Okay, I think we will try to make a timely start because we have a webcast going. A warm welcome to this first quarter 2025, and we're on by FID. The long gestation period is over. Presentation by BW Energy. This presentation will be hosted by Jérôme Bertheau, our Chief Technical Officer and in charge of the Maromba project. Thomas Young, our Chief Strategy Officer, who is here to present the financials we have, or the project financials. Brice will round up the presentation and complete the quarter. We also have some key people from the Maromba not only project, but involved in our Maromba development, our Brazil office. If you can raise up when I say your name, that's fine. Alex Almeida, he's our regulatory responsible for Maromba and Brazil. We have Chris Boyers, our subsurface for Maromba. We have Thomas Kolanski, our Chief Business Development Officer. We have Kei Ikeda, who's responsible for the FPSO refurbishment. Last but not least, Ricardo Mucci, who's our GM in Brazil. Please ask these guys questions. I know there's some questions around regulatory process, etc. Please benefit from having these people here and ask questions after we have finished the presentation. Please note our disclaimer, as usual. Highlights for the first quarter. We recorded a quarterly EBITDA record. Very pleased with that. We had a $74.8 per barrel realized oil price. We may not see that next quarter, but still, it was good to have such a quarter. We had a net production of 36,000 barrels per day, which gave us 3.7 million barrels sold in the quarter. We made a substantial oil discovery on Bordeaux. The other highlight is, of course, the Maromba FID, which we're going to present today. We had a very solid cash position of close to $287 million. The key figures for the revenue, we were suitably up on the first quarter last year, 55%, $282 million. Also up on the fourth quarter due to improved production regularity. We had an EBITDA of $182 million, also significantly up, and net profit of $83 million. We had an operating cash flow of $155 million. Also significantly up on first quarter 2024 and the last quarter. We have a diversified asset base, and I am particularly fond of these numbers. We have close to 600 million barrels of 2P2C reserves, which to me talks to that we have a long horizon in front of us. We have 230 million barrels of 2P reserves net, and we have 10 operated fields. We're also involved in one non-op operation. Last year, we produced 10 million barrels, about 27,000 net barrels per day. 10 million barrels. That gives you a kind of perspective on the longevity of our business, I think. It's a pretty good resource position for a company our size. Our production increased in the first quarter. Very good regularity on all operations. Of course, we could also note a reduced unit cost, mainly due to the increased volume, but also some increased efficiencies in consumption of natural gas, diesel fuel, etc. We had another reasonable quarter in terms of environment. We had zero loss time incidents, but we did have one environmental incident. That was a spill of drill fluid due to equipment malfunction. It's been, of course, notified to the local authorities and dealt with. On to Gabon. Dussafu production was 2.6 million barrels, up 3% from the fourth quarter. Very good regularity, as I mentioned. We had all production wells online. Our operating cost reduced to just below $10 per barrel. Please note that we have changed the reporting regime. We are excluding some royalties and tariffs. This is to be in line with what is common when you report costs per barrel. We have a break in our reporting. If you look for numbers across, you will see that. It is because we are now more in line with what is usual in our business. We had a very good turn on Bourdon with a nice discovery. We have discovered very good reservoir, and we have the best fluid quality of all the Dussafu discoveries so far. We are very pleased with that. We drilled three penetrations, two into the main reservoir, and we are very confident with what we have found. We are going to very shortly start the process of planning a development similar to what we have done on Hibiscus Rouge. The initial plan is for four wells. Of course, we are now fast-tracking our understanding of the nearby bumps as well to see or to map out an appraisal program that will go along with this development. Very exciting. Again, bodes well for Dussafu and continued success there. On to Brazil. Golfinho also saw a good increase in uptime, and we were up 12% on production to 600 and close, yeah, 56,000 barrels per day. Operating costs came down a bit to $42.2 per barrel. We had an unfortunate shutdown of Petrobras gas supply due to maintenance, which affected previous quarters. That was completed, and we now have full gas supply again. We will, with the FID Golfinho Boost project, now focus not on drilling in-field wells, which was our original plan, but on making incremental improvements in the production facilities to increase uptime, also reduce gas consumption, and install subsurface ESP skids, mudline ESP skids that will increase the production from the existing production infrastructure. The target is about 3,000 barrels per day and releasing about 12 million barrels of additional reserves. The investment is calculated to about $100 million. We have a break-even of this investment at $47 per barrel. We think it's a very attractive project. On to Namibia. The Karas appraisal well planning is going well. We are currently in negotiations with rig owners about rig availability. We talk, of course, also to our peers. It is, of course, good to see that people around us are still making discoveries. Rhino just announced a sizable discovery just south of us. That is good. Our process is tracking well. Our long lead items are in or will be in-house by June. We are ready to go in the second half. There is some uncertainty onto exactly what rig and rig availability. We may be third quarter. We may be fourth quarter. We do not know yet. It depends on the rig that we choose in the end. We had a very accretive start to 2025. The Burton discovery, the Golfinho Boost FID, and then the subject of this presentation from here on, the Maromba FID, which will be a transformative project for BW Energy. We expect the project to yield about 123 million barrels of 2P reserves. We target first oil end of 2027. It has an exceptional IRR at more than 30% at $60 per barrel flat forever, and a break-even of $40 at 10%. It will deliver a doubling of BW, or more than a doubling of BW Energy's net production. It is a super interesting project for BW Energy and will have material impact on the company. The concept we have finally been able to develop after quite a bit of back and forth. That has been mainly caused by swings in the market. What is available and at what price? The new concept, we benefit from the availability of large jackup drilling rigs capable of operating in the water depths of Maromba. The new concept is based on a jackup that will be converted to a wellhead platform with full drilling facilities. The development will consist of six plus six wells. The first six will go in and will give production to underpin the investment in the infrastructure. The real objective is to, in the second set, also appraise the other resources that are available in the Maromba concession. Again, just to remind you, we have 100% working interest. Our target is a plateau production of about 60,000 barrels per day. The total CapEx, that's including the 12 wells, is $1.5 billion. Maromba was discovered back in 1980. When it was discovered, it was one of the biggest discoveries of its decade. It was a very big thing when it was found. Petrobras and their partners drilled nine wells, eight found oil. They made five penetrations in what is called the Mystrictium. It's a very well-defined sand, and it's been highly appraised and delineated, as you can understand, by all these penetrations. They also carried out two drill stem tests where they confirmed the reservoir quality and the productivity of the wells. What we are addressing with the first 500 million barrels is very well-defined, very well-proven reserves. That is going to underpin the development. There is a lot more in the Maromba concession. There are underlying carbonates. There is a lot, there is Lobo and a number of names on secondary targets. The concept we have developed, and that is why we are so pleased with this concept, allows us to unlock all this potential in addition to the Mysterium. The Mysterium in itself is a super world-class project, which you will hear much more about from the later presenters. The price is, of course, to unlock some of these additional reserves. The first phase is the Mysterium, the focus on Mysterium, six wells, plain vanilla, get production going. We have the capacity to drill and appraise and infill, etc., to really benefit from the resources. The potential is significant. The estimates are around one billion barrels of oil in place. We can maybe not multiply by seven, which we have been able to on Dussafu. That would be great, but maybe not realistic. We do definitely have a fantastic runway. The future is to unlock these reserves and create very much the same type of dynamics that we've had on Dussafu. With that, I will hand over to Jérôme, who will take you through the project. Thank you. Good morning. We will take you through the value aspect of the Maromba project. Starting with the field layout, we intend to deliver first oil in 30- months from today. We will be using a wellhead platform, which will be a repurposed jackup, as you see in the illustration. It will drill the wells and as well support the production during the 20 years of operations. The production will be then routed to the FPSO Maromba, which will process the oil, gas, and water, and store the oil before it's offloaded. We intend to use the deep-sheltered tankers for the offload due to the weather condition in the Campos Basin. If we look now into a bit more details, the wellhead platform, as I said, is a repurposed jackup. It will hold 16 slots. We will be able to drill our 12 wells, but there will be some spares for future development and for future upside. The idea of the jackup will also be to support the ESP changeout when we are in operation with the derrick. When we will not have any more development, we will replace the derrick by a hydraulic workover unit. It will hold the personnel to drill. It has a 140 POB living quarter. It will be converted in a shipyard. We are actually pondering it now. All the production from the wellhead platform will be transferred to the FPSO via flow line. It is a 10-inch and a six-inch flow line. The process will be made on the FPSO. The FPSO will be designed to handle 100,000 barrels of liquid, 65,000 barrels of oil, and 85,000 barrels of water. It will be able to store 1 million barrels of oil before it is offloaded to shuttle tankers. Now, if I go to the FPSO, the FPSO was acquired by BW Energy. It's ex-FPSO Polvo, which was operating for BW Offshore. It's currently in a shipyard in Dalian at COSCO. We have conducted a FID, basic engineering studies, to define all the scope that we need to carry to be suitable for the Maromba oil and the Maromba field. We have done in-depth inspections to understand what's required as steel renewal and refurbishment so it can be operating for 20 years on Maromba. The Polvo FPSO was a turret-mode FPSO. We've decided, after some studies, to transition from that to a spread-mode FPSO. We believe that it's a much better solution, and it saves as well on the planning. I will show that in the next slides. This is a top view of the ex-FPSO Polvo, which is going to be FPSO Maromba. We have color-coded the scope. What is in blue on the illustration is new. We will replace the offloading holes, the helideck. We are refurbishing the living quarter. We are installing actually three new floors of living quarters, which were found not in condition for new use. As I said, it is going to be spread-mode. We will add the structure to support chain stoppers and all the facilities to spread-mode the FPSO. On the process side, we will mostly reuse the existing Polvo process. We will refurbish it, obviously. We will replace only the heat exchanger at the inlet of the process to be suitable for the new use at Maromba. The boilers were inspected and found not in condition to reuse. We will purchase new boilers for the Maromba project. For the wellhead platform itself, as Carl said, we benefit from availability of heavy-duty jackups. We secured a jackup for Maromba. The jackup will be both drilling and supporting the production for the 20 years. We have been through detailed studies on soil and lake penetration at Maromba and also structural studies as we are close to the limit of the jackup capability in terms of water depth. We have done the static and the fatigue analysis, and we have confirmed that the rig that we have selected is suitable for Maromba conditions. One of the challenges we had to overcome was the conductor pipes. You see them pink on the illustration. We need to keep those in position for 20 years because we are using dry trees. The span between the deck of the jackup and the seafloor is quite high. To mitigate this and limit the bending moment, we will install a subsea template that you see on the bottom. This template will be installed by the jackup itself. That will be fully self-installable. In Brazil, there is no specific equipment that will be used for the installation, only supply vessels. We have the story of Maromba on this. We have done that before in the group. We will start by a six-well drilling campaign that will start when the wellhead platform will be installed and the template is in place. We will be drilling at a depth of 2,900 meters, and we will land in the Mystrictium reservoir with an 800-meter horizontal section. The well will be completed by gravel pack completions to deal with the sand and to control the sand and with ESPs activation. One key factor for us to go for a dry tree solution was to be able to maintain our ESP. As you know, the run life of ESP is three to five years. We need to have a way of maintaining them. The solution we've selected is really made for that. Our design is also flexible for future upside. We will be able to connect flexible risers for gas import. As we see that along the life of the field, we will be gas deficient. We will have to import gas from others. We have raised that the aquifer is not connected to all the portion of the reservoir. We have left space available for future water injection on the process and as well space available to put water injection risers on the wellhead platform and FPSO. We will leave space for further upside on both units. Looking at the planning now, we are intending to have first oil in 30 months from now. The FPSO is currently at the COSCO Dalian shipyard. We have a 24-month program before it leaves the shipyard. The main constraint on these 24 months are the boilers that we are intending to purchase very shortly and the living quarters that we are refurbishing and, as I said, building three floors new. The wellhead platform has been secured. We have purchased the jackup. The delivery is scheduled for Q4 2025. We are working on the detailed scope for the yard that we will shortly ponder. The idea being to start the refurbishment and conversion as soon as the jackups reach the yard early 2026. This activity will take eight to nine months before we can dry tool the jackup to Brazil for its installation on Maromba field. We will start drilling end of Q1 2027, early Q2 2027, the intent being that we have two wells completed when the FPSO is ready to start. We will have first oil with two wells already drilled. The SURF is critical because the delivery of flow lines and umbilical is quite long these days. We have launched a tender already, and we intend to order that by the summer. It is a 22-24 month delivery. Finally, the drilling. We will drill the six wells in a row. The drilling is 51-53 days per well. As I said, we will start production after two wells, and we will be in seam off between production and drilling after that. We mapped out a robust regulatory roadmap. It is very small, but it is really to show you how detailed we went to map all the processes that we will go with the regulatory bodies to get validation on the various aspects of the project. Our strategy is to engage early and be proactive with different regulatory bodies in Brazil to make sure that we receive early feedback and we can incorporate that in our design. Also, we will get the agencies in the yard so that they can audit the unit before it gets to Brazil. We can have the full list of commands and punch list, if there is one, so that we can solve that in the shipyard rather than offshore. We know that we will be more efficient in the shipyard to deal with commands than offshore. Finally, our strategy is to repurpose existing unit. This has a significant impact on our greenhouse gas emission. We have calculated the impact on both FPSO and the wellhead platform. As you can see, the FPSO refurbished will generate 75% less CO2 than if it was a new build. The wellhead platform itself will be 65% lower emission than if we had built a new jacket-type platform. This is a cycling economy. I will hand over the presentation to Thomas. He will talk about the financing. Thank you. Thank you, Jerome. Hello, everyone. I'll start off with giving a bit of an overview of the CapEx for the project, a bit more granularity. You have the $1.5 billion. That's for the wellhead platform, the FPSO, and the 12 wells. To break that down a bit further, we have $1.2 billion for the initial six wells, plus the FPSO, plus wellhead platform. Then $300 million that comes in the secondary phase. Prior to first oil, we're looking at roughly $1 billion. You can see that kind of spread out fairly flat on the phasing of the project. In terms of the $1.2 billion, roughly 70% of the $1.2 billion relates to the production infrastructure, so the FPSO and the wellhead platform. That's a relatively stark difference to where we were before with the subsea development. It was rather flipped. It was 30% infrastructure, 70% wells. The benefit we get from that is we managed to reduce the incremental well cost in a dry tree development case, which is fairly impactful. The first benefit we get is obviously we get a higher well inventory because the threshold just went down. A dry tree well at $45 is roughly one-third of the cost of a subsea well. It means that we can add these next six wells, and they're all in the same proven reserves, and they're all highly economical. It also means we can de-risk the project quite a bit. I mean, it's cheaper to deal with issues as they arise. I mean, dealing with ESP workovers is cheaper, faster, with an integrated drilling platform. We can do further appraisal work. It costs roughly $30 million for an appraisal well. That will allow us to further appraise the field and then set up the subsequent phases, which is what we did at Dussafu. It also allows us to test some of the nearby carbonates and the producibility of the fields. Carl mentioned that there are carbonates around in Restriction Main, and there is also a lot of carbonates over in the west of the field. That allows us to kind of test and set up, hopefully, the subsequent phases as we move around. I would like to just carry over this $1 billion. That is quite important. Here you can see the split of the same $1.5 billion, but the pre and post first oil. Obviously, post first oil, it is financed with the funds that we produce at Maromba, which is significant. Prior, it has come from external sources. We have initially cash and RBL. That's cash and available on the RBL. Just as a reminder, the RBL is a revolving credit facility. We can draw down on that, distribute it, and spend it on Maromba as we see fit. We use that to adjust our interest exposure. Secondary, we have the FPSO financing. That's a dedicated project financing for the FPSO. It's export credit agency-backed, so ECA-backed, with Sinosure. It's with a group of Middle Eastern banks led by ADCB and ABC Bank. And China Exim Bank is in it as well. It's relatively long-term. It's nine and a half years door-to-door. Because of the ECA component, it has a lower margin, which is great. Overall, it works well for us because we can draw as we require it. The wellhead platform lease, we signed a term sheet with someone that we worked with before. It functions as a traditional lease in the sense that it's 100% financed, effectively. It's up to $275 million. It has a tenor of roughly construction plus 10 years, so long tenor, which is helpful. Finally, we have a committed shareholder loan from our largest shareholder, BW Group, of $250 million. That's available to us should we need it. It's a 36-month kind of working capital loan that we can put in place rather quickly. We'll see do we need it, do we not. That's there for us to use if we need to in relation to Maromba. Finally, you have the free cash flow from the rest of the business. That includes Dussafu, Golfinho, CapEx for Rouge Phase 2, Boost, etc. You can see kind of all in all, we're in a good spot when it comes to funding the Maromba project. I'm going to jump to OPEX. I say it's predictable. It looks very variable. What I mean is, well, it's variable here because of the OPEX per barrel. What I mean is the underlying absolute OPEX is fairly predictable and steady and flat. Only 5-10% of the OPEX is variable. And when I say variable, it's variable with production. And then I mean it's primarily lifting costs. So if you produce more, you lift more, deeper shuttle tankers come in more often, you incur a higher cost when you do that. Generally, it's pretty flat. We've benchmarked this with the fields around Maromba. Polvo, we know very well. The Polvo field. Papa Terra field, Peregrino field. Most importantly, we've benchmarked it with Golfinho. That's our operated field. It's with an FPSO. It's in Brazil. We have a decent handle on the OPEX. Key difference with Golfinho. Golfinho is gas deficient. We're importing gas. That costs quite a bit. We don't have that issue on Maromba just yet. The infrastructure at Golfinho is older, so more repair, life extension, maintenance costs. On Maromba, we also have an extra piece of infrastructure, which is the wellhead platform, and that will add a little bit of OPEX. Generally, we're in a good spot with OPEX, and hopefully, we'll see some synergies between Maromba and Golfinho as well. The kind of five-year weighted average OPEX per barrel on Maromba is expected to be roughly $9 per barrel. The fiscal regime, it's a simple concession arrangement. Unlike Gabon, in Gabon, we have a PSC, which is more a partnership model with the state. We pay our tax in kind, in barrels. Here in Brazil, it's just corporate tax and royalties. This is a round zero license, so it's even simpler. The later licenses have special participation tax. Other types of tax, we avoid that. We also do not have any local content requirements on Maromba because it's a round zero license. We added a comparison here. It's from Rystad. It shows comparisons of government takes. Obviously, lower is better. Actually, because Maromba is a round zero license, we sit a little bit below that. We're somewhere between 35%-40% government take, which is good. We included this graph here. Maromba is positioned among top global projects. This is from Goldman Sachs' top 100 projects. It shows top as in having a low break even. Maromba isn't currently on the list, but maybe one day. The difference is really with these mega projects is typically you achieve scale by having a big investment. Bigger investment, you bring down scale, you bring down that cost per barrel. Really, for Maromba, which currently sits in the top 10% of this list in comparative basis, we achieve that similar scale on the economics by redeploying infrastructure. Really, by bringing down the cost of the infrastructure, we've actually able to bring down the break-even to $40 a barrel, which is quite significant. You could say, yes, the greenfield is risky, but a greenfield can also be, with economics like this, can also be quite forgiving in the sense that, I mean, if you just take the Grand Marugu project in Suriname, that's a $10.5 billion project with a $57 break-even. For us to achieve that and to still be below the average break-even of the top 100 projects, we could have a more than 50% overrun on the Maromba project. It speaks a little bit about how robust the economics are in Maromba. Finally, we're set to generate material value. We set the target in 2020 of achieving 50,000 barrels of operated production. With Maromba, we'll get close to 100, especially together with all the other stuff we've got going on. We'll reduce our OPEX in half, which is big. Our OPEX per barrel will go from roughly $30 to roughly $15 per barrel, which will make a big difference. It will give us diversity, and it will give us diversification. It will also give us materiality, which is key. I think most importantly, it will also continue to prove up this model where we take, we buy undeveloped barrels. We unlock them through repurposing existing infrastructure, which allows us to get great economics like this. There are not a lot of other companies like us that do greenfield developments like this. Yeah, I'll leave it at that and hand over to Brice. Thank you, Thomas. As you have noticed, this is our best quarter since startup. All of this is possible because our financial situation is very strong. We have a strong balance sheet and very good result coming from the operation. We had three Dussafu liftings and one Golfinho lifting in this quarter, supporting the operating revenue is very solid due to a strong production. We had a loss in oil derivative of $0.9 million. That's unrealized. Operating expenses of $99.8 million for this quarter. Depreciation and amortization is a bit up. This is due to the higher production. We have some adjustment in interest expenses and other financial items. A profit before tax of $109 million, $26 million of income tax expense. There is $8 million of tax deferment adjustment in it. We finally have $83 million of net profit at the end of the quarter. Very good results for the company, supported by strong production. To the cash flow, we had $221 million at the end of December, operating cash flow of $155 million, and net investment activities of $81 million, $8.6 million of net financing activities, and a cash position at the end of March of $286 million. We have a total available liquidity of $407 million. That includes the unwritten debt, $120 million on the reserve-based lending facility available at the end of the quarter. To the balance sheet, we have a very strong balance sheet supporting the execution of our growth strategy. $2.1 billion of total asset. There is plus $50 million in Dussafu this quarter. Net interest bearing debt of $296 million. Very strong equity ratio of 46% and a NIB EBITDA of 0.56. You can see on the right side of our presentation the maturity profile of our debt. In here, we have $100 million of bonds. The $80 million of the Golfinho prepayment that we intend to repay by the end of 2025. The Dussafu RBL, $280 million. The maturity will be 1st of April 2028. We just renewed the facility and increased it to $400 million with an accordion option of $100 million. The Maromba lease of $138 million. Very strong balance sheet. I think it's the right moment. It's the good momentum for us to sanction our two main projects, Maromba and Golfinho Boost, because we have a solid balance sheet and operational cash flow to support these developments. For the guidance, we give the same guidance for production, operating cost, and G&A. On the operating cost, the OPEX are lower on our two assets, Golfinho and Dussafu. We had $11.7 per barrel OPEX in Gabon. That has been decreased to $9.9 this quarter. This is mainly due to more reliability in the process and less diesel consumption. We have exactly the same figure in Brazil, $45 per barrel OPEX down to $42, also due to less diesel consumption and as well better tax on the diesel purchase. We have a higher guidance for the CapEx. This includes Maromba and Golfinho Boost, $650 million-$700 million net for the company in 2025. This is the last slide of our presentation. BW Energy is a fast-growing E&P company with a differentiated strategy. The production is growing. Production is going up on our two assets, Golfinho and Dussafu. Costs are going down thanks to the efficiency, operational excellence of our team on site. We have a diversified asset base, so material reserve on both sides of the Atlantic in Gabon and in Dussafu. A success with Bourdon that we intend to develop as well. Exciting wells in Kudu and as well good opportunity with Nyosi and Guduma in Gabon. Basically, we have material reserve for the coming decades. What we intend to do, BW Energy intends to do exactly the same thing as we've done in Gabon, is to develop low-risk reserve with repurposed assets. We've done that in Gabon, and we will do that on the other side of the Atlantic in Brazil. We already have established subsidiaries, a very competent team. We know how to operate in Brazil, and that's the right time to do it for us. We are in a good path to double the production by 2028. All of this is possible because we have a solid capital structure, solid balance sheets, and a well-diversified source of financing. I think that demonstrates our disciplined approach to investment. Thank you very much for attending our presentation. Now we will take questions in the audience and then from the web. Thank you. Yes, Theodore? Can you tell me something about the markets? First, a couple of questions on Maromba. Could you say something more about the ramp-up speed for first oil late 2022, before the 60,000 barrels today? And then the next step from Maromba. We talked about farm down before. Should we expect that? Farm down before first oil? Could you talk about if you had any incoming calls at all? Final question on the Golfinho Boost project. Will that impact the production cost per barrel? If so, how much? We expect to start with two wells on Maromba. We expect the drilling time to be around 60 days per well. That will be the ramp-up. We will complete the, let's say, the remaining four wells in the first set of six in four times 60 days, so 240 days. It is a bit under a year. That will be the ramp-up. The second. Just for modeling purposes, then we should estimate 60,000 barrels per day by end of 2028, maybe. Yeah. Yeah. No, but early, yeah. We will start up, let's say, sometime between third quarter and fourth quarter in that three-month period. You could add 240 days. That's your ramp-up. We'll farm down? Farm down, I mean, everything is for sale. If somebody comes to us and wants to buy into Maromba, we'll certainly entertain discussion. As you understand, we're extremely comfortable about our project, and we're prepared to run it 100% on our own tab. We're very comfortable with Maromba. We're very confident with our plan. Yeah, sure. If somebody wants to buy into this exciting story, we'll talk to them. They will need to pay us a handsome pot of gold to get in. It's that simple. I know we're a bit unconventional, but when we get our head around the project and the development, we're prepared to go along. We have done that more or less, I mean. We lifted all of Dussafu in reality. I mean, we borrowed money to Panoro to do their part. We're comfortable. Golfinho or Flex Boost? Golfinho, that's a slightly different project. First of all, getting into Golfinho was really, we saw it as a very interesting way into Brazil and get established in Brazil. The main thing about getting established in Brazil was for Maromba to have a working relationship with the regulatory agencies in Brazil and have a working organization because Brazil is tricky. If you just land there day one with a $1.5 billion project and think everything is going to be honky-dory, I think you're doing something dangerous. We really wanted, we were looking for something like Golfinho, and we found it. Golfinho has in itself quite an interesting set of upsides. What has happened is that the subsea market has become quite frothy, and we've had high-cost inflation. We've reined back our ambition on doing in-field wells. There is a great potential for it. We do not think it is the right timing for that due to the frothiness of the market. If the market comes down a bit, we will be there. The project is really the fine-tuning of the machine. We are fine-tuning the production asset. We are fine-tuning the well performance. We are installing some of these subsea skids that we have developed to boost production from the existing infrastructure. That is Golfinho Boost. It is 3,000 barrels increment, I think, and we expect by the end of 2027 to be up to that. Of course, we will have some decline in the meantime, so you have to do a little bit of curve shifting. That is where we are. I do not know if you guys want to add anything. Just that we are also selling at the reopening of certain wells that they've got us threaded in. Those may add additional production. We are increasing the water handling capacity at the assault to do that. Okay. Thank you. Thank you, Theodore. There were some more questions. Yes. Tom Erik from Pareto. A couple of questions, please. First, congratulations on Maromba getting the FID at, I think, stronger economics than some expected as well. Looking forward now, where do you see the biggest kind of risks and which milestones should we look the most for? Is it execution on yards? Is it production from the wells when you start those up? Or is it kind of the regulatory process that could kind of trigger some delays? What are you most worried about, to put it that way? I mean, obviously, all the risks we know. We're trying offensively to tackle ahead of them becoming a problem. We have already gone to the yard. We have already done the demolition. We have a unit that we know well. We've tried to de-risk the yard. We have 24 months of yard stay in our plan. That is, I'm almost crying. It's too long. We should be able to make it faster. I think we have a very, I don't want to say relaxed, but I think we have a very, very hyper-realistic schedule. I don't think we'll miss that one. The regulatory process, again, we have a working relationship. We're in constant dialogue. Again, we have tried everything we can to de-risk it as much as we can. The work scope for the rig is very limited. It's a bolt-on kit. Most of the stuff is going on on the FPSO. All will be serviced from the FPSO. It's more or less just dumb steel parts going on. The rig in itself is capable of drilling. We, of course, need to inspect it, change anodes, etc. The work scope is fairly limited. It will remain more or less as is with a little bit of additions. The kit we will build to add is really going to be installed by the rig itself. We'll bolt on the well bay, and we will install the frame that we showed on one of these captions. Again, we have a very, I think, realistic schedule, not aggressive at all. It's not a kind of hurry-up type of schedule. We're super comfortable. I would say the only thing is the things I don't know. Obviously, I cannot speak about them because I don't know them. Those are the risks that are okay. It's very difficult to quantify what you don't know. But everything we know, we're comfortable. Perfect. Thank you. Can I follow up a bit on that work with the yards? How much of a difference does it make that you're part of the BW Group and have that main shareholder and you contact them and have them engaged to work for you? Is that a huge difference, or? It depends where you are. Of course, in China, it makes a big difference because in China, the group is building a lot in China. COSCO has just built quite a few wind turbine installation vessels, among others, for a group-related company. Yes, we have very good relationships there. Less so in other places because, well, they are less frequented by group vessels. In general, I think we have a reasonable name, yes, with the association or affiliation with BW, if you like. Okay. Thank you. On Dussafu, another discovery there now. Are we starting to see kind of maybe too early to put it into reserves and you need some planning? Internally, are you starting to see that you can maintain the plateau to 2030 and beyond? Yes. I think we're full steam ahead already on the Hibiscus Rouge phase two drilling campaign. That's being addressed. That was being addressed when we made the discovery on Burdon. Now we're kind of, of course, stepping through all the potential bumps that we see around Burdon because there's more there. If you remember, in the old days, it was called Prospect A and Prospect B. Abelia is the new A. Abelia is still there. Yes, we have, so we're now kind of stepping through all that based on the drilling we have just done and the new data we have from that drilling. We will probably be more forward-leaning and go full speed on our development because we know we have sufficient resources for development anyway. We may also then, of course, end up with two rigs in the yard, which could give some benefits as well. Okay. Thank you. Last question for me. If you take big picture now that you added major development, a lot of growth, should we think that now the company will be solely focused on delivering this? Could there be that you also want to balance with more acquisitions like you've done in the past of producing assets, things like that? Will you not kind of have capacity to look at that as well? Yeah. We're quite happy to invest counter-cyclically. Investing, I mean, the oil price isn't great. We're quite happy to invest in this environment. We know we have the projects that can support even this oil price, so we're okay. Are we then interested in doubling up with taking even more oil price risk by making brownfield acquisitions? That's something we're mulling over. There are quite a few opportunities out there that we're looking at. A brownfield is very much a pure oil price play risk. How much oil price risk do you want is something we have to ask ourselves. Thank you. Peter from Pareto. A bit on financing. Can you provide some color on the margins on the asset financing on Maromba? We typically don't disclose that, but on Maromba, because of the ECA backing on the FPSO financing, it's rather low, lower end of the scale. For the wellhead platform lease, it's kind of mid—let's call it mid-range for the margins. Because of the tax benefits you also get in terms of a lease, you do get some effective tax rate deductions on it. Thank you. It is good to see the committed shareholder loan from BW Group. You are writing in your comments here that you are considering also alternative financing solutions. You are well-financed seen from the project financing. Will that be in addition to the shareholder loan, you think, or instead of it? How do you look at those kind of things? Again, it's partly an oil price question because we do depend. The oil price will give a little bit of or will play over into how much free cash flow we get. We typically like to be a little bit of belt and braces on the liquidity side. The shareholder loan is very useful. It gives us great optionality to look at, okay, other types of financing. We have been looking, as you know, on a Nordic high-yield bond. We did one last year. We like the instruments. We are quite—we would be, when the time is right, when the conditions are right, we would be absolutely looking at that. We are also looking at other types of corporate finance as well. Some, let's say, not Western banks, but other banks are still quite keen on the EMP space. We're trying to open up new, let's say, tools there too. Yeah. Perfect. Thank you. Any other questions from the audience now? Maybe we take some questions from the web? Yes. Questions from the web. Do we have? What water depth is the Kudu field and the Karas wells? I think it's 640 meters. That's what we target for this well. Will the Burdon new development include subsea wells or a new jackup with dry tree? This will be a dry tree development. We intend to do quite the same thing as we've done on Maromba. No subsea wells. Question on regulatory. How are you prepared to get all the approvals? Maybe a question that you can take, Alex. Alex is our regulatory specialist in Brazil. Yes. As has been said, we already operate in Brazil, so we know how to do that. We plan ahead. We have already started the main processes. We have reviewed recent projects. We have set a very strong plan. We have approached regulators, show our plan, get their comments. We are very aligned with them. We are very confident that we are going to deliver the schedule. Thank you, Alex. Was there questions on Maromba reservoir? Can you elaborate on the reservoir data you have and the work previously done by Petrobras? We have our Subsurface Manager, Chris Boyers. Maybe you can take that question. Yeah. What's interesting about Maromba is since all the activity previously was done by Petrobras, it's really the question asked is, what haven't they done? They have pretty deep pockets. Most of what you see they do when they execute exploration or appraisal, they acquire all the data that you would. In fact, most operators would require less, would spend a little less. We feel that Maromba is quite well delineated. They have numerous well tests, not just the two in the Maastrichtian, which is the primary reservoir, but also in other reservoirs that we want to appraise later and develop on. You name the log, you name the sample, you name the study, it's pretty much fully covered. I would say if we would have done it out of the gate or a Chevron would have done it out of the gate, we would have acquired less. I think for us, we feel very confident that we have about as much as we can use. Thank you, Chris. Was there a question from the web? I think for you, Jérôme, will the Maromba FPSO flare off all produced gas, or is it only liquid produced? Obviously, we will start with a small production with two wells. We will ramp up, as Carl mentioned, over a period of 240 days. The production initially will cover the full gas requirement for the field. At some stage, we will have an excess of gas. It is going to be for a temporary period of estimated 12-18 months where we will flare the excess. Most of the gas will still be used for power generation. After this, we will get to further drilling to maintain the plateau of gas production to keep up on self-power generation. We know that the GOR of the field is not sufficient to support the production of electricity for the 20 years. We will be gas deficient in a certain time. We will flare partially for a short period at the beginning of the production. Thank you, Jerome. We answered most of the questions on the web. Maybe last questions. What are the major FPSO upgrades and key long-leg items? What are the key risk factors associated to this development plan? Maybe we can ask our FPSO manager, Kei Ikeda. I think, as mentioned by Jérôme, the long-leg item is a boiler that is 18 months. Okay. We have done all sorts of preparation to shorten the integration and the commissioning stage. That's one. The rest of the equipment is quite simple. There's no major authentic machinery like power gen, gas turbine. We don't have. Water injection, we don't have. Gas compression, we don't have. We are quite confident with the long-leg item. In terms of the major risk of the redeployment, looking around the industry, usually the supplies of the condition is usually the case. We have a very unique advantage of having the people who have actually operated both on onshore and offshore in this ORBO project. They were involved during the feed for the condition assessment. In terms of this risk, we are quite comfortable. Thank you, Ikeda. Thank you. I think we answered all the questions. Thank you very much for attending BW Energy presentation. Carl, I leave it to you to close. I do not think I have much to add to that other than, again, thank you for attending. I hope we have given you a flavor of the Maromba FID and why we are so excited about this project and the next step in the development of BW Energy as an E&P company. Thank you for attending. I am looking forward to talking to you again, hopefully not very long in the future. We discussed a bit before everybody arrived whether this format is good. I know we have become a bit lazy, and it is so convenient to sit behind your desk and do a webcast. Maybe we should at least on a regular interval do this face-to-face again. Thank you for attending. Thank you very much. Thank you.