Bw Energy Ltd

Okay. Good morning, everyone. Pleasure seeing you here live at Hotel Continental in Oslo. And also welcome to you who are following us on stream. My name is Martin Simonsen. I'm head of investor relations in BW Energy. And I'll take you through the Q&A session later. But first, we have a large part of our management team here today traveling in from Lisbon. So they'll take you to the Q1 2026 and strategy updates. So please save up some questions for them after the presentation. And with that, I'll leave the word to our CEO, Carl Arnott.

Thank you, Martin. Again, a warm welcome to this presentation of first quarter and we have added a small update on our activities. Please note our disclaimer as usual. So today will be hosted by first our Chief Operating Officer Brice Morlot that will take you through the operational update. Then Jerome Berthaud will take you through the Maromba update and then Thomas Young will round it off with the financial update. I will have the pleasure of taking you through a little lead-in where I boast about our exploits, of course. And then Martin will be taking care of the... He will be the moderator for the questions, Q&A. So first quarter, all projects on plan and cost. We have been able to sanction Burdon and new Golfino wells. And we have lifted our production target to more than 100,000 barrels per day, sustained production into the next decade. We have a strong position financially and we are generating cash so the business looks good and we had a very decent operational performance in the first quarter. That's the bottom line. EBITDA 111 million net profit 33 and this will of course be gone through in detail and our end cash position was a healthy 161 million plus we have of course unused facilities on top of that. So BW Energy is delivering on its growth strategy. We are pleased that we can now say that Maromba, which we presented to you last year, more or less exactly a year ago, we said we were going to do funding. We have delivered on all the funding activities. We have acquired the jack-up. It's now in the yard and the conversion has started and the FPSO upgrades are going well. So we are very much on track for first oil in end 2027 and we are working hard now on the next phases of the Maromba development. This is of course a big transformative project for us and we will go through that in more detail. Golfino Boost project is on track. We have done the initial subsea work that is completed. We are now entering a phase where we will focus on the FPSO and optimize that and its operations. This is an old asset and we have to lift the performance of this asset, which is something we have known about for a long time, which we are very capable of. We have done this many times in our previous life, so we know exactly what to do. But it is a significant effort, but we have now a very clear path for production and production increase. And that's why we are now going to take this significant step and upgrade Vittoria. We have sanctioned Berdon. This will add very material resources to our DUSIFU license. We have also achieved a license extension. But more of that will follow. The Bourdon development will follow the Mabomo blueprint. So it's a sister rig. It will be a somewhat simpler topside. but it will have 12 well slots and this is of course to be able to harvest from the greater Beurdon area. It will be placed in a location where it will have very nice reach over nearby potential resources. So we have also sanctioned four greater Burdon area appraisal wells, and we will also drill one well in the Walt Whitman area as the next area in the DUSAFU license we want to unlock. So again, DUSAFU continues to deliver We're extremely proud of the license and what we have been able to do with this license. Golfino, we have sanctioned new wells. These are infill wells, low risk wells that we will drill and connect to the infrastructure that is there. We're targeting to lift production from Golfino to 30,000 barrels. And we have now completed a very extensive study of the total Golfino area. We have a huge license in Golfino and we have now had time and let's say we've had the time to go through all the data that we have acquired with the license from Petrobras, the previous operator, and we are finding a lot of opportunities. More wells and more appraisals will follow on Golfino as well. We have identified a huge number of targets for these activities. We are actually 10 years this year. BW Energy and if we look back from 2016 when we started we estimate that about 300 million dollars has been invested and the current market cap is 1.5 billion. So we are, I think, rightly proud of that. And as we are going to explain today, there's a lot more coming and we're targeting more than 100,000 barrels per day in 2028. So our model, We have explained this many times, but I think it doesn't hurt to repeat. We are looking at discovered resource, but that cannot be unlocked with potential. That's the first step. If we get access to it, we reuse existing infrastructure, we repurpose, facilities. We thereby do not have to take on the huge investments associated normally with oil and gas developments. So we limit the cash at risk. We are now fully capable of doing all developments internally. Of course, we use subcontractors, but we run all our projects in-house. Then we prove up. We show that our models are working, that we get the production we're supposed to have, and then we scale. And on top of that, we have very efficient infrastructure financing. So we are very capital efficient. So this is the BWE model. I think we're quite unique in many of these aspects. And in particular, I think we're unique in our ability to repurpose existing assets and in the financing that we have managed to put together for these assets. So if you look at our Assets, we have demonstrated this strategy, I think very clearly. Jusufu started out 24 million barrels. Today, we have increased that by 580%. Golfino, not as significant yet, but we're working on it. And of course, Moromba, there was no clear path to development at all. So in percentage terms, it's unlimited. But of course, it's 122 million barrels of reserves in the current development. So in aggregate, I think we have an excellent track record of expanding our high quality resource base. And we have had excellent reserve replacement, which I think is also a bit unique as this is getting tougher and tougher in the industry in general. Our portfolio. So today, production is about 25,000 barrels per day. We operate two production assets, Golfino and Dusafu. And as you can see, we have five projects in execution and our total reserve base is more than 600. And we have a lot of reserve life left at current production, but we're also, of course, working to increase our resource base. We operate in what we consider to be very stable locations, very stable countries. I know there are some confusion on what stability is. We're not necessarily talking about political stability, but we're talking about stable conditions for the type of business we are in. And if you look at Gabon, they have an excellent track record of 100 years of never challenging PSA terms. That is more than you can say about a lot of other places where oil and gas operate. Brazil, we also see that as a stable country in terms of their support for the oil and gas industry and their interest in exploiting their indigenous resources. A bit more temperamental on tax maybe, but Still, we regard this as a very stable place. And all the places like Namibia, we think also has great stability. So we operate in what we consider to be an interesting part of the world, the Atlantic margin. Today we are executing, we have three projects in execution that will add 154 million barrels of oil equivalent to P reserves. We have just FID'd two more projects which will add 68 and we have significant growth potential in all these licenses. That is really the bottom line. So we have a clear path to sustaining more than 100,000 barrels per day production. And as you can see, this is how it's composed of project producing, project in execution and appraisal and upsides. And of course, we have a significant exploration activity. And just to remind everybody, we recently shot seismic of the Niossi and Gduma licenses in Gabon. We also covered part, the Walt Whitman part of the Dusevu license, where the seismic resolution was not perfect. So we are active also in the near field exploration activities already. So investment case, more than 600 million barrels of oil equivalent, reserves and resources, more than 100,000 barrels per day by end of 28, more than 30% IRR at 60, and we will generate between 2 and 4 billion US dollars at 60 to 90 dollar oil price from until 2030. So with that, I will hand over to Brice that will take you through Ducifu and Golfino and the operations in general. And then he will hand over to Jerome that will go through Maromba. And then we have Thomas that will take you through the financials.

Thank you, Carl. Good morning everyone. Operational performance and production availability stays high. At Dusafu, we completed a well workover to maintain ESP. The job was completed with a hydraulic workover unit, so without a rig in three months, so we are very happy with this result. and Dusafu has since returned to normal operating level. Production availability for the quarter is high at 86%. At Golfino, the production was impacted by one unplanned whale maintenance, but corrective measures are underway, and availability for the quarter was 79%. On the rig schedule, we have decided to optimize the 2026 drilling sequence to confirm the potential of the northwest hibiscus area. We will drill two pilot wells, the 10P1 and 10P2, and the objective is to confirm this area upfront because in a case of success, we will install two additional slots on the Mabomo well bay and we will increase the well capacity of the platform from 12 to 14. So that means that at the end of Mabomo phase 2 draining campaign we can add two additional wells and we'll have six wells in production by the end of 2027. Therefore, we are updating the 2026 guidance to 23,000 to 26,000 bpd. The revised reading sequence is a value-driven decision and it sets the stage for higher long-term production capacity at DUSAFU. On OPEX, OPEX were impacted by one workover in Gabon and one unplanned maintenance in Brazil. So the Q126 OPEX came in at $26.9 per barrel. So this reflects two factors, the lower production because of the Goldfino well maintenance and the workover cost at Dusafu. So in light of this production outlook guidance revised, we revised as well the OPEX guidance to $22 to $26 per barrel. The change is driven by a revised production range and it's not indicative of a structural cost increase. Let's go to Gabon now. Dusafu remains the backbone of the company. And this illustration is interesting because it demonstrates the strategy of the company, which is repurposing assets to develop discovered resources. The company installed the FPSO Adolo with just two subsea wells. And at the time, the recoverable reserves were only 24 million, which is very low. Since then, the reserves have been multiplied by seven. Tortue was a success. The company added four additional subsea whales, then spent money in appraisal and discovered the hibiscus field. They installed a jack-up, repurposed a drilling rig as a production facility. with more slots, with 12 slots and it was a success because today we have 8 ESPs in production and at the end of Mabomo phase 2 we'll have 12 and maybe 14 if Northwest is a success. So that's great and in Q1 26 the asset produced 19.2 1,000 barrels of oil per day for the quarter, net to BW Energy. Operating costs in Gabon are low at $16 per barrel. One important milestone is this quarter, we have now produced a total of 50 million barrels on the Dusafu license. 50 million barrels produced already in this license from zero. We are continuously adding new discoveries with minimal incremental capital and we have grown the net 2p and 2c recoverable resources to 136 million barrels. Since 27, BW has delivered good reserve growth and multiplied by 7. So we can now zoom in on the reserve. This slide is quite interesting. This slide captures the reserve and resources trajectory of DUSAFU and the underlying approach that has driven it. 11 of 12 successful exploration and appraisal wells since the inception. And at the beginning in 2017, the reserve has grown from 24 million to 163 now. So this track record speaks directly to the quality of our subsurface understanding. Looking ahead, there are a lot of left potential in the license. All the yellow dots you see will be appraised. And we have both short-term and long-term plans for the area. So let me go through the next drilling campaign. This is the Mabomo phase 2 drilling campaign. The drilling program is designed to maximize long-term value rather than near-term production. So we will spud in July with the bore rig. And we will first drill the northwest region of Hibiscus to appraise this region. And in case of success, that would trigger two additional development wells. We have the long-league items, so in case of success, we will put those wells in production. Mabumo Phase 2, outside of these two additional wells, is four wells that will be put in production end of 26 and in 27, and each well will add 5,000 bpd, with a first oil expected by the end of this year. Then we will present you Bourdon. Bourdon is the next step on Dusafu. This is a major development for us and we are very happy today to announce that we have made final investment decision on the Bourdon project. We have a short video to show you the project.

BW Energy started the development of Dusafu with a simple and fast-track approach, targeting the Tortue field. The field was brought to production in just 18 months, making it one of the fastest offshore greenfield developments ever delivered.

BW Energy's strategy is to unlock discovered resources through phased developments and reuse of infrastructure. Instead of committing large capital to full field developments, we start with a minimum case, an approach that limits capital at risk and brings fields on stream quickly. Then, as production data confirms reservoir performance, we grow into the opportunity step by step, unlocking additional reserves and value over time.

BW Energy has continued to successfully develop the area, with the addition of the Mabomo production unit in 2023, bringing the total production up to 40,000 barrels per day early 2025. In parallel with these key milestones, the exploration team drilled the Burdong prospect nearby and discovered a presence of 25 million barrels of recoverable resources.

The Bourdon Discovery from 2025 is the next step in our phase development strategy. It will establish a new hub that will fast-track production through existing infrastructure and a new wellhead platform. The project economics are strong, with a break-even oil price around $45 per barrel and an average annual return above 25%. At DUSAFU, our phase development strategy has already increased reserves more than seven times the original estimates. We hope to create a similar story around Bourdon, which has several interesting upsides already identified.

To date, BW Energy has discovered or successfully drilled 11 out of the last 12 prospects here. A remarkable track record for any operator. The development of the Dusafu area, together with the new Bourdon expansion, fortifies BW Energy's position as a key offshore oil producer in Gabon, accounting for 15% of total production in the country. The company continues to successfully expand the Dusafu reserve base, which, along with several other prospects yet to be drilled, will support the company's long-term production and value creation in Gabon.

Thank you. We love Gabon. We'll continue to invest in Gabon. This license keeps on giving and there is more to come. And the next phase is Bourdon. Bourdon is unlocking growth. Phase 1 targets 25 million barrels of growth 2p reserve. First Oil is planned in Q1 28. The project delivers a strong economics IRR of 25% at $60 per barrel. And we have a capital efficient development concept that replicates the approach we have proven at Mabomo with a redeployed Jacob. Basically, it's a blueprint of Mabomo, but with an optimized development. And after that, we will have another phase. We call this the greater Bourdon area. This area contains additional unrisked oil in place with Bourdon UpDeep, Bourdon SoftWest, SoftEast, and Abbey. And by installing a 12-slot wallet platform here will enable us to produce this region as well. All these targets are reachable from the platform that we will install. The development of Bourdon is a capital-efficient design with the capacities to scale. You can see on the right how we intend to develop this field. We will have a jack-up rig that will be converted as a well-head platform, 12 slots well-bay, giving us ample capacity to future appraisal wells. The new wellhead platform will be uninhabited. We want to leverage the Mabomo living quarter and we will transport the crew with boats between the two platforms to reduce the OPEX and leverage the existing assets. There will be three initial ESP wells and the production will be exported in multi-phase flow, oil, water and gas through the existing pipeline. The power will be supplied by ADELO, the FPSO ADELO, to leverage the existing power capacity. And Mabomo Wallet Platform will be as well connected to a subsea cable to reduce the diesel consumption on Mabomo. We will have an integrated electrified field from the FPSO ADELO. So this design reuse existing infrastructure to the maximum extent possible, keeping capital requirement low and execution risk manageable. Basically, Bourdon is a blueprint of Mabomo, but with an optimized approach. On the capital side, Bourdon economics are compelling and we have an efficient leasing structure. The total phase one capex is approximately 300 million dollars, covering the wellhead platform and four wells. There will be three producers and one pilot to appraise the Bourdon northwest area as well. We will order the long-league items and we will put this well in production in case of success. On the leasing side, the long-term lease covers 100% of the wallet platform cost at highly competitive terms. And we will sign very soon the term sheet is not signed and so the lease structure will cover 200 million and 100 million will be for the drilling part. Economics are compelling, the IRR is above 25% at $60, breakeven of $45 per barrel at 10% discount, and a payback of less than 2 years. So this project is providing strong returns, minimal upfront capital, and very important, there is no balance sheet conflict with the Marumba development. This is for Bourdon phase 1, but we have other phases. And beyond phase 1 of Bourdon, I will show you how Doussafou looks like. We are working on a 5 years business plan. Doussafou area has a clear multi-year drilling pipeline targeting 30,000 to 45,000 bpd. Bourdon phase 2, the drilling will start in 2028 and we are targeting 200 million barrels in place across Abaye, Bourdon, Bourdon soft west, Bourdon soft east. Then we have the Walt Whitman area and we want to create another satellite here. There is an existing discovery. We are actually working right now on the reprocessing of this region. And there is as well 200 million of potential oil in place in this region. And all in all, the total appraisal span from 28 to 2030 is approximately 100 million dollars. This is the future of Dusafu. Each platform we install will unlock a new wave of development. And that's what we're going to do as well with Wild Whitman. That was to cover Gabon. Now we will go in Brazil and I'm going to cover Golfinho. Golfinho is 100% operated and owned by BW Energy. The production this quarter was around 6,000 barils in Q1. And we are very happy as well to announce that we have made FID on three infield Wales long league items and the tieback of the Camarupim field. that you can see on the right, there is an existing wellhead on this field that we acquired and we will just put this wellhead back in production to the FPSO Adelo by pulling a new pipeline. This new phase targets approximately 15 million barrels of reserves with highly attractive economics. And beyond that, we have as well a phase program to unlock Golfino with more than 500 million barrels of near-field appraisal targets, including Camarupim and the field on the right that is called Brigadero. On the reserve side, the company acquired Golfino in 2023. The 2PO reserves have grown significantly from 40 to 105 million barrels. The new phase will extend the field lifetime, but as well adding reserve. This is the 64 million you see on 2C resources. We see the license as highly prospective with multiple growth opportunity. And the existing infrastructure of DFPSO and as well the pipeline that the company owns can allow us to export gas and sell gas onshore. So it provides very attractive tieback opportunities. I will give you an update on the booth project that we sanctioned last year. GOLFINO booth project is progressing to plan. This project is on time, on budget. The purpose of this project is to change the artificial leaf system from gas leaf to seabed ESPs. It's a 12 million barrel of incremental reserve. The purpose of this project is to set the stage for the infield wells, stabilize the production to 10,000 and stabilize the uptime as well because we are investing in maintaining the FPSO. It will add 3,000 barrels of production plateau and the capex is around 107 million so far on budget. Good economics as well, $47 per barrel at 10% discount. But the real step change for Golfino are the infield wells program that I'm going to present to you now. The Golfino infill campaign tripled the production, roughly from the 10,000 after boost to 30,000 when the three wells will be online. The project includes two gas wells, the tieback of Camarupim and a twin well, Golfino 50, and two oil wells, two twin wells, Golfino 51 and Golfino 54. Production will start end of 28 and the main capex will be spent after Maromba First Oil. The campaign targets 50 million barrels recoverable. Actually, those wells are some of the highest returning projects in our portfolio. In terms of capex, in total we will spend 450 million, of which only 170 million are committed to the Long League items, with investments starting in H226. We want to order the Long League items to reduce the rig commitment time. The remaining 280 million are optional and it will depend on the condition of the market. The development costs are quite low. It's $9 per barrel and this is because of the existing infrastructure. And in terms of economics, the economics are excellent. Breakeven of $40 per barrel at 10% discount. IRR above 50% at $60 rents and a payback of around two years. So in sum, the launch of the first whale campaign on Golfino makes a lot of sense for us now. And it shortened our decision cycle on rig contracting. And it allowed us to act swiftly on attractive opportunity in a don't cycle market. This is the last slide of golfino, and it's to give you the flavor of what we call greater golfino area. There are a lot of opportunities in this block. We are currently working on optimizing golfino production through boost. Then there will be phase one with the four wells, tieback of Camarupim and three infield wells in the reservoir we will know. And then there will be phase 2, there will be a second well in Kamarupim, Kamarupim 5H, which looks commercially very accretive. And the broader area on phase 2 contains a mix of undeveloped discoveries with DSTs and exploration targets as well. We are actually working on reprocessing the seismic of this phase 2 region. And then there will be a phase 3. A study is ongoing to evaluate the possible tieback of Brigadero. There are as well discoveries on this block and DSTs. And then phase 4 is more exploration driven phase with additional targets within the tieback distance to the FPSO. This is GOLFINO. This gives you an indicative plan of what we intend to do in the coming five to seven years on GOLFINO. But we are very excited with GOLFINO. We see a lot of potential on the greater GOLFINO area and we are looking forward to progressing the infield development program. Then I will give the floor to my colleague Jérôme that will present you the MARUMBA project.

Thank you, Boris, and good morning, everyone. So we were here a year ago to FID this Maromba project, and we are now in a full execution phase. So as a reminder, Maromba until a production platform, a wallet platform, which is a converted checkup that you see on the illustration here, which is being converted in Dubai, and an FPSO, which is a repurposed polvo, and being converted in a Costco Dalian in China. The key figures of the project remain the same. We are targeting 60,000 barrels of oil per day from end of 27 with a plateau. This is developing 122 million barrels reserve at below $10 per barrel OPEX and a breakeven around $40 per barrel. This is in the best ranking of the worldwide project today. We have a very good project here and I'm pleased to report that we are executing on time and on budget. This is our target from last year. Going now in the different work stream. So the FPSO is in Coscodalia and as I said we just completed the first dry dock. All long lead items are on order and all the vendors are confirming that they are on time. Topside refurbishment is ongoing, preparing for the new module to arrive and we are targeting sail away to Brazil in March 27. Wallet platform has arrived in Dubai end of last year. We've spent three months to do in-depth condition assessment to understand the full scope. We dismantled a lot of mechanical equipment to go for OEM refurbishment. and we are now working on the leg extension so we've completed two out of the three legs so we rotated the rig two weeks ago to be able to do the last leg extension and then and then the next step will be to go to dry dock and then restart the unit before it leaves to brazil And the last work stream is preparation for drilling. So we've purchased all the tangibles. They will be delivered by the end of the year. We are tundering all drilling services and the O&M services. We are planning to get the rig to be operated by a third party in Brazil. And we will work on the mobilization of... So we will work on the mobilization of the crew in Dubai to commission the unit before it leaves to Brazil. So the idea is to have a fully commissioned unit before we leave Dubai. Going now into details of the FPSO. We've been in dry docks during Q1. Dry docks lasted 55 days. We've replaced 1500 tons of steel. This is a key milestone for the refurbishment of the unit. So the FPSO is now back at Quayside and we're working on the refurbishment of the topside, preparing for the new module to arrive in Q3. So that's new boilers and the produce water module. And the idea is to start commissioning activity during the summer. So we commission in stage and we can ensure that we will be ready on time for March 27 sale away. We also plan to get ANP, the Brazilian authority, to audit the FPSO end of the year. So we have some time to take their comments into the work we are doing in China and fix all snag lists before we leave the Quayside. So the jack-up in Dubai, so this is a picture taken two weeks ago where we were doing the first two legs extension. We're using one of the highest cranes of the world, so this is the tallest in the Middle East. I've been actually on top of the leg, it's a bit scary to get there. We are finishing this leg extension in June. We will be testing what we've done. We will jack to the top and then we are preparing to go to the dry dock. In parallel of this activity, we are refurbishing all drilling equipment. Most of the critical equipment have been dismantled and sent to OEM. They will start delivering during the summer. So cranes, BOP, drawworks, all this is being refurbished, getting ready for drilling. Of course, the situation in UAE has changed from late February. We have closely monitored the situation for our people first. We have a plan in place should the situation deteriorate. And as well we had to follow closely all the logistics. So some equipment had to be rerouted to other ports in the region. But so far we managed to get all the supplies to come to Dubai. And the other work we are looking at is the final towing to Brazil. Of course, almost straight is closed now and will be difficult to pass, but we are already talking with the HLV companies and trying to maximize chances to be able to leave. And so this is work ongoing to make sure that we don't get any delay. So this is the overall plan and how it's getting together in 2027. So FPSO will be towed to Brazil from March 27 during 90 days. So the FPSO will arrive just before summer and we have a couple of months of hookup and then commissioning. The wellhead platform will arrive in Q1-27 in Brazil and the plan is to install a subsea template and then spud the first well. The idea is to have two wells ready when the FPSO is commissioned so that we can make first oil with two wells. So the surf, the flow lines are on time, so they will be delivered in UK in late 26, and we plan to install them from Q2 next year. So we are finalizing the tender for the installation vessel now in Brazil, being ready for chain, so the mooring of the FPSO and the surf installation. And the drilling, so we will start in April 27 when the template is installed. And it's a six-wells program. Each well is around 53 days. So we will finish early 28 the drilling program. So this first phase of Maromba is 12 wells so we are drilling six wells from next year and then we will pause and then drill another six wells but this is not the final development we see a lot more potential on Maromba And one potential is carbonate. So carbonates are actually being produced in the region on Peregrino, have been produced on Peregrino and Polvo as well. And we want to use our wallet platform to appraise those carbonates. So this is a finger-shaped reservoir you see in the illustration. And if we are successful, we could replicate our development model with additional platforms that we could install and keep a longer plateau on Maromba. So now I will update you on Namibia, on Kudu. Kudu is a gas field that was discovered in 1974. There were 8 wells drilled in Kudu and 5 were encountered hydrocarbons. This is 1.5 TCF recoverable resources. We've been doing a 3D seismic acquisition that allowed us to drill an appraisal well end of last year that encountered a petroleum system and we discovered liquid hydrocarbons. So the Keras one allows us to understand better the reservoir, but we've seen that we will need more appraisal program to be able to develop Kudu. And given this is not our core business to do this long appraisal program, we want to open a data room to bring in a partner to be able to do this program. Also we see Kudu as a very well located in the orange basin with all the other discoveries. This is a gas reservoir that could be a great hub for LNG and power and so we are working on some potential development plans having Kudu as a hub. So this is the update for for Namibia. And I will hand over to my colleague Thomas.

Good morning, everyone. It's a pleasure to be here today. It's another exciting quarter for BW Energy. We have two big FIDs, so we're keeping fairly busy. With the current state of the macro environment, I think it's fair to say we feel pretty invigorated about our strategy, as well as maybe slightly vindicated in our position as a growth-focused EMP. And it's nice to have such a vast opportunity set of organic growth opportunities that we can deliver on that Rhys and Jerome took us through. Let's look at some numbers. had high roll prices in q1 that helped the quarter that converted to an ebitda of 111 million q1 net profit was at 33 and we also reduced our guidance a little bit on the production side as bruce mentioned this was because of a optimization of the rigs on moboma phase two We pushed two production wells in 27, put forward two appraisal wells. This will allow us to then effectively drill these wells sooner in a success case. So negative for 26, positive for DUSAFU as a whole. More importantly, we had two new FIDs at Bordone and Gofinho. This raises our long-term production outlook to more than 100,000 barrels a day by 2028, which we are excited about. We've also been quite busy on the financing side. We closed another sale and lease back of the Jasmine rig. We signed a term sheet for the Wellhead platform, the long-term Wellhead platform for Bordon. And we also executed our accordion option on the RBL on Ducifu, which adds 100 million in liquidity next quarter. Moving into presentation, starting with the current quarter and then moving to the long-term outlook. Production in the quarter was the same, 2.3 million barrels, same as Q4. Sales were slightly up. That is really because we sell our cargoes in 500 to a million barrel parcels. Some quarters can slip into the next. Oil price was higher, $79 realized oil price, up from $62. That's really a function of we sold about half our barrels early in the quarter when oil price were low, and we sold the other half later in the quarter when oil price was high. So that resulted in $79. Revenue side, higher oil price and more sales, it puts us at $173 million. Let's take a look at financial... Oh, sorry. The cash flow bridge here. We opened the quarter with 151 million in cash. Operating cash flow before working capital was 87 million. That was largely in line with EBITDA. Working capital change, probably worth mentioning what's going on here. We had a lifting at the end of the quarter, where a substantial part of that was pushed into the following quarter. We also had an underlift position in Brazil, inventory accruing at $104 per barrel, which was the whole price in March, which added to this. On the investment side, we invested $126 million in Maromba and Gofinio Boost primarily, but that was as planned, and we also drew down some debt to support those financing activities. That leaves us at 161 million in net cash at the end of 26 and liquidity of 333 million. Probably worth mentioning that, I think Carl alluded to it, in addition to liquidity we have about 350 million in undrawn project finance facilities across the Marumba weather platform and the FPSO. And next quarter, we're adding 200 million in addition between the RBL and the long-term lease, so worth noting. Turning to the balance sheet, I think the graphs show a pretty clear story. We're leveraging the balance sheet to support our growth phase. Our interest-bearing debt has gone from 300 a year ago to now 800. That's according to plan, and that's what we said we would do a year ago when we were here. Leverage ratio is increasing, naturally. A lot of these investments are, of course, EBITDA is coming 27, 28, 29. Book equity is increasing. You can see the equity ratio dropping a little bit. Again, a natural function of a growth phase. We're adding to the denominator into total assets, which is then awaiting profit coming in 27, 28, 29. and liquidity i think we've largely covered so moving to the debt stack you can see at the end of quarter we had now a billion in debt that is across seven highly diversified financial instruments mostly are bank based they have a low low cost and they're quite efficient and long term I think probably worth mentioning is a couple of things there. Firstly that we've structured our debt so most of our amortizations are happening after Marumba first of all and a significant part of that again is very long-term infrastructure-based financing with seven to twelve year amortization profiles. In addition, we've added some debt to the quarter, like we mentioned, 80 million on Jasmine, as well as 200 million coming next quarter. That's not currently reflected here in additional liquidity. Next, I'd like to spend a couple of minutes on how we think about our capital allocation framework. We have three tiers in order of priority. First is high return growth investments. We have a very large organic opportunity set of fully operated opportunities with an IRR ranging in 30, 40, 50% at $60 price that we feel compelled to invest in. Secondly, we have a target to optimize our capital structure. And to be specific on what we mean here, so we have a baseline of efficient long-term infrastructure financing that we intend to keep. It improves our economics. It's long-term, it's flexible. We have the other part, which is quite a bit of revolving credit facilities, either through RBL or on corporate level, which we want to repay after Maromba First Oil. Once we've done that, then we have the firepower to keep investing in new opportunities as they come up. Lastly, we want to return excess cash flow to shareholders. We have a framework today where we can pay 50% of net profit as dividends after Maromba First Oil. So we think this is pretty straightforward, and it's really what drives our decision-making day to day. Next, as we called it, a strategy update. I felt compelled to make a slide that kind of explains how this all fits together. I think I see key three structural advantages that sets us apart. Number one, we can acquire proven reserves and attractive entry price. There's not a lot of other oil companies our size that play in the greenfield space, so we're left mostly alone, which means we don't have a lot of competition. Also means that whether oil price is 50 or 150, you can still acquire barrels in the ground at a relatively low price. I mean, Maromba as an example, we acquired the, or to date, we've paid 30 cents per barrel 2p. And by the time we get first oil, we've paid roughly 90 cents per barrel 2p in acquisition costs. um secondly we're a full cycle field and infrastructure capable company i think what is worth focusing on and carl did as well is really the infrastructure being able to manage operate deliver the infrastructure really sets us in a unique position when we develop new fields it allows us to create efficient uh field developments that minimize cash at risk and also maximize returns and set up this phased approach. It's really where we see quite a unique opportunity set also in terms of how we finance infrastructure, which is really how we unlock the green fields through the financing as well. We've developed what we think is a creative, low-cost, infrastructure-backed financing model. I can't take you through how that worked on Maromba as an example. Starting at the unlevered case, we have a 35% RR at $60. That's already very good, or I think Jerome said world-class returns, which I agree with. We then added the FPSO financing and the FPSO financing is interesting because it really relates to the redeployment of infrastructure. When we take a redeployment versus a new build or a new conversion, it's mostly pipe, steel, repair, life extension. Boring work, but it's shipyard work, which increases the local content of the project, which then enables ECA financing. So that's export credit agency-based financing because of the high local content. So countries try to get you to their country to do their project, and they provide an insurance wrap around it. That then allowed us to finance the project 80%, nine and a half years door-to-door at SofaPlus, 2.8% margin, which is competitive in our business. On top of that, we've added a... We've created a... Greenfield infrastructure finance model with Chinese leasing houses. This has been something we've been working on for many, many years. It was always a core idea behind the B2B strategy. And now we're delivering on that. So so in total, we we have a very, I would say, repeatable model. We've done it on Doosafu, we're doing it on Maromba, and now we're about to do it on Bordeaux. So let's take a look at our project pipeline. This is an extended type line. It shows really everything that we plan to do with what we already have. On the green side here, you can see these are projects that we have FID or sanctioned that we are executing on. On the gray side, things that are coming, I think we covered a lot of that. The green side, it represents 222 million barrels of net reserves to B2B. These are our investments to have a portfolio NPV zero break even of about $40 per barrel, which we think is quite strong. And I think a key takeaway here is you can see in Gabon, we're pretty much drilling for the foreseeable future. And in Brazil, we're doing the same. We're ping-ponging between Gofinho and Maromba for the next few years. And this really reflects our company's value buckets, as you can see. Moving to our sources and uses. Yeah. So we have on the left hand side, we have our sources on the right hand side where we're going to spend it. We're focusing on Maromba First Oil. That's been, you know, that's we've done that. We did that also last year. It's life before and after Maromba First Oil and Maromba is a little bit closer today than it was a year ago. We're 18 months away. And the reason we do that is because after Morumba first of all, we're pretty much self-funded and this graph becomes somewhat irrelevant at that point. But until then, we've added Bordone and Gofinio FID to this, to our users. We've added the financings that we discussed and also the ones that we're planning to add next quarter. And I think a key takeaway is that we are covered at $60 per barrel, long-term oil price. So with these new FIDs, I'd like to show you a new slide that we've included that includes our phasing of CAPEX. I think key takeaway here again is we've, or first thing to note is we've increased our guidance from 500 to 600 to 600 to 650. off the back of the two new FIDs, Zungo Finio and Bordon. I think it's also worth noting here that all these projects in this CapEx pipeline have a payback of about one to two years after first oil at $60 per barrel Brent for each respective project. So it's a strong CapEx spend portfolio. In terms of growth and investments, I always like to think quality over quantity, but B2B is brimming with quality. On to our production outlook. With the additional FIDs, we are now above 100,000 barrels in 2028, and with the additional wells, we'll be keeping it that way for a few years. In 2027, we're doubling our production due to Mobomo and due to Golfinio Boost. In 2028, we're doubling again with Marumba coming in line with 60,000 barrels a day. And then Bordon and Gofinio is really creating this run room here. And then I think we've talked about the upsides and appraisals that we're also working on through further exploration at DoSafu and work on Gofinio, etc. The next slide looks at how this translates into free cash flow generation for the company. It's a new slide we've added to highlight the significant value creation that's coming up in the company. It compares our enterprise value as of a few days ago, sitting at 2.4 billion with free cash flow at various oil prices. Not to pick a particular one, but since the red line kind of lines up well with the $70 case, you can see at $70 price, the company pays itself back within five years. So we think this is a pretty solid investment case, of course. That concludes the outlook section, so let me just recap the updated production guidance for the year. There's been several revisions. We've talked about the production. It's due to the optimization of a BOMA Phase 2 and a delay to a vessel on Gofinio. On the unit OPEX, that's naturally increasing. Production down, OPEX goes up. There's also some effect from higher oil prices. Goffinio is exposed to higher gas price, which is a function of oil price. And both fields are exposed to diesel. But obviously, that's disproportionate to the increase in our revenues. So it is what it is. CapEx we covered. GNA is unchanged. Then onto the investment case. Just to repeat it, B2B is a resilient company. We have a diversified growth model. We have more than 600 million barrels of reserves and resources that we are either executing on or will execute on. We're currently executing on projects that will bring us from 25,000 barrels a day to 100,000 barrels a day by the end of 2028. That's with a portfolio return of more than 30% IRR at $6 per barrel Brent. And with a free cash regeneration that we just looked at that will repay the company in about five years at fairly reasonable oil prices. So with that, thank you. And back to Martin for Q&A.

Yes, great. We will start with questions from the audience and then move on to questions online. So anyone online, you can just start sending in questions and we will take them in the end. So maybe we start from here, right? I have a helper here in the audience too, so...

Congrats on two FIDs, looks really promising. Just want to ask around the, you talked about sustained production of more than 100,000 barrels after 2030. If you could give some more colors on how you're going to fight decline, which exploration prospects, which appraisal wells that will ensure no decline or low decline after 2030. A second question, that is on financials. Thomas, you mentioned $125 million change for capital, which definitely hit the cash flow this quarter. How much of that is related to the late lifting and how much should we expect to reverse next quarter? And final question that is all on dividends. You previously talked about dividends after Maromba first oil. You didn't say anything about that now. Could you just comment on how you think around potential dividends or buybacks in future?

Maybe I could start in the reverse order, perhaps. So I think on the dividend side, we mentioned it in our capital allocation framework. Post Maromba First Door, we have a framework to do up to 50% of net profit as dividends. That's something we intend to do as long as we don't have an abundance of 50% IRR projects to deliver on. That follows the plan, and we've been consistent on that since the IPO, really. It's just taken a bit longer than planned to get Maramba going. On the working capital adjustment, I need to get back to you on the exact split, but it will mostly be reversed due to the lifting and due also to the unlift position in Brazil. I'll get back to you on the exact split. Carl, do you want to take the question about delivering 100,000 barrels long term?

Well, I think what we try to... to illustrate is the the quality of our assets is well Dusefu or offshore Gabon is a extremely oily area and I think we have managed through the appraisal activity we've done to unlock or to understand Of course, you don't always find oil, but we now know that if we have a thick salt layer, we have oil, as long as we have a four-way closure. So we do see significant upside. So this has revised our understanding of the Berdon, greater Berdon area, where we see a lot of opportunity and we now install an asset there. which then will allow us to appraise and put in production consecutively. So the next, and that's why we have reworked our drilling schedule, is to step out to Walt Whitman. Again, we know there's a discovery. It's already been done a long time ago, but nobody could unlock the area. Now we can unlock that area and we reshot the seismic. We're reprocessing it. Again, we are very, very confident about the outcomes. It doesn't mean that every drilling we'll make will be a success, but there's so many targets and we now understand the subsurface. So we are very confident about DUSIFU. We see a little bit the same happening on Golfino and I tried to mention you know when you take over something like Golfino with 20 year plus of history there's a lot of data to digest and it's taken our team quite a bit of time to go through everything and catalog everything and you know get a full perspective. We knew there were other discoveries with DSTs, with everything. But now we have had the time and opportunity to step through everything, rank it and structure it. So what we see is extremely promising. from our way of thinking so we see you know potential and don't take those plus one billion barrels but we see a one billion barrel potential That's the potential price of Golfino. It's a huge potential. It doesn't mean everything will come in, but with the discoveries already made, we're looking at 200-300 million barrels and then we can go from there. When you are in an oily area, you find more oil. The more you drill, the more you understand, the more oil you find. That's what we're seeing. So we are extremely pleased with our assets.

So meaning that Namibia is maybe not the key to sustain production above 100,000 barrels per day?

We are keen to try to unlock Namibia in the same way, but we do realize that the exploration game, or the appraisal game if you like, because technically we're doing appraisal in Namibia as well, because there is a discovery, and we have a production license. It's a bigger game than we prefer to play because every well is about $100 million. And if you want to do a drill stem test, you're talking $100 million plus. So in Namibia, We are thinking more, could there be potential partnerships? The other reason is there's a great potential for associated gas. Associated gas is complicated to monetize unless you have gas in addition. If you have pure gas fields, that's easy to monetize because you can produce gas and monetize gas. Associated gas, you don't like to try to monetize the gas. It's well known from the North Sea because you really want to run it on oil, not on gas. And that's complicated because anything you do with gas is commitments. It's either power station commitments or LNG commitments. So having a swing producer in a big associated gas play could be very valuable. So we're kind of looking to see if other operators in the region could have similar ideas. We know from the press that there's been discoveries. We know they're very gassy. I mean, I think it's a reasonable punt that it will be a gas play in Namibia at some point. and we think we could have we could play a part in it but we think maybe this is an area where it's partnerships that's why we're doing a data room to see if we can get dialogues going thank you

Yes, Stefan Evian from D&B Carnegie. Three questions on Dusafu and Adolo. Could you remind me just the production capacity on the FPSO and what's your ambition here for sustaining Plateau now with Bordeaux Phase 1 and 2 and Walt Whitman? My second question on Golfinio seems to be some more gas coming out there. Wondered what the off-tick agreements are and what kind of gas prices you could realize there. And on the long-term, sort of 100,000 barrels per day plus, could you provide some color on the capex required to sustain that level, normalize capex, if we assume BW is going to some sort of normalized territory within that time? Thanks.

Would you like to take that? Yes. So on the first question on the nameplate of Adolo, we've done some study, and we can produce more than 50 actually, would be the nameplate so far. We can produce more than 45, and we think we can reach a plateau at 50. All the technical studies have been done. So no limitation on the top side of Adolo so far. Bourdon first phase will be between 12 and 15,000 barils a day with the three initial wells. But we will maintain the plateau with the phase two. We want to start phase two in 29. And we have more than 10 wells in the pipeline of the greater Bourdon area, 10 targets on top of the three wells that we will put online in 28. So we hope that by the end of 29, early 2030, we will have the 12 slots producing from the Bourdon area if the appraisal happens to be successful. What was the last question?

It was a question on gas offtake.

Yeah, gas of take. So we own the pipeline, which is a great value in Brazil because we can sell gas onshore. We are actually working on a gas purchase, sell and purchase agreement with companies on the market in Brazil. And we cannot communicate today the terms, but we are working on it at the moment.

And long-term capex maybe as well?

Yeah, just to kind of cover that, I mean, just to, I think we've said this before, what we import out is about 10% of Brent, so you can kind of assume what we'd export out is roughly around the same price for the gas in Brazil. In terms of CapEx, that's a good question. We haven't done the exercise yet, so we've been focused on our project, so... And having a mix of subsea developments as well as exploration, as well as dry tree, it's hard to kind of pin it down to a specific number to achieve an exact production. What was the question specifically on the company or was it on Doosafree?

To keep that production level.

At Doosafu or B2B?

Oh, total.

In total.

So sort of just some sort of normalized cash flow number is what I'm trying to get at.

Yeah, I will have to get back to you on that.

But basically to maintain the production, actually in Brazil, we will have the phase one of Maromba with six whales, then phase one of Golfino with three whales, then phase two of Maromba with six identified whales, then we'll have phase two of Golfino that we already identified with three additional whales. And that will continue like that. After phase two of Maromba, we'll appraise the carbonates of Maromba that we will penetrate actually in phase one. So we'll have a flavor of it. And it's going to be the same process in Gabon. The good thing in Gabon is we have already the infrastructure and in Brazil as well. So the additional cost will be more drilling cost than infrastructure cost because the infrastructure we have in Gabon and Brazil can accommodate more production. Perfect. Thanks.

I think you can take a look at this slide with the investment outlook that obviously reflects then the products that's been sanctioned. And then beyond that, we'll have to add some investments, I think, to keep it going.

Thank you so much for your presentation today. It's been a thorough walkthrough. I appreciate that. I wanted to touch upon the Marumba and potential execution risk there. You mentioned Strait of Hormuz is clearly closed. You want to have a sail away of the wallet platform there in late 2026. you're talking about with heavy lift contractors to to mitigate that risk. But how what how can you mitigate it if it's closed? Surely, if we get to late Q4 and straight to hormones is still closed, we have bigger problems in the world. But but how long before how much time do you have to contract that before you're starting to remember one thing?

We're Chinese. Our rig is owned by the Chinese and our heavy lift will be owned by the Chinese. So we're going to be Chinese when we go out to Hormuz.

Excellent point. But if there is a delay, you have a lot of capex on Marumba. How should we think about potential capex overruns if there is a delay into 2027 for the sail away?

Well, I think the biggest risk of delay, I agree we shouldn't just laugh Hormuz away, but we do think that we should be able to transit Hormuz because of our somewhat peculiar nationality. We think the bigger risk is in actually getting started and getting all approvals in Brazil. That's traditionally the risk. We have spent a long time reviewing every FPSO project and every other project that we have been able to get data on and what has been their issues, why have there been delays in approvals. So, of course, we try to cover everything we can. Our sensitivity, we have run a sensitivity of six months we can easily sustain. If we get more than six months, then we will be, I wouldn't say in trouble because it depends again on oil price etc going forward of course so you know it it becomes tighter if it's more than six months to put it that way so our sensitivity is uh is six six months is kind of in our plan already up to six months right appreciate the color yeah

Just if I may add, we want to start drilling in April 27 to make first soil in September. So even though we would have the rig to come a bit later, we could still manage to do first soil next year, but maybe only with one well. So basically, we may have a bit of delayed production, but not fully in the project.

Thank you. That concludes the questions from the audience. We have received some questions online, too. So perhaps, Brice, could you just go through the plateau production at Bordon phase one and talk a bit about Bordon phase two, how we anticipate taking FID on that?

Yes, so plateau production, three wells from 12,000 to 15,000, as I said. And then we will trigger phase two in 29. And we have 10 additional opportunities in the pipeline for the greater Bourdon area. So all these wells will come online as we appraise the greater Bourdon area.

Yeah. What makes the Bourdon development simpler compared to Mabomo? And why did you go down this road?

Yes. So we tried to leverage the asset that we have in Gabon. We have additional power capacity on Adelo, so it was cheaper to send the power from Adelo. If you want to generate power on Bourdon, you need to have a process to separate the oil, the water and the gas, take the gas, use the gas to produce electricity. So then it comes with a very expensive platform. The idea is to use the existing facility that we have. So we will send the gas directly to Adelo, process the gas and produce electricity and send the electricity directly on the wallet platform of Bourdon. It's not very expensive to pull an additional subsea cable to Mabomo. and actually it's going to be quite a good savings in diesel consumption and we will reduce as well the greenhouse gas emission of the whole field and on the Manning we have quite a strong platform on Mabomo with enough people to operate the platform of Bourdon so the idea is to install boat landings and use crew boats to transfer the crew off Mabomo to operate the Bourdon wallet platform. So every morning the team will go there to operate the platform but we will use the existing team we have already on site and optimize the OPEX of the fields.

Good, and maybe just a round of the SAFU area. There's a question regarding the option exercise of the Adolo FPSO in 2028. Is that included in the CAPEX guidance?

So it's not included. We have a purchase option of 100 million.

The guidance is 2026, so that's not included because it's in 2028. And it's subject to agreement with B2B Offshore.

Yeah.

But logically, if the field delivers this trajectory, then it will likely be more profitable for us to take the purchase option relative to paying a tariff and bearable trade.

Yeah, we'll come back to that later. And some M&A questions. On M&A in Greenfield versus Brownfield, you're taking a contrarian approach by leaning into Greenfield projects, while most of the market has gravitated toward Brownfield opportunities. Has that gap in appetite started to narrow? I'm sure you got a finger on the pulse when it comes to most recent developments in the M&A markets.

Gap narrowed?

Gap between the brownfield and the greenfield markets?

I don't know. It's an interesting question but I would say we're kind of alone in the greenfield space while we see that the brownfield is getting increasingly crowded. And in particular, I would say Brownfield is now also the arena for local indigenous companies. So that these days get financing from the traders at a totally unprecedented level. And the traders have a lot of money. They've obviously made a killing in the market lately. And they are very active supporting local indigenous companies. So we see the brownfield market as crowded. And the greenfield market is very open. But there's not that many greenfields In the market, that's true. You have to find them.

Perhaps also allude a bit to what is the vision for BW Energy for the future regarding exploring other countries and also give a status on the Angola acquisition?

I think we can say that, yes, we have a strategy, but, you know, we also have other strategies. So we're not really, I mean, we are participating in land drilling in Namibia. So we're not moribund by a particular strategy, but we're cognizant of what we're good at. So, of course, if it is offshore, if it's If it involves assets that we are very familiar with, we are good. We know what we know. We are not particularly good at operating on land because we don't operate on land. But I think strategically, if we saw an opportunity, we would still go there. We're more driven by the opportunity. then we're really driven by a set strategy i would say so we are yeah we would look at anything with interest we have also looked at the area other areas of the of the world like far east but we just haven't found the right opportunity we're picky about the opportunity, but we're not really picky about where.

Yeah, good. One final question on hedging. To what extent will you hedge the Marwamba production?

I can take that one. We will not hedge Marumba production until we get the first oil, because that would be speculation. So once Marumba is producing, we may follow our current company policy, which is to hedge about 40% of our net entitlement in the next 12 months, and then 25% the following 12 months, plus minus.

All right. Thank you. That concludes. Oh, one more question here.

A very quick one on M&A. Is it a prerequisite that assets would have to be operated or could you be partner as well?

Yes, we could be partner as well. But we prefer to be operator. But of course, given the right opportunity, if we saw a pipeline of development opportunities where we could play a role, active role, we could also consider to be a partner. Again, we're quite flexible on strategy. We're not hung up. We're okay to We're okay to be opportunistic.

All right, thanks.

All right, that concludes the presentation. So thank you for showing up here today, and thank you for attending online.

Yeah, thank you so much for your participation and interesting questions. Always enjoyable to do this face-to-face, so have a very nice day. Thank you.