras and the IOCs is actually quite phenomenal.

And we can talk more about that. It's been a very interesting market for us. It's been -- it supported a lot of growth in the offshore. And again, it's Petrobras, but it's also companies like Equinor, Shell, Caron Energy and others who are really driving the developments in Brazil. Then when you look at the rest of South America, you cannot ignore the phenomenal success that ExxonMobil has had in Guyana. It is a story that will be talked about for years to come. It's substantial. It continues to just perform at an exemplary level.

We're honored and humbled to be their exclusive partner. We do 100% of Exxon's work for the subsea in Guyana, and they continue to move forward at just a record pace with greenfield development after greenfield development. A shout out to suriname, Total Energies what used to be Block 58 now called Gran Margo. We'll be doing that project as well. Again, that's another iEPCI 2.0 project. Very excited for the country of Suriname. It will be incredibly important for the for the people of Suriname and for the country of Suriname as they start to convert that into revenue as we have seen occurring in Guyana.

In addition, you have Colombia, you have Mexico and you potentially have Venezuela that is going to continue to make South America very, very attractive in the portfolio in the offshore world. If I do say what is the next big frontier, I would agree, Africa. Now it's important when we say that offshore subsea developments have been occurring in West Africa for many, many years. It's actually a very mature basin. When you think about places like Ghana, not Guyana. And when you talk about places like Nigeria, Angola, this has been a very mature basin. -- and will for quite some time.

But what we're seeing now is we're seeing customers go back and relook at their portfolios in Angola, Nigeria and Ghana and saying, okay, there's already existing infrastructure, can we do. Can we do some of these 14-month projects, as I mentioned earlier, what can we really do here differently than how we've approached in the past.

The national oil companies are being very constructive in their conversations with our clients as far as attracting investment back into those countries. And then you have the rest of Africa, which is really the emerging part of Africa, which, let's start on the east side. What is happening in Mozambique is profound.

People forget, we're already producing offshore gas in Mozambique. That's through E&I, who has now launched their second -- with their ongoing with their second project and talking about their third. Total energies with the Mozambique LNG project, again, an project for us, which is that integrated -- I'm sorry, that iEPCI or these integrated projects that we can do uniquely.

And then you move over and you look at places like the maybe Namibia and the Orange Basin, including South Africa. And as you mentioned, very exciting, not only for Total Energy, but also for others. And I think the opportunities there could be very rich as we continue to move forward. So indeed, Africa is an area that is very attractive in terms of offshore investment. We've been there a long time. We have well-established infrastructure in Ghana, Nigeria, Angola, we're launching and have launched infrastructure in Namibia, and then maybe we're active in Mozambique today.

Again, we've done the majority of the work in Mozambique. So it's very interesting. And there's other areas that we could see add to that portfolio. And it's interesting because it's a balance of oil and gas. You've got parts that is very heavily on oil and others that are very heavy on gas. So it actually is a unique balance, too, if you look at it from the continence point of view, and the gas tends to be on the eastern side, which tends to be closer to the end user assuming that gas is going to be converted to LNG, excuse me, and make its way to the Asian market.

Thank you very much. So before moving to the future, i.e. what TechnipFMC can do even better in the coming years and in order to try to be intellectually consistent. I'm going to read a question from the audience. So thank you for the writer of this question. So I'm quoting, it's always good to quote, it's good also. In a structural up cycle for offshore come, do you and the industry have sufficient capacity to deliver without significant oil service inflation and potential quality issue. Do you view -- are there any potential bottlenecks? .

It's a great question. And I think it's part of the story that I had left out. So I thank you to ever asked that question because it's an important part of the story. I said, we fundamentally changed what we do, but I didn't -- and then I said in how we do it, and I didn't really touch on the how. So this gives me the opportunity to touch on the how.

That question is 100% accurate, historically. That question is 100% accurate for anybody else who's working offshore because that's exactly what they're experiencing today. They're going to -- their capital costs are going to go up. They're going to have roofline. They're going to add vessels. They're going to add capacity. That will challenge the way that they do business, the quality of how they perform because we know in growth mode, that tends to negatively impact the quality of the work that's done, which then will deteriorate the offshore project economics, everything that I said at the beginning, we're trying to avoid.

So we had to change how we did business as well. So we have fundamentally changed the way that we operate our company and by utilizing first of all, the investment in technology, where we have gone from a configured -- I'm sorry, from an engineer to order. We were a bespoke manufacturing company. Our customer set the specifications for the equipment, new and different every single time. And then we built -- engineered and built that equipment.

That very much would lead to an inflationary environment because when that's the situation, there are no economies of scale. There is no leverage. You just take those requirements, you work on it, you make some mistakes. That's called waste in the lean world, you redo it, you try again, you deliver late, you deliver over budget, it repeat, repeat, repeat.

To avoid that, we invested heavily, and this is well over a decade ago from about 2013 to 2017 in changing our architecture. And when I talk about that, think about it, we're building small cities on the seabed, small cities on the seabed. And we looked at that architecture and we said, how could we do it differently? And we actually worked with the Lean Institute and with Toyota, and we adopted the lean principles of industrialization.

So we said we have to go from an engineer to order to a configure to order. So when you buy an automobile today from whomever your provider is, at least I want to believe they're building that vehicle just for me, and they're got a bunch of engineers doing drawings just for me. But the reality of it is even though they make you feel good because of those drop-down menus, they're doing 0 engineering. The engineering was done at the subcomponent level.

So they dictated the outcome by being able to take that thousands and tens of thousands of parts in a car, put those into these manageable elements call them subcomponents and then make those part of an ordering system that allows you to feel good about that you had choices, but it had no negative impact on them in terms of their delivery.

So we did the same thing for subsea equipment. Now it took a long time as I said, from about '14 to '17, and then we had to convince the customers to move in that direction. We call that Subsea 2.0. It is a configure to order subsea architecture. You can go on to your iPad as our customers do and order subsea equipment today from your iPad, series of drop-down menus.

So it's just profound difference. When that order is placed, it goes straight into assembly and test. We take out 9 to 12 months of engineering because every project was different in the past. Every product was different in the past that required 9 to 12 months of engineering before we could start to manufacture. We've eliminated that. Remember, I said we cut a year out of the schedule earlier. That's the secret.

But hard to do, easy to say, hard to do. Today, Subsea 2.0 represents the majority of our orders. We have never had a customer that has experienced Subsea 2.0 that has ever gone back to the old way of doing business. We are the only subsea provider of Subsea 2.0. Remember that other statistic, 80% of our work is direct awarded never goes out to a competitive tender. These are the reasons why, but we had to change the how and the way we work.

Now I want to -- since we're talking about the future, I also want to touch on the fact that there's a lot left in the tank. When we did all of that, what we're calling Subsea -- or what I just described as Subsea 2 point today, we did that before the merger with Technip. We did that from '14 to '17, we merged in 2017 and created TechnipFMC.

So when we originally worked, we only operated on the seabed. FMC Technologies only operated on the seabed. So we've done the Subsea 2.0 configure to order on the seabed, but now all of the umbilicals and the risers and the pipelines, everything that comes back up to the top of the water column, which is an enormous amount of additional opportunity for us is still able to be converted to configure to order from engineer to order.

Today, as we sit here, it is still engineer to order. So we're working on that now. And that is the big opportunity for us going forward is we will make that entire system configure to order, including the installation. So we've done the seabed, then there's the water call them, then there's the installation. So what we've said is we've only -- we're only 1/3 of the way there.

We have 2/3 left, which will allow us to continue to what, relentless pursued a reduction of cycle time, drive down cycle time, improve our economics, whilst our customer benefits because they're seeing shorter cycle time, which drives their project economics. It's not a pricing thing. It's not a pricing thing. And that's where fixed asset companies want to talk about pricing. It's not a pricing thing. We can benefit, but our customer benefits because of the relentless pursuit of reduction of cycle time, and we still have 2/3 of the way to go. So we're very excited.

When you envisage those next to come 2/3, you seem to be quite confident, meaning that you have identify the potential bottlenecks, the potential limitation, you have found technical or organizational answers to that.

You're trying to get me to give away the secret -- so what I -- look, what I can say -- well, let me start by saying I am 100% confident that the impact of the remainder will be as great as what we have already achieved. And again, if you look at what we've done and where we've come as a company, it's -- we're humble -- and I think it's recognized, but there is a lot left to be done. And again, this will continue to make offshore investment even more attractive, continue to grow the overall size of the market, continue to grow our our inbound, our backlog, our revenue and continue to allow us to have margin expansion as a result of that.

And we have that visibility. We're a unique company that we have that visibility because we're sitting on a approximately about a 2-year backlog as well. So we see that quality of that backlog continue to improve as a result of this.

Where we are in actually the technical solutions, I'm going to be careful here because there's a lot of work that's being done, but I am confident that we have some very viable technological solutions that are truly, truly revolutionary in the way that work will be done in the offshore going forward with the delivery of a reduction in cycle time without capital investment. This is the key. So then you start to look at indicators like ROIC, ROCE. You look at our balance sheet, you look at our net cash position, you start to say, wow.

So we have all understood that the strategy, which has been followed by TechnipFMC, is it still working? Integration is probably better, but how do you view this next to come potential merger? Could you provide us some -- with some colors about it? .

Sure. And no, it's not a -- it's a fair question. I don't hate the question. You're saying CEO. I mean, I think in life, be it for your family or for your company, you have to make decisions. The lack of making decisions, you're losing ground. You're falling backwards. So you have to make those decisions. You're not always going to make the right decision. And I think that's where you have to be humble and you have to just do what you believe is best.

And again, if you go back to the way we made the decisions we made, we put the customer first. If you put the customer first, the customer will reward you. We just talked about customers where we do 100% of their business. We have customers, large IOCs where we have done 100% of their business for over 30 years. We talked about the fact that 80% of our business is direct awarded and never goes out to a competitive tender. So we put the customer first.

Now that wasn't easy to do. because, again, back in that prior period of time when we were doing well you had to acknowledge that the way we were doing well was not helping the client. It was destroying their project economics, delivering late, delivering over budget. They had no certainty. Therefore, they shifted their investment to somewhere else.

We had to change that. And we've done that, and we've done that successfully. So when you look at strategic decisions that a company can make, there's to build it, there's to buy it and then there's do something radically different. And so you always hear a build versus buy. And what we're seeing now in the industry is a lot of buy, a lot of consolidation. And it's happening on the earn side and it's also happening on the services side.

That's okay. That's not something I subscribe to. I believe as a technology company, we have to be the one and really the stewards of the offshore and the stewards of the subsea, I believe we have a fundamental responsibility and almost a moral responsibility to do things differently. Now I'm going to repeat. We won't always get it right. But by doing that, we'll be able to drive substantial change. We'll be able to and create substantial value for our clients, for our employees and for our shareholders.

So all that you're seeing is a difference of philosophy, the traditional way of we'll let you buy and consolidate and leverage and that's that supply-demand kind of thinking. That is shorter cycle reward or the opposite whereas we're looking at doing things that are, again, going to set up for a very different long-term structural change. And I believe we're on the right path.

And more importantly, our clients have embraced this. Our clients have embraced Subsea 2.0, as I mentioned earlier, they've embraced the integrated model, the iEPCI. And the vast majority of our contracts are now IPCI 2.0 put together, and leads to these 80% direct awards. So we're going to continue to innovate. We're going to continue to work on the rest of the 2/3. We're going to continue to reduce cycle time. I talked about 26 to 14. We're not satisfied at 14 -- you start getting much below 14, you're now challenging cycle times of every other investment opportunity to have in their portfolio, including onshore.

Because you can drill onshore wells very quickly. But by the time you tie all them in because remember, it's not 1 well. You got to tie in 200 wells into a production facility, whereas in the offshore because of the production per well. It's just so substantially greater. It's -- we're very proud of the path we're on, and we're going to continue to stay focused. And by the way, I wish no ill will to others. And I hope that the result for them that they have a successful result as well because I truly just want to make sure that the offshore remains the most attractive investment opportunity for our clients.

There remains 4 minutes and 33 seconds. So if you have some further questions, please do not be shy. In the meantime, maybe I would say a more open question, if I may, so are there 1 or 2 messages you would like maybe to specifically highlight or which we haven't spoken, which you believe is important. .

Sure. I know I have a short period of time, but there are a couple of things we didn't get to touch on. I want to go back from the question from again thank you for that question. We have demonstrated the ability to grow this company without expanding the capital investment. We've demonstrated the ability to be able to grow this company because we are thinking and operating differently. The relentless pursuit of reduction of cycle time not only affects our customers, it affects us. If I can take 1 year off of a 3-year project, I've increased my capacity by 33%. So as simple as that.

So we don't have to build new stuff. We don't have to consolidate. It's not about more. It's about doing more with the same. And that's what's driving returns to levels that are extremely attractive to you as the investor. The other area that I also want to touch on is there is a lot to do beyond the traditional oil and gas market offshore. And we've talked a lot about that today. But there's a tremendous amount of opportunities.

Let's first start with the area of carbon transportation and storage. There's a lot of people who say are anti-fracking around the world. If you're anti-fracking you should be anti-C2 injection in your backyard. This belongs offshore. We're doing this now in the U.K., where we're taking carbon that is being sequestered, 145 kilometers offshore to be permanently and safely stored, 145 kilometers. That can only be done with all electric subsea technology.

And we're the only ones who can provide that, and we're doing that project today for BP called the Northern and Orange project. Another example would be in Brazil. Brazil has a very high CO2 content in the oil that they produce. Today, that's being produced to the surface to a floating production storage offloading facility that needs to be treated separated and reinjected. So you're being it all the way to the surface, allowing it to potentially be exposed to future greenhouse gas releases only to be reinjected in the reservoir.

We worked with Petrobras for 7 years. We have developed a technology that will allow us to separate the CU on the seabed. It will never see the environment. It will be separated on the seabed, reinjected on the seabed, which again is a huge benefit, not only from a greenhouse gas point of view, but also from allowing our customer to produce more of what they want, they value to the FPSO, which is the oil without having to bring the associated CO2.

Another area we continue to be believers in is offshore floating wind, not fixed bottom that is economically challenged, but offshore floating wind. It's time will come, we are very proud. We've invested and developed a technology for a high-voltage dynamic in our rate cable. It is the highest quality specification power cable that exists today.

We're able to do that because as a subsea company, we're used to things moving around, so we understand dynamic versus static. And we have partnered with Prismen, who's the leading provider of ocean bottom electric cables, and we'll be bringing to the market an integrated approach like we have in oil and gas, which will be iEPCI or an integrated project for offshore floating wind.

But you'll be able to -- today, it's 40 different contractors, we'll be able to take that package from the water column down, somebody else will make the turbine, we'll do the rest. We will take it from the mooring systems, the power cables, the communication and the long-term service contract associated with that into the offshore floating market.

And the final thing that I'll say because I know we're running out of time, is the seabed is 70% of the world's surface areas covered by water. We all know that. We learned that in school. But people don't really think the inverse of that means 70% of the world's surface is underwater. We like underwater. We understand how to live and how to work and how to breathe and how to do things underwater.

We work on the seabed 2 miles deep in the ocean. Everything is advanced automation, robotics and control. We often don't get thought of as that type of a company. We put things on the seabed that are designed to last as the equivalent of with Nasaputs on the moon or on Mars. So if you really think about what we're doing, it's quite phenomenal. And I think I'm going to run out of time.

Thank you very much to all of you. Thank you very much, Doug. So we spoke about Most, I would like to conclude and maybe some of you are going to smile with a quote from Mother Teresa, yesterday is good, tomorrow has not yet come. We have only today. So let's begin. Thank you very much. .

Hello, and thank you for standing by. My name is Regina, and I will be your conference operator today. At this time, I would like to welcome everyone to the TechnipFMC First Quarter 2026 Earnings Conference Call. [Operator Instructions]

I would now like to turn the conference over to Matt Seinsheimer, Senior Vice President of Investor Relations and Corporate Development. Please go ahead.

Thank you, Regina. Good morning and good afternoon, and welcome to TechnipFMC's First Quarter 2026 Earnings Conference Call. Our news release and financial statements issued earlier today can be found on our website.

I'd like to caution you with respect to any forward-looking statements made during this call. Although these forward-looking statements are based on our current expectations, beliefs and assumptions regarding future developments and business conditions, they are subject to certain risks and uncertainties that could cause actual results to differ materially from those expressed in or implied by these statements.

Known material factors that could cause our actual results to differ from our projected results are described in our most recent 10-K, most recent 10-Q and other periodic filings with the U.S. Securities and Exchange Commission. We wish to caution you not to place undue reliance on any forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any of our forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise.

I will now turn the call over to Doug Pferdehirt, TechnipFMC's Chair and Chief Executive Officer.

Thank you, Matt. Good morning and good afternoon. Thank you for participating in our first quarter earnings call.

Our quarterly results reflect strong operational performance throughout the company, driven by solid execution. Total company revenue in the period was $2.5 billion. Adjusted EBITDA was $453 million with a margin of 18.2% when excluding foreign exchange. Free cash flow was $277 million with total shareholder distributions of $285 million in the quarter. This early momentum positions us well to achieve our full year financial targets.

Turning to Subsea. Orders in the quarter were $1.9 billion, driven by robust services and unannounced project activity. Our inbound highlights the importance of strong and enduring customer relationships as we continue to benefit from a high level of direct awards to our company. Importantly, we see a strengthening trend in order activity as we move through the year, supporting our confidence in achieving $10 billion of Subsea orders in 2026.

Turning to the Middle East. Our thoughts are first and foremost with the people who have been affected. The well-being of our employees and their families is paramount. We took immediate and comprehensive measures to ensure the safety of our teams in the region. We were able to operate safely with minimal disruption. As a reminder, only 4% of our revenue is derived from the Middle East. This is almost entirely related to work we execute through onshore activities within our Surface Technologies segment. Our offshore operations in Subsea have not been impacted.

Even before the conflict, the queue of potential deepwater projects had been expanding over the last 5 years. The significant impacts to both security and energy supply resulting from the conflict are likely to have lasting impacts on the perceived risk assigned to the region. We believe this builds further momentum in the ongoing shift in capital flows toward offshore developments with the potential to accelerate opportunities in markets with extensive infrastructure, including the U.S. Gulf and the North Sea in regions with previously discovered and well identified resources that can add material volumes to an operator's reserve base such as West Africa.

Our Subsea opportunities list highlights several of these opportunities. With our quarterly update, the list now identifies approximately $30 billion of opportunities for potential award over the next 24 months, representing the seventh consecutive quarterly increase in value. Over the last 2 years, this list has grown by more than 30% when using the midpoint of project values. While all global regions have experienced growth during this time, the most significant increases have come from Africa, Asia Pacific and the North Sea. The average project size has expanded to nearly $800 million driven by more than doubling our potential developments over $1 billion versus just 2 years ago.

Additionally, this list now includes 22 distinct clients, which speaks to our expanding customer base. This trend has been supported by our unique capabilities an integrated execution as demonstrated by our proven iEPCI model. Looking ahead, we believe there will be a step-up in inbound orders in 2027 and extending through the end of the decade. Importantly, this growth will be supported by iEPCI, Subsea 2.0 and Subsea Services, much of which will be direct awarded to our company.

I now want to close with a few key messages. First, we remain focused on the relentless pursuit of the reduction of cycle time. With every activity we undertake with every change in process we pursue and with every capital investment we propose, we ask ourselves, does this shorten project cycle time. This unique mindset continues to serve as the fundamental driver to improving project economics, benefiting both our customers and TechnipFMC.

Second, as we continue to drive a different paradigm around capital investment, we are delivering improved capital efficiency and higher free cash flow conversion. Importantly, we remain committed to returning at least 70% of free cash flow to shareholders through both dividends and share repurchases. Lastly, our strong commercial success and high-quality backlog built upon an expanding mix of direct awards, iEPCI and services position us well to increase Subsea inbound revenue and EBITDA margin in 2027. TechnipFMC is in full growth mode.

I will now turn the call over to Alf to discuss our financial results.

Thanks, Doug. Revenue in the quarter was $2.5 billion, adjusted EBITDA was $453 million when excluding a foreign exchange gain of $13 million. In Subsea, revenue of $2.2 billion increased 1% versus the fourth quarter. Results in the period benefited from higher iEPCI project activity, particularly in Brazil. Project revenue grew sequentially in Latin America, Africa and North America, partially offset by lower revenue in Asia Pacific and the North Sea.

Adjusted EBITDA was $441 million, up 6% sequentially, primarily driven by the increased project activity. Adjusted EBITDA margin improved to 20%. In Surface Technologies, revenue was $284 million, a decrease of 12% from the fourth quarter. The sequential decline was primarily driven by the scheduled timing of project-related activity in the Middle East with only a minimal portion related to the regional conflict. The decline was partially offset by higher completion activity in North America. Adjusted EBITDA was $50 million, a decrease of 15% sequentially, largely due to the lower activity in the Middle East offset in part by higher collision activity in North America. Adjusted EBITDA margin was 17.4%, down 60 basis points from the fourth quarter.

Turning to corporate and other items. Corporate expense was $37 million. Net interest expense was $6 million and tax expense was $96 million. Cash flow from operating activities was $332 million, with capital expenditures totaling $56 million in the quarter. This resulted in free cash flow of $277 million. We repurchased $265 million of stock in the first quarter when including $20 million of dividends, total shareholder distributions were $285 million. Cash and cash equivalents was $961 million. We ended the quarter with a net cash position of $540 million.

Moving to guidance. For the second quarter, we expect Subsea revenue to increase high single digits sequentially, with adjusted EBITDA margin improving approximately 300 basis points to 23%. For Surface Technologies, we anticipate revenue to decline low single digits sequentially with an adjusted EBITDA margin of approximately 17%. And as previously indicated, we expect corporate expense to decline approximately 25% in the second quarter. This assumes the remainder of our annual guidance is evenly distributed across the remaining 3 quarters when using the midpoint of the range.

In summary, I am pleased with the team's performance in the quarter. The solid financial results are tangible evidence of our continued success in driving greater operational efficiency. These results also reflect our continued success in winning high-quality backlog for future execution. The strong performance gives me confidence in our ability to meet our financial commitments for all of 2026.

The Middle East remains a key driver of long-term growth for Surface Technologies, but it's also important to put our exposure into proper context. Today, Middle East revenue for the segment represents just 4% of total company revenue. And for Subsea, when we consider the remaining $5.2 billion of backlog scheduled for 2026, along with the balance of our expected services revenue. We have revenue coverage of approximately 95% when using the midpoint of guidance.

So let me close on just 2 simple points. We remain very confident in our ability to exceed $2.1 billion of total company EBITDA in 2026. With each segment contributing to EBITDA in line with their full year guidance and the operational momentum and improving commercial backdrop gives us high confidence in our ability to deliver continued growth in 2027.

Operator, you may now open the line for questions.

[Operator Instructions] Our first question comes from the line of David Anderson with Barclays.

So it's been a long time since I've heard a service company talk about being in full growth mode here. So obviously, we're looking towards '27, you're getting pretty optimistic. Just curious how much of that has to do with what's happened in the last 60 days and how this impacted the deepwater cycle? Are you expecting FIDs to kind of accelerate from here? I'm just kind of curious your customers? Are they getting more confident in long-term oil prices? Just some insight into how they're thinking about deepwater, please?

Thanks for the question, David, and it gives me an opportunity to clarify. I could have made the same statement in prior quarters. Certainly, last quarter, we talked a lot about the growth of the market in terms of the Subsea opportunity list, which again grew this quarter for the seventh consecutive quarter, now achieving $30 billion, a 30% increase over the last 2 years. So we talked about -- we talked about that aspect a lot last quarter and how that was going to translate into a step-up in inbound orders for TechnipFMC from 2027 through the end of the decade.

So the short answer would be we could have made the comment prior to the conflict. What is true, David, is, indeed, our customers are looking at their portfolios. We are in discussions on opportunities to accelerate both brownfield tiebacks as well as some greenfield developments. At the same time, our customers are looking at replacing their reserve base. The reservoirs offshore are prolific, they're well known, and the economics now are extremely attractive by our ability to be able to reduce cycle time and accelerate time to first oil. If you complement that with a higher commodity price, yes, clearly, those project economics look increasingly interesting to our clients.

So Doug, Subsea 2.0 has obviously been a game changer for you. You talked about reducing the cycle time that has been critical there. Just curious how that's tying into what you're seeing in terms of Subsea margins for '27. You're guiding them higher.

Can you talk about kind of what percent of that revenue you're expecting to be Subsea 2.0 within kind of the '27 number and how that's trending forward? I know we've been talking kind of looking historically, the last kind of year or 2, Subsea 2.0 has been something like 80% of some of your orders. Can you just sort of talk about the orders and into revenue and how that's sort of impacting your margins in the '27?

Yes, David, I don't have an exact number. We haven't rolled that forward, if you will. But if I think about where we are today and where we would likely to be in 2027 in terms of the revenue being recognized from the Subsea 2.0 orders, I would put it in the neighborhood of about 50%, perhaps a bit north of 50%.

What's important is what you also said, which is 80% of our new orders are coming in with Subsea 2.0 is representing about 80% of our new orders. So that obviously demonstrates the glide path that we have to improve the efficiency simply by converting the higher-quality backlog as a result of our customers' acceptance and the significant impact of Subsea 2.0 and the integrated model, iEPCI, is having on shortening cycle times and improving their economics. And as I said in the prepared remarks, we're happy is when our client wins and we win.

Our next question comes from the line of Scott Gruber with Citigroup.

Yes. So it looks like we're probably going from a good market to potentially a great market. And so I want to dovetail off the full growth mode commentary.

You guys have obviously increased your own internal capacity with Subsea 2.0. But just curious how you're thinking about preparing the organization for additional growth, especially if there are some kind of pull forward on some projects. Do you anticipate any constraints, whether that's potentially roofline or engineers or vessel capacity? Just give some color on needing that growth and what you're doing to prepare to meet that.

Sure. Scott, thank you for the question and an important question. And I think something that really differentiates our strategy and the vision that we laid out now almost 10 years ago, and I have been executing against it, both in terms of Subsea 2.0 and iEPCI, creating TechnipFMC back on the 17th of January 2017. So I guess or approaching that 10-year anniversary.

What is true, Scott, is that every single day and every single decision that we make, we ask ourselves will this, whatever this is a change in process, change in structure and investment, whatever it may be, will this reduce cycle time? Why is that important? Reducing cycle time allows our customers to win, while we also win. So it's a true scenario where both sides are satisfied and complementing each other. But it also means we can do more with the same. It's as simple as that. If we can reduce cycle time, I can take whatever that is, people are planned, and I can get more capacity because I'm doing things faster.

So this doesn't just affect the manufacturing. This is everything we do in every part of our company, Alf has finance organization and everyone else throughout the organization is looking at ways that we can be more efficient. That means our people, by the way, are more satisfied because we reduced some of the mundane redundant type tasks that they have to perform. They're doing more value-added work, which is much more motivating. And quite frankly, we can generate more with the same.

So our ability to be able to do that, which we have much more to go. There's more runway ahead of us to be able to continue this journey that we're on is what allows us to continue to grow without being constrained or without having to have a big significant CapEx expenditures. As you may have seen, CapEx this quarter was again in line, a bit actually below the guidance level, just a bit of a seasonal effect, but also demonstrates the fact that we are able to grow this company with the infrastructure that we have in place, and we'll continue to do that by becoming more and more efficient every single day by reducing cycle time.

I appreciate all that color. And then turning to your initiative to industrialized SURF. I'm curious, Doug, as you reap those benefits, which I assume includes some installation efficiency gain, how does that impact your overall kind of vessel needs and your vessel strategy?

I'll give you a short answer, Scott, since I gave you a long answer to the first one. It's really exactly what I said to the first comment. So it applies as much to Subsea 2.0 going through the manufacturing plant as when we start to think about the remainder of the industrialization of the work stream of Subsea, and just to remind everybody, we started now over a decade ago back in 2014, premerger, we started working on industrializing the sea floor. So all of the assets that sit on the sea floor not just the trees, but there's an entire village down there and really working on industrializing all of that infrastructure, and that's -- what we have referred to as Subsea 2.0 thus far.

When we -- post merger, we obviously picked up the water column and products in the water column. I think about umbilical, risers, flow lines, flexible pipe, et cetera. And then we also picked up installation capability. And we've begun that process, but we're only in the very early stages of the industrialization of, let's say, the remaining 2/3. So as we industrialize that, it will be the same concept. We'll do more with the same or we'll do more with less. And that's the entire strategy of the company, and we think we can be as impactful or more impactful than what we've already experienced from what we've done on the sea floor.

Our next question will come from the line of Arun Jayaram with JPMorgan Securities.

Yes, Doug, I know one of the core objectives of the company is to reduce cycle times. And I was wondering maybe as a follow-up to Scott's question, if you could maybe elaborate a little bit more on your SURF 2.0 strategy? It feels like you're putting together kind of a Manhattan project type of a group at FTI to tackle this objective? And maybe give us a sense of where you're at in terms of the process? You get any pilots going on today, maybe some of the technology you're thinking about bringing to the installation part of the SURF process to reduce cycle times?

Arun, I'd like to use the rest of the time on the call to talk about it, but it probably wouldn't be the right thing for me to do. And what I mean by that is we are in the concept select stage. We have a ton of really great ideas. We have a phenomenal team of individuals working on this, but I don't want to get ahead of them, and I certainly don't want to disclose anything that wouldn't be appropriate at this time I can only repeat Arun, I am as excited and I think the impact will be as important as what we did on the sea floor.

And now having had the pleasure and the opportunity to have been involved in both of these, I can say with great confidence that the impact will be significant but I really need to be careful not to go much further than that right now, Arun. But we -- our customers and hopefully, you all have the confidence that we've demonstrated that we think differently that we approach challenges differently and that if we bring something to the market, it will be significant and meaningful and structurally change not only our company but the industry.

Yes. Fair enough. Fair enough. My follow-up, Doug, I was wondering if you can give us a little bit of an update on the flexibles segment at FTI. One of your peers talked about their plans to maybe double some of their capacity in Brazil. I know the industry is working on some solutions to tackle CO2 corrosion for flexibles, particularly with Petrobras.

But just maybe give us an update there and what kind of visibility do you have in that business and your ability to meet what looks to be a really good market for flexibles.

Sure. I'm going to go a few different -- come out from a few different angles here. Let me start by saying flexible pipe is an integral part of our iEPCI offering. So as the Subsea architects, and we're the only ones out there actually involved very, very early in the life cycle of a project. working with our clients to unlock the full economic potential of the project.

Often flexible pipe is a key contributor to the architectural design allowing us to have not only meet the functional requirements but to be able to do it in the most efficient manner. So it really is a key offering of ours. It's an area that we continue to be the market leader, both in terms of the specifications of our flexible pipe, but also in the ability to meet the market demand.

So that's important to us as well. It's an area we continue to invest in, not only as a result of what we're doing with iEPCI today, but as we look towards the future together. So very exciting about that.

On the stress corrosion cracking angle that you mentioned, yes, the industry has -- is a well-known industry problem. The industry has been working on it. We have been working hand-in-hand with Petrobras for several years. We are well into the qualification phase of our definitive solution for the stress corrosion cracking challenge. And we'll be able to say more as we continue to advance through that qualification program with Petrobras. I was just in Brazil, I will tell you they are very pleased with our technical solution, which is different and unique to us. And they are also very pleased with the pace of the qualification and the success that we're having in the qualification.

Finally, in terms of the global demand and the global capacity, it's not just for iEPCI. We do use flexible pipe outside of iEPCI. We obviously prioritize it within the iEPCI projects that we have, but we also have just some direct flexible contract awards. An example of that would be Petrobras in Brazil. We have always been their leading flexible pipe provider. I think you should expect that to continue to be the case. Often, we are the only ones who have the technical -- the ability to meet certain technical specifications. And in other cases, it's a more generic technical specification that others can also participate in that activity.

Keep in mind when I said we're industrializing more than just the seafloor. So when you think about our approach to our capacity, that's going to be by increasing efficiency through the plant. We have multiple flexible plants not only in Brazil, but outside of Brazil. And as we look every single day to industrialize and lean out the processes, we're finding the ability to increase the throughput quite significantly through those plants. So we are increasing capacity, but we're increasing capacity by improving efficiency, not extending roofline.

Our next question will come from the line of Victoria McCulloch with RBC.

Can you start with a quick shot on Subsea Services. There were notable contributor in 1Q order intake. Can you give us some color on how that addressable market has evolved on a quarterly basis over the last year? And how much of the $10 billion order intake do you expect to come from Subsea Services?

Well, in terms of the -- how has it evolved? Victoria continues to grow quite significantly. I think if you look back over the last several years, we've indicated that it would be about $2 billion or about 20% of our revenue this year. It continues to be quite a significant contributor it's been growing at a pretty steady -- well, I'd say, a slightly accelerated rate. It's been in line with the growth of the overall segment. Quite frankly, that's only because of the strength of the growth of the market. I think if you look at kind of the underlying and sustainable growth rate of Subsea Services, which is what gets us most excited it is quite significant.

And you should expect that this location at some point in time, and it's not going to be anytime soon just because, again, the overall market is growing so significantly. But the dislocation will be that the Subsea Services growth rate will continue for an extended period of time. And that's quite important to us. As you know, this is an important contributor to the financial performance of our company. It's a differentiator. As we continue to grow and have the success that we've been having as a result of everything we've talked about earlier on this call, which has increased our position in the market, which means we have a much larger and ever-growing installed base on the sea floor. All of that needs to be maintained. All of that needs to be inspected, et cetera, and that is an OEM model where we perform all of that activity on our own infrastructure.

So it's important today, and it will be even more important as we move forward.

And just a follow-up one for Alf. Obviously, Q1 incredibly strong free cash flow and CFFO despite working capital outflows, can you give us some insights into how you expect cash and working capital to look for the remainder of the year?

Sure. No, thank you. Indeed, the first quarter free cash flow was to us a very solid start. We see consistent execution in both our segments really and the strong Subsea backlog that we have continued to really fuel the free cash flow generation throughout the year. The working capital usage that you see in this period is primarily really due to the annual incentive plans that we pay once a year. And we do that in the first quarter.

So that is not something that we expect to see be a headwind in working capital in the same way as we go through the year here. And as you also -- as Doug already pointed out, the capital expenditures are well under control. We expect clearly to be at the guidance where we are anticipating capital expenditures to be, which is just above 3% of our revenue. We continue to see that we will convert from EBITDA at about 65% conversion from EBITDA into free cash flow. And when it comes to thinking about how it goes for the rest of the quarter, the best I can say at this point is we expect a fairly evenly distributed free cash flow across the remaining quarters of the year.

Our next question comes from the line of Marc Bianchi with TD Cowen.

I wanted to ask about the Subsea orders first in the first quarter here. So maybe the headline was a bit lower than the midpoint for the year, and you talked about confidence going forward. But I'm curious about the composition of the awards in the first quarter because you didn't have anything large that you press released or large that you mentioned in the press release for the quarter.

So I'm wondering, is there a message here about the recurring small award composition and kind of the breadth that maybe we could take away as we think about the go-forward order level?

Sure, Marc. Fair question. As you know, and you've got the experience, there's no way that this is ever going to be linear. It always comes and goes. It can be a matter of a few days at the end of 1 quarter or a few days at the beginning of the other quarter. I can only strongly reiterate my confidence that we will achieve $10 billion for the full year, and nothing should be read into Q1 other than the kind of second part of your question, which was a very strong quarter given the fact that the amount of announced awards -- versus the amount of announced awards.

So look, I just want to reassure everybody that the underlying business is very solid. You see the strength of having the installed base that you -- that we have. You see the show up in our Subsea Services you see the strength of the customer relationships that we have in the direct awards as a result of that, that shows up into the large portion of unannounced awards. And look, embedded in the quarter, there was a large project that we will be announcing once the customer gives us the permission to announce that award here sometime in the near future.

Okay. That's helpful, Doug. And then on the surface guidance, I guess just considering the commentary in the press release, how it didn't seem like there was a big effect from the conflict, and it's only 4% of revenue. I was surprised to see it down just given the strength that everybody is looking for in North America.

Can you kind of unpack what's driving second quarter if there is an assumed war impact and what your sort of macro assumptions are around that?

Yes. This is Alf here. I'll take that one. So first of all, as I as I kind of mentioned in my prepared remarks, backlog scheduling in the Middle East is a big portion of the answer here. So even before the conflict, the backlog scheduling not as high in terms of activity levels in the first half of the year. So you're just continuing to see that spillover into the second quarter as well.

But the reality is that -- that is still a far bigger effect on the overall than the content itself. So that's an important point. We continue to see strength in the back half of the year. We continue to see that our U.S. business is doing well. We are introducing technologies in our U.S. business that is driving our activities and they are creating efficiencies, both for us and our clients. And that is also supporting a more favorable margin mix.

So when you look at surface for the full year, you should probably, at this point, expect that the revenue will be slightly lower compared to full year guidance. But on the other hand, the offset is that we are seeing an opportunity for stronger margin performance. So overall, we expect that the total EBITDA dollars for surface will be in line with whatever you see implied by the midpoint of the current guidance.

And just to be overly clear, the Subsea guidance remains unchanged. And thus, what we are confident in is what I said before. We will exceed $2.1 billion of company EBITDA. It's just that the mix a little bit on the surface right now could be tilted a little bit towards lower revenue but higher margin.

Our next question will come from the line of Caitlin Donohue with Goldman Sachs.

You mentioned seeing an order step up in inbound into 2027, which you anticipate to drive further earnings growth. Can you walk us through where you're seeing the most inbound geographically? Particularly as we now may see a move towards more incentivized exploration, whether this is greenfield versus brownfield work?

Sure, Caitlin. I'm happy to take your question. In terms of the 2027 inflection, it's really -- let me kind of talk about the big buckets that it's being driven by and then we can maybe get into the geographies. 2026 is going to be a year of a lot of smaller awards as we just saw in Q1, fewer big announced awards. That was always -- we talked about that back in 2025. We saw that kind of -- it was just a period of time. And a lot of that is a result of the contribution from some of the new and emerging markets that we've also been highlighting for quite some time. That -- and what we're seeing is that those will really be -- they'll have some impact on 2026, but the larger impact will be on 2027 through the end of the decade.

So think about it as new big contributors to the offshore space in terms of capital expenditures, that's 1 bucket. The other bucket is this continual flow of capital from the unconventional U.S. onshore to the offshore as customers are focused on reserve replacements as customers are focused on bringing in some of these very prolific offshore reservoirs. Now that they have the economic means to be able to achieve that, not because of the increase in the current commodity prices I spoke to earlier on the call, but because of their increased confidence in our company being able to deliver an integrated 2.0 contract to them on time, on schedule or ahead of schedule, shortening cycle time, improving their economics and giving them certainty in that outcome. That's very, very important to them.

And then finally, yes, we do see now with a higher commodity price potentially being around for longer than many anticipated that, that will also have a contribution -- a positive contribution to those economics. And then finally, we were really seeing a shift towards offshore gas developments. And I would say we're going to see that a more balanced approach now with more offshore oil developments as well as the continuing drive up in the offshore gas developments.

So when you think about the offshore gas developments, now I'll get to the geographical part of your question, you're thinking about East Africa, you're thinking about Asia Pacific, Australia, Indonesia, you're thinking about the Eastern Mediterranean. When you think about the oil -- offshore oil developments, you're thinking about Latin America, be it Brazil, Guyana Suriname. You're thinking about the U.S. Gulf, you're thinking about West Africa. And I think those are areas that we'll start to see a lot of increased activity from as well.

And I don't want to forget my Norwegian friends. Also, when you think about the offshore gas, you should think about Norway and the significant contribution that it's making to Continental Europe gas supply by being able to accelerate projects in the Norwegian sector of the North Sea.

That's helpful. And then just a follow-up there. For the magnitude of the step-up post 2027, I know you said FTI is in growth mode and we're going to see some of these larger projects come in and towards the end of the decade. Can you just help frame the magnitude of what orders might look like over the longer term for FTI?

That's a fair question, Caitlin, and I thought I [ fill the buster ] enough on the prior question, I might have gotten away from it. No, I'm just teasing you, fair question.

Look, if we thought it was going to go from [ 10% to 10.1% ], we wouldn't make such a bold statement. So I would consider it a bold statement.

Our next question will come from the line of Derek Podhaizer with Piper Sandler.

So I appreciate the company's advancement in making offshore markets more short cycle than longer cycle. But given the current oil prices and macro, renewed focus on energy security. Just wanted to ask about the shortest cycle barrel of the offshore markets, maybe from a regional perspective?

And how FTI can support that and have exposure through that maybe whether it's brownfield tiebacks, electrification or the Subsea Services piece. So maybe, Doug, just some thoughts around the shorter-cycle barrel of offshore and your exposure into those markets?

An important question, and I referred to it earlier in the conversation when we were talking about some of the recent client conversations that we're having. So as they look around their portfolio, they've always got a list of what they would call stranded reservoirs. That does not mean poor quality reservoirs. It just means the reservoirs don't have the reserves in place or the barrels in place to be able to justify their own development. So then the way that those get developed is through technology and innovation that will allow those smaller or stranded assets to be tied back to an existing infrastructure, wherever that may be floating something or a fixed bottom something or back to the shore just depending upon which country and which we're working.

So we are absolutely spending a lot of time on working on those stranded assets. It's the shortest cycle time to bringing barrels online because you're not waiting and building or having a large capital expenditure around building a host facility. In this case, the host facility would exist. The role that we're playing is one, from a technology point of view, it's Subsea 2.0 plays a big part of that because remember, in the old Subsea world or, let's say, the way that the rest of the industry is operating today, when they take an order from the moment they take that order, that order is a fixed to that client and that project. It can never be used for someone else or for a different project even for the same client because it's built to a unique specification.

With Subsea 2.0 when we take a 2.0 order pretty much up until the time it's delivered, we can modify that because it's just a series of features that we add or subtract onto that core product meaning it can be shifted from one asset to another from one client to another, and we have real examples of how we've been able to do that to help our clients accelerate their developments and accelerate their production levels by doing such. And again, we always refer to the automotive industry. Think about the automotive industry. When you order a car, that is not your car. The engines already been designed, the transmission has been designed, the frame and the chassis has been designed. It's only yours when they put everything on when they put all the pieces together, apply the final paint color then its yours.

And so it's a very similar approach, and it's really changed the game for our customers, and they're really beginning to recognize that attribute that it provides. So that helps in the short -- that helps shorten the shortest cycle barrel. The other way that we do that is through our OE electric system. And the OE electric system allows us to increase the distance from those host facilities to look for these stranded reservoirs and to tie those back.

And then finally, it will be the way that we do the rest of the project or the rest of the work stream, meaning the water column as well as the installation. And as we talked about earlier, that's a portion -- that's a big effort that's going on within our company today to look at how we can industrialize that. So we have the 2.0 seafloor. We have the OE electric today, and in the future, we'll have even more. So our belief that today that we can continue to reduce a significant portion of time off of an offshore development where as we've already taken anywhere from 9 to 15 months off of the cycle time of a project, we believe there's even more to come in the future.

Got it. That's very helpful and encouraging. Maybe just switching gears up. Just curious if there's any updates around some of the new technologies or R&D projects you're working on with third parties or start-up communities in the new energy sector or bringing some onshore industries to the Subsea. Just maybe some updates around there -- around that, some of the advancements you're making?

Derek, that's another one I'd love to talk about, but it's probably not appropriate. But yes, please rest assured, as a company, we are looking at challenges that are occurring in the world today. We look at them from a different perspective. We look at them from what could be done. 70% of the world is covered by water. The seabed is quite attractive, at least to us, it's quite attractive. And how can we leverage that portion of the geography in a different way than people have considered using it today. I won't go much further than that, but so lots of kind of innovative thinking around that, in the area of new energy specifically.

The work that we're doing in carbon transportation and storage continues to be very important to us. I just got back from Brazil where we were focused on our HISEP project. And Petrobras is very pleased with the progress that we're making. This will be the -- again, this is a very novel technology, the first time that CO2 will ever be separated on the seabed and reinject it, meaning it doesn't come up to the FPSO. It's never exposed to the atmosphere. So it's a significant improvement in the way that things are done today and also debottlenecks in existing production facility for Petrobras, allowing them to produce more oil and generate, obviously, the financial benefit from that.

So that's a really interesting project and it's going well. And then in the North Sea, we are going in June to participate with my peers there. And with our clients, we're looking at -- that's where we're taking CO2 that's being captured from the meters onshore and then we're taking at 145 kilometers offshore for permanent storage offshore. Again, these are really novel technologies. That one is enabled by our OE electric system because you wouldn't be able to do that with hydraulics and certainly not be able to do with hydraulics all on the sea floor like we can with the OE electric.

So yes, some really neat things, Derek. There'll be more to talk about in the future, and we look forward to the opportunity to do so when the time is appropriate.

Our next question comes from the line of Samantha Ho with HSBC.

Doug. I wanted to spend some time on surface. I was surprised to see in your prepared remarks that you called out higher completion activity in North America. And I was just wondering if you could elaborate on that.

Sure. So thank you, Samantha. Your question was on surface and completion activity and surface?

In North America.

Yes. Okay. Sure. So we did see North America had a strong contribution. As you know, there was a an acceleration in the conversion of wells that had previously been drilled but uncompleted to complete those wells that obviously consume -- we provide the surface assets to be able to allow that to be accomplished.

We're not seeing a big recovery in the North America business, if that's maybe what you're wanting to -- if that's where you're wanting to go. It's been a pretty steady business for us. What's most important for us in that business is how we're transforming our product offering within that business. So moving away from the commodity products where there's a significant number of competitors doing the same thing we are and really focusing on our digital offering which we call [ cyber frac ], which allows us to be able to automate the entire completion well site and actually allows our customers to be able to monitor and operate the assets remotely from their own office, wherever that may be.

And you would have heard about this in the past. The drillers do that for the drilling and the frac companies do that for the fracking, but we've actually put in place now an architecture that is an open architecture, allowing us to plug in the various service providers, including ourselves, on the well site, but in a fully integrated approach allowing a single interface for our clients, and that continues to make good inroads. And that's a very different business model for us as again, it's a digital offering with very minimal capital investment. But a very important financial contribution to the segment.

And as a follow-up, I was wondering if you guys have looked into maybe expanding into Argentina or Venezuela?

So we have -- certainly, we are and have worked in Argentina for quite some time, like everyone else or most everyone else, I should say. We worked in Argentina up until the sanctions and then we recognized and did the right thing and left when the sanctions were put in place. As we move forward now in Venezuela, we are looking at the opportunities as they present themselves. We are talking to our clients, both remember in surface, our clients are both the E&P operators, but also the service companies. So we are talking to our clients in Venezuela. And as they start to put together their plans their plans to potentially move back into Venezuela, then we will be there to support them as they need us.

But we're going to allow them to really identify an environment, an investable environment. And once they achieve that, then we'll support them. And again, back to Argentina, we've been there for a long time. We continue to be there. And yes, when we have a technology offering in the U.S., we also -- Argentina is a natural extension to take those type of unconventional technologies to that market as well.

Our next question will come from the line of Saurabh Pant with Bank of America.

Maybe I want to just go back to some of the line of questioning initially, right? Full growth mode uptick in inbounds in '27 and beyond. But just from a supply chain standpoint, right, I want to go back to that. I know Subsea 2.0 makes things easier, right? But as you look at your supply chain, Doug, right, I'm thinking things like castings and forgings and your own vendor base. How are you preparing your supply chain for the growth that you see coming?

And then related to that, things on the partnership side of things, right, especially on the vessel ecosystem, maybe just give us some color on how you are thinking that partnership structure you have worked to put in place. How is that looking in terms of supporting your growth outlook?

Sure, Sir. So let's do the -- let's tackle the supply chain first. First and foremost, I want to recognize my team. They've done a tremendous job, not only dealing with the uncertainties around the tariffs, which we manage quite effectively. But now looking at potential disruptions and how we can manage that. And at the same time, we're growing the company. So yes, indeed, that means the supply chain is also growing.

You said it earlier, Saurabh, the shift to a configure-to-order system or Subsea 2.0 and has significantly reduced our reliance upon the supply chain, and it has significantly reduced and/or eliminated their requirement to build things for the first time on a project-by-project basis. So when we talked about in the Subsea 1.0 world or again, the way that the rest of the industry is still operating, when they get that order, they've never built it before. So everything is specific to the specifications of that project. So by definition, it's a novelty or a new product.

So the same thing when they place an order with the supply chain, so in order to place that order with the supply chain, they have to do the drawings. They have to create all the building materials before they can even go to the supply chain. That typically takes 9 to 12 months of engineering. So you get an order, you spend 9 to 12 months of engineering and then you go to the supply chain and ask them to build something they've never built before. That's Subsea 1.0.

In Subsea 2.0, it's all pre-engineered preconfigure component including the components that are being manufactured by our supply chain. So at the time of the order, we place it flows naturally straight into the supply chain. We eliminate the 9 to 12 months of engineering, one of the key reasons we can shorten the cycle time on these projects, but also it's very important. They now are building something and they're getting quantities. They're not getting specifications to build something they haven't built before.

So Alf and I were actually hosting a charity dinner a while back for some of our key suppliers that were supporting a charity that we support TechnipFMC. And I always give them the opportunity and ask them, what could we do better, how could we work better with your company, and across the board, and this was suppliers from all around the world, they were thanking us for the way that we operate today. And just to put that into context, we sit down with them now on an annual basis. And on an annual basis, we say we're going to need 50 of this or 500 of this or 5,000 of this, but this is a defined product that they built before. Then by giving them the quantities, they can decide to do it divide by 12 and do it over a monthly basis. They could accelerate it and do it early and hold it on their balance sheet for us for future consumption. But whatever is easy as for them and whatever is best for their business model and for their capacity.

So it really has changed the way that things are done. We obviously retain redundancy to address challenges that occur sometimes around the world. So we have redundancy, but we have a much more streamlined supply chain I would say, a more sophisticated supply chain as a result of moving to the configure-to-order approach. And I'm sorry, Saurabh, I've already forgotten your second question.

So I was thinking on the partnership side of things, right? You addressed the [indiscernible] of things right to the partnership, especially the way vessel ecosystem.

No, no. Thank you for reminding me. So I don't want to start by saying the partnership approach also applies to our suppliers. So we spend a lot of time with our suppliers, like we do with our clients. We have partnership agreements like we have with our clients, we have with our suppliers. We like the way our clients treat us, and we think that's the way to treat our suppliers.

So first and foremost, they are part of the partnership. Beyond that, as you indicated, we also have partners with other providers of assets for us to be able to utilize on our integrated projects. The ecosystem is strong. And I will tell you the ecosystem is growing probably since the last time we've talked about it. We've added 1 or 2 additional companies to the ecosystem. There is a queue that will -- that also want to join the ecosystem. And we are considering those as we move forward.

So again, the success of the iEPCI model, the success of the direct awards to our company as other providers of assets, very interested and enticed to work with us to be able to have access to that market, which is now direct awarded to TechnipFMC.

That's fantastic color. And just a very quick follow-up, Doug. I know somebody asked this question every quarter, right? But I want to make sure we get an updated view on this, right? We're talking about growth, obviously, a lot today than we did maybe a year back. But in terms of the margin outlook, Doug, right, obviously, the 2026 outlook, we got Subsea 21% to 22%. Maybe just help us think through the moving pieces as you pursue the growth that you see ahead, right? Where can margins go? And what are the key moving pieces that we should bear in mind? Again, Subsea 2.0 is one of that, right? But just a reminder of the key moving pieces.

Sure, Sure. I also just gave you 2027. So I thought we were being pretty generous. Here, we are committing to not only inbound growth but revenue growth and EBITDA margin growth in 2027 for Subsea, just to remind everybody of that comment, which I think is pretty spectacular and speaks to the high quality of our backlog, our execution capability and our deep insight into the market and our customers' need because of the privileged position that they allow us to be in.

Look, the underlying fundamentals, it goes back to the earlier question about Subsea 2.0 and it's ever increasing contribution to the revenue. So I indicated that it would be going to about 50% in 2027, yet inbound levels are 80%. So you know that's going to continue to go up. iEPCI, the amount of integrated work that we're doing today and inbounding today is at an all-time high. That will continue to be converted into backlog, there's less and less low-quality historical legacy backlog left. So as that continues to get worked off, that's obviously a tailwind as well.

And then sure, the market and the market dynamics are also a position of strength, and we benefit from that as well. So -- but I try not to focus on that one. It's why I said it last but we really focus on what are the things that we can do, what are the things that are within our control, so that we build the sustainable business and continue to drive the financial results even higher. So thank you.

And we have reached our allotted time for questions. I will now hand the call back over to Matt for any closing comments.

This concludes today's conference call. A replay will be available on our website beginning at approximately 3:00 p.m. New York time today. If you have any further questions, please feel free to contact the Investor Relations team. Thank you for joining us. Regina, you may now end the call.

All right. Good morning, everybody. We're going to keep this thing going. My name is Derek Podhaizer. I'm senior analyst covering Oilfield Services here at Piper Sandler. So up on stage with me next, we have CEO, Doug Pferdehirt of TechnipFMC, ticker FTI. We're going to be discussing the offshore production cycle with Doug.

So look, Doug, I always like to -- I always like when you kick off these -- any fireside chats around framing how you structurally changed the landscape of offshore development. You talked about returning certainty to the market and the company's relentless produce -- sorry, relentless pursuit of reducing cycle times and increasing project economics. Could you provide your comments to the audience on how FTI is leading those efforts?

Sure. First of all, Derek, thank you for having us here, participating in the conference. Thanks to everybody in attendance and to those that are on webcast for your interest in our company. We deeply appreciate it.

So look, a decade ago, we looked at the economics in offshore and realized they were no longer sustainable. Projects were being -- the project returns were deteriorating due to the poor performance of the offshore project. Projects were being delivered a year late. Projects were being delivered 100% above the budgetary cost, just significant time and cost overruns. And this was somewhat the norm and actually accepted by our clients. But we looked at it as the offshore company and realized this was not sustainable.

So something needed to change. We were part of the problem. You have to acknowledge that. But then it's about developing the solution and being the solution. And we're really proud of what we've been able to do over the last decade. It's been 10 years in the making. But as we sit here today, we are now driving the cost curve down or we have a deflationary environment offshore versus other areas of capital flows, which are facing fairly significant inflationary effects. Now how are we doing that? We're doing it by the relentless pursuit of reduction of cycle time, shortening the cycle time accelerates time to first oil, dramatically improves our clients' project returns, of which we share a portion of the economic value that's created.

We also get the internal benefit of much greater efficiencies because we're doing things faster. We're doing more with the same amount of assets, if you will. So much higher returns, much better profitability and build a business that is now truly sustainable to where our customers have the confidence back in investing the offshore. It's important to understand the reservoirs were always there. I'm a reservoir engineer. The best reservoirs are offshore. The reason why the money was not going -- was going from the offshore to the onshore was not because of the quality of the reservoir, far from it, it was just simply because of the performance of the execution of the projects. So we fixed that.

We redesigned the Subsea architecture. We made it to where it's a configurable architecture, does not require any incremental engineering at the time of order. There's nothing bespoke. We're going off a catalog, using a configurator that allows our clients to be able to have what they need, have the choices that they need, but the certainty of the outcome. In addition, we merged FMC Technologies with Technip back in 2017 to create the only integrated offering. And this integrated offering starts all the way at the architectural phase where we design the architecture all the way through the building of that architecture, the installation of that architecture and then a 20- to 30-year life of field or aftermarket services OEM-style contract to support that architecture.

All of these things is what's making offshore extremely attractive to our customers again and what is now we're seeing the capital flows returning back offshore.

That was great, Doug. I appreciate that. Obviously, very exciting and one of the main reasons why your stock is up over 300% over the last few years. We always get kind of pushed back on that as far as just the mean reversion in valuation. But as you just laid out for us, we are a structurally different market here that you transformed the offshore. So let's just talk about the growth trajectory from here. We talk -- you talked about the Subsea opportunity list. I always like looking at that over $1 billion project wedge that continues to grow.

So maybe just in your mind, talk to us a little bit more about the future outlook with growth and maybe walk around the world for us pointing to the specific regions like those -- the emerging markets and what's getting you excited with that opportunity list?

Okay. Sure. So we published quarterly the Subsea opportunity outlook to give you all an idea of what's actually happening in the market. We break that down into different categories, projects that will be above $1 billion and then different increments below that. That list has grown tremendously. It's grown over the 6 -- the prior 6 quarters. It's now at $29 billion, which is a high watermark.

On the conference call this past quarter, I indicated that, that is likely to expand further in 2027 and also the $1 billion projects, Derek, that you mentioned, have doubled in just the past 24 months. So the number of billion-dollar projects has doubled, and that really has to do with some of the big greenfield opportunities within existing basins, but also new opportunities in emerging basins. So maybe to do that, I'll walk around the world to talk about that.

Now I think given the current events, it's impossible not to start with the Middle East. So I really do want to -- I do want to start there. It's important to understand that our company, although we're an offshore company and you hear about offshore incidents that are occurring, we do not operate in the shallow water market of the Middle East. So thinking about Qatar, Saudi Arabia, UAE, we don't do subsea work there. As a subsea company, it's shallow water, it's commoditized. We have not done that for decades. So we're not in that market, so we're not impacted by those activities in the shallow water market portion of the Middle East.

So just kind of get that on the table upfront. More broadly for the company, we do have a Surface Technologies business. It's a smaller business. We do operate onshore in the Middle East. But just to put things in context, 4% of our revenue is exposed to the region, 4%, so relatively de minimis. So now let's talk about the rest of the world, but I thought it was important to talk about the Middle East first.

So it's hard to know where to start. So I'm going to start with Brazil and just kind of go -- try to go around the world a little bit. It is an exciting time. There's more going on offshore than there's ever been. There's more new opportunities in offshore than I've ever seen in my career. But let's just start with where we are today, where we're seeing activity and where activity could be emerging from.

So if we start with Brazil, continues to be extremely active in the pre-salt, not only Petrobras but also other IOC operators that are now operating in Brazil doing very large projects. We -- in Brazil, there's the exploration work that's being done in the equatorial margin. This would be a whole new opportunity set within Brazil. Then you go to Suriname. Suriname has its first project FID by TotalEnergies where we're honored to be doing that work for them as an iEPCI 2.0, this integrated offering, 2.0 being this new architecture in Suriname.

Guyana continues to be extremely robust off of the success of ExxonMobil, where we're humbled to do 100% of the work for ExxonMobil and very excited to be able to be a partner with ExxonMobil in their activity in Guyana. Let's jump -- we'll jump over Venezuela for the moment and Trinidad and Tobago, and we'll jump up into the U.S. Gulf, probably the most exciting region within the U.S. Gulf, although there's a lot of activity around the mature parts of the -- the mature areas of the U.S. Gulf is the Paleogene. The Paleogene is the deep, high-pressure region. There, there's been 6 projects. We are on 5 of those 6 projects and most recently announced 2 additional projects for BP in the Paleogene an area that we're very excited about.

Now we'll shift over to the North Sea, lots of activity in the Norwegian sector of the North Sea. Also a couple of ongoing projects in the U.K. sector of the North Sea. But clearly, a focus on developing gas for the Continental Europe energy security and exporting that gas to Continental Europe. So lots of activity there. When we look at Africa, Africa is an exciting opportunity. And I think over the next decade will really be a driver of activity, and it goes from north to west to south to east. And you tend to have more oily on the west, more gas on the east but there's activity in multiple countries.

Some historical countries that haven't had a new development in over a decade that have recently announced new developments. And then on the Eastern side, you have an emerging areas like Mozambique, which there's now 2 -- 1 producing asset, 2 ongoing projects with the potential for additional awards in Mozambique. You have the Orange Basin, which we've all heard about, which is largely Namibia and South Africa, very exciting. There is projects that are now being actively in the tender pipeline there that we should start to see some project FIDs occur in that region as well.

Then if we shift over to Asia, it's really about Indonesia. Indonesia, large natural gas deposits important for LNG, as a source for the LNG. And we're starting to see those be FIDed at a pretty rapid pace. And that has a lot to do with the partnering between the Indonesian regulators and the Indonesia national oil company with the IOC operators moving those projects forward.

And then down in Australia -- Malaysia, Australia, we see a few more mature properties that we're doing, adding additional wells just due to natural decline rates, particularly in Australia, where you have a lot of LNG infrastructure, all that LNG is fed from offshore gas, subsea gas. So as those wells decline over time, they have to be replaced and replenished with additional wells.

So I probably left a few out, to be honest, but that's as quickly as I could get around the world. It's very exciting right now, the amount of activity again, within existing basins, new areas within existing basins and brand-new basins that are being developed at this time.

That's great. I think you hit on all the main regions. And maybe just to follow up, you talked about accelerating FIDs on the Far East side of things. I mean I think what we're seeing today with current events as far as LNG being cut out in Qatar impacting the Southeast Asia Far East market. Would you see almost even a further acceleration of the FID just when we start thinking about energy security just given what's going on today in the Middle East?

Yes. Look, I think it's hard to say anything definitive at this time. It's obviously an ongoing and a fluid situation, which we hope resolves itself and, first and foremost, looking out for the safety and well-being of our people and those who work with us. But what is true is the risk profile of that region has obviously been elevated, which will force capital to find other opportunities that maybe have a slightly lower risk profile. And we firmly believe in what we are seeing and experiencing is that is likely to go to other offshore basins around the world.

Right. That makes sense. And just to kind of get this question out of the way that everybody always likes to ask. You kind of laid it out already, but just order outlook as we think about 2026, 2027 on the last call, reiterated over $10 billion in '26, grow from there in 2027 back by that Subsea opportunity list and then maybe within your answer, talk about margins. And we don't talk about peak or mid-cycle anything just continuing to grind higher from here as you flow through more Subsea 2.0. Is that just still the fair way to look at you right now?

I think you summarized it really well. The only color I could really add to that is, clearly, we are in a growth mode. The company has been growing inbound. It's been growing backlog. It's been growing revenue. It's been growing margins. It's been growing free cash flow. And I think what we laid out with some of the recent updates on the Subsea opportunity outlook and some of the commitments that we've already made for 2027, companies are talking about Q1 of 2026, and we're talking about 2027 and making commitment. That's the type of visibility that we have, and that's the strength of the backlog that we have.

I think we're in for a period of continued growth. In terms of the margin, the margin isn't just because of the market growing and the volume growing, it's also because of what we are doing to completely reshape our company, much of which I talked about at the very beginning about how we've reshaped the company and reshaped the offshore industry to make it attractive again and to bring certainty, predictability and to make the economics, the most attractive economics for the capital to flow today, which is something we did not have for the past decade, but we've now addressed that. But we're doing a lot internally within our own company as well.

So when I talked about the ability to be able to do things more efficiently or reducing cycle time, I'll give you an example of that. The new architecture of equipment that we call Subsea 2.0, it's just a new architecture that's configurable. So instead of going from building something the first time or bespoke engineer to order, we're now doing this configurable product platform like the auto industry does. When you place your order for your most recent automobile that manufacturer is doing 0 engineering at the time you place the order, it's going straight into assembly and test. That's what we have been able to achieve.

The cadence, therefore, of the flow through our facilities is 2.5x the historical cadence. So we've created capacity just by having that additional throughput and it's just phenomenal and obviously shows up both in the margins as well as in the returns.

Great. So you brought up the 2 FIDs with BP in the Gulf, Kaskida and Tiber. And I think that was one thing that you really focused on the last call, this portfolio approach by your customers. I do feel like this is an underappreciated new dynamic in the industry that we're seeing today. So maybe help us understand the benefits of running 2 projects in parallel for you. And I know not to speak for BP, but from your perspective, why is this so important?

Derek, I would agree. I mean it's -- this is not business as usual. This is very different. Our customers in the past would initiate a project, wait for that project to be completed, take the learnings from that project, then attempt to reincorporate them into the next project. And the reason why in the learnings, and I'm being very gentle when I say learnings, was really because, as I said, it was typically cost overruns or schedule overruns. So with certainty that we've been able to bring back into the industry and into our customers has changed the way that they're approaching their developments.

They're now saying, we don't have to wait. We know this project is going to be delivered on time, on schedule. We have that level of confidence. They have that transparency and that visibility into our operations. We're doing these in a collaborative way, such that if we just roll into the next project, so right now be doing, if you will, simultaneous engineering or be doing simultaneous supply chain, what implications would that have from a portfolio approach? The answer is quite profound. Clearly, they see a cost benefit of doing that. We see a cost benefit. We share in that. We also see a much greater benefit in terms of efficiencies and the continuity is so critical.

This will now be done by one joint project team. So it used to be a stand up a project team that finished the project, they would go away, go do whatever they were going to do in their careers and you stand up a new project team. So when I kind of jokingly talked about knowledge transfer or lessons learned, it didn't happen. There was a deep cavern between the two projects, both in terms of time and in terms of talent. Now we have that continuity.

So this portfolio approach is something that BP embraced. I think it's absolutely -- and it's being looked at by others and some others are actually applying it as well. And I think we'll continue to see this not only in greenfield developments like BP is doing in the Paleogene, but as importantly in brownfield developments because these are multiple smaller projects that would benefit from a portfolio approach.

Yes. No, it's a very interesting and exciting dynamic to see. So obviously, we're having evolution of oil versus gas to offshore. I guess maybe for FTI, how should we think about the calorie count for the company, maybe the differences in technology for deploying oil development versus gas development?

Yes. Interesting question. We're definitely seeing more of a shift to gas. We talked about Indonesia, but there's multiple regions around the world, East Africa, the Eastern Med. We're seeing more gas offshore developments come into play, which I think makes sense and is something we certainly anticipated and certainly welcome.

From a company perspective, let me start by saying we're agnostic, be it oil or be it gas. It's -- we're agnostic to it. It doesn't have a large delta from a project cost point of view or revenue recognition point of view from us. But what is different between a gas development and an oil development, the requirements of our equipment for a gas development do tend to be higher level, more sophisticated. This is simply because of the corrosive nature of the gas and also the velocity. I mean, this is being produced at just tremendous velocities.

So everything has to go to where the pressure containing portion of the system. Everything goes through our equipment. And therefore, it has to be built in most instances to a higher standard and different metallurgies, different coatings, different techniques to be able to deal with that environment. So you tend to see a bit higher cost per unit in a gas field versus an oilfield development, but you also tend to have fewer wells on a gas development than in oil development. So it kind of nets out for us. But certainly gas, if it was one that I had to pick, we certainly have more differentiation in gas because of the higher technical requirements where we lead the way.

Very exciting. So let's talk about SURF 2.0, something you've been teasing a little bit here over the last few months. We talked about it at dinner last night, [ SPS ] versus SURF. I think it was 1/3 versus 2/3 as far as overall content for the company. I know it's early stages, but maybe help us in the audience understand how you're thinking about what SURF installation 2.0 could mean and could unlock for FTI going forward?

You made me nervous when you said we talked about it at dinner last night because it was a long dinner and an enjoyable dinner, but we talked about a lot of things. No, this isn't important. This is very important. So I just try to kind of simplify it. When you think about a subsea development, we start, remember back at that architectural phase. So we're designing the entire system. The system is really 3 components. It's what sits on the seabed. It's what's in water column and then it's the ability to be able to install, hook up and commission all of that equipment.

So those are really, if you will, the 3 phases and somewhat equally split, roughly equally split, in terms of the cost of those 3 elements. So back in 2013, a long time ago now, we started on the seafloor, architecture. And that's what we initially called Subsea 2.0. That's the configure-to-order like the auto industry, no engineering at the time of order, all pre-engineered configurable components, everything we talked about earlier. That was the seafloor. And that's all that we looked at because at the time we were FMC Technologies and FMC Technologies just had the seafloor.

When we saw the opportunity to merge with Technip and create TechnipFMC because we wanted to have that fully integrated system, all 3 elements of that, that's why we move forward with the merger, and that's this iEPCI, integrated EPCI, that we talk about. We had not addressed the elements of the other two, which came from Technip because that merger wasn't until 2017 and then we had a pandemic to deal with, and we had a major spin-off to deal with of an E&C company, all of which is behind us now.

So about a year ago, we actually have begun the process to look at the 2.0, which is the industrialization or this configure-to-order approach for the other 2/3 of the subsea development. This is what has us hugely excited because Derek was kind enough to point out the success that we've had thus far, but it's only been on 1/3. We have 2/3 left to go. So I can tell you this is what gets me out of bed every morning. This is what keeps me hugely engaged and motivated. It's what keeps our clients hugely engaged and motivated with us. It's why they're looking at portfolio approaches because they know we're going to continue to innovate and deliver on that other 2/3. That could be as compelling or more compelling than what we've already done.

Super exciting. So we've got time for two more questions. I do want to touch on Subsea services because this continues to be a pretty big growth tailwind for the company as your installed base continues to increase. So how should we think about the growth of that business, the drivers of that business and just the upside of the business as your installed base continues to increase here?

Yes, it's really important. I mean we have the world's largest installed base on the seafloor and it's growing every day, and it's aging every day. So I can say this because I'm at that point now to where every day I feel that I'm aging and I need a little more intervention from the medical field and the Subsea equipment is no different.

So it's designed for anywhere from a 20- to 30-year life. This is very sophisticated equipment. It's sitting on the seafloor in very harsh conditions. On top of that, we're typically operating at about 1 mile deep in the water up to 2 miles deep in the water, not into the earth, just in the water column. So obviously, not being intervened with by a human being, like you can on land. So this is all done with very sophisticated automation and control and robotics.

We have a bunch of robots down there, doing things to maintain the infrastructure that's in place. And again, designing -- imagine designing electronics to work in a saline environment, underwater for 25 to 35 years. Ask your IT guy, they don't like when you spill water on the keyboard, and that's the world that we live under in a saline environment. So it is pretty amazing work that we do.

We partner with NASA in terms of the development of the automation and control systems because although they're going up in the air and we're going below the water, it's actually very similar conditions that we have to operate in for our automation and control in our electronics. So look, all of that needs to be maintained. All of that needs to be inspected from time to time. Our subsea services, basically from the time the project delivers the equipment, they're involved in the installation of that equipment all the way through that life of field or aftermarket services contract.

That business will be about $2 billion this year. It's a reoccurring revenue stream. It is high margin. It's an OEM-type model. And it is extremely resilient, including when we went through the pandemic, we had very little change in our services activity. So something that is very important to us and something I think that a lot of investors have picked up on, starts to look more like an industrial, if you will, than a traditional oilfield services type application or a company.

Great. Appreciate that. And so last question, I want to make sure we show [indiscernible] love here with this one. Just latest thoughts on capital allocation, free cash flow generation, shareholder returns. I mean it's been a pristine story for you guys. So just where would you like to leave the audience on that subject?

Well, first and foremost, we are proud to be in the position to be able to generate the free cash flow that we're generating. And we're also very proud to be able to redistribute that back to you as shareholders. You entrusted and put confidence in our company as we now have grown and continue to grow and generate tremendous amounts of free cash flow and are in a position to redistribute that to you, $1 billion last year between share repurchase and dividends. We just announced a $2 billion share repurchase authorization.

We said we would deliver no less than 70% of free cash flow back to you as the shareholders, something we are committed to doing. The balance sheet is extremely resilient. We've paid down any near-term debt that is on the balance sheet. We're net cash, and we have -- we got about $400-some million of debt, so net cash of about $600 million. So we're in a position of strength. And our commitment to you is that we're going to be thoughtful in how we use those, how we use that cash and very comfortable continuing with the share repurchase and dividend program in terms of the distributions back to our shareholders.

Great. We're up on time. I mean I can spend another hour up here with you, but really appreciate you running the business with us, the outlook of FTI. Super exciting as always. So Doug Pferdehirt, CEO of FTI. Thank you very much. Appreciate it.

Thank you, Derek.

Hello, and thank you for standing by. My name is Regina, and I will be your conference operator today. At this time, I would like to welcome everyone to the TechnipFMC Fourth Quarter 2025 Earnings Conference Call. [Operator Instructions]

I would now like to turn the conference over to Matt Seinsheimer, Senior Vice President of Investor Relations and Corporate Development. Please go ahead.

Thank you, Regina. Good afternoon, and good morning, and welcome to TechnipFMC's Fourth Quarter 2025 Earnings Conference Call. Our news release and financial statements issued earlier today can be found on our website.

I'd like to caution you with respect to any forward-looking statements made during the call. Although these forward-looking statements are based on our current expectations, beliefs and assumptions regarding future developments and business conditions, they are subject to certain risks and uncertainties that could cause actual results to differ materially from those expressed in or implied by these statements.

Known material factors that could cause our actual results to differ from our projected results are described in our most recent 10-K, most recent 10-Q and other periodic filings with the U.S. Securities and Exchange Commission. We wish to caution you not to place undue reliance on any forward-looking statements, which speak only as of the date hereof.

We undertake no obligation to publicly update or revise any of our forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise.

I would now like to turn the call over to Doug Pferdehirt, TechnipFMC's Chair and Chief Executive Officer.

Thank you, Matt. Good afternoon and good morning to all. Thank you for participating in our fourth quarter earnings call. I am very proud to report our strong quarterly and full year results as we closed 2025 with solid operational momentum.

Total company inbound for the year was $11.2 billion. Backlog ended the year at $16.6 billion. Total company revenue for the year grew 9% to $9.9 billion with adjusted EBITDA improving to $1.8 billion, an increase of 33% when compared to the prior year. Full year free cash flow increased to $1.4 billion and shareholder distributions grew to $1 billion, both more than double the levels achieved in the prior year.

Turning to Subsea. Orders in the quarter were $2.3 billion, resulting in $10.1 billion of inbound for the full year with iEPCI projects being the largest contributor of inbound in 2025. There was also continued momentum for new opportunities within existing basins with bp Tiber being our most recent iEPCI contract in the Paleogene. Notably, TechnipFMC has been awarded 5 of the 6 20K projects sanctioned thus far.

The widespread adoption of our differentiated offering has clearly been a catalyst for our commercial success. Over the last 3 years, we delivered on our goal to inbound more than $30 billion of subsea orders. This has driven Subsea backlog to $15.9 billion with legacy projects now representing less than 10% of backlog. Given our expectation for $10 billion of Subsea inbound in the current year, we anticipate further growth in backlog.

Direct awards, iEPCI and Subsea Services represent an increasing share of our inbound. In fact, this combination accounted for more than 80% of our total Subsea inbound in 2025. We continue to be selective in the work that we pursue. We prioritize projects that utilize our iEPCI and Subsea 2.0 configure-to-order offerings. And our services business has been a clear source of differentiation, leveraging the industry's largest installed base. Most importantly, this high-quality inbound derisks project execution, enabling accelerated project timelines and increased schedule certainty.

The inbound secured in 2025 also speaks to a change in customer behavior with more clients adopting a portfolio approach to offshore development. Instead of focusing on the next project exclusively, operators are taking a broader portfolio view of their opportunities, executing a vision for their entire asset base. An example of this mindset is simultaneous development of greenfield assets where operators execute multiple projects in parallel, industrializing the entire field.

bp's approach to the Paleogene is an excellent example, where TechnipFMC is executing the Tiber and Kaskida projects at the same time, utilizing a consistent project methodology focused on our 20K equipment and integrated delivery. To be clear, this is not business as usual. Historically, operators would wait for the completion of the first project to incorporate learnings into subsequent phases. Today, those benefits are seen as incremental to the more substantive improvements gained from a portfolio approach.

By executing as a single unit, operators benefit from integration and standardization that enable them to reach target production more quickly and economically than would be possible as stand-alone projects. This shift in customer focus from a single project to a more comprehensive portfolio view clearly benefits from our differentiation with TechnipFMC's iEPCI model and Subsea 2.0 solutions serving as key enablers of this change in behavior.

The increased collaboration that comes with a portfolio approach also provides us with greater visibility into the project pipeline. Importantly, this early engagement provides us the greatest opportunity to help our customers more efficiently design and develop their entire program. Today, our clients are much more confident that they can build cost and schedule certainty into their expectations, and that is creating additional opportunities for our company.

This change in customer behavior also has a positive impact on the outlook for Subsea. We expect a greater share of capital spending to move offshore, where reservoirs are prolific, high-quality and accessible to many operators with attractive project economics that continue to improve. And we are seeing the impact of this change on our Subsea Opportunities list, with the latest update reflecting the sixth consecutive quarterly increase in value.

The list now highlights approximately $29 billion of opportunities for future development when using the midpoint of project values. This is the highest level ever recorded, and it was achieved even with a significant level of projects awarded in the period. And keep in mind, this only reflects a 24-month view and is not indicative of the full opportunity set for our company.

There are multiple new frontiers under consideration for greenfield development, more than at any time I can remember. Greenfields are unique in that they provide a blank slate. They have no preexisting field infrastructure where legacy architecture and technologies can limit flexibility in future enhancements. This makes a portfolio approach very effective for accelerating development in new frontiers, reinforcing our confidence and continued strength in offshore activity through the end of the decade and beyond.

I now want to close on a few key messages. First, 2025 was another year of exceptional performance for TechnipFMC. And I want to acknowledge the efforts of the 22,000 women and men across the globe. They take great pride in the company and are passionate about what they do. This is evident in our full year results, where continued strength in order inbound drove growth in high-quality backlog and continued strength in execution elevated the expansion in both EBITDA and free cash flow. This team has a strong desire to win and is unwavering in its commitment to deliver.

The second point I want to convey is that 2025 was another major milestone for TechnipFMC, but we are far from achieving optimal performance. We had great commercial, operational and financial success in the year, but the groundwork for these results was set in motion many years ago with our introduction of new commercial models and configure-to-order product architecture and our internal focus on the principles of simplification, standardization and industrialization.

While the impact of these changes is real and sustainable, we are confident that considerable upside remains. And much like our current success, it won't be dependent upon any one driver. We are confident that we will deliver further advancements in integrated execution. We will benefit from an expansion in configure-to-order offerings as we adopt them across more product platforms, and we will deliver greater operating leverage than what has historically been achieved in our industry.

Finally, I want to reiterate our commitment to the relentless pursuit of the reduction of cycle time. The actions we have taken, which are ultimately focused on driving project returns higher, clearly demonstrate our ability to create sustainable value for our customers and real differentiation for our company. We know that our work is not complete. We know that more value can be created. And with a culture focused on continuous improvement in everything we do, we also know that we have the right strategic mindset in place to make offshore investment an even bigger and more sustainable opportunity.

I will now turn the call over to Alf to discuss our financial results.

Thanks, Doug. Revenue in the quarter was $2.5 billion. Adjusted EBITDA was $440 million when excluding $52 million of restructuring, impairment and other charges and a foreign exchange gain of $1 million.

Turning to segment results. In Subsea, revenue of $2.2 billion decreased 5% versus the third quarter. The sequential decline was primarily due to lower activity in the North Sea and Latin America, offset in part by higher activity in Asia Pacific. Adjusted EBITDA was $416 million, down 18% sequentially, primarily driven by seasonally lower vessel-based activity and reduced fleet availability due to higher scheduled maintenance in the period. Adjusted EBITDA margin was 18.9%. For the full year, Subsea revenue grew 11% versus the prior period with Subsea adjusted EBITDA margin up 340 basis points to 20.1%.

In Surface Technologies, revenue was $323 million, a decrease of 2% from the third quarter. The sequential decrease was driven by lower activity in North America and timing of project-related activity in the Middle East, partially offset by higher activity in Asia Pacific. Adjusted EBITDA was $58 million, an increase of 8% sequentially, due to higher services activity in the Middle East and operational efficiencies related to business transformation initiatives. Adjusted EBITDA margin was 18%, up 160 basis points from the third quarter. For the full year, adjusted EBITDA margin improved 170 basis points to 16.7% even with revenue essentially flat when compared to the prior period.

Turning to Corporate and Other items. Corporate expense was $35 million. Net interest expense was $5 million and tax expense was $33 million. Cash flow from operating activities was $454 million with capital expenditures totaling $94 million in the quarter. This resulted in free cash flow of $359 million. Free cash flow for the full year was $1.45 billion.

We repurchased $168 million of stock in the fourth quarter. When including $20 million of dividends, total shareholder distributions were $188 million. For the full year, total shareholder distributions more than doubled versus the prior year to $1 billion. Cash and cash equivalents ended the year at $1 billion. Our net cash position increased to $602 million.

Moving to our financial outlook. We have provided detailed guidance for the year in our earnings release. I will now provide additional color on the guidance and our first quarter outlook.

Starting with Subsea. During the fourth quarter, we incurred restructuring charges related to simplification and industrialization actions being taken to further improve operating efficiency. As Doug indicated, our financial results and operating momentum remains strong, but we know we can achieve even more. These actions will deliver sustainable improvements in 2026 with additional benefits to be realized beyond the current year.

With that in mind, we are updating our previous Subsea guidance provided in October. We now expect revenue of $9.4 billion with adjusted EBITDA margin of 21.5% at the midpoint of the full year range. This implies growth in Subsea adjusted EBITDA of 16% when compared to 2025. For the first quarter, we anticipate subsea revenue to increase low single digits sequentially, while adjusted EBITDA margin is expected to improve approximately 50 basis points from the 18.9% reported in the fourth quarter.

Moving to Surface Technologies. We are guiding to full year revenue of just over $1.2 billion with adjusted EBITDA margin improving to 17.25% at the midpoint of the guidance range. For the first quarter, we anticipate Surface Technologies revenue to decline approximately 10% when compared to fourth quarter results with an adjusted EBITDA margin of approximately 16.5%.

And turning to Corporate. We are guiding to full year expense of $120 million with an expectation that we will incur approximately $40 million in the first quarter.

Lastly, I want to comment on our free cash flow guidance. We remain committed to a very disciplined asset-light approach to capital management. We anticipate capital expenditures to approximate $340 million for the full year, representing just over 3% of revenue. Additionally, we expect full year free cash flow to be in a range of $1.3 billion to $1.45 billion. This would imply free cash flow conversion of approximately 65% at the midpoint of guidance. And as previously indicated, we expect to return at least 70% of free cash flow to shareholders in 2026 through dividends and share repurchases.

In closing, I am very proud that we delivered on our financial targets in 2025. When excluding foreign exchange, we increased total company adjusted EBITDA to $1.8 billion, an increase of 33% versus 9% growth in revenue. We drove strong improvement in adjusted EBITDA margin for Subsea and Surface Technologies with increases of 340 and 170 basis points, respectively. And we delivered growth in total company backlog to $16.6 billion, up 15% from the prior year.

I'm also proud to share our full year guidance for 2026, which reflects continued operational momentum with total company adjusted EBITDA expected to exceed $2.1 billion at the midpoint of our guidance items. This represents growth in adjusted EBITDA of 15% versus 2025 when excluding foreign exchange with margin expansion in both segments. Lastly, we expect strong cash conversion from our growing EBITDA. And given the flexibility provided by our strong balance sheet, you should expect us to return the majority of this free cash flow to our shareholders.

Operator, you may now open the line for questions.

[Operator Instructions] Our first question will come from the line of Arun Jayaram with JPMorgan Securities.

Doug, I wanted to see if you could elaborate on your thoughts on margin expansion potential from industrializing the SURF process. And you talked about this morning in your prepared remarks about delivering further advancements in your integrated project execution. So just wondering if you could maybe shed some light on your thoughts on industrializing the SURF process to drive margins higher.

Thank you, Arun. Look, I'd be happy to. As I noted in, I think, a prior quarter, when we started down the path of industrialization and the configure-to-order product architecture, which we call Subsea 2.0, that was prior to the merger. So we're obviously focused on the assets that reside on the seabed because that what was within the scope of FMC Technologies at the time. As a fully integrated company, we now have access to not only the seabed but the water column in addition.

So that is where our focus is now, is to expanding that configure-to-order applications and all the efficiency gains and all the improvements in terms of reduction of cycle time for our clients and improved project certainty in terms of the delivery of the projects, which our clients benefit from, to the remainder of the subsea environment you're referring to the SURF or, if you will, the water column. I will say this. I think that the opportunities there are as substantial as the opportunities we are experiencing now from the Subsea 2.0 architecture on the seabed.

Great, great. And just my follow-up, Doug, is you mentioned how 10% of your backlog is legacy, call it, maybe lower margin kind of backlog from a few years ago. But as you look at the margins that you're booking in backlog today relative to your Subsea 2026 guide of 21.5% for EBITDA, can you talk about how much visibility do you have on further margin expansion Subsea? How many years of margin expansion do you see when you think about that backlog versus what you've guided to this morning?

Sure. So let me start by confirming that we are inbounding at a level that is accretive to our backlog margin. And that's important. And that will obviously flow through revenue and then ultimately through EBITDA, EBITDA margin. So you will see that. And as you know, we have a substantial backlog already, which is very high quality, and we're adding additional quality to that.

Look, I've said this publicly, I want our clients to win. And if our clients win, they like us to win as well. So this isn't about pricing or this isn't about margin. This is about the relentless pursuit of reduction of cycle time and certainty. If I can sit down with a client and show them that we have the unique capability and the only ones who can deliver them a project on a significantly shorter time frame, accelerating their time to first hydrocarbon and giving them certainty in that outcome, then I share a greater economic value that I create.

So we feel that we have a long way to go in terms of the reduction of cycle time. Remember, this industry, we just started this with the creation of TechnipFMC. We have a long way to go. We talked about it in response to the first part of your question. There's even more scope within our own remit, let alone further innovation that we are working on today as well. So that is our focus. That's what we think about every single day. That's why we make our customers win. And that's why we win as well.

Our next question will come from the line of Scott Gruber with Citigroup.

Doug, you mentioned the renewed interest in greenfield developments. Just wanted to see if you could unpack that a bit more for us. Obviously, hearing exploration mentioned on some customer calls, but just how widespread is the renewed interest in exploration across your customer base and across geographies?

Yes, Scott. I'm going to parse the question just a little bit, right? Because there's greenfield developments and then there's exploration. And you're right to point out, exploration leads to future greenfield developments. But I want to make sure everybody recognizes or appreciates that there are substantial greenfield developments where the exploration has already been done.

These projects didn't move forward for a variety of reasons, including take everything I said to Arun's question in the inverse. The industry wasn't good about reducing cycle time. The industry was not good about certainty in terms of delivery. And because of that, the economics didn't necessarily support those projects to move forward. So we're seeing quite a few greenfield developments that the exploration has been done, that, if you will, have been in the queue.

In addition to that, you're hearing about increases in exploration budgets. You're hearing about new emerging basins being identified, be it the equatorial margin in Brazil. We're hearing about Colombia now. I mean, almost every day, we wake up hearing new news of new opportunities in the offshore environment. We would humbly like to think that's because we've given our customers the confidence and the ability to go back and really scrub that portion of their portfolio or their reserve base and look for those opportunities.

So really, Scott, they're quite global in nature. And I'm only parsing the fact that this isn't about waiting on seismic and waiting on exploration drilling. That's happening and that's good because that will continue to feed the hopper, if you will, and I kind of referred to that when I talked about through the end of the decade and beyond. But as importantly, there are opportunities out there that are being accelerated right now, and we have the tools and the kit and the ability necessary to accelerate those developments for our customers.

I appreciate that. And then a quick follow-up on Arun's question around the SURF standardization. It sounds like there's a big opportunity here, and I remember having a detailed discussion with you maybe a year ago or so about it. And I know this takes a while to execute on. But where do you stand in that process? And kind of how much more is there to go?

Yes. I thought I was going to get away without committing to it, Scott, so thanks for circling back.

Well, I wasn't going to let you.

That's fair. Look, we've been working on it for a bit. We're impatient. Our customers are impatient, and that's a good thing. But we want to make sure we do it right. But look, there will be more to come and we'll be excited to share that news with the industry.

Our next question will come from the line of Mark Wilson with Jefferies.

I'd like to ask, Doug, about the point you make about you see considerable upside still. And just to check how clearly returns have been coming through. Margin has been improving. Three years now of $10 billion inbound in Subsea and another $1 billion to come and more opportunities in greenfield than you've ever seen. So could I ask regarding the volume you see able to continue to do going forward, considering that CapEx also remaining just 3% of revenue?

You spoke in the past about no expansion to roofline was a key element of previous years. In terms of the capacity that's within this business, should there be more of a response beyond, I don't know, the $10 billion level? How much volume capacity do you think there is within your existing setup? And I think I particularly speak to the Subsea 2.0, if that's done at 2 of your 3 facilities.

Thank you, Mark. I definitely knew I wasn't going to get away with this one. So it's a fair question, and let me give you a direct response. So as you pointed out, we've had a healthy rate of inbound. We've had $30 billion over 3 years. We just now reaffirmed the $10 billion for 2026 but we're also showing a Subsea Opportunity list that is really expanding at a rate that we have not seen before.

If you look at the number of projects that were awarded in this quarter, i.e., they came out of the Subsea Opportunity list, we're talking about the net increase. But if you look at the gross increase, it was quite substantial and there's others to come. So as we look forward, and you're right, you're hearing this from our clients, which is more important. We're just basically gathering that information and sharing that with you. Their focus is on offshore. Their focus is on developing offshore reserves. Their focus is on adding reserves by focusing on offshore opportunities. And again, we're seeing that happen around the world across our client set.

And as we've talked about before, our client set has expanded quite dramatically 3 to 4x what it was historically. There's many new companies that are operating and performing offshore subsea developments enabled by the simplicity and the ability to work with one company, TechnipFMC, in an iEPCI 2.0 direct award manner.

But if I really kind of encapsulate your whole question and, to me, what it really comes down to is, is this $10 billion a magic number? Or where do we go from here? And I want to be very, very clear that the Subsea Opportunity list is both growing and accelerating, and we fully expect that this will be reflected in inbound order growth in 2027 and beyond

Our next question will come from the line of Derek Podhaizer with Piper Sandler.

Doug, I wanted to go back to your comments around your portfolio approach, specifically bp's Tiber and Kaskida. Maybe could you help provide us with tangible examples of how Tiber is leveraging the engineering and equipment progress with Kaskida to help drive down cost and increase your efficiencies? Ultimately, just trying to understand more what this means for your earnings power and margins moving forward, if you have more of this portfolio approach from your customers.

Sure, Derek. And look, all the credit goes to bp. We're humbled in order to be their partner in the Paleogene. I want to start with that. Working together in many, many discussions, we came to the conclusion that there was a different way of working than the historical way of working together. And when we looked at it, we knew we wanted to go towards standardization. We knew we wanted to have repeatability, the old saying, design one, build many.

But when you have large gaps of time and distance in between projects, when you introduce new project directors on both sides, our side, their side, when you introduce new engineering teams, both sides, our side, their side, et cetera, et cetera. And then you get into the supply chain and you're dealing with the supply chain that you turn on, you turn off, you turn on, you turn off, you're never going to get those efficiencies.

So bp decided to take a very different approach. We are extremely humbled and honored to be part of it. I don't want to get into, if you will, the dollar savings because I think that would be not appropriate for me to do. That's more bp's business. But they clearly are benefiting.

We clearly are benefiting as a result of the ability to be able to have continuity, visibility and continuity into our own manufacturing, also being able to have 1 single project team instead of sending up 2 teams and in the supply chain because our suppliers benefit from that visibility and that continuity as well. So again, I don't like to talk about margin. I'd like to talk about improving Subsea project returns, which benefits our customer and also benefits us.

Got it. No, that's very helpful. I appreciate that. And then maybe on Subsea Services, clearly a differentiator for the company. I think you previously guided that it should grow in line with your top line growth, which we have the guidance on. But maybe could you touch upon what your expectations are for the Subsea Services side of things? Is this an expectation around $1.92 billion for the year? Just maybe some more color and help on how we should think about services as we look into 2026.

So again, in line with revenue, so let's call it $2 billion.

Our next question will come from the line of Victoria McCulloch with RBC.

Just one for me on Surface Technologies, I guess, to slightly discussion, but a similar theme. You've seen a material increase in the margin over the past 12 months in Surface Technologies. You attribute it in the presentation to operational efficiencies. This is what you spoke to us about a year ago. But can you give us an idea of how this compares to your expectation and how this was delivered? And again, on that, on Surface Technologies, how much more is there to achieve there?

Look, very proud of the segment. As we talked about in a prior call, we took a decision to really look at that business, make some tough decisions, really focus on the right customers in the right geographies utilizing the right technologies, so if you will, high-grading our portfolio. That isn't a business, when you focus on market share, that ends up very well. So we took a different approach and we said, look, we're going to focus on quality, not quantity, and we're going to high grade our portfolio.

We've done that. It's performing very well, as you can see as a result of that. There were some incremental benefits in Q4. But as we move forward, we expect this segment to continue to operate at a very high level. It's now 65% of our business in Surface Technologies is in our international portfolio. We continue to benefit from the investments that we've made both in Saudi Arabia as well as in Abu Dhabi in terms of local content, local manufacturing. And so yes, that's how I would summarize.

The outlook remains difficult because of the North America market. But we obviously benefit from the strength of having the majority of our portfolio outside of the North American market.

And maybe just a follow-up to look at Subsea. Can you talk to us a bit about how your discussions with customers have been in a very choppy macro environment, but then reflecting how there is greater CapEx moving offshore? And we are seeing pressure certainly, and discussion points around resources and reserves alike.

Those are conflicting, I guess, points but more is being added to the Subsea. Do you think that potentially the market is more caught up in the stock pricing than your customers are when they have discussions with you? And how much does that benefit TechnipFMC from a, I guess, pricing perspective?

Sure. I would describe it this way. One of the benefits of being in the offshore market is our customers -- some of that near-term choppiness, if you will, is smoothed out. They understand, these are prolific reserves. These are prolific reserves. So when they're going after these, they have a denominator that's much different than any other investment opportunity they have in their portfolio.

So all that they're looking for is obviously a forward view of the commodity price and a confidence in the ability to execute the project both from their team as well as from the industry. And this has been the biggest change that has occurred in the last several years, is they have regained their confidence because of what we have created with TechnipFMC with the Subsea 2.0 configure-to-order product line and with our commitment to them and to the investment community of our relentless pursuit of the reduction of cycle time.

So we don't talk about price. We talk about improving project returns, which benefit our clients. As I said earlier, if it benefits our clients, it benefits us. And once you get that mindset and you get out of a fixed asset mindset of day rate utilization and pricing, you can really change your conversation with the clients. We have a seat at the table far earlier than anyone else, and they give us visibility, now as they look and take a project approach, that is unprecedented because they like what we're doing and they want to make sure that they have the access to our iEPCI 2.0 solution, which leads to this level of direct awards that is now over 80% of our business is direct awarded to our customer and never goes out to a competitive tender.

Our next question will come from the line of Dave Anderson with Barclays.

This is [ Eddie ] who came on for Dave who had a prior commitment this morning. Doug, you mentioned operators are increasingly taking a portfolio approach to their opportunities. Of course, this provides you with greater visibility on Subsea orders. But does this also maybe result in more content with this approach, where developing 2 projects simultaneously results in more content for you than if developed one after the other?

And do you expect more companies to start to adopt this portfolio approach going forward? Or is this really limited to a few select majors?

Sure, Eddie. Thank you. In regards to the approach, you're on to something. Very astute. Remember, we're the architects. So when we're talking about either a portfolio approach or an integrated FEED study leading to an integrated EPCI study, we are the architects. Now we will always design the field to ensure the best suitability for the reservoir, the best in terms of the relentless pursuit of reduction of cycle time.

But clearly, we are going to make sure that if we have any technologies that are applicable that are going to help meet those objectives, that we're going to incorporate those into the architecture. So the benefit of being the architect and the builder, if you will, it's pretty clear that there are benefits of being able to do both. And we're uniquely positioned as the only company that has the capability to do both. So that's the position we're in. So yes, to your point, it does create opportunities.

Now in terms of the portfolio approach, look, you have to have the asset base, right? So not all clients have a reservoir that has a clear line of sight to doing multiple greenfield developments. Sometimes it's a one-off development. And that's absolutely fine. That's absolutely normal.

But where clients have the ability to do multiple greenfield developments within a area, if you will, it's certainly applicable to any client. And bp is not the only one. I thought it was appropriate to pass the message about bp and what they're doing to Paleogene because it was a recent award, and I do think it's appropriate to do so. But others are looking at the same approach.

Got it. So a number of signs pointing to a 2027 inflection in offshore activity that seems to be reflected in your growing Subsea Opportunity list. But could you talk to customer behavior and what you're seeing from them? You've consistently mentioned sort of this growing shift of capital into offshore. I guess what innings do you think we're in, in terms of operators shifting capital to offshore? Just wanted to get your sense of if most operators are already there at this point or if we're still in the early stages of this capital shift into offshore.

Good question. And I don't want to answer on behalf of my clients. That would be inappropriate. I'm a service guy, I always have been. I know where I am in the food chain. I would just look at their behavior. And I think what you're seeing in their behavior is they are in the very early stages and they see a long runway ahead.

Our next question comes from the line of Caitlin Donohue with Goldman Sachs.

Doug, you mentioned the iEPCI and Subsea 2.0, representing a good portion of total Subsea in orders in 2025. Can you speak to your long-term expectations for this continued adoption? How do you see this flowing through to further margin expansion over the next few years?

Great question, Caitlin. We've identified -- we said that the iEPCI was the majority of our inbound orders this past year, which is really quite substantial. A new product architecture like Subsea 2.0 figure-to-order, introducing that into the market is one challenge. An even greater challenge is when you change the commercial model. So look, there was a point in time -- it was a few years ago admittedly.

But there was a point in time where I said if we could achieve 1/3 of our orders from iEPCI or the integrated approach, that would be substantial. We're obviously well beyond that. And when you look at the different applications around the world, neither iEPCI or Subsea 2.0 have any sort of a technical limit or commercial limit that they both couldn't go to 100%. What I did allude to in my prepared remarks, though, is in legacy fields, is Subsea 2.0 backwards compatible? Yes. Is iEPCI applicable in brownfield, greenfield, emerging markets, mature markets? Yes.

But sometimes you will find customers who just want to either repeat the past because it's a small tieback and maybe the last activity in that field or that region for them. So I think there's always going to be a percentage. But Caitlin, it's a fair challenge. And I think that we certainly approach every opportunity as iEPCI 2.0 until proven otherwise. And you will see and continue to see both iEPCI and 2.0. As a result of that, you'll see iEPCI 2.0 continue to grow in our inbound.

That's helpful. And then just one more question on the Subsea 1Q revenue guide. I know it's the increase sequentially of low single digits. Is that just more of a comment on a little bit less of that muted seasonality we're seeing in 1Q as a result of some of these macro factors? Or there are certain regions that you can call out that you're really looking out for some of this increased activity through 2026?

Sure. I'm going to give that to Alf and he'll get into that detail. But if you don't mind, I'd like them just to first kind of summarize the revision to the 2026 guidance because I don't want that to get lost on the call. It was an important element.

Thanks for the question. So first of all, just to summarize, we did raise Subsea guidance, as you probably all noted. It's an important piece of reaching company EBITDA for the year. The adjusted EBITDA, we expect to be -- adjusted EBITDA, about $2.1 billion. So that is built on a lot of the things that Doug talked about already. We clearly achieved our inbound objective in 2025. We have a growing opportunity list. We are committed to $10 billion and have a solid path to that. The high-quality backlog, all of those things come together and gives us confidence. And then the Subsea Services revenue and growth on top is giving us a $2 billion business.

So we thought it was important, as we were overall initiating guidance for the company, to update this. If you look at the margin profile of Subsea, and again, I want to point out that we are introducing through the restructuring charges we've taken this quarter, we're initiating actions, and we are further taking actions in 2026 to further boost our margin expansion, not only in '26 but also beyond. And I think with what Doug said, we are very focused on driving revenue and margin expansion into the years beyond 2026.

Regarding the Q1, it is definitely what you were talking about. There is nothing big happening or anything structural that you should think about more than the seasonality. We continue to have 2 quarters a year, where several of our vessels in our fleet is either drydocked. They might be in for maintenance or some sort of upgrade and taking advantage of the slower period, in particular in the North Sea area. And that's what you see pronounced, and you will continue to see some of that in the first quarter. But there is nothing really otherwise.

The underlying run rate of our Subsea business is very strong. And then coupled with all the things that we already said about our outlook and our ability to expand margins, we're confident in the overall guidance that we have given for Subsea.

Our next question will come from the line of Mark Bianchi with TD Cowen.

Doug, I'm going to ask you if you could to quantify two things to the extent you're able to. So first, on this portfolio approach that you're talking about and working with the customers, can you maybe help us understand how much of the sales funnel of opportunities that you're looking at? And I realize we've got the Subsea opportunity slide and then there's like all these other discussions that you're having that might not be on the slide.

So if you sort of take that together, is there a percentage of the stuff that you're discussing with customers that would be part of a portfolio approach? And then as we think about $10 billion of orders this year, more than $10 billion in '27 and beyond, what proportion of those orders would be coming from the portfolio approach?

Yes. Mark, hard to put a hard number on it only because, as I said earlier, it depends on the client and it depends upon their portfolio in that particular geography, if you will, because when you do the portfolio approach, it's more focused around a particular reservoir or a particular geography.

So I would say today, it's a smaller portion, but it's something that our customers are responding well to and, I think, looking at their own future developments,and seeing where and how it could be applied within their own opportunity list. So I guess that's the big difference, Mark, is we're sitting down looking at their opportunity list instead of, as we were in the past, sitting around waiting to receive a request for tender. So very different seat at the table than we used to have.

Yes. Okay. That's helpful. And then the other thing to quantify, and this is really just to maybe level set and understand. You talked about 80% of the orders being direct awarded, right, so with services and iEPCI and so forth. How much of revenue is coming from direct awarded projects maybe in '25, '26 and '27? Just so we can get a sense of the progression on the revenue side and maybe versus what the order percentage is.

Sure, Mark. So I think if you go back just a couple of years, we used to talk about 50%. I think 2 years ago, maybe 1 year ago, we started talking about 70%, this year, 80%. Projects take 2 to 3 years to flow through. So I think that gave a pretty good road map, and that's obviously going to benefit us going forward.

Our next question will come from the line of Saurabh Pant with Bank of America.

Doug, maybe I'll just dig into the whole Subsea Opportunity list discussion. The one thing that I'm noticing, Doug, is that there are more and more projects that are gas-directed versus just oil-directed, right? We remember a decade back, anybody struck a big gas reservoir, it used to be a disappointing moment, right? But we are more and more developing these bigger reservoirs that are part of the opportunity list.

But for you as the subsea architect, how much difference does it make if a project is oil versus gas? Is there any revenue intensity impact? Anything we should read into the complexity and, by extension, margin impact potentially down the road from just the whole oil versus gas dynamic in subsea?

No, it's a great observation. It actually is something we internally had anticipated would happen a bit sooner than it has happened. But we are seeing a shift towards gas, and that's partly driven by there was quite an expansion in terms of LNG capacity around the world. That's slowing down but you got to feed that. And I guess, the dots that people don't necessarily connect is other than in the U.S. and Russia, almost all LNG is fed by offshore reservoirs, not onshore reservoirs. That's a generalization but it's directionally correct.

So okay, two things happen. One, you have to develop the offshore assets therefore to feed gas. But then over time, you now have a massive investment in an LNG facility. You have to continue to feed that with gas. So you almost commit yourself to continuing doing subsea developments offshore once you build that LNG facility. So we see that happening around the world and we're obviously a beneficiary of that.

In terms of gas versus oil, we love everybody equally. That being said, a gas tree tends to be as a higher unit cost than oil tree, and it typically has to do with a more corrosive environment and the velocities that we need to be able to control and operate safely in a subsea environment. So net-net, a gas equipment tends to be more complex. It's better for us because it's more differentiated, and that's who we are. It fits better. It just creates even greater differentiation versus the rest of the industry.

But either way, we'll take either one. We're just here to help our customers reach their objective.

Got it. Right. Okay, okay. That's fantastic color, Doug. And then Alf, maybe one for you on the whole free cash flow discussion. Like you said, '26 guidance implies 65% conversion out of EBITDA at the midpoint. But we were talking about orders. Working capital is a big part of it, right? So if orders start to inflect again from that $10 billion annualized run rate in '27 and beyond, working capital should be a tailwind, again, just how you get paid from a timing perspective, right? So are we looking at a prolonged period, 2 to 3 years, where so free cash flow conversion out of EBITDA is going to be higher than that 55% working capital neutral number we were talking about on the last call?

Thanks for the question. So first of all, your observation is correct. We've had, first of all, a really strong and exceptionally strong free cash flow generation this past year, I think our cash conversion is actually mathematic close to 80%. And it is, in terms of the foundation for this, is always going to be both commercial and operational execution towards your goals. And that is the foundation of improving our working capital.

Now we are setting ourselves up for another strong year. We are clearly improving working capital once again from the same variables that I talked about, the commercials and operational side. And as well, we couldn't forget that our CapEx is being kept at a 3.2% level. However, having said that, looking out several years, there's always a mix of orders, et cetera, so you can never fully predict.

But in general, if we are able to continue to have good commercial success in terms of how work is falling into where we have commercial strengths to realize and, as well, we need to execute on this because it's not just commercial we'll be setting up, we need to execute on this. There is opportunity to continue this. But I would caution against just assuming that you can in perpetuity keep putting up better and better working capital numbers. Because every year, you start at a better position, and you need to improve from there.

And there are still, from some of the cash that you're collecting, you still need to execute, and that creates timing of where outflows could be higher. So I won't speculate out more, more than say that '26 is going to be a really, really good year where we improve working capital again. But I still think we need to focus on the neutral when we look in the very long term.

Yes. No, that makes sense, Alf, right? I mean, the whole point is that yours a very low capital intensity business, right? So on a through-cycle basis, your free cash flow power would be really strong. That's what I wanted to just get into.

Yes. Thank you. Clearly confirmed.

Our final question will come from the line of Paul Redman with BNP Paribas.

You mentioned earlier that you are the only company that is an architect and a developer. But I also wanted to ask, what are the risks about replication on iEPCI or Subsea 2.0 with your competitors? Because a company generating such fantastic margins growth, growth in backlog, you'd assume that companies would like to pick up and think about how, we could possibly challenge this. Are you seeing any actions by customers to copy what you're doing? Is it copyable?

Sure, Paul. The short answer is it's difficult. Many years ago, back in 2017, I said it took us 4 years, so kind of an idea of how much detailed engineering program it requires. Look, can others do it? Yes. We have never said we're the only ones that can do it. We were the only ones who chose to do it. We chose the path of integration while either our others have chosen a path of consolidation. Just a difference in strategy. We're going to stick with our strategy.

And I will now turn the call back over to Matt Seinsheimer for any closing comments.

Thank you. This concludes today's conference call. A replay of the call will be available on our website beginning at approximately 3 p.m. New York time today. If you have any further questions, please feel free to reach out to the Investor Relations team.

Thank you for joining us. Regina, you may now end the call.

This does conclude our call today. Thank you again for joining. You may now disconnect.

All right. Good afternoon, everyone. Thank you for joining us today. We've got Doug Pferdehirt, CEO at TechnipFMC with us. Doug, thank you for taking the time.

Doug, the first question I wanted to ask is, FTI has been the poster child of services for all of last year. Stock has done really well. The multiple has rerated. There were some order concerns halfway through the year. Those order concerns have largely gone away. As you think about '26, as you think about the messaging for investors, what is the strategic focus point for you? And what would you want to highlight?

Sure. So first of all, thank you for having us at the conference. Thank you to Goldman Sachs, and thanks to everybody here in the audience as well as thanks for those that are joining via the webcast.

Look, very proud of the accomplishments in '25. I mean we're not publicly reporting yet, but clearly, '25 shaped up to be a very good year. Proud of the 22,000 women and men who delivered those results and continue to deliver those results. We've already gone out with guidance for 2026. We did that back in October, demonstrating in our subsea business, further growth in revenue as well as EBITDA margin and therefore, a compounding growth to EBITDA dollars. So a high level of confidence again in 2026, something that we remain very proud of and very confident in.

Look, this is a company that had to redesign itself, had to reengineer itself in order to make the offshore segment interesting again to our clients. And it's just about grabbing part of that capital flows and making sure that, that those capital flows are going into the offshore market. The way that we do that is by showing the ability to have the relentless pursuit of reduction of cycle time, which shows up for our customers in terms of acceleration of time to first hydrocarbon, improving their project returns, whilst at the same time for us, allowing us to share a greater portion of the economic value that we create, and that shows up in our margins, and it also shows up through the internal efficiencies that we've gained as a company.

To do this, this was a 10-year process. We actually started back in 2015, where we entered into a joint venture, which we call Forsys Subsea to really understand the value of integration in the offshore market. We consummated a relationship with Technip in 17th of January 2017, so many years ago in terms of creating this new entity, which would have the capacity, the capability to be able to deliver these integrated projects offshore, removing waste, removing interfaces, improving certainty of outcome.

At the same time, we redesigned the subsea architecture called Subsea 2.0, which we went and we designed a configurable architecture where our customers still get the choice of what they want at the end, but it's based on a set of pre-engineered components at the subcomponent level. So what we did by doing that was we went from a bespoke environment or an engineer-to-order environment where we were doing everything for the first time. That would include 9 to 12 months of engineering before we could even cut the first shaving off the block to now going straight into assembly and test, much like the automotive industry does.

So what we're seeing now is our customers have acknowledged and recognized both the Subsea 2.0 architecture as well as the integrated projects or iEPCI and the value that they're creating by reducing cycle time and increasing certainty. And it's that increasing certainty and improved economics that are giving them the confidence now to shift ever-increasing amounts of their capital flows to the offshore market, where we are the primary beneficiary of that.

That trend is in its early stages. We expect that to continue. We have a long runway ahead of us in terms of cycle time reduction, and our customers are, therefore, going to benefit from continuous improvements in their subsea project economics, and we benefit as well internally. So we've created a real win-win dynamic, which is unique in the industry to be able to do that.

So I think the setup is very strong for our company. There's a lot of runway ahead for us to achieve even better results with a proven model. So you have the certainty of a model that's been proven that's been accepted by the shareholder base. And now you have a company that has many opportunities to enhance and improve that going forward.

The one number that I'll say now, and I'll probably repeat at the end, if I remember, is 80%. 80% of our business is direct awarded to our company, never goes out to a competitive tender. To me, that really speaks to the differentiation and the success that we've created.

Doug, this is something that we were talking about last night as well. I want to ask you on FTI, the stock has done so well, everyone, the most important or most topical inbound for us is stock has done really well. Offshore activity might be picking up in the second half of the year and into '27 really. So the rate of change in some of the higher beta offshore service names might be higher. But we were talking about this yesterday. Do you want to talk about that dynamic? What would be your pushback to them as you think about the relative positioning?

Sure. And I'll probably get in trouble for this. So let's just have a little bit of fun. And I'm not here to sell anybody else's equity, and I'm obviously biased. I believe in going with the winners. And I don't know how more directly to say it than that. And I think you're not betting on a portion of the cycle. This isn't a cyclical bet. You've got a company that has redefined, reshaped itself. The industry around us has reshaped itself. It is a very unique market that has a growth element that we just discussed, that has a very different market structure than it has in the past with a company that is getting 80% of its business direct awarded by the customers because the customers see the value that we're providing to them. There's a reason for that, and it's substantial.

So to me, I don't want to get into picking one part of the cycle or not. By the way, happy everybody is excited about offshore again. So let's just start with that, right? There was a point not so long ago,where there was a lot of [ skepticism ] about the offshore market. So the fact it's -- if you want to play the offshore, go for it, I think you're doing the right thing. Obviously, I'm biased. And I think if you want to have the most successful -- be the most successful in that investment, I would go with the proven entity that's got the winning track record. And it's not -- I mean, there's a lot more to go.

I think if you believe that we have achieved the level of full optimization or we can't improve upon where we are today, then I would understand an investors' sentiment and maybe looking at other opportunities. I think that would be a mistake because there's a lot more to go at FTI.

Doug, you've previously spoken about offshore economics improving quite a bit over the years. You've played an important role there in terms of the efficiencies that customers are getting. Are you a little surprised looking at how resilient U.S. production has been? Is there anything that you would want to highlight there, maybe your time line lag because that's what we're hearing from some investors or some companies as well? And how do you think that changes? Or does that impact the way you think about the economics, relative economics at all?

Yes. No, look, I'll let others talk about the North American market. We work in the North American market, but it's only 10% of our business. So I want to be fair, let others talk about the North American market, the resiliency element of it, whatever angle you want to take. We're just looking at it in terms of capital flows. And clearly, the reservoirs offshore are much more prolific. They have a much lower decline rate and therefore, the project returns are substantial.

The reason why the offshore kind of took a step back was the emergence of the U.S. unconventional and some of the early economics of the U.S. unconventionals, but more importantly, because of the deterioration of the offshore project economics. That was our fault as an industry, and we were part of that, and we have to hold ourselves accountable. That's why we reinvented the company. Everything I talked about in the opening, that's why we did that because we observed that through our own performance and the performance of those around us, we were leading to a deterioration of offshore project returns. And clearly, the customers were going to look for other flows to other capital flows for those due to that deterioration of economics. It just so happened that the U.S. unconventional appeared at that point in time, and that became the transition.

So look, we look at it very simple. We have to beat the economics of U.S. unconventionals, which we do today. Clearly, we do today. Our customers have -- it's demonstrated by our customers' order flows. And we're going to continue to work really, really hard to further improve those through greater efficiencies and shorter cycle time as we move forward.

You have a strong position in Guyana in Brazil. Do you want to talk about the region-specific outlook that you're seeing? Anything that you would like to highlight from a frontier region that could be new people are not talking about and just regional color in general?

Yes. There's quite a few. Maybe we'll just kind of go around the world a little bit. So look, let's start in Brazil. Many of you have heard about the equatorial margin. This is extremely exciting. It is a whole incremental leg of growth. I would call it -- it's a new frontier, not new -- it's not a new country, but a new geography within an existing -- obviously, within an existing offshore producing country. And Petrobras is extremely excited. We're extremely excited. All indications from the seismic are it could be very meaningful. Obviously, the exploration needs to be done. That's underway now, and we'll learn a lot more from that. But that's a region that we focus on and is a very important region to our business.

You mentioned Guyana. I still think of Guyana is emerging. I think it's phenomenal what ExxonMobil has done because it's also now almost thought of as a mature basin. And if you look at the time line in which ExxonMobil has achieved what they've achieved in Guyana, it is just hugely successful and unprecedented. We are humbled and honored to be part of that. We do all of ExxonMobil's work in Guyana, and it's been very important to us, and we continue to demonstrate exemplary performance there and be rewarded by ExxonMobil in terms of continued direct awards in Guyana.

Suriname. Suriname Block 58, now called GranMorgu with TotalEnergies. We're very proud to have been to receive that award, IPCI 2.0, first project in Suriname. We are anticipating additional projects in Suriname. There's other operators who are looking to potentially FID projects as well as Total looking at their portfolio now in Suriname. So that continues to be very interesting as well.

If we shift across the ocean, West Africa will continue to surprise to the upside. It's been a bit quiet. I will acknowledge that, but I would be aware of the fact that there could be some substantial moves in West Africa in terms of incremental activity. The Eastern Med as an emerging entity continues to be quite strong, and that goes anywhere from Israel, Cyprus, Egypt, all continues to be quite meaningful in terms of offshore, and it's gas on top of that.

If we go to the East Africa, Mozambique, I think at this conference last year, I said there's been one project. Don't be surprised if there's multiple projects. Well, there's now multiple projects going on, a second project for ENI and an initial project for Total, which we're participating in both and very honored to do so. And I think there will be further activity in Mozambique, also a gas region.

The Norwegian sector of the North Sea remains very active, again, supplying gas to Continental Europe. And then when we look at Asia Pacific, it's really about Indonesia. Indonesia, again, gas, very interesting, multiple projects being tendered at this time, projects underway, but also multiple projects being tendered by multiple operators. And I think Indonesia will remain very active and very strong. And then back here in the Gulf, we have the Paleogene, which continues to be, I'll be candid, it's moved at a faster pace and a faster cadence than I anticipated. We've done multiple projects or are currently doing projects for multiple customers. We're producing 20,000 into Paleogene today.

And just last night, we were awarded from BP, a direct award for the Tiber project, which follows the Kaskida project, which we had received earlier. So yes, several areas to be very excited about. There's a couple of other countries I haven't mentioned that are maybe even beyond that.

Well, I'm sorry, I skipped over Namibia for China. Namibia, we're actively tendering in Namibia today. There will be all reasons to believe that there'll be multiple projects in Namibia. So yes, and then even beyond that, there are some other countries that will potentially come into the offshore mix.

So where at one point, I think there was a perception that it was like limited in terms of the opportunity set, I would call the offshore opportunity rich as we sit here today.

Doug, on Brazil, in particular, we've been hearing some inbounds and concerns around maybe the longer-dated activity levels are under question, under review because of budget constraints. There were some news on platform support vessels being retendered. Is there anything that is that could potentially spill over? Are you hearing anything that would impact the way we think about Brazil today?

Brazil in specific?

Specifically, yes.

No, nothing in particular.

Nothing to highlight there?

No.

Cycle time reduction has been a very important focus area for you. You've talked about how that works with Subsea 2.0 as well. How far are we there? Like how much more do you think we can do in terms of the industry level? And how do you think about your role there?

Yes. Look, thank you for asking because I think it's an important takeaway from this discussion. Our order our orders for Subsea 2.0 -- Subsea 2.0 represent about over 50% of our orders today. It consumes about 1/3 to 40% of our manufacturing capacity today. So we're benefiting as it flows into orders and through execution. But those orders continue to grow beyond the 50%.

But when we talk about that, the original Subsea 2.0 was all about the seabed architecture. We often talk about subsea trees, but there's a whole city on the seabed supporting those subsea trees. But Subsea 2.0 was really about the seabed. After the merger and the creation of TechnipFMC, we now have the opportunity to look at the water column, which is umbilical risers and flow lines as well as the vessels and the installation process, which neither of those have been addressed by Subsea 2.0 as of this date. So that is extremely exciting for us.

So if you put that into rough terminology, I'm a hockey fan. So let's go with a hockey analogy. We're just finishing the first period. We're in the first period in our mission. So in other words, we're about 1/3 of the way there. There's about 2/3 of opportunity-rich data set within our own scope for us to now industrialize using the Subsea 2.0 model. It's why I remain convinced that we can continue to reduce cycle time in the offshore, which our customers benefit from improved project economics.

Doug, from that perspective alone, as you think about the other components, the order number that you've been talking about at $10 billion for '26, for instance, in the last few years, is there a way to think that, that that $10 billion number as a result of what you just said is very sustainable? Or is there a little bit more upside to that? How should we think about the order impact as you go beyond just the tree?

Yes, we just gave 2026 guidance. So I don't want to get too far ahead of myself. But look, we do believe it's sustainable, and I will say it, we do believe there's upside. So let's see how it plays out. I think the fact that it's been pretty steady around $10 billion, don't read -- it's a point in time kind of thing. I wouldn't read too much into that. We gave an objective -- or we gave guidance of $30 billion over 3 years. It happened to come pretty close to $10 billion, $10 billion, $10 billion, but it could have been $8 billion, $12 billion and $10 billion or any combination thereof. It just happened to be relatively stable. It's not a sign of the total market size. It's not a sign of any capacity constraints on our side or the supply chain side. It's just the way that it's actually materialized.

But from everything we can see today, the conversations we're having, the visibility that we have because we're not just designing the equipment and installing the equipment, we're back at the architect or the FEED or pre-FEED phase. So we're doing those projects in conjunction with our customers sometimes 2 years before they FID the project. So we have a lot of visibility out beyond the end of the decade, out beyond the end of the decade today, which is why we can say -- which is why I can say with a degree -- with a high degree of confidence that we believe that, that's a sustainable rate or greater.

Okay. On the margin side, Doug, I think throughout the year, we've spoken about various components that could add to the margins, whether it is increasing revenue contribution from Subsea 2.0 or there's internal optimization. Do you want to talk about what those components are, how we should think about margin expansion in general?

Sure. So look, internally, we believe as a company that we have not achieved optimal performance. And I know that probably is surprising to hear somebody sit up here and say that, but it's true. And I think we will never achieve optimal performance. And if we take that mindset to work every single day, 22,000 women and men, we will find opportunities. It may be hours, it may be days or it may be weeks to do a certain task more efficiently. But if everybody is pulling on the same end of that rope and saving hours, weeks or hours, days, weeks, it's a meaningful impact to the company.

So we benefit from this whole lean methodology that we've applied across the entire company. We don't look at it just as a manufacturing -- from the manufacturing processes, which is how most companies do. We've actually used it to change the culture of the company, and this is the success that Toyota has had with it in the past. We've been working really, really hard to take this and make this part of our culture, and we've achieved that.

So we now have this element of looking for savings, meaning efficiency gains, which results in savings, which results in margin expansion across the organization every single day with every single person performing the task that they're doing. It also allows us to grow the company without having to do consolidation, without having to do large-scale capital investments. It does wonderful things to your returns in terms of -- it shows up, obviously, in the ROIC of the company to be able to grow while maintaining a very stable discipline around capital expenditures and not requiring M&A for growth. This is what we've created. We're seeing the benefits of that today, but there's a lot more to come.

Doug, would you add anything incremental on the Subsea 2.0 adoption rate? I know that it's been increasing, and you've talked about the mix in orders versus mix in revenue. But are you seeing further adoption to the point where you could get to 100? Where are we today?

It's a fair question. And I have this debate internally within the organization. So let's start with the first part, and then we'll talk about the 100%. To me, one of the most reassuring or complementary things about Subsea 2.0 is we've never had a customer that went with Subsea 2.0 that ever went back. That says a lot. That says a lot. So once they adopt, it's very sticky. It's very sticky, which means direct awards to our company because we're the only ones with the Subsea 2.0. So that's been very rewarding, and it demonstrates that they see real value in the Subsea 2.0 architecture.

Where is there upside? Look, there's upside as we move these projects into the Life of Field services. There is a whole benefit of Subsea 2.0 to Life of Field. And when I say a benefit, I always think of my customer and ourselves. There's a benefit to the customer because the customer gets the leverage the same installation tolling assets and work over assets that they have to buy for their subsea equipment.

If they have Subsea 2.0 in multiple geographies, they can share the installation tolling. It's a benefit to them. It's a benefit to us in terms of our ability to be able to be more efficient and generate a higher return from those assets. So as an example, we'll see that benefit in our Life of Field services.

We have continued to see customers adopt Subsea 2.0 to where it's a very significant percentage now, approaching 100%. I don't know that we'll achieve 100%. And I don't know that, that's a bad thing because there will always be some nuances and some reasons to maintain some 1.0 capability or bespoke capability. But let me be clear, we will not allow that to disrupt the flow and the efficiency of Subsea 2.0. So if we retain 1.0 capability, it will be located to a specific line in a specific geographical plant. So we have Subsea 2.0 plants that we won't introduce 1.0 into because if we do that, it disrupts the flow and you lose all those efficiency gains or it disrupts temporarily those efficiency gains we talked about.

So if we maintain 1.0, and I think we will for some period of time, it will be isolated and contained, and it won't disrupt or dilute the progress we've made in Subsea 2.0.

That's very helpful, Doug. As we think about the $10 billion orders for '26, is there anything you can talk about in terms of the mix? I want to get to the Life of Field services as well because the service aspect also has unique growth drivers there, but maybe we start with the mix, if there's anything you can provide.

Sure. So look, at a high level, I think we'll continue to be pleasantly surprised, and I'm speaking to the community at the level of greenfield awards in 2026, much like we had in 2025, representing -- continuing to represent a significant portion of the overall awards. I think you'll start to see some incremental brownfield awards, and you'll start to see those in geographies that will -- that are relatively new in terms of the emerging market status that are actually now starting to look at brownfield opportunities as well as continue to look at greenfield opportunities. So you get that compounding effect. I think you'll start to see that in 2026, which will surprise some people.

And look, Life of Field services continues to be extremely important. It's an OEM model in our industry. We continue to grow our installed base because of the success that we've had, but also our installed base continues to age every day. And the more mature of the assets, the more inspection maintenance and repair that is required. And that is a very important element of our overall margin mix, meaning the subsea services business or the Life of Field services business. So continued growth there, and we would expect, as we are seeing on the rest of the subsea business, continued expansion in our profitability due to those internal efficiency gains.

Doug, on the services side alone, late, I know we were talking about this yesterday as well is that there's a lot of organic growth because of the installed base. Can you give us a sense of what that organic growth looks like over the next several years as you think about beyond the decade because you still have orders coming through? And is there a reason opportunity to do anything inorganic on that side of the services element alone?

So yes and yes. In terms of the first, what we have said is we expect services to grow in line with the overall segment growth, which, again, we've already put 2026 guidance out there, so that's public. There's reason to believe that there's potential upside to that, and that would be important to us. So that -- I think that's very -- we have a high degree of confidence there. That's kind of on the organic side.

On the inorganic side, we will look at things that could either improve our cycle time efficiency or potentially where we could create some incremental value for our customers in looking at the inspection, monitoring, repair of their subsea assets.

And an example of that would be historically -- and when I say historically, meaning including today, if you wanted to repair something subsea, there was only one way to do it. And that was to go out with a vessel or a rig, retrieve that asset, bring it back to the water -- to the surface of the water, put it on a supply vessel, send it back to the shore, bring it to the OEMs' site, wherever that may be in the world. It would be refurbished, repaired, whatever. It would be back on a vessel, it would go back. It would be lowered back by a rig or a vessel and reinstalled. That would lead to plus or minus 9 months of downtime.

So 9 months of lost production, that well is shut in. At that point, you put a BOP on the well and it's shut in with 0 production. We are now demonstrating that things that used to be done with that model can now be done in situ on the seabed with advanced robotics, allowing us to repair things in days versus plus or minus 9 months. So days of lost production versus plus or minus 9 months of lost production, huge value proposition for our customers. So that's where we talk about innovation and doing things differently. And this is very deepwater. Remember, when we say subsea, we're talking 1 to 2 miles deep in the ocean. So this is all with advanced robotics, advanced automation and control. And this is an area that is an expertise of our company, and we're looking now to use that in our subsea services business.

Doug, can you talk about the opportunities, both on the electric subsea infrastructure that we've spoken about before? I'm sure there's companies that are still adopting, still trying to figure out what that opportunity set could look like. So would love to hear there.

And then you've previously spoken about brownfield opportunities, the tiebacks that could basically increase the size of the footprint, the area, hugely cost efficient and breakevens for offshore gets impacted by that. Can you talk about what you're seeing on those 2 fronts?

Sure. So the -- most of the equipment today on the sea floor is controlled by hydraulics. So somewhere on top of the water on some vessel or platform, there's a hydraulic pump. You kick it on, you pump hydraulic fluid down to activate something that will turn something, i.e., an actuator to close a valve. It works. It's always worked. It's fairly reliable. The challenge you have is friction pressure because you're pumping that fluid through a very small, very high pressure, mostly [ in canal ] tube and I just said 1 to 2 miles down, that's a lot of friction pressure. So you're limited by how far of a distance you can go before the hydraulic pressure is offset or consumed by the friction pressure. So you're constantly fighting that battle.

What we know about electricity is it has very limited friction loss, and it can go a very long distance. So it just makes sense to use electric actuation versus hydraulic actuation where it's applicable.

So the industry has looked at this for a while. Where we're seeing the fastest adoption rate today is actually in greenhouse gas or CO2 or CCS applications. Where we were -- we received from BP, it's called the Northern Endurance partnership in the U.K., where they're taking CO2 that's captured onshore and taking it 145 kilometers offshore and injecting it for permanent storage and saline aquifers offshore.

The challenge was you can't push hydraulics 145 kilometers. So either you were going to have to come up to all these floating production platforms that were just going to be hydraulic pumps or booster pumps or you thought differently. So we attacked it from an all-electric application. We have tremendous amount of experience using electric actuation. So we applied that on this project, and this has enabled that project to remain everything on the sea floor, and we're just using electric actuation. So it's a full -- first full field all subsea electric actuation, and that's for a CCS project in the North Sea.

In terms of the brownfield, it's exciting because remember, I said you're limited by the distance you can go on the seabed by the distance you have to go through the water column. So again, move to electric actuation, you can move much further laterally, if you will, away from the landing point and go further and be able to tie back more assets to that host facility that already exists in a brownfield, the host facility exists. And you're just trying to tie back more wells to that to improve the level of production that's flowing through that asset and improve the return on that asset. All electric will enable that, which hydraulic has been limited in the past.

Doug, do you want to talk about your capital allocation priorities? How should we think about free cash flow, the use of CapEx, the use of cash? You're obviously building cash on the balance sheet, M&A outlook.

Sure. And I know we're going to run out of time. So thanks for giving me the opportunity. Look, we're really proud of the balance sheet that we have -- that has resulted from all of the actions that we've taken. We're investment grade by all 3 of the facilities, a pristine balance sheet. We're a net cash company, and we are in a position right now of material cash flow generation. We made a commitment and we distributed -- again, we got to get through the full year, but the commitment is 70% of that free cash flow will be distributed to our shareholders, principally in share buybacks as well as our dividend, and that's something we're very proud of, and we expect and we will continue to do.

In terms of the overall free cash flow generation, it's been robust, continues to be. No big M&A. Our strategy isn't evolved around M&A is not a necessity. So we would only do M&A if it was something that significantly reduced cycle time, further improving project economics and growing the market, which most of that we will do internally just within our own R&D budget. So no big M&A necessarily required.

And in terms of CapEx, we've been very disciplined of -- we said we'd spend between 3.5% and 4% -- 3.5% and 4.5%. We've been spending below the 3.5% and growing the company. The way you can do that is you have to do more with the same. It's this relentless pursuit of the reduction of cycle time. That also benefits your asset base. You can do more with the same amount of assets. I know it sounds simple, but this is not the way the industry has worked or much of the industry continues to work today, and it's something we continue to benefit from.

So our commitment remains the same. We also reduced debt this year. So again, gross debt is now at a very low level. There's nothing due for multiple years. So you should expect next year another strong free cash flow generation and another strong shareholder distribution as well next year.

Great. Doug, thank you so much for taking the time. Very helpful information.

Thank you very much.

Thank you.

Hi, everyone. I'm Marc Bianchi, U.S. oilfield services analyst here at TD Cowen. We're excited to be joined by Doug Pferdehirt from TechnipFMC -- Chairman and CEO of TechnipFMC. So thanks, Doug, for being here. I'll -- I guess, maybe not everybody is as familiar with what you guys do. So maybe give us like 1.5 minutes on what you do just to get us going.

Marc, I don't think I've ever given an overview in 1.5 minutes, so that's a challenge. But let me first start, Marc, by thanking you for allowing us to be here and for the quality of research that you do. Also to TD Cowen, to everybody here in attendance and for those joining via the webcast, thank you for your interest in our company. It's very humbling. Look, we looked at the industry back in 2012 to 2014, and we made a decision that we felt there needed to be a material change in the way the business was done offshore in order to ensure that our customers would have confidence again and that the capital flow would go from the U.S. unconventionals, which at the time was attracting a significant portion and a growing portion of the total capital expenditure back to offshore.

That was about bringing certainty back to these offshore developments. The challenge was always the certainty and the delivery of these very large and complex projects. So we knew we had a role to play that we had to materially change the way that we operated as a company. That led to us developing a configurable -- configurable architecture. So much like the auto industry, moving to where there were subcomponents that were pre-engineered, predesigned and were configurable based upon the customer need. So the customer experience was still, I'm getting something built for me as when you place your order for an automobile. But in reality, they're not, and we're not doing any engineering specific to your requirements. That's all been done upfront.

That in itself removes 9 to 12 months of detailed engineering -- and it also removes a great degree of uncertainty and allows us to ensure the delivery of this very complex architecture when as promised. Beyond that, we said, okay, this is good. This is important, but is there more that we could do? So we're not a company that focuses on consolidation. We're a company that focuses on integration. What can we do in the adjacent space that will create greater value towards our singular purpose, which is the relentless pursuit of the reduction of cycle time, again, making offshore projects more economical and with greater certainty of the outcome of the delivery of those projects. That led to a merger between FMC Technologies and Technip on the 17th of January 2017, a long time ago, almost a decade ago. And here we are today to where the market is largely -- we call that iEPCI, integrated engineering, procurement, construction, and installation.

On those projects, we're the architect, we're the builder, and we provide the life of field services contract. So we are literally engaged with the customer anywhere from 20 to 30 years. So it's a very intimate long-term relationship that we build with our customers. The success of these 2 things, moving the business to being integrated, which it was never in the past. So it used to be up to 14 different contracts, now a single contract with a single company and the Subsea 2.0 architecture, both unique to our company, have led us to where we are today to where our customers are rewarding us by recognizing that value because we're creating the value for them by the relentless pursuit of reduction of cycle time, improving their project returns. And they're recognizing that and rewarding us with now 80%, 80% of the business being direct awarded to our company in a market that's growing. It's a humbling and exciting position to be in, Marc.

Good overview, Doug. I think -- so this sort of plays into one of this ability to lower the cost and make offshore more competitive than it was a decade ago. And I think you have this view that we're not really going to be necessarily in cycles anymore because really the marginal barrel -- or the lowest cost barrel is offshore enabled in part by you. But can you just talk about maybe your world view of some of the other sources of supply and why you think offshore is really going to get the majority of the capital as we go forward?

No, it's a fair question. And also, I will acknowledge that the lowest cost barrel is in the Middle East. But you have to have economics and you have to have access. So the lowest cost barrels in the Middle East, but there's very limited access in terms of capital flows by other than the national oil companies involved into those regions or into those countries or kingdoms. So as a result of that, they have to go to the next best economics that has access and that's offshore. And it's really as fundamental as that. We saw this coming back in the third quarter of 2012 -- 2011, excuse me, 2021, we started talking about this. At the time, it seemed a little far-fetched, but you could see how that was setting up because at the same time, the economics in the U.S. unconventional were deteriorating. Plenty of access but deteriorating economics.

We knew with what we had done with Subsea 2.0 product, configurable product platform, we knew that what we did with the iEPCI and having this integrated model and all of this capability in-house that we could drive that cost curve down. So we had our own internal ambitions. And by doing so, we realized that we could improve the economics offshore again. Then what we had to deliver at the end of the day was certainty. That was the variable because our customers were still hesitant. Yes, we get it. We see it. We believe it, but you've got to deliver it. And I will tell you, we have yet to deliver an iEPCI 2.0 project that wasn't followed up by a direct award of subsequent projects. That's how successful it's been. It's given our customers the confidence back. They're prolific reservoirs offshore.

These are prolific reservoirs offshore. No fracking, no artificial lift. They flow naturally, very low decline rates, 4% to 6% per annum versus the unconventionals 30-plus percent over the first couple of years. So a very different setup in terms of your -- the size of the reserves, the ability to be able to -- the recoverable rates are much higher and the decline rates are much lower.

So very favorable economics. It's just about making sure that the business is done the way that it was intended to be done, meaning on time, on schedule, and that's what we're delivering today.

And there's really -- it's unique what you're doing, but another competitor is attempting to replicate what you're doing, but they're a ways behind. Maybe just talk about like the lead that you think you have...

Well, there's -- of those 2 components, let's break it down into the product architecture and the integrated model. So in terms of the product architecture, this was an extensive engineering effort. It took a -- we started this in 2013. We announced it in 2017 and started taking orders in 2019. I mean it's a huge body of work. There is no one else trying to do that today. There are companies talking about standardization, but standardization is not -- it's not configurable. I don't think configurization is the word. But there's a very distinct difference because we started focusing on standardization, too.

Standardization is simple, buy my piece of equipment. And a customer, just like you, it would be like the auto industry saying, buy my car. It's the only one I'm going to make, and this is what I want you to buy. No, you want to have choices. You want to have color choices, you want to have engine size choices, whatever it may be. You want to have some choices. That's what we mean by configurable. So that's -- so it's just a different approach. Clearly, I think the market's adoption of the configurable platform is indisputable. And we have a significant advantage. And now we're well over 50% of our orders are coming in with this 2.0 architecture. Now there will always be space for this kind of bespoke one-off kind of building and our competitor is kind of filling that void, but it is not somewhere where we aspire to participate. And then if you look at the integration side, look, there's a fork in the road when you come to -- from strategic decisions in terms of making M&A type transactions.

You can focus on consolidation or you can focus on integration. I will tell you, consolidation -- the outcome is more certain because you're just buying somebody who does what you do and then cutting cost and trying to get benefit from it through synergies, cost synergies. That's a well-known playbook. And integration is often less traveled of the 2 paths. And in our case, had never been done before. So look, it was not obvious. We chose that path, and our competitor has now chosen the path of consolidation. So I would say we're actually heading in 2 very different directions. And our clients see that and our clients recognize that. And there's space for both of us, but we have different strategies, and we're proud of what we've delivered.

Okay. You've said this, and we've had a few sessions together over the last couple of days, the relentless pursuit and reduction of cycle time, I think I've got it down now. Like talk to us about how far along you are on that journey and what it means for the business? What does it mean for margins? What does it mean for capacity? And what kind of advantage do you think it gives you?

So I've always been on the service side of the table. I started delivering newspapers before school and then many other service jobs throughout my career. So let me start with what's most important, which was what is the benefit to our customer. That's all that matters. And that's a thing. You have to focus on your client. You have to focus on creating success for your client. So the relentless pursuit of reduction of cycle time translated for our customer means higher project returns. And not only higher project returns, but higher project returns with certainty of the outcome. which is why they're spending more capital offshore, why they're exploring offshore again, why this is the big focus for them in their portfolio now that maybe it wasn't over the last 15, 20 years because of other distractions that had occurred in the global energy mix. So that's most important to me and keeps me aligned with my customers' interest.

Now we benefit as well. And how do we benefit? Because by focusing on the relentless pursuit of cycle time and having the 2.0 and the iEPCI where the competition doesn't, it creates just greater differentiation for us and aligns our outcome with the outcome of our clients. So people often use win-win. This truly is a win-win. Our clients are winning because they're getting improved project returns with greater certainty, and we're winning because they're willing to give us a greater portion of the economic value that we create. That's only fair. So both sides are feeling good about it and both sides are winning. Whereas if you're in a commodity business and you're just trying to increase day rates or you're trying to increase pricing, that's obviously counterproductive to your client relationship. Our client relationship is aligned. I mentioned earlier that we're the architect as well as the builder. So we are sitting there at the table working with them intimately to design the architecture to meet their economical hurdle rates 2 to 3 years in advance of that project actually becoming -- moving into the execution phase.

So we're aligned from the beginning. And this is why they have the confidence in us to, again, honor us by giving us 80% of their -- honor us by us receiving 80% of our business as a direct award, never going out to a competitive tender. So it was all about getting those aligned. Now maybe to further answer your question, Marc, is it over? Have we achieved -- we achieved that outcome? Well, yes, but only partially because we're only about 1/3 of the way through this journey. So we still have significant areas that we are convinced that we can reduce cycle time and improve the certainty of the outcome, hence, improving clients' project returns offshore, which will lead to greater value to us and to our shareholders at the same time.

So I'm sure this is a question on everybody's mind is like how do we translate that opportunity into margin upside or business throughput or something that I can put in a spreadsheet. How -- what do I do with that?

Well, look, let's just look at what's happened so far. I think the numbers speak for themselves, right? You've seen that incremental margins that we've been able to deliver. Again, I shy away from talking about it because it's more important for me to focus on my clients' returns and my clients' project returns. But yes, we benefit from it as well. But this isn't something that -- this isn't a concept that I'm trying to convince you of here today. This is the way we've been operating. Remember, January 17, 2017, we created TechnipFMC. November of 2017, we launched Subsea 2.0. So this has been going on for a while. 50% of our inbound in 2024 has been iEPCI or these integrated projects. We've said this year, Subsea 2.0 is well over 50% of our inbound. So this is happening today.

Our customers are realizing we are -- we have delivered iEPCI 2.0 projects multiple times for our customers today. So they're experiencing it already, and they're seeing that benefit. So you see what we've been able to deliver. We've already given 2026 guidance, which I think is probably unusual for most companies. We've already done it. We're a backlog company. We have significant visibility. And yes, it included more revenue and more margin. So I think you're seeing it build out. And we believe that as we continue to convert more of our backlog to this higher-value backlog, iEPCI and 2.0, both for our clients and for ourselves, we'll continue to be able to grow margin as a result of more of that flowing through our execution. And so you're building that sustainability that is not necessarily driven by external factors. It's because of the difficult decisions we made almost 10 years ago and realizing the benefit of those now in our results.

I think someone had asked the question recently about where can margins go? And I think you gave a really interesting answer like, I don't want to have a target and I don't want to give targets to my people because we get some other benefit from them thinking through how to do that. So maybe you could just talk a little bit more about that because there's some interesting organizational things that you guys are doing that I don't think comes out as often as it could.

Sure. And I know I wasn't going to get away with the prior answer, Marc. So I knew you're going to follow up, and that's a fair question. So look, we get asked that question a lot because there's obviously interest. What I have said, and I appreciate you saying it was an acceptable answer. In some ways, I could understand it. People may not be satisfied with it, but it's the truth, which is I don't know where the margins are going to go. And that doesn't mean I'm worried about them going down, let's be clear. But I don't know where they're going to go because, again, this is a new experience for us as well. But what I do know is that we have real tangible evidence that the cadence and the flow rate and our ability to be able to deliver these complex projects in shorter and shorter cycle times.

And we're not shaving days, we're shaving months and years off of a project on a consistent basis. And we know we're -- as I said earlier, we're only in the early innings or early -- I'm a hockey player. So we're only in the first period of a 3-period match here. I mean there's a lot left to be done. But look, me setting a target in this environment, I do think would be counterproductive because the organization where we have gone as an organization is dramatically different than where we were just 5 years ago. And everybody talks about transformations, and I get it. But we'd love for you to come and see how we operate today. It is a very different company. I had to change my behavior significantly. But as a result of that, you've truly empowered 22,000 women and men and the output from that is just tremendous.

Everybody is looking to shave a minute, an hour, a day in everything that they're doing. This is really lean. I mean, we have tried to model a lot after Toyota, who has been hugely successful in this area. They've been very supportive in the Lean Institute in helping us through this journey. And a lot of companies get lean through their manufacturing and then they stop. We've taken this through the entire organization, every function, every person, including myself, has had to transform their behavior in the way that they work to where we're all focused on the same thing, which is the output which is relentless pursuit of reduction of cycle time, i.e., improving our clients' results. And our clients see that. This is all about the clients being successful and then we're successful as a result of that.

So the cultural change within the company is dramatic. And yes, so maybe I'll pause there. But it's -- what I do know is that there's certainly more fuel in the tank. We have a higher quality backlog than what we're executing today because of what we're putting into it, more iEPCI, more 2.0, higher quality. All that will need to be executed. Today, it's another 1/3, not to be confused with the prior 1/3, but only about 1/3 of our manufacturing capacity is actually executing Subsea 2.0 work today, but yet 50% of the inbound is coming in at 2.0. So by definition, as that flows through manufacturing, that will go to 50%. So we should see a benefit from that. And again, I just want to keep repeating this because this is the key. It's not about our margin going up. It's about our clients' project returns improving. And as a result of that, our margin is going up. That's how you keep the relationship with your customers.

Yes. On the topic of lean, you -- I think this is what you were alluding to on the earnings call, where there's sort of an opportunity to start to leverage lean maybe further downstream into some of the development. Is there anything more you can say about that? And if there's a plan to say more in the future, like let us -- when should we be expecting to hear more from you about that?

Okay. So let's just go back quickly through the history of it. So 2013, we launched this concept of configurable architecture, started working with the Lean Institute on this. We were FMC Technologies at the time. So our scope was the seabed. FMC Technologies was everything that sat on the seabed, which, by the way, everybody talks about a subsea tree. It's far greater than a subsea tree. Everything is big, the size of this room, and it's a small city down there. So a lot of things are on the seabed. But the seabed needs to be reconnected to the surface. That's what led to some smart people in the company saying, well, maybe we should do an integrated approach, not do a consolidation, but do an integration. And that's the area that Technip played in, if you will, in the water column, that's called umbilical risers and flow lines. So we brought that into the portfolio.

We created the iEPCI, the integrated commercial model that we've talked about, again, about shortening cycle time, removing redundancy. But we've never really taken the opportunity yet to take all of that -- all those products and put those -- fully move those to be configurable, okay? Just because it takes a while. As I mentioned, 2013 and 2017 as we went public with the seabed. So you should expect that now that's the benefit of becoming one company. We couldn't have done that in a joint venture or an alliance because your interests are not aligned enough. So that's why we did the merger. And now we're looking at all of that other architecture, which there's a significant amount in the water column and remember, when we talk about water column in subsea and this stuff just gets me super excited, and I might not get everyone excited, but we're talking 1 to 2 miles deep, 1 to 2 miles of water before you get to the seabed.

So this stuff is pretty amazing. And down there where no man has ever been, all remote automation and control robotics. We have robots on the seabed working on stuff. You just can't go down there. And now we have the opportunity to take 2.0 and apply it to all of those -- that other part of the architecture. And we've been working on that, and we're making good progress, but that's an upside, and that's what I was referring to.

Okay. Great. Well, maybe to talk a little bit about kind of the market -- current market state, the outlook. So you've been -- you've guided to and have been delivering $10 billion of orders in Subsea per year. It's from an outsider, that's like a remarkably consistent number. Is there something that drives that? Is -- there's a certain amount of sales capacity to work through projects with customers, maybe there's the customers' capacity. Is there any reason that 10 is like a magical number? Or that's just maybe it's coincidence that we've seen 10 for 3 years?

So I'm just going to have a little fun, right? Better than 9, right? So -- but let's go back to how the 10 came to be because I think that's important. 2021, wouldn't have been as many people in the room and probably wouldn't have been as many people on the line. 2021 was a very different setup. There was a lot of skepticism. We're out there saying projects are there. We're talking to our clients. Capital is going to flow to the offshore again and a whole lot of doubt and a whole lot of skepticism. So in 2021, we put out a 3-year target.

And the target was over the next 3 years, we would achieve $30 billion. Now we did that with a lot of science behind it, but we gave a $30 billion target over 3 years, never intending that it was going to be $10, $10 bill, $10, $10 million. And by the way, it hasn't been. It's been $9.7 billion, $10.3 billion. But we weren't expecting it to be as consistent as it was because these are -- some of the projects we do are $1 billion, $1.5 billion projects, and they could fall on December 31 or they could fall on January 2, and you don't worry to do on an annual basis. It has just so happened to have been actually quite linear beyond what I would have expected. But we set a 3-year target of $30 million, which is how -- I think it's important to go back and realize that. We weren't saying it's going to be $10 million -- did I say $1 million?

Billion.

We didn't say it was going to be $10 billion per year every year for the next 3 years. We just said it was going to get to $30 billion. Now we said for 2026, we've already said we expect it to look like 2025, which will be the $10 billion range. So we do expect that again next year. The market size is growing. We've talked about that because of the capital flows going offshore again. We see exploration happening. That's going to drive more capital flows and more projects. So that market is going to grow. So is there the capacity to grow? Yes. But I think we're in a good spot right now with revenue growing, EBITDA growing, solid inbound, meaning backlog continuing to grow, I think, is a good place to...

Maybe we just got a few minutes left, and I have a couple I want to ask on cash flow before we get there. Just in terms of the frontier market opportunities that you're talking to customers about. So I think we all know, all right, Suriname, Namibia, there's maybe West Africa starts to come back, maybe there's Equatorial margin in Brazil. But like what are the next -- we know the Subsea opportunity slide. What's the next stuff? When we update the subsea opportunity slide a year from now, 2 years from now, what's going to be on there that isn't on there now, like geographically-wise, not like customer-wise or anything like...

And I know we're going to run out of time, but I got to step back for a minute. Imagine what Marc just said. What he just said was 4 countries that weren't on the map before from offshore production or from production period. In my career, there has never been a period of time where in a couple of years, you've added -- it's just profound. So I just want to be careful, oh, Suriname, Guyana, Namibia, Mozambique. Holy heck, this is amazing. This is truly amazing. And I think we're taking it for granted, not you, Marc. But I just want to make sure that we realize this is significant and the growth in Guyana, where we are honored and humbled to be partnered with ExxonMobil and have provided 100% of their infrastructure in the country.

Suriname, we will do the first project there, the GranMorgu project for TotalEnergies. We're very grateful for that. iEPCI 2.0. Mozambique, we're working for ENI in Mozambique today. Just -- it's profound. I mean don't understate Equatorial margin you even throw in there. Equatorial margin is potentially another massive development. Now this is in Brazil, which is already a large country, a large oil-producing country, but this could be another massive growth opportunity within Brazil. The Paleogene in the Gulf of Mexico, this is the 20,000 psi deeper horizon in the Gulf of -- I'm sorry, Gulf in the U.S. Gulf. I mean, this is dramatic and these are providing significant growth to the offshore that even without what are all those other countries that are potentially going to come online, just focus on those. Those are real. Those are material. Those are going to drive activity well beyond the end of the decade. Now to answer your question, I get interested in other countries in East Africa?

I won't be specific, but there's other areas in East Africa that could potentially share the same geological feature as Mozambique. I get excited about the Eastern Mediterranean. I think both the activities from Israel to Egypt, but now in between, that could also come on. You could add 2 to 3 new countries producing in the Eastern Med. I get interested in the southern part of Africa beyond Namibia, which is obviously very exciting, but beyond Namibia. We didn't mention Indonesia. Yes, it's been a long-term producing energy country. But now with the gas projects in Indonesia, that is growing quite rapidly. There's other areas that are probably further out. There's large gas reserves offshore Colombia. It's very deepwater, but it's certainly something technically we could accomplish for our customers. So yes, there's a lot more to be excited about. But realize what the setup that's there already is significant and material.

Excellent. All right. I'm going to squeeze one more in, and we're probably going to go over. You just had a buyback reauthorization. You've been consistently buying back a lot of stock. And I think your message before had been we're really focused on buying back the stock rather than raising the dividend. But as something occurs to me, it could be a signal to send to the market about the stability of the business if you raise the dividend. How do you think about the decision process between buyback and dividend?

No, no, it's a fair question. And look, it is one that we discuss often with our Board. And certainly, last quarter before we announced the increase of the buyback program. But let me be very clear. What we announced was a $2 billion buyback. That's a large portion of the outstanding shares of the company. So the reason I'm emphasizing that is I think that exudes confidence, right?

So it's not that a dividend would exude more confidence than a $2 billion buyback on top of what previously had been a much smaller buyback program. Look, we think it's a great investment. We look at -- just look at the numbers. Just look at the fundamental metrics of the company, it looks like it should be trading at a much higher multiple. If you do a blind test and put those numbers against any industrial company, you're going to get a very different result. We believe that. We believe the investment community is recognizing and acknowledging that. And therefore, we believe that's the best place to return the cash to our shareholders, and we are honored to be able to do so.

Awesome. I'll leave it there, Doug. Thanks a lot.

Hello, and thank you for standing by. My name is Regina, and I will be your conference operator today. At this time, I'd like to welcome everyone to the TechnipFMC Third Quarter 2025 Earnings Conference Call. [Operator Instructions]

I'd now like to turn the conference over to Matt Seinsheimer, Senior Vice President of Investor Relations and Corporate Development. Please go ahead.

Thank you, Regina. Good morning and good afternoon, and welcome to TechnipFMC's third quarter 2025 earnings conference call.

Our news release and financial statements issued earlier today can be found on our website. I'd like to caution you with respect to any forward-looking statements made during this call. Although these forward-looking statements are based on our current expectations, beliefs and assumptions regarding future developments and business conditions, they are subject to certain risks and uncertainties that could cause actual results to differ materially from those expressed in or implied by these statements. Known material factors that could cause our actual results to differ from our projected results are described in our most recent 10-K, most recent 10-Q and other periodic filings with the U.S. Securities and Exchange Commission. We wish to caution you not to place undue reliance on any forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any of our forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise.

I will now turn the call over to Doug Pferdehirt, TechnipFMC's Chair and Chief Executive Officer.

Thank you, Matt. Good morning and good afternoon. Thank you for participating in our third quarter earnings call.

Total company revenue in the period was $2.6 billion, adjusted EBITDA was $531 million with a margin of 20.1% when excluding foreign exchange impacts. I am very proud of the continued strength in our execution and the delivery of another quarter of high-quality inbound. With total company orders of more than $2.6 billion in the period, 15 of the past 6 quarters have achieved a book-to-bill above 1.

We generated free cash flow of $448 million and distributed $271 million through dividends and share repurchases, continuing to deliver on our commitment to return a significant portion of free cash flow to shareholders. Subsea realized quarterly inbound orders of $2.4 billion. This commercial success is the cornerstone of our ability to deliver growth in both revenue and profitability.

In the quarter, we announced 4 awards driven by continued strength in South America. We received multiple flexible type contracts from Petrobras, which included the direct award of a high-pressure gas injection risers for pre-salt projects. We were also awarded a contract to supply subsea production systems to be deployed in an array of greenfield developments, brownfield expansions and asset revitalizations across Petrobras' extensive portfolio. In Guyana, we were awarded the Hammerhead project from Exxon Mobil, where we leveraged our in-country experience and solid track record for providing schedule certainty. This award represents the seventh greenfield development on the Stabroek Block and will utilize our Subsea 2.0 technology.

TechnipFMC has supplied all of the subsea production systems for ExxonMobil in Guyana, since the first contract award in 2017. Our commercial success year-to-date reinforces our confidence in delivering more than $10 billion of subsea orders in 2025 as well as achieving $30 billion of inbound over the last 3 years.

Beyond the current year, we believe that offshore projects will continue to receive an increasing share of capital investment. This change in spending allocation is due in part to the significant improvements made in developing the large, high-quality and prolific reservoirs found offshore. These strong attributes were always known and the resource quality was always there, but cost overruns and schedule delays in the past would ultimately challenge project economics. In today's offshore market, much has changed, driven by a number of factors, including improvements in the quality and interpretation of seismic data, shortened delivery times for large production infrastructure, significant reductions in the time required for drilling and completion activities and as reflected in our inbound awards, the introduction of new commercial models and innovative technologies.

At TechnipFMC, we wake up every day with a single purpose, the relentless pursuit of cycle time reduction. This mindset led to the development of our pre-engineered configure-to-order product platform, Subsea 2.0 as well as the creation of the industry's only fully integrated execution model, iEPCI. These innovations provide the elements to shorten cycle times and improve project returns. But even more importantly, to help provide our customers with greater schedule certainty in our project execution. It is this combination of higher economic returns and greater project certainty that is providing sustainability to current activity levels, underpinning our outlook and securing $10 billion of Subsea inbound in 2026 and our confidence that activity will remain strong through the end of the decade.

In closing, the continued strength in our Subsea inbound orders reflects the confidence our customers have today and our ability to successfully execute their projects on time and on budget. This is making the author resurgence more durable as evidenced by the shift in spending to these markets. TechnipFMC is also driving this change in behavior. With iEPCI and Subsea 2.0, both having a profound impact on investment decisions by derisking and accelerating subsea projects. The success of these unique offerings has also contributed to the notable increase in the level of direct awards to our company.

With greater project certainty, we now see the execution phase of subsea developments as an opportunity to further leverage lean operating principles. In doing so, we can learn, refine and enhance our own processes, driving a culture of continuous improvement to further shorten cycle times and improve project returns. While focusing on the customer is always a top priority, we also believe that our shareholders should share in our success. Yesterday, we announced our Board of Directors authorized additional share repurchases of up to $2 billion. This significant increase to our share authorization exemplifies our confidence in the outlook as well as our commitment to maximize shareholder value.

I will now turn the call over to Alf to discuss our financial results.

Thanks, Doug.

Inbound in the quarter was $.6 billion, driven by $2.4 billion of subsea orders. Total company backlog ended the period at $16.8 billion. Revenue in the quarter was $2.6 billion. Adjusted EBITDA was $531 million when excluding a foreign exchange loss of $12 million.

Turning to segment results. In Subsea, revenue of $2.3 billion increased 5% versus the second quarter. The sequential improvement was largely driven by increased project activity, particularly iEPCI projects in Africa, Australia and the Americas. This was partially offset by reduced project activity in Norway. Adjusted EBITDA was $506 million, up 5% sequentially due to higher project activity. Adjusted EBITDA margin was 21.8%.

In Surface Technologies, revenue was $328 million, an increase of 3% from the second quarter. The sequential increase was primarily driven by higher activity in the North Sea and Asia Pacific, partially offset by lower activity in North America. Adjusted EBITDA was $54 million, an increase of 3% sequentially due to higher activity in international markets. Adjusted EBITDA margin was 16.4%, in line with the second quarter results.

Turning to corporate and other items in the period. Corporate expense was $28 million. Net interest expense was $11 million and tax expense in the quarter was $76 million. Cash flow from operating activities was $525 million and capital expenditures were $77 million. This resulted in free cash flow of $448 million. We repurchased $250 million of stock in the third quarter. When including $20 million of dividends, total shareholder distributions were $271 million. We have also increased our share repurchase authorization by an additional $2 billion, providing us with $2.3 billion of current authorization. Since the time of our initial authorization in 2022, we have distributed more than $1.6 billion through buybacks and dividends, representing nearly 60% of free cash flow generated over the period.

During the quarter, we reduced debt by $258 million including early repayment of the 6.5% senior notes maturing in February 2026. We ended the period with $438 million of gross debt, largely comprised of private placement notes that extend out to 2033, with interest rates of 4% and below. Cash and cash equivalents was $877 million. Our net cash position increased to $439 million.

Moving to our guidance. For Subsea, we expect seasonal impacts to our fourth quarter results, with revenue declining mid-single digits sequentially. Adjusted EBITDA margin is expected to decline approximately 300 basis points to 18.8%. For Surface Technologies, we anticipate revenue to decline low single digits sequentially, with an adjusted EBITDA margin similar to the 16.4% reported in the third quarter. Lastly, we expect corporate expense to approximate $35 million.

Moving to our full year outlook. I'm going to highlight a few items. Most notably, the updates we have made to our guidance ranges. For Surface Technologies, we now expect adjusted EBITDA margin to be in the range of 16% to 16.5%, above our prior full year view. And for total company, we are increasing our guidance for adjusted EBITDA by $30 million, which we now expect to approximate $1.83 billion for the full year when excluding foreign exchange. Lastly with the continued strength in our cash conversion, we are also increasing free cash flow guidance for the year to a range of $1.3 billion to $1.45 billion. All other guidance items for the current year remains same.

Before I move to my closing remarks, I want to recognize the tremendous progress the team has accomplished so far. The consistency in execution and further adoption of lean operating principles make us well positioned for continued improvement in most everything we do. Additionally, our commercial differentiation and the relative stability of offshore markets give us unique visibility, allowing us to provide an early view for Subsea for the upcoming year.

For 2026, we are guiding Subsea revenue to a range of $9.1 billion to $9.5 billion with adjusted EBITDA margin in the range of 20.5% to 22%. We will provide the remainder of our 2026 financial guidance with our fourth quarter earnings.

In closing, the continued momentum in operational performance drove another solid quarter for TechnipFMC. The strong execution was also reflected in robust free cash flow generation, leading us to increase our full year expectation to $1.375 billion at the midpoint of the guidance range. We are on pace to return more than 70% of free cash flow to shareholders in 2025 through dividends and share buybacks. And with our increased free cash flow guidance, shareholder distributions now have the potential to double versus the prior year. Yet even with this substantial increase in distributions, we have maintained the flexibility to further strengthen our balance sheet by reducing gross debt almost $450 million since the beginning of the year, including the opportunistic prepayment of our highest cost debt.

And finally, as we look further ahead to 2026, we have provided our outlook for Subsea, which at the midpoint of the guidance implies double-digit growth in adjusted EBITDA. Importantly, this level of EBITDA growth in Subsea is essentially double the anticipated growth in revenue, further expanding margins, improving returns while providing strong support for robust shareholder distributions.

Operator, you may now open the line for questions.

[Operator Instructions] Our first question will come from the line of Scott Gruber with Citigroup.

I wanted to start on the share repurchase authorization. It's going to be another good year of free cash this year, strong returns to shareholders above 70%. With the increase in the repurchase authorization and what should be a strong free cash year next year, how are you guys thinking about the right level of cash return in '26?

Sure, Scott. So obviously, we are very pleased with the year we've had with free cash flow generation this year, really supported by our strong commercial and operational execution that we had all year. This execution is foundational because the operational delivery uncertainty around that is really leading to the consistent achievement of milestones that then trigger billings and associated cash collections. So that's really, again, the fundamental strength in the cash flow conversion out of EBITDA clearly has increased significantly this year. However, when you exclude maybe working capital benefits and a few onetime benefits that we have seen in our free cash flow conversion from EBITDA may not be able to stay at that level. But if you think about what we have said historically, we said that we're going to be around 50% of free cash flow conversion from EBITDA, and we think we're now approaching more like 55% when you're normalizing for working capital to a more neutral position.

That's great. And how to think about the kind of level of return to shareholders from the free cash flow for next year kind of what's the framework you guys are thinking about?

Yes. So we are just recommitting that we will have at least 70% of free cash flow returned to shareholders. So that's -- we will continue at that level at the same level as we've had in '25.

Our next question will come from the line of Victoria McCulloch with RBC.

Just on the Subsea award intake, when we were speaking last quarter, you mentioned that there were some awards that haven't been announced to the market that we would see in the coming weeks. I think there was 1 from Equinor in July. Has there been anything that possibly still yet to be announced from of the order intake. Certainly, it seems your to the order intake is obviously very strong and running ahead for of others in the market. It's very strong by TechnipFMC. And then as a follow-up, not totally linked, what are your working capital expectations for this year within the new free cash flow guidance?

Sure. Thank you for the question, and happy to clarify. First of all, thank you for pointing out another solid quarter of inbound. We are differentiated in that. And I think that's very much a result of what we've done to create the company that we have, and it shows up in the level of direct awards it comes to our company. So in other words, the total available market that's accessible by the rest is shrinking every day as our direct awards continue to increase. So if you think about it that way, that's what gives us the confidence, the reassurance and the ability to continue to outperform. In terms of those specific, the comment around potential future announcements, there are actually still more to come. That really is governed by our clients. It typically has to do with their conversations with the local governments or their partners. And when they give us the green light, then we go ahead and make those announcements. But nothing -- there's no surprises there. There's no -- it's just a normal part of the process. It's struck out a little bit longer than we had anticipated when I made that comment. But again, thank you for pointing out the strength and resiliency of our outlook and our ability to win and secure the highest quality projects, realizing that we are being very selective in what we focus on.

Yes. And this is Alf. Regarding the free cash flow and the working capital assumptions. As you clearly point out, we have had a very exceptional year this year and a very strong year in terms of working capital performance. So whatever you can kind of gauge from the year-to-date numbers now is kind of one way to see the upside this year. When we guide for going forward, we will typically put ourselves with a neutral position. That's the right starting point.

Our next question comes from the line of David Anderson with Barclays.

I was hoping you could unpack the '26 Subsea guide a little bit for us in relation to kind of what I'm hearing from the rest of the market. Recognizing the midpoint of the guide, the revenue guide on Subsea is in line of consensus. I'm assuming the service component is up roughly cut 10%, like we've been seeing in the past years. So if as backlog conversion looks pretty steady for next year. We keep hearing about offshore picking up the late '26 building into I'm just curious if that's a trend that you think should also play out in your Subsea revenue. You mentioned shortened cycle times. I guess does that imply backlog conversion should start to accelerate in the second half of next year? And does Subsea 2.0 convert faster in the mix?

Sure, Dave. I think you dropped off there at the end. You might have to bring me back. There were quite a few a few things packed in there, year back, Dave. So if I don't catch everything, just you can ask me a follow-up. So first of all, thank you for asking us about 2026. I think we're the only ones talking about 2026, to be very clear, which again says a lot about who we are as a company, the unique visibility that we have, our position within the market and the confidence that our clients have in us to be able to award us projects far earlier than they have done historically or that they would do with the competition. So again, it's a privilege for us to be able to talk about 2026. When you -- as you said, as we kind of unpack that guidance, you're right, backlog coverage is strong. And it's not just the quantity of backlog coverage, it's the quantity of backlog coverage, and that was both in my prepared remarks as well as in Alf's, it's that ability to have confidence in increasing not just revenue, but also margin and margin at a faster rate than revenue growth. So this isn't just about volume. This is about higher-quality inbound and just, quite frankly, exemplary execution, which I'm extremely proud of our team and all of our employees for what they've been able to deliver. So those things set us up very well and give us the confidence to be able to go out now and no one else is talking about 2026, and we're able to go out with guidance for 2026, with a high level of confidence that we will be able to achieve that. You asked a question about Subsea services and kind of its growth rate, like in 2025, I would think of it as in line with the growth of the overall business. So in other words, we gave you the revenue forecast. So you can look at that top line growth and reflect something similar for subsea services. In terms of cycle time reduction and how that helps the conversion from backlog, indeed, it does, and that's a big part of the secret sauce is in terms of our ability to grow, whilst retaining a modest CapEx investment, meaning we don't have to invest to grow. We decided to do more with less. So we're not about building and spending capital and adding assets. The smart way to do it is to do more with less, which quite simply shows up in returns have not been achievable historically that we are demonstrating, and we'll continue to demonstrate as we go forward. So that's -- now we're not -- everything is tied to that accelerated cycle time, still the offshore installation side where there's work to be done. And it's an area we're focusing on how we can make that as efficient as we have the configured order Subsea 2.0 product architecture. And there's not everything in the Subsea 2.0, not every of our product architecture has achieved the level of Subsea 2.0 if you will, customization. So there's a lot of upside here left in the company, and those are all of the things that we're focusing on that we'll benefit from as we go forward. If I didn't cover everything you had hoped, please feel free to follow up.

Pretty close, pretty close. Let's hope I don't drop out here. So my second question is just about the Subsea margin guide for next year. What percentage of revenue are you expecting to be Subsea 2.0? And can you tell us how much -- what percentage of the inbound year-to-date has been Subsea 2.0?

Sure. So I think the easier way to think about it and maybe how it creates leverage for the company, is how much of it is actually flowing through the facilities. So we are right now -- let's say, when we exit 2025, exit this year, we'll be approaching about 40% on of our capacity, we'll be working on Subsea 2.0. Now the inbound levels of Subsea 2.0 have exceeded the 50% mark and continue to grow, and we would expect Subsea 2.0 orders to grow as a percentage of total orders also next year as well as iEPCI orders as a percent of our total orders will grow substantially. So these are big, big leverages -- these create a lot of leverage for us as we continue to move forward in ensuring that we continue to grow, expand our margin, increase our leverage and drive returns.

Our next question comes from the line of Arun Jayaram with JPMorgan Securities.

My first question is regarding your 2026 Subsea guidance. Doug, at the midpoint of the guide, it implies 175 basis point improvement in margins. I was wondering if you could help us understand how you think about the drivers of the margin expansion between Subsea 2.0 mix -- Subsea services mix and maybe pricing improvement?

Sure, and good morning, Arun. So clearly, all of those factor in. I'm going to really focus on the first 2 because to me, those are the ones that are sustainable. I think too many companies for too long, have just focused on the last one, and that is never a long-term strategy. So we have redesigned our company. We changed our operating model to create that leverage that we can have that sustainable leverage regardless of the level of activity that there is in the marketplace. So when you think about it, there's really the 3 components. There's -- we do have some legacy backlog, some legacy projects still in our backlog, and those will be working off. And we're getting down now to below the 10% mark of what is left in our backlog. So there'll be some of that remaining in 2026. And then -- but there will also be more Subsea 2.0, as I just responded today and more iEPCI execution going through. All of that is -- those are the things that are like, let's say, very tangible. But what you have to keep in mind is the entire organization, it's not just the manufacturing part of the organization. The entire organization is on this industrialization journey, and it's real, it's real. And many of you have had the opportunity to visit and see how we operate today versus how we used to operate and the rest of the industry still operates, and it's very different. And it creates that what we call solidification, standardization and industrialization. And it goes across everything that we do, including the functions and every activity we have in the company. This is what creates that leverage. So when you get over 20,000 women and men working together every single day, finding those incremental improvements and being rewarded and celebrating those successes, that creates that momentum that gives us just a high level of confidence in room that we're going to be able to continue to accelerate and grow the performance of the company.

Great. Maybe 1 for Alf. Your net cash position has grown to just under the $500 million, I think it's like $439 million. You highlighted plans to return at least 70% of free cash flow. I just wanted to talk about what you think about the balance sheet and future uses of free cash flow because you have a very underlevered balance sheet. And I guess the ultimate question is could we see you returning essentially all of your free cash flow, just given how strong the balance sheet sits today.

Thanks, Arun. Thanks for the question. I think it's well placed. Yes, for sure. I mean we have taken care of a lot of things on the balance sheet, pointed out in my prepared remarks, $450 million of reduction of debt this year in addition to delivering on our commitment to at least 70% to shareholders. This debt reduction really reflects more than 50% of debt reduction since the beginning of the year. And clearly, our balance sheet needless to say, is just in great shape. We don't see any major change to our capital allocation, meaning we intend to continue to be a capital-light company. We have guided in the past that we will have CapEx in the range of 3.5% to 4.5%, and we continue to intend to stay at the low end of that range. So given also that we have taken care of most of our debt obligation, and we have really -- we like the maturities that we have out there for the rest of our debt, and we really don't see work in the debt structure significantly at this point. So it certainly leaves opportunity to -- when we say at least 70%, we clearly are focused on minimum that amount, but any excess cash, clearly, shareholder distributions will be one of the areas where we go to.

Our next question comes from the line of Derek Podhaizer with Piper Sandler.

Just to kind of keep going on Dave and Arun's comments about just the catalyst within the backlog improvement and the margin outlook. You talk about the industrialization, you have the Subsea 2.0. But Doug, can you maybe talk to us about what 2.0 could mean for the surf side or the installation side of things? Just thinking about those continued catalysts as we work towards the year, just the continued improvement of the business.

Sure, good morning, Derek. I don't want to say too much, but I think there is a significant opportunity to further industrialize the full iEPCI scope. So remember, back in history, we were running them in parallel. We were working on the Subsea 2.0 configure to order for the SPS or the subsea equipment portion of the -- of our activity. And then as a result of the merger, we now have the ability as a single entity, and you cannot do this if you are not a single entity because it has, let's say, conflicting behaviors between a traditional surf company and a traditional equipment provider. So as a single entity, now for 8 years. It's been 8 years ago that we actually merged. It gives us the opportunity to expand that across the whole portfolio. So I am sure you all will have an opportunity to hear much more about that in the future. But I'm going to be a little bit quiet today, which I know is not my normal behavior, but there is a -- it's an incredible opportunity, but I am going to stop there. We're working hard at it.

Got it. Fair enough. I appreciate that. Second on the subsea opportunities list, it's pretty noticeable and evident that scope of over $1 billion is meaningfully increasing really since the middle. Could you talk about the drivers behind that? I'm assuming the certainty that you guys bring to the table. But where could this ultimately go from a project scope perspective as we continue to see that wedge just increase over time?

Thank you. I didn't think of it as a wedge, but I'll take that. It's certainly been an ever-increasing wedge. And we've talked a lot about that, including the prepared remarks and that's really being driven by the fact that the best reservoirs are offshore, at least the best reservoirs that are accessible to the marketplace. So the capital is going to flow in that direction. It was always -- there was always some hesitation by our customers in the past, again, because of the unpredictability of the execution of offshore projects. What we have brought back to the industry, we've given our customers their mojo back, we have our mojo, and it's simply a fact of being -- performing well every single day, giving our client confidence by providing certainty. We have to reduce cycle time every single day. whilst providing certainty. If we can do that, and we will do that, we have done that, and we'll continue to do that. That will give our customers great -- ever greater confidence to invest more and more of their capital allocation to the offshore. It just makes economic sense. The breakevens of the projects, the returns on the projects the reserve base of very minimal decline rates compared to other areas that they can invest in. It just makes sense. So look, the opportunity list continues to strengthen. As you pointed out, Interestingly, the 3 new projects that are on the list are all gas. I wouldn't overreact to that. I think -- but I do think there is something to be said about that. I do think gas is a bigger portion of the future of the hydrocarbon mix in particular, in the offshore. And again, a lot of these offshore gas as LNG. So we often think about LNG in a terrestrial way because LNG is the physical thing that you see is often on the key side. But a lot of the supply of that gas is coming from offshore gas, particularly outside of the U.S. So anyways, it's an interesting combination of projects that were added, but here's something -- maybe here's just a little teaser for you. The livid you don't get to see, which is our proprietary opportunity list, which drives our direct awards, that list has grown at an even faster rate.

Our next question comes from the line of Ati Modak with Goldman Sachs.

Can you talk directionally about the outlook for Surface Technologies for '26 given the Saudi activity potential? And then you also raised the margin guide for '25. So maybe help us understand the drivers there as well

Sure. So we talked a bit about it last quarter. I'm super proud of the team. They've taken the necessary actions to ensure that they can provide adequate returns to the company and to our shareholders. We've focused where and what we do. And as a result of that, they're able to deliver quite exceptional results and actually improving results when others in this realm, I think, are going the other direction. So I will tell you the outlook is less certain. It is why we did not include that in our early guidance. We were able to for Subsea, but the Surface or the Onshore business remains much less predictable. Certainly, the -- historically, the level of continuity in our international business or non-North America business, it's much more predictable. It has less less downside swings to it, if you will. But it's still very early. And we are talking to our clients now. We're working through that on a budgetary work. There they're doing it themselves. So there's not a lot of information to be exchanged. But we positioned ourselves with the right customers, in the right basins, providing the right technology. And we've had very good success with our iComplete offering, which is the digitalization of the entire frac pad, not just the [indiscernible] digitalizing their work or the wireline company digitalizing their work, but we put an overlay interface, where we can control the whole well site, allowing record performance in terms of continuous pumping. So we're going to continue to bring those high-end solutions as well as continue to benefit from the in-country investments that we've made in local manufacturing in the Middle East, where we are very well positioned with those clients, and we'll continue to succeed on a relative basis because of those investments that we've made. So just a little less clear at this point, and I think we will provide that guidance along with our -- the full company guidance and -- with our Q4 results as we do historically. It's just a different business than our Subsea business.

Got it. That's helpful. And then can you give us an update on the electric Subsea infrastructure opportunity, where that stands as of now, I've seen some announcements from some of your peers earlier this year as well. Just wondering if that is starting to become a little bit more topical and what that could mean in terms of orders and margins for you?

Sure. It's progressing. What you've seen is to greenfield, all-electric awards. TechnipFMC received the first-ever All-Electric Subsea award and that was for the BP Northern Endurance partnership project we announced a few quarters ago. And then more recently, there was an award in the North Sea. We have said this, and I'll repeat it. I think the level of transition in terms of greenfield developments, to all-electric are not going to be as strong as I originally had anticipated. But there are 3 areas that are most definitely going to benefit from all-electric. And the third one being actually very, very interesting and very new. So those 3 areas are carbon capture and storage. We believe they will go -- they have gone all electric, and we'll continue to go all electric. So all of those opportunities that we're working on or we have secured are based on an all-electric infrastructure. And we have the industry's only certified all-electric CO2 injection tree, and that's important. The second area is in the area of brownfield tiebacks. We've talked about this before. It increases the radius from the host facility by about 4x and potentially even greater than that. And that has a lot of implications and positive implications in terms of customers being able to tie back to existing infrastructure, very low -- at a very low breakeven or very high returns. It helps us not only in the fact that we have the old electric solution, but we have other solutions like flexible pipe and subsea processing that all kind of come together to create that opportunity. And then the third area is where we're actually now able to retrofit hydraulic trees with electric actuation, if hydraulic actuation was to be deteriorating, there's always redundancy, so it doesn't fail. I don't want to say -- I don't want to put the wrong impression in your mind, but when it starts to deteriorate its performance over time, the customer would have to retrieve that tree, bring it back to the surface, take it back to the shore and retrofit, reinstalling, that is certainly months and can be quarters before that production is put back online. We have developed a novel solution to be able to go into a -- in situ on the C4 with the use of remote-operated vehicles and swap out hydraulic actuation controller for electric actuation. It is really interesting. And obviously, you don't lose that multiple months, multiple quarters of production. So it has a lot of upside for our clients, too. So I just think the original focus of electric as well, all new projects will go all-electric. I just don't think that's the case anymore, but we are finding by having invested and developed the technology, we're finding these other applications that could be quite exciting as well.

Our next question will come from the line of Sebastian Erskine with Rothschild.

Can you hear me now?

Yes, we can.

The first one, just a bolt-on, it's a very strong year for TechnipFMC on order intake. But I think a theme that has emerged perhaps is that some operators have kind of chosen a bit, they're going to slow walk deepwater FIDs. Some competitors have called Sub-Saharan Africa is a good example of that. And I also saw an estimate that was putting company tree awards down mid-teens percentage year-over-year in '25. So it would be great to kind of get your perspective on how the cycles evolve year-to-date versus your expectations at the beginning of the year? And I guess, looking forward, perhaps, what are the specific key basins that are going to drive '26 for you?

Sure. So look, I just have to be candid. We're not experiencing that. And I think that's clear. I mean, 3 years ago, we called the market and we said that the market was going to be resilient. We were going to be able to secure $30 billion worth of awards over a 3-year period, and we're well on track to do that. So -- and as far as our expectations for this year, they're right in line with original expectations, which is we said would be in that $10 billion range. And now we're saying we'll be more than $10 billion. So I'm not sure what others are experiencing, but our results, I think, speak for themselves. Now let me maybe explain why. Remember, 80% of our business is direct awarded to our company never goes out to competitive tender. So just think about what that does to the total available market. The total available market that's left is very small compared to what we have privileged access to because of the trust and the confidence that customers have in us, our unique offering and our ability to be able to reduce cycle time, improve their project returns, hence leading to those direct awards. And that's why when I say that proprietary data set that we work on our opportunity set that we're working on, which is not on our public list. Even though that public list is growing, those other projects are are only accessible by our company. And keep in mind, we are at the table very early because these are direct awards. We are doing the concept study. We're doing the pre-FEED study. We're doing the FEED study, and we're going straight into an iEPCI 2.0 execution. So I guess we just have greater visibility.

Really appreciate that. And a follow-up on that. I mean, looking at your backlog at a very large level, I'd like to get your perspective on kind of resourcing to execute that level of work. And I read somewhere that had increased staffing at your manufacturing facilities in Brazil, Malaysia and the U.K. by some 20% to 40% in 2024 versus a kind of base of '21, so post-pandemic. Are you happy with the resourcing at the moment? I guess looking at it, given the tightness is, are there some concerns in the industry around potential bottlenecks or capacity constraints? And how are you positioning to execute that work.

Well, first of all, I can't confirm those numbers. Those are new numbers to me, but I'm not sure where they came from or what you heard, but let me just answer the question more broadly. First and foremost, and this is a commitment I make to every single customer, we do not take on any work that we can't execute. And so look, we know bid work. I mean there's work out there with our competitors, we're now bidding it. It's very clear if it doesn't meet our threshold in terms of the quality of the work or the type of execution that is expected or where it is expected or the currency in which we're going to be paid or the risk that we're asked to take on, and we will just now bid that work. So first of all, it's -- what we inbound, we have a commitment to deliver and it's important, deliver on time, on budget. I mean the reason why we get repeat awards is only because we're performing at a very high level. We have never not gotten a repeat award. We often replace the competition. I mean it is a very different scenario in terms of how we are operating versus how we used to operate, which is all the industry -- the rest of the industry still operates. So I really can't say much more than that other than we just have a different operating model. It took a lot to get here. Thankfully, we did it 10 years ago. And so now we're singularly focused on execution. We're not focused on anything else than delivering to our clients and meeting their expectations. So long answer to your question is we are very confident in our staffing levels. We're very confident in the resource levels. The whole strategy of the company and reducing cycle time is the ability to do more with the same. So it's not about staffing levels. It's about being more efficient.

Our next question will come from the line of Marc Bianchi with TD Cowen.

I wanted to start with some more questions on services. So Doug, can you remind us what the mix of services between like installation versus servicing your installed base is in the business like roughly? And the reason I ask is the the comments earlier about kind of '26 and a service growth rate looking like the overall subsea, I would have thought that services could be doing a better growth rate than sort of decelerating, so maybe you could unpack that a little bit for us? And then the second part of it is like if you look longer term, is there anything we should be thinking about how the integrated awards that you've taken in the past several years affect the servicing opportunity and then anything with like the vintaging of your installed base as we come up on maybe some anniversaries of more service opportunity?

Sure. And thanks, Mark, for bringing us back to service, its important. The only thing I would disagree with in your statement, I think you said deceleration. There certainly hasn't been a deceleration. Look, you do get a compounding effect. The larger the installed base, the more opportunity set there is, and certainly, the higher the volume, the longer the tail and the more opportunities you have. So let's talk a little bit about the mix of services. So yes, you have the original installation activity. And then you have all of the activity around the inspection, maintenance and repair of the installed infrastructure. And then you have another bucket that's all around refurbishment of equipment. And then you have that final bucket that's all around intervention services. And what is very beneficial, not just driven by iEPCI, but just probably driven by the market presence that we have is that whenever the wellbore needs to be intervened on or in which happens at a much higher frequency than the equipment because the equipment is built to last for 25 to 35 years. We come out -- we provide the services associated with giving the client assets to the wellbore. So that's what I mean by that intermittent work. So -- and wellbores can fail within the first year, wellbores can fail within 5 years. The more intelligence and all that, that are put in the wellbores, it's just more opportunities for things to potentially need to be replaced or repaired, which means we are involved. So look, there is no doubt that we have -- the Subsea Services business has grown substantially. We I gave some prior guidance for this year at about $1.8 billion. As you know, that's almost double where we were not too long ago. So yes, very proud of our Subsea Services business. It is a business that's going to -- it's not just the quality of the earnings associated with it, but it's having that leverage in that footprint and that sustainability and continuity. So perhaps my remark about it being growing in line with the core business, which is also growing at a good rate, maybe made it seem understated, but that wasn't the intent.

Got it, great. And my second question is just around fourth quarter. And if I sort of look at what the revenue guide is here for Subsea, it would look like you're highly covered with backlog like more than usual. But I think there were some conversations during the quarter about some extra vessel downtime beyond normal seasonality. Maybe you could just unpack a little bit what's going on there, and maybe how we should think about how that progresses through the -- into the first quarter?

Sure, Mark, Alf here. So yes, you are right. First of all, we are well covered on the backlog. We did have a strong Q3, and -- but we are, as you point out, guiding Q4 down versus Q3. And that revenue is declining largely through the utilization of vessels. We have this seasonal activity levels pretty much every year, where we see that decline, particularly in the North Sea. But overall, it's affecting our ability to go offshore and generate revenue. So that's there. And then we talked about the revenue -- the associated EBITDA decline. However, when you look at the big picture of where our guidance was in terms of revenue, we were at $8.6 billion of midpoint. And if you kind of take this all together between the Q3 and the Q4 performance, you'll see that there is an uptick and an expectation that we will be above midpoint for the full year when it's all said and done.

Our next question comes from the line of Saurabh Pant with Bank of America.

Doug, you gave some good color on 2026, and you gave that color early, a lot of good questions, but your revenue is still below the orders you have been booking for several years now, right? So there should be upside going forward. What I want to focus on bags as you enter deeper into the execution phase of this backlog, right? What are you focused on? What are you looking at, especially among wondering both the installation, the side of things. the vessel side of the market, especially given some consolidation out there. Just maybe talk to the execution side of things as you execute on the backlog and orders you're booking.

Sure. I think the biggest thing to focus on, and we've talked about this previously on calls was just if leads the quality of the inbound, which obviously goes into the backlog, which then has to be executed. And what we know is we know there's more iEPCI, we know there's more 2.0, and that creates a significant level of confidence in our ability to be able to execute those projects. I said earlier, it came out on a couple of the earlier questions. it's all about relentless pursuit of the reduction of cycle time. Sure. That makes sense. It means our customers get a higher project return. It means they're happy for us to share a greater portion of the economic value that we create, but it also has to do with our internal efficiency. And again, being able to do more with the same or the same with the last, whatever scenario you might be in. But that's how we're able to ensure that we can deliver this backlog successfully for our clients and maintain that reputation and the honor position that we have with our client base today.

Right, right. No, that makes sense, Doug. As maybe a quick one for you or maybe correct me if I'm wrong on this. I think I heard you talk about 55% normalized free cash flow conversion, right? And I think you were assuming neutral working capital in that, [indiscernible] I'm wrong. And then how does the order exceeding your revenue dynamic play into it, right, as long as orders are above your revenue, should we think that working capital should continue to be a tailwind? Maybe just spend a couple of minutes on that, Alf, please.

Sure. So first of all, maybe the clarification maybe I made around our normalized working capital -- normalized free cash flow conversion. Again, I said that before, we have talked about it being 50%. And now as a guide at this point in time, we say that if you think about our EBITDA, we think we will be getting around 55% conversion from that EBITDA number if you assume working capital neutral. You're right about the dynamics of working capital being a variable to our business. And clearly, in a period of significant growth in inbound, providing that you can get the high-quality backlog that we've been able to do that gives us the ability to achieve early milestones and ongoing milestones in the projects and allowing us a consistent execution. We have the ability to stay neutral or better which is always the ambition we have as we execute the incremental subsea work. When you now look maybe a little bit at the inbound picture year-over-year as we kind of have similar inbound year after year. we may see some diminishing opportunities to incrementally build on that, but that's certainly always our ambition. But at this point, if I'm looking ahead, I wouldn't go much about neutral working capital at this point if you're looking ahead but that's certainly something to -- that we will come back and guide further on when we come back in February.

Our final question will come from the line of Mark Wilson with Jefferies.

Obviously, the adoption and the resilience of what you put in place here just jumps off the page yet again. And I'd say the ExxonMobil ahead Subsea 2.0 awards seems to be the ultimate validation of that. However, one part, Doug, I'd say that we haven't touched on is the question about installation capacity out there in the market, still essential for all clients. And obviously, you work with Saipem in Guyana at Hammerhead as well. So could you just update us on TechnipFMC's view on that merger that's going on to Saipem 7 in the market, and whether you see any impact from that regarding the vessel infrastructure you've spoken to in the past and indeed, if anything, worth commenting on your submissions regarding that process?

Sure, Mark, and thank you for your patience. So just a clarification. So well, first of all, thank you for the comments. Those are well received. Yes, the seventh project in Guyana was critical. The fact that 2.0 shows that evolution, that continued market adoption and with obviously a very important client to us. The only thing I need to clarify is we don't work with Saipem in Guyana. So we do and our scope is our scope and then the installation scope is bid separately. So that question would really need to be answered by ExxonMobil not by ourselves. In regards to the merger, look, the regulators will make their decision. Our customers will make their decision. So they ever the regulator decides and then there's whatever behavior the clients decide on how they want to react. We are in a position where when asked or encouraged by our clients or the regulators to comment. We have a responsibility to comment, and we're just providing clarifications on market, market segmentation and the way that the market operates, but it will be what it will be. Keep in mind that we have this relentless pursuit of reduction of cycle time meaning if we can now deliver a subsea project in 2 years versus 3 years, I've created 33% more capacity with my existing fleet. So this is about being more efficient, having higher returns, not having more assets.

And I'll now turn the call back over to Matt Seinsheimer for any closing comments.

This concludes our conference call. A replay of the call will be available on our website beginning at approximately 3:00 p.m. New York time today. If you have any further questions, please feel free to reach out to the Investor Relations team. Thank you for joining us. Regina, you may now end the call.

This will conclude today's call. Thank you all for joining. You may now disconnect.