Good day, everyone, and welcome to Kosmos Energy’s first quarter 2022 conference call. At this time, let me turn the call over to Jamie Buckland, Vice President of Investor Relations at Kosmos Energy. Please go ahead.

Thank you, operator, and thanks to everyone for joining us today. This morning, we issued our first-quarter earnings release. This release and the slide presentation to accompany today’s call are available on the Investors page of our website. Joining me on the call today to go through the materials are Andy Inglis, Chairman and CEO; and Neal Shah, CFO. During today’s presentation, we will make forward-looking statements that refer to our estimates, plans, and expectations. Actual results and outcomes could differ materially due to factors we note in this presentation and in our UK and SEC filings. Please refer to our annual report, stock exchange announcement, and SEC filings for more details. These documents are available on our website. And at this time, I’ll turn the call over to Andy.

Thanks, Jamie, and good morning and afternoon to everyone. Thank you for joining us today for our first-quarter results call. I’d like to start today’s presentation by looking at the company’s portfolio, focusing on the key characteristics, which differentiate Kosmos's position in a rapidly changing oil and gas sector. We’ll then talk about the quarter, looking at both the operational and financial progress we’ve made year-to-date before opening up for Q&A. Starting on Slide 3. This is a slide we showed with our full-year results in February, updated for Tullow preemption in Ghana. The war in Ukraine has fundamentally restructured the global oil and gas markets, and we believe we have the right portfolio at the right time to address the challenges this irreversible change has introduced. Our production is expected to grow by approximately 50% in the next two years, helping to provide the oil and gas the world needs today. We have a strategic LNG resource needed to support a just transition in Africa while enhancing energy security. We think these attributes differentiate Kosmos and offer investors a compelling opportunity to own a company with a purpose and a portfolio that is fit for the future. First, on the left, we have low-cost, high-quality assets. The company is underpinned by world-class fields with a combined 2P reserve life of over 20 years and the longevity to deliver sustainable, high-margin cash flow. This gives us the ability to invest in our existing assets to materially grow production and free cash flow while simultaneously reducing debt, and we’ve made excellent progress on that during the quarter. Second, as the chart on the right shows, we’re increasing our exposure to LNG at a time when both the strategic and financial value of gas is rising. We have Tortue Phase 1 expected to come online late next year and another world-class gas development opportunity in Mauritania and Senegal that should provide further growth beyond 2024. Third, we have a robust balance sheet, which continues to get stronger. Liquidity is increasing, and absolute debt is reducing, with leverage making good progress towards our year-end target of less than one and a half times at current prices. Fourth, as planned, CapEx falls and free cash flow grows. There is potential for meaningful shareholder returns once we reduce leverage sustainably below our target. And finally, we have strong ESG credentials underpinned by our commitments to climate targets, track record on sustainability, and strong governance. Our stakeholders are asking us to do more than just ESG, and our company has a bigger agenda. With growing exposure to gas, we support a just energy transition for our host countries in Africa as well as provide enhanced energy security for regions of the world, in particular, Europe, that are looking to diversify their current supply sources. Turning to Slide 4. Events of the last two months have emphasized the importance of having reliable access to energy and gas in particular. At Kosmos, we have a material stake in a significant and strategic gas resource that can play an important role in enhancing energy security. Over the last 18 months and well before the war in Ukraine, we’ve seen the impact on gas markets of rising energy demand in years of underinvestment in supply. The chart at the top right based on Wood Mac data shows how LNG demand is expected to grow sharply over the coming years, almost doubling by 2035 and enduring forecast. The chart on the bottom left of the slide shows the expected shortfall of new LNG needed to satisfy that rising demand has grown significantly in the last few months. This is a direct result of countries in Europe looking to reduce their dependence on pipeline gas and replace it with LNG from international markets on the back of the war in Ukraine. With demand expected to strengthen further over that period, prices have responded accordingly. The chart on the bottom right shows the forward curve for TTF today versus November last year with forward prices around $13 and then MMBtu higher today on average over the next three and a half years than they were in late 2021. While short-term prices have traded at all-time highs, it’s important to look at the impact of the current situation in Europe over the medium to long term. We believe the longer-term outlook for LNG has fundamentally changed with higher prices likely to persist as a result of premium placed on greater security and flexibility. At Kosmos, we have around 27% of an estimated 100 Tcf of gas in place across Mauritania and Senegal. We expect this gas to play an important role in meeting rising demand with enhanced energy security. Turning now to Slide 5. Our gas in Mauritania and Senegal has a cost advantage due to both location and the quality of the resource. It’s geographically advantaged into Europe with a major time and distance benefit over U.S. supply, resulting in significantly lower transportation costs. For an LNG cargo traveling from Tortue into one of the existing UK terminals or into Williams Hub and the proposed site of one of the new German import terminals, the sailing distance is around 2,000 nautical miles or a sailing time of five days to six days. From the U.S. Gulf Coast, the distance is closer to 6,000 nautical miles or three times as long to deliver the same cargo, resulting in shipping costs that could be almost $1 MMBtu higher at long-term charter rates. We believe we can produce gas at an upstream cost of approximately $2 to $3 per MMBtu over the life of the field, which compares favorably with current U.S. gas prices of around $8 per MMBtu. While we believe the U.S. will be an important partner to Europe for future LNG supply, the data on the slide shows that Tortue competes favorably on both upstream and transportation costs to Europe and therefore, should have an important role to play in the growing European LNG market. Our served gas in Mauritania and Senegal also has a carbon advantage with almost no CO2 in the feed gas coming from the field. As a reminder, our gas on Phase 2 of the project is yet to be priced, which creates a significant opportunity for Kosmos when we bring that gas to market. Turning to Slide 6. This is also a slide we showed at year-end, we’ve updated for the Tullow preemption in the first quarter of the year, which are now behind us. In 1Q, the business generated free cash flow of around $220 million, excluding Tullow preemption proceeds. With minimal capital expenditure in Mauritania and Senegal in the quarter, the number demonstrates the steady-state cash flow potential of the business once our growth CapEx is behind us. At $75 oil, we’d expect the business to generate over $700 million of free cash flow in 2024 as production ramps up and CapEx falls. At current prices, that number will be significantly higher. We believe this level of cash generation is sustainable and underpinned by our 20-year 2P reserve life, putting us in a position to be able to deliver consistent, material shareholder returns at the appropriate time. The combination of quality growth and cash flow generation of our portfolio is unique within our peer group, which is why my team is excited by the future potential of our company. Next, we’ll look at the 1Q results in more detail starting with Slide 8. It was another quarter of strong operational and financial delivery. Operationally, we performed well with production at the upper end of our guidance range, helped by the sustained robust performance at Jubilee, in particular, which continues to perform strongly. Adjusting for the impact of Tullow’s preemption, we’re at the top end of our original guidance. In our developments, both Tortue Phase 1 and Jubilee Southeast remain on track, currently overcoming the more challenging operating environment we’re seeing with regards to supply chain issues and cost inflation. FID on Winterfell is expected around midyear as we continue to work to optimize the development in response to the current environment. On the financial side, as I mentioned, we had an excellent quarter for cash generation, helped by the strong production and supportive commodity prices. That strong cash generation, coupled with preemption proceeds from Tullow, allowed us to reduce net debt by $330 million in the quarter, resulting in leverage at the end of 1Q of 1.9 times. On the balance sheet, we successfully completed all our financing requirements with the RBL redetermination and RCF refinancing, which were important steps to secure our strong liquidity position. Turning to Slide 9, which focuses on the operational performance in the quarter. As I mentioned on the previous slide, Jubilee performance during the quarter was strong, averaging just over 91,000 barrels of oil per day gross with 99% uptime. The field is currently shut in for the planned two-week shutdown and is expected to be back online at the end of this week. Prior to the shutdown, Jubilee was producing at a daily rate of around 95,000 barrels of oil per day gross, which demonstrates the potential of the field with improved reliability and disciplined investment. We expect an additional production well and water injection wells to be online later this quarter, which should help to support production levels through the end of the year. On TEN, gross production in the quarter of around 25,000 barrels of oil per day, again with high uptime of 99%, is in line with expectations with the next wells planned for the third quarter. On Jubilee Southeast, we’re making good progress with the ordering of long lead items ahead of drilling, which is expected to commence around the end of the year. Production from the first well is targeted for mid-2023, which should push gross production at Jubilee over 100,000 barrels of oil per day. On the Oxy transaction, the completion of the Petro SA preemption has not yet taken place, and we’ll update the market in due course once it has been done, although the impact on our production and guidance is immaterial. In Equatorial Guinea, gross production in the quarter of around 35,000 barrels of oil per day was supported by high uptime on the Sabre FPSO. The reliability projects we’ve invested in over the past several years are delivering with 99% uptime at Sabre within the quarter. Combined with the benefit of the wells we drilled in the second half of the year, first-quarter production was 15% higher than 4Q 2021. In the quarter, we also successfully completed the accume upgrade project, which increases our ability to support additional ESPs, which we started to install in April to further support production levels. In the Gulf of Mexico, average production in the quarter was around 19,000 barrels of oil equivalent per day net, impacted by unplanned facility downtime. All facilities are back online, and April production was around 22,000 barrels of oil equivalent per day net. We’re currently drilling Kodiak the sidetrack with production expected next quarter. Turning to Slide 10, which focuses on three low-cost resource additions in the Gulf of Mexico and Equatorial Guinea deepening in our existing asset base. Combined, we’re adding around 12 million barrels of resource at a total cost of around $4 per barrel with very attractive economics. Firstly, on Winterfell, we increased our interest in the central Winterfell blocks where we have the initial discovery and successful appraisal well. We acquired an additional 5.5% from one of the partners for around $10 million, taking our overall interest in those four core blocks to around 22% and to 36.5% in the derisk northern blocks. The consideration will be offset by capital reductions elsewhere in the Gulf of Mexico business unit. Secondly, we exercised our preferential right to purchase an additional 6% in Kodiak for a total cost of around $28 million, with the first installment in 2022 and a subsequent deferred payment. It’s important to note the original transaction was negotiated largely in 2021 at much lower oil prices, which created the opportunity for Kosmos. On Kodiak, the transaction has a forecast payback of around 13 months at $75 per barrel and an IRR of over 95%. At the current oil price strip, payback should be less than a year with an IRR of above 180%. To fund the Kodiak preemption, we signed a small amount of the Ghana preemption proceeds to invest in this compelling opportunity. Third, alongside our JV partners, we’ve agreed with the Ministry of Mines and Hydrocarbon of Equatorial Guinea to extend the Block G license to 2040, adding 11 years to Sabre and six years to Accume, which supports the next phase of investment in the country. As part of the extension, we’re paying a signature bonus, which is already included in our full-year CapEx guidance, and we have agreed to undertake a work program focusing on the next infill and exploration drilling campaign. The extension adds around six million barrels of 2P reserves, which generates around $100 million of NBV 10 at $75 Brent net to Kosmos. Turning to Slide 11, our developments in Mauritania and Senegal. Phase 1 of Tortue continues to advance with all major work streams making progress in the quarter. On the hub terminal, construction continues on schedule with the 21st and final caisson shipped offshore in early March 2022, with three caissons left to be installed. On the subsea, the offshore installation campaign is expected to commence this month. Drilling of the four wells required for first gas commenced last month with two top holes completed. On the FPSO, mechanical completion continues. There was a two-week COVID-related lockdown of the Costco yard in China in early April, but that now has been removed and the yard is back up and running. As the operator communicated its first-quarter results call last week, the FPSO is on the critical path, and the team is working hard to mitigate these disruptions and maintain the contractor sailaway schedule for the end of Q3. The FLNG vessel is making good progress at the Keppel yard in Singapore with the pipe rack installation now completed. Overall, the project was around 75% complete at the end of the first quarter, with first gas targeted in the third quarter next year. On Tortue Phase 2, we continue to work closely with the operator, the governments, and the NOCs to optimize the development scheme with regards to both scale and timing. That work is progressing, and we expect a development decision around mid-year with formal feed and FID to follow. It’s important to manage future cost pressures in the right way to maintain the project’s attractive economics. With that, I’ll hand over to Neal to take you through the financials for the quarter.

Thanks, Andy, and good morning and good afternoon to everyone. On the back of the robust operational performance Andy talked about for the quarter, we posted strong financial performance with the key highlights outlined on this slide. EBITDAX of $430 million was over 25% higher than the fourth quarter, thanks to the full impact of the Oxy Ghana transaction in the quarter and strong realized prices. Net debt fell over 10% from year-end, which, coupled with the strong EBITDAX performance, drove leverage to 1.9x at the end of 1Q, a significant reduction from last quarter. Free cash flow in the quarter was approximately $220 million, an increase of over 60% on our previous quarter, demonstrating the cash-generative ability of our low-cost portfolio. With good performance across the portfolio, liquidity rose by around 20% over that period. Turning to Slide 13. We completed the RBL redetermination and RCF refinancing at the end of the quarter with liquidity rising to over $900 million, and we expect it to continue to increase further by the year-end. The right-hand chart shows we have no material maturities until 2025 after repaying around $100 million on the RBL in the first quarter. As we generate cash, we plan to pay down additional debt, pushing debt maturities out even further. Turning to Slide 14, which looks at the quarter in more detail. As Andy mentioned, net production of 72,600 barrels of oil equivalent per day was at the upper end of our guidance range, up almost 40% on the same quarter last year. The realized price per barrel after hedging impacts was $88 per barrel, almost double the same period last year. On cost, we performed in line with guidance with higher OpEx per barrel this quarter versus last year, largely a result of lifting at TEN cargo this quarter. Total CapEx in the quarter was just over $100 million, excluding the impact from the Tullow preemption. There is very little CapEx for Mauritania and Senegal in 1Q as we expected, as we continue to benefit from the FPSO sale transaction last year, although we expect it to increase in the second quarter. The inflation we are forecasting for 2022 is minor. As a result of the longer-term nature of our contracts with the inflation, we experienced rising from the variable elements in those contracts, such as fuel. We have also mitigated inflation this year by drawing down on existing inventory for some materials. On our largest development projects, we have also locked in large components of our future capital spend, reflected in the progress of GTA, Phase 1, Jubilee Southeast, and to a lesser extent, Winterfell. Although even for that project, we have committed to long leads, representing approximately 10% of the total cost of Phase 1 of that development. That said, we do expect increased costs to show up next year if we remain in an inflationary environment. Turning to Slide 15. As I mentioned on the introduction slide, we’ve made good progress on leverage in the quarter with the combination of rising EBITDAX and significant debt paydown. Quarter-end leverage of 1.9x was a meaningful reduction from around 2.5 times at year-end 2021. At current prices, we remain well on track to hit our year-end leverage target of below 1.5 times, with further absolute debt reduction a key priority. The bullets on the left show the progress we have made so far in 2022 with more to go later in the year. At current prices, we’d expect a further $200 million plus of free cash flow and the likely payment from Shell in the coming months on the back of the exploration success they’ve had from their first two wells in Namibia, supporting a total debt reduction of approximately $550 million to $600 million this year. I’ll now hand it back to Andy to conclude today’s presentation.

Thanks, Neal. Turning to Slide 16 to wrap up today’s presentation. In summary, we’re delivering on our promises for today while building a company for the future. Our producing assets are performing and generating material free cash flow. Our defined development projects are progressing well despite the challenging environment. We’re growing our exposure to international LNG at a time when gas and LNG demand is rising sharply. On the back of strong cash and EBITDAX performance, leverage is falling, and liquidity is rising. And finally, we’re committed to a just energy transition and can play an important role in enhancing the energy security of those nations looking to diversify future energy supply. Thank you. And I’d now like to turn the call over to the operator to open the session for questions.

Thank you. Our first question is from Neil Mehta with Goldman Sachs. Please proceed with your question.

Team, thanks so much for taking the time this morning. The first question is around Tortue Phase 2, and I would love your perspective. We got a little bit of color from the operator a few days ago. But your perspective on are we tracking towards new FID? And to the extent you can talk about it, how do you think the economics of that incremental growth project have evolved as it is much lower capital intensity?

Yes. Thanks, Neil. Yes, I think we’re taking the time to make sure that we’ve got the right scale and fundamental concept, both in terms of the scale of the project and timing to fully optimize the resource. I think there have been a lot of changes in the market, and we need to ensure that we’re bringing the right project forward with the right timing. We’re clearly at an inflationary period. And one of the things that I think both BP and Kosmos are aware of is we need to ensure that it’s fully optimized, and we’re putting in the right capital for a long-term project during this inflationary period. So we have the ability to expand the project and build on the current infrastructure that we put in place, and that’s clearly our focus. As we’ve said in the past, the hub terminal will serve as an offloading point for future expansion of the project. We have the ability to expand offshore at relatively low cost. So we believe we’ve got a cost-competitive project. We need to be very disciplined about the capital that we put into that, given the more challenging supply chain and inflation environment we’re seeing.

I want to stick with Tortue Phase 2, second question which is as the project is up to 75% construction now, what’s the biggest risk around execution? Is it COVID or is it something else? And how are you – what steps are you and the operator taking to mitigate that risk?

Yes. Look, as I said in my remarks, as you go through the various work streams, the FPSO is on the critical path. Nothing has changed. The key next step is clearly the sale away from the yard in Costco, which is close to Shanghai in China. We have had a short interruption with the lockdown of the yard for a couple of weeks. And again, as the operator said on their call, I think the team has done an incredible job to keep the project moving forward in that environment. So that’s the thing that we’re really focused on now is the release of the FPSO to enable it to then sail to Mauritania and Senegal. And then we can start, as it were, all of the hookup activities, which would commence at the beginning of next year. So that’s the critical issue that we’re focused on. As I said, we’ve commenced the drilling. That’s going well. I think the hub terminal, we were concerned in the past around COVID-related issues there. But obviously, we’re making good progress on that. The subsea installation will start this month. And the FLNG vessel is being built in Singapore, where I think there is less of a risk of COVID. So I think the FPSO remains the item that we’re focused on.

Thank you, team.

Thank you. Our next question is from the line of Charles Meade with Johnson Rice. Please proceed with your question.

Good morning Andy and Neal to the rest of the Kosmos crew there.

Good morning.

Andy, I wonder if you could elaborate a little bit more on the inflation that you’re seeing. I think you’ve referenced it a couple of times in your prepared comments, but should – are the concerns you’re confronting are they just cost? Or are they also on availability? And is it – I think you’ve touched on some already with the FPSO, but is it more around – just give us a flavor is it more around drilling your facilities or something else?

Yes. Look, I think as I said in my prepared remarks, I think we’re probably seeing a little bit in some of the sort of commodities and almost fuel costs, actually. But apart from that, nothing really of any great scale. And actually, we’ve mitigated that, and as we said, we’ve included a couple of new opportunities in the Gulf of Mexico and in Equatorial Guinea and still kept our CapEx guidance in the same place. So I think the first message, Charles, is that it is a period where we’ve got to be phenomenally disciplined around the allocation of capital and therefore, we’re absolutely focused on execution and doing everything to the highest possible standard. So that’s 2022. As you look forward to 2023, I think you’re seeing inflation really across the board, whether it’s the deepwater rig market, whether it’s actually connected to the fundamental sort of commodity prices. We’re probably seeing deepwater rigs over the last two years from sort of $200,000 per day probably into the low to mid-300s, yes. So maybe around 75%, you could see casing and sort of others supply vessels the same. And I think the market is adequately supplied at the moment, but you are seeing a tightening of that market. Rigs would be an example of that, which is why we’re getting ahead with sort of the long leads, in particular, on our projects, both in Jubilee Southeast and on Winterfell. So I think it is a time for real discipline anticipating the market tightness and then actually trying to get ahead of it. And, again, I think I sort of put the COVID-related issues in China sort of in a separate area because I think those are very specific. So hopefully, that gives you a little more color around our approach. And to me, it is about discipline. You’ve got to ensure that in a higher-price world, you have to be able to execute to a high standard, and that’s what we’re doing.

Got it. That is helpful. Andy and then my second question is actually about the possibility of share buybacks. And I know this is looking – it may seem like it’s looking too far down the timeline, but the truth is you’re 18 months away or 19 months away from that $700-plus million. And I know you’re focused on projects between here and there, and then you’ve got – probably got some work you want to do on your – on the debt side of the balance sheet, but can you give a sense for – for you and the Board, is this something that you guys have spoken about or would think about whether opportunistically on a day like today or whether it’s something that would be perhaps programmatic if your share price is still in the same ballpark?

Well, look, I think we’ve been clear, Charles, that the first agenda item is around debt reduction, and we need to get the balance sheet sustainably below a leverage level of around 1.5. And clearly, it’s about a sustainable price environment that delivers that. So I think that is the first focus. And I think through 2022, that’s absolutely what we intend to do. We believe at current oil prices we can get below 1.5 by year-end. And I think then you start a slightly different conversation around where do we believe we are on debt reduction for the debt reduction, where are we in terms of a sustainable leverage level and what opportunities would that create for us. So I think in a sense of messaging, nothing’s changed. I think what your point you’re pushing on is that the future may well be accelerating towards you and how do you take account of that. But we just want to be very disciplined about what we’re doing. We’re disciplined about the capital in terms of our growth options. We’re disciplined around the cash flow, how it’s being used. And then I think when we got to a position where we feel we have the balance sheet in the right place, then I think share buybacks would be one of the things that we would look at.

Got it. That’s helpful. Thanks, Andy.

Thanks.

The next question is from the line of Bob Brackett with Bernstein Research. Please proceed with your question.

Good morning. You highlighted a couple of transactions with acquisition prices around $4 a barrel oil equivalent. Can you talk to how you did those deals, the appetite to do more of those and how it might inform your strategy?

Yes. Thanks, Bob. Yes. Look, they’re both, I would say, in the bracket of being opportunistic. They’re relatively small, but they are important. What I like about them is that they’re in fields that we understand today. We’re deepening in our existing asset base, and I think that is actually a very efficient way to continue to grow the company. So Winterfell rose, one of the partners had a larger share than they would typically carry through the development phase, and we were able to negotiate that I think at a time when there was a favorable environment. The Kodiak preemption actually occurred back in 2021. It took some time for all of the deal to close that for the preemption to come forward. But again, it was priced in a very favorable environment, and therefore, we were able to take advantage of it. As you look beyond, I would say we’ve been really disciplined with our M&A. We’re clear about pursuing deals where we believe they are consistent with the strategy of the company, shorter-term, high-margin oil growth now supported by longer-dated quality gas. We’re looking to deepen in areas that we understand and, therefore, where there is true economic value that we can add. And fundamentally, they need to be cash accretive and continue to strengthen the balance sheet. I think our track record on deals has actually aligned with those criteria. If we see opportunities that enable us to continue that, we will do it. I think clearly, in today’s price environment, I think it’s slightly tougher, but that’s the path we’re on.

Appreciate that. The follow-up would be the journey time from Shanghai to Greater Tortue is perhaps 60 days. If hookup is in 1Q, sort of implies that even an early 4Q sale away would still be okay on that critical path. Is that the right way to think about it? Or there – it’s more complex than that?

Bob, as always you’ve got the numbers. What I would say is depending on sailing time and the sort of the transit speed, it’s probably 60 to 90 days, put in a bracket like 60 to 90. Yes, the 90 would be the outer edge, 60 would be the shorter edge. Yes. So look, you’re right, there is a degree of flexibility. But clearly, this is the item that we’re focused on intently because the hookup of the FPSO then allows you to start the subsea completion work, the tiebacks, the FPSO, et cetera. Yes. So it is absolutely on the critical path. And as you well know, with projects of this scale, there’s always sort of opportunities to mitigate an over one area with other activity. Yes, but you basically got the timeline.

That’s clear. A final very small one, Winterfell is a tieback. Have you decided on the host to which it ties back?

No. We’re in negotiation with several opportunities at the moment.

Very good. Thank you.

Thanks.

Our next question is from the line of James Hosie with Barclays. Please proceed with your question.

Hi there. A couple of questions on the Tortue projects. I guess, first, on the FPSO sail-away schedule. I mean is the plan to hit that end Q3 target by carrying over some of the work when the vessel arrives on location? And then on the Stage two, just how should we think about the inflationary pressures and part the previous cost estimate of less than $1 billion gross? I guess, is that figure still valid?

Yes, thanks, James. Look, yes, you’ve obviously – the most important part with the project of this is to ensure that you minimize that carryover because there is a cost multiple of taking jobs out of the yard to offshore. So that’s clearly the point of optimization now. How do you ensure that you’re not taking a significant amount out offshore? Yes. So I think our objective is for the FPSO to serve with very little carryover. That traditionally has been the way to deliver successful offshore projects, and that’s clearly the focus of BP today. So I think you’ve asked the right question. And clearly, from our perspective, it is an important criterion to ensure that we deliver both on time and on budget now. Yes. And in terms of Phase 2, yes, it is really important that we put capital in a slightly inflationary period that is truly efficient and again, as you go through cycles to ensure that we’re not investing at a time, putting heavy amounts of capital in when inflationary pressures are there. So that’s the reason we’re going back and making sure that we’ve got a properly optimized concept, both in terms of scale and timing, and those inflationary pressures. And it’s not only the inflationary, but it’s actually the execution issues on the supply chain have been properly evaluated. So that’s the work that’s ongoing at the moment with the partners and with the government.

Okay, thanks. And then just a follow-up to that last comment then. Is it potentially the end up looking at like a Tortue Phase 1.5, where you kind of – you upscale the project, but not to the size that you’re previously talking about on Tortue Phase 2?

Look, again, what we’re trying to do is make sure that we’ve got the right concept for the environment. Yes. So I think, as it were, we’re going back and making sure that the work that we’re ensuring fully captures the timing and the scale to best execute the project. Yes, it’s a great resource. It’s a resource that the world needs. We’ve got to make sure that we’ve properly optimized that.

Thank you. Our next question comes from Mark Wilson with Jefferies. Please proceed with your question.

Hi, good afternoon, good morning. I’d like to ask about thegreater Tortue area rather than volumes outside of Tortue in BirAllah and Yakaar-Teranga. You’ve got a very clear path to monetization Tortue Phase 1 and then Phase 2. You’ve got over 20 years of reserve life. So these additional volumes, very large gas volumes in terms of in place. What would be the strategy for monetization of those now for Kosmos? Has the market view towards them changed? In the last few years, a few years before you had a sale process going. And indeed, would there be any additional appraisal drilling required, do you think to maximize valuation there? Thanks.

Yes, Mark. Good questions. The significant resource. Yes. The fundamental strategy has not changed. I think when you look at Yakaar-Teranga, Angus adjacent to the Dakar Peninsula and the first phase of Yakaar-Teranga is focused on a gas power scheme, so a relatively low cost, almost early production scheme. It allows you actually to appraise while developing. So you wouldn’t do additional appraisal. And for the country, what it does is it displaces diesel burning power with gas burning, both lower cost and lower carbon. So I think you can see Yakaar-Teranga being developed in that way, and that’s the agenda with the government about how do we move forward with that scheme, rightsizing the initial development that gives them the sort of baseload power – gas power that allows them to deal more credibly with a very volatile external world. So I don’t think nothing has changed on that and almost the volatility externally has actually probably reinforced that agenda. When you look at BirAllah, it’s different. I think BirAllah is driven by resources in the country with a relatively low population, sort of around four million people. Power used domestically is probably not the long-term agenda. There is a need for gas resources in the near term, and there are other fields that can be developed to do that. So BirAllah is fundamentally about how do you get to a low-cost modular development that allows you to access the market with the right timing and sort of build another export scheme. So that’s the concept work that we’re pursuing now. So I think there are clear plans and in our view today is we have a resource where significant value can be added by the progression of those development plans and making them real. And I think the external environment has made that easier rather than harder, and that’s the work that we’ll pursue with both BP and the government.

Okay, understood. I suppose, down the line, once plans have gone through, there would be a decision of whether Kosmos would enter into such developments. But understood. And second question, therefore, on Winterfell. Just like to ask you to speak about the $100 million of resources in the area. But what sort of percentage of that do you think you’ll develop in the initial phase as tieback?

You probably – I think the initial two-well scheme could grow to something as large as sort of six wells probably to cover the full development. So you think about it in concept. I think we might see three phases of up to six wells. So the initial phase is probably around a third of the resource, something like that. Maybe a first half on the upside, Mark.

Got it. Okay. No, thank you. I’ll hand it over.

Our next question comes from the line of Matthew Smith with Bank of America. Please proceed with your question.

Thanks and thanks for all the details so far. So it’s just a quick point of clarification left for me, please, and that was, could I just check on your understanding on the sort of Shell exploration campaign so far, whether it’s your belief that you’ve triggered the, one, of the contingent sort of consideration payments of $50 million or whether you think; two, and therefore, you’re already at the cap of $100 million, which you’re expecting to receive, please?

Yes. Thanks, Matt. Just so we’re clear about what we said. The payment comes following an exploration well that is included in an appraisal plan. So I’ve indicated that they anticipate drilling further at the end of this year, which would require an appraisal plan, whether it’s 50 or 100 would depend on whether they include both discovery wells or one of them.

Sure. Okay. Understood. Very clear. Thanks Andy.

Great. Thanks.

Thank you. At this time, there are no additional questions. I will hand the floor back to management for any further or closing remarks.

Yes. Thanks, everyone, for joining today and don’t hesitate to get in contact if you have any further questions. Thanks very much.

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