Ladies and gentlemen, welcome to the Seplat Energy 2022 Results Presentation. My name is Natalie, and I will be the operator for your call this morning. Following the presentation, we will go to the phone lines for the question and answer session. If you wish to ask a question, please make sure you dial in on the conference call. The presentation is available on the webcast and can also be downloaded. I will now hand you over to Roger Brown, CEO. Please go ahead. Thank you. Morning, everyone, welcome to the 2022 Result Conference Call for Seplat Energy. Turn to slide 4, and we'll run through some group highlights. First of all, we're declaring a dividend of $0.075, which is a special dividend. It's made up of a $0.025 final dividend, and then we've topped it up with a special dividend of $0.05. Total production is 16.1 million barrels of oil equivalent for the year, which is slightly down on last year, largely down to 3 shut-ins that we had, and Sam will deal with that when he goes through it. The revenue is up almost 30% on last year, largely to do with the higher oil prices. EBITDA numbers around $415, slightly up to 12.1%. In terms of the 2022 achievements, we continue to pursue the Mobil Producing acquisition. We'll deal with that later in the slide. We're looking obviously at our new energy investment plan. We announced that at our strategy day, and we've made good inroads in terms of looking at new energy opportunities. We're going to take FID on at least one of them by the end of this year. In terms of the PIA voluntary conversion, obviously the PIA went in 2021. There's ability to do a voluntary conversion. We've opted to do that, and we did that in February. Work is ongoing in Seplat midstream gas business under PIA. This is a separation of midstream away from upstream and working hard to deliver that. We believe that will create a lot more value for shareholders in the longer term. We're going to disclose the first climate risk and the report, that'll be end of March, this month, or it's actually next month. It'll be under TCFD guidelines. We've commenced our implementation of achieving net zero, and that's largely to do with taking a lot of the flares. We've had some Board changes. Obviously, we announced earlier this year, a new independent Chairman, Basil Omiyi. We have another Board member which is today, which is Koosum Kalyan, joins as an independent non-exec director. This is part of the refreshing of the Board for the coming up for the future. Okay, moving on slide, it's just a few words about sustainability. We have a quite a number of corporate initiatives in our scorecard. Sustainability is about 15% of the scorecard in 2023. If you combine that with the safety at 10%, you know, one quarter of the overall scorecard is now related to safety targets and sustainability targets. In terms of reporting, talked about just putting out this, the climate risk and resilience report. You'll see that at the end of March. We'll put that on the website, and it's compliant with TCFD guidelines. Just some stuff on the emissions reductions. We have committed, and we're still on track to delivering a flares out initiative by 2024. Beyond we will be flared out completely separate, obviously safety flares, which we'll need. Largely a lot of that reduction is coming from the AG compression, which we've put in place at the end of last year. We're not in operations. We've also re-looked the calculators for the Scope 1, Scope 2 emissions. We have been making a lot of estimates around that, had to be overstating them. We now have a new calculator in place, which is much more accurate. Our carbon intensity is down 2020 and 2021 levels, 29 kg per BOE. Our diesel program is underway across all of our, obviously our Tree 4 Life project is making some inroads with the first pilot project. I'm gonna now move over to operating review and hand to Samson Ezugworie, who is COO, and he will then take you through the slides. Sam. Thank you very much, Roger. Moving on to slide number 7. Good morning, good afternoon, good evening, everyone, depending on where you have joined this call from. Just to highlight, our operational performance in the year under review continues to follow our very strong strategic agenda, focusing on maximizing cash generation through operational efficiencies. We focus on our 3 key strategic pillars, the upstream, the midstream gas, and the new energy. Over the next few slides, I would like to take you through some of the key initiatives that we are driving to strengthen our performance along those lines. Specifically, just on this point, I would like to highlight that we continue to diversify our export routes to continue to assure revenue generation, learning from the quarter three performance of 2022, when we had very significant pipeline and terminal outages that impacted our operational performance in the year. So if you just go straight to the next slide, on slide 8, I will lead into one of the key strategic drives, where you will see how robust our reserve base is. Looking at 2022 relative to 2021, our reserves decreased by 19%... 19 million barrels. 84% of that was significantly related to production. 9 million barrels of oil and 41 Bcf of gas. 12% is due to the divestment of Ubima and reclassification and revisions, which is our strict petroleum engineering practice, leading to 4% reduction. Our 2C reserves volumes also decreased by 7.3%, 17 million BOE, and we are currently farming into the Abiala marginal field through our non-operated venture. That is not yet in the books simply because we have not completed the farming operations at the time we are staff audit in the year. If we go to slide number 9, you will also see our growth agenda through the exploration well that we drilled in Sibiri in Q1 2022. Significant progress has been made with this. We have very fastly moved to extended well testing of this particular opportunity following the discovery that we made. I would like to comment that the e-extended well testing is underway as we speak here with very promising results. Well is currently flowing, good API, flow rate yet to be determined. Also we are driving the further appraisal of the Sibiri discovery. Also we have made some very significant discoveries with this. The flank, the flank appraisal has yielded many more positive results, including two new pay zones. Overall, we see a very clear indication that the Sibiri discovery will be in the upper margin of our in-place volume estimation. We are going to quickly move into field development planning and bring this to production shortly. Speaking to slide number 10 and our overall operational performance in terms of production in the year under review, we started the year very strongly with very good quarter one and quarter two performance. As I stated earlier, quarter three was heavily depressed by pipeline and export line challenges. By October last year we recovered, and we also then made a very strong recovery in the last quarter of the year, leading to an exit of 53,000 barrels of oil per day at the end of the year. Learning from this, we will continue to drive additional export route opportunities to ensure resilience as we go into the market. On terms of operational performance and resilience, we also achieved ISO 55001, which is also a very big one for us at Seplat, being the first in Africa to achieve this feat. We also feel very proud about this. Lastly, our operational performance continued to run on a very strong safety performance in the Niger Delta area of Nigeria, where we actually achieved 31 million hours of LTI free operations over a space of 3 years. However, we recorded 1 non-operational LTI in October last year, and since then we have also ratcheted up to 2 million, almost 3 million man-hours of LTI free operations since the last incident. If I go quickly to how we are building resilience on slide number 11. Resilience for export operations into the market. We delivered the alternative the Amukpe- Escravos pipeline in July last year. Following that in itself has opened more opportunities for three additional export routes out of there. Learning from the incident that we also had, we continue now to look at other opportunities to bring our crude to the market in OML 40 and in OML 53. If I go to the very last slide, for me, that is also how we are driving our midstream agenda in line with our strategy. The first big ticket item there is how we utilize the installed capacity in our facilities in Oben and Seplat. There you will see that we continue to export very significant volumes into the market. In the year under review, we exported over 110 million scf of gas our year average, and achieved an average gas price of $2.82 per thousand scf. We also additionally signed some 3 new GSAs to a total volume of 86 million scf per day. That now brings us to 8 GSAs in total, with offtake capacity of 390 billion scf of gas per day. We are also driving ANOH. ANOH is also our very strategic growth opportunity. The current outlook is that we would bring ANOH to onstream by the last quarter of this year. We achieved 95% mechanical completion in the course of the year under review, and we are driving and working closely with our partners to achieve the pipeline network that will bring this gas to the market. Lastly, is the Sapele delivery, where we are having a combination of 3 agenda here, driving cash flow from gas sales, LPG, and then also reducing our gas flaring with this opportunity. This is supposed to come onstream by the last quarter of 2024, in line with our end of routine flaring agenda. On this point, I would just like to end and hand over to Emeka, who will take us through the financial performance. Thank you very much. Thank you, Sam. Good morning. My name is Emeka Onwuka, I'm the CFO. I'll take you to financial review, starting from page, slide 14, which give the financial highlights. You will see that total revenue $151 million, and EBITDA was $416 million. We stand out with a very strong cash on our balance sheet of $404 million. You will also see the realized oil price at $101 per barrel and the gas price at $2.82 per million scf of gas. If you go to slide 15, we give more details on the financial results. You see oil revenue at $839 million and gas at $112 million. Yes, the gas revenue dropped a bit, this owing to the earlier pressure we faced in 2022 on gas prices, particularly the Domestic Gas Delivery Obligation price that came down to $2.65. However, during the year, we recovered in terms of the new GSAs we signed, and we're able to build out the price of a $2.8, $2.82 per million scf like I said in the earlier slide. The cost of sale affected by royalties, given the higher oil prices for this year. The G&A went up significantly. One is increased Naira spend in 2022. Usually there's a FX implication for that because you convert, books are maintained at systemic rate of the central bank and FX rates. When you spend that and convert, it has an implication in terms of the $ reflected as the G&A cost. The global inflation which put impact on the traveling side, travels and cost of imports as well. Staff emoluments increased marginally during the year and we also had a prior cost of about $12 million that we had to charge this slide in 2022 due to partner recovery issues. If you go to the impairments, we had on Ubima that we have a loss of sale of Ubima of about $13 million on that after deferred of that asset, like Sam already mentioned. The tax share for this year apart from direct tax is $7 million. That was also a deferred tax share of about $33 million. That's increased tax share for the year. The oil prices, the higher oil prices meant that we need to reverse some of the deferred tax to the business account in our books. Ended up with $104 million on profit after tax for this year. The capital for it is $163 million. That takes us to the next slide 16, where you see that we spent $163 million, like $4 million of that on drilling. We did about 13 wells, 2 of that completed this year, 11 delivered in 2022. We also made part of the CapEx was also used for engineering projects and our gas plant. On the drilling side, we continue to make saving improve the cost of drilling. We're targeting $10 million in terms of average cost. In the past two years, we've achieved about a 5% reduction in drilling costs. The details of the wells that we drilled this year are also contained in page 16 on the slide. I'll take you to page 17, slide 17, which shows our very strong cash generation this past year. We opened with 302... $324 million and we have $404 million cash generation from operations, which utilized the Ubima receipt. In terms of that disposal, we received about $18 million during the year. Also on the NPA transaction, where we deposited $128 million as part of our formerly 10% of consideration for that asset that CBA held, which is part of, we adjusted on completion of the transaction. CapEx for the year, $163 million, like I said in the previous slide. We ended the year strong on liquidity of $404 million. I'll take you to the next slide 18, which shows our overall liquidity situation of $404 million. We have a debt of, they will have bought out their $650 million, ultimately what we have closing the year on net debt of $95 million. Net debt EBITDA of 0.88. We also on that same slide, have an indication of how we manage our capital. We are very conservative. We have our 70 by 70 and 70 by 70 in terms of Naira to dollar. We always hold about 30% of our liquidity in dollars. Also 30% of that dollar is also held outside the country. For the year ended 31st December, as at year end, we had $103 million option. In fact, the $49 million that came in just on the last day, and it that we had offshore. Of course, immediately we open the next the year, we transfer that offshore as well. We talked about debt management. Our target entirely is 2x. At our, Although our comment is about 3x the EBITDA, I'll talk about our EBITDA figures earlier. We also engaged in terms of capital investment, low risk capital investment. Our first priority is to drill wells, to arrest decline, and also to continue to invest in midstream, which for us is a natural hedge. This last year, in terms of production, 44% was from gas and for the sakes of oil. This normally for us is a natural hedge as against fluctuation in crude oil prices. We also hedge our production. We are hedged onto second half of 2023, about 3 million barrels at $50 a barrel. We just buy simple put options. I'll take you to slide 19, which is on our special dividend, which Roger has spoken to. Seplat have consistently paid dividend in the past 5 years, including declared dividend paid in 2022. Also, we paid about $460 million since we went to the market where we raised $5.5 million gross. This year, we ended with a strong liquidity. Like I talked about, our $404 million on the balance sheet on the back of higher oil prices, where we reviewed our cash requirement for this year, including the CapEx of $160 million, which Roger will speak about, and also the MPN transaction where we're keeping funding for only equity contribution on that transaction. All together, after this review, we also considered a couple of $0.15 that we have in our bond covenant. The board has recommended beyond the $0.025 final dividend for the last quarter of 2022, an additional top-up of $0.05 as well. Adding up together $0.075 for final dividend and for year 2022, $0.15 on the whole. I'll now hand over to Roger for the next section on outlook. Thank you. Slide 21, I just look forward to this year. Just looking at our CapEx, it's as similar as to 2022, though there are more wells going in. As you can know that the guidance for CapEx, $160 million, split between the development production, security, maintenance and exploration. That's going on development and production. 18 wells this year, on the right-hand side of the slide, you can see where we're putting those wells. A bulk of them in the Western assets in OML 38, OML 41. 3 oil, 3 gas, water disposal, which is needed for the water that's coming through, then 1 exploration well. We're trying to get more out of those assets. 153, we're doing 5 in OML 40, 4 oil, 1 appraisal. Abiala, which is effectively OML 40, it's a marginal field. We're putting 2 there, 1 workover well and then 1 oil well. ANOH, there'll be 2 gas wells, which complete the drilling for ANOH. In terms of then sustaining projects, we're completing the Sapele integrated gas processing plant. We've talked a lot about flaring, that's our commitment by 2024. This is flareside project, Oben, Umuigbo, Sapele and GCK. Looking at some renewable energy power opportunities as part of our sustainability drive. The final slide, which is looking at guidance. We're guiding at 45-55. That range is we've risked that range, and likely that we will narrow it during the year, but risk that obviously with less actions going on right here at the minute. There's obviously exclude our Mobil Producing. ANOH, first gas moved to Q4, 2023, and we have a long explanation in the accounts, so you can look at that. The export routes, OB3 pipeline and the spur line, they are scheduled to be completed by the half year. We went further than all our projects we're doing, so we'll risk them further. That's why we've put our first gas at the end, Q4 towards the end of the Midstream gas, again, we're underway to make that a standalone business. I really genuinely do believe this will create more value, and that's in line with the PIA. The new energy we talked about, we're going to see hopefully an FID on a power opportunity later this. In terms of the sustainability that's been quite a big drive for the business. Good. Finally, on MPNU, we're producing, you know, we are continuing to pursue a reaffirmation of the approval from the President we received on the 8th of August, and we are still trying to push this through the President Buhari before he leaves office. That wraps up our presentation. I'll hand it back for Q&A. Thank you. Ladies and gentlemen, if you wish to ask a question, please press star followed by one on your telephone keypad. If you change your mind and wish to remove your question, please press star followed by two. When preparing to ask a question, please ensure that your phone is unmuted locally. To confirm that star followed by one to ask a question. One moment for the first question, please. Ladies and gentlemen, another reminder, if you have a question, please press star and one on your telephone. Our first question is from [Denise Silano] from Jefferies. Please go ahead. Hello, can you hear me? Hello, can you hear me? Yes, we can hear you. Yeah, go ahead. Thank you. Thank you very much for the presentation. I have, like, a few questions. First on this situation with Forcados Terminal that was unavailable for almost 140 days during the period. I mean, like, this, like, kind of material event for the company. Could you kind of provide more color on the situation, what caused this kind of force majeure? Is there any kind of mitigants in place to hedge against this risk? Are you kind of thinking or is any availability of insurance against this potential events happening? This like the first question on Forcados Terminal incident last year. The second question would be on this like Mobil asset acquisition that you still plan just to execute by May. Is it possible just to provide more kind of color on this deal? Like, are we kind of talking about the same valuation? Do you have financing secured to close this deal? Are we talking about the same financing structure as we discussed, like, last year when the loans will be obtained in a like ring-fenced structure with no recourse to the existing perimeter? Any color on this Mobil assets acquisition would be great. The last question might be on operational performance of kind of assets and especially IP pipeline throughput. Maybe if you could kind of share any color on the operational statistics for the first two months of 2023? Do you see kind of what levels of the throughput oil lifting you see in the first month of 2023, especially when we talk about the new commissioned IP pipeline? Thank you very much. Three questions for me. Okay. Thank you. Like, why don't I just start and then Sam, you can jump in on the operational stuff. In terms of Forcados Terminal, what happened was a force majeure, largely due with an SBM. There's a loading arm and there were some integrity issues with that. The pipeline through Shell, well, took some time to fix those issues. That largely led to the force majeure being called there. Now in terms of the impact, you know, Forcados is up and running again, and we're using that of our production. We have identified that as a long-term route for us, we're looking at alternative on that. I'll ask Sam specifically to come in on that now before I go to the other questions. I think we have some technical issues. I'll keep going around this one. What we look to do is, I mean, it's highlighted looking at alternative routes. We want to use AP as a in case we discover pipeline as our mid-export routing. We have an ability to put 35,000 barrels a day on that line. What we found since we were operational late July line is, certain months, we've had extremely good results from it. For instance, December, we had no downtime on it. Other months we've had some downtime largely to do with the fact that in some tapping points that we've had to remove. We see this as improvement. In terms of the downtime, we expect less than 10% downtime, lead trending to more like 5%. Be materially better for the business, and that deals with the throughput. Obviously, to the extent we can, we want to engage with Chevron and try to put more volume. The remaining volume then that we'll have from our western assets, we'll look to, we're looking to barge out long term, but we need to put barging operations in place, which is what we're working on. That should then fix the sort of the Q3 situation we had here, where we had force majeure across a lot of our terminals. Dealing with your MPNU question. In terms of the financing related to that, it's no change. We have committed thing to it from our, a mixture of banks and so because that's still is, and obviously we're now we're just waiting, the President, who's also the Minister of Petroleum, to reaffirm the approval. We're hoping to get this transaction through either this present or if it need be, going to the next president. The loans and financing of that is no different. Okay, hopefully I answered that. Sam, go ahead. To clarify. Financing is secured, so there is no change to the amount of the deal value. The only kind of like bottleneck at the stage is the final approval of the deal. Once you have this approval, you go ahead with the deal. There is no kind of additional like due diligence revision in deal price. Just you need to get like approval, formal approval. Yeah. You know, we have our view is, and obviously the seller's view is that we have approval, but there's a difference of view from the national NNPC around the terms that's what's holding it up. We need to resolve that. In terms of the transaction SPA, it's in place. The funding is largely ready to go. Obviously, CPs have to be satisfied to fix that. It's ready to go. We're waiting just for the reaffirmation from the president. We're pretty sure, because obviously the president will be in place until the end of May, and then beyond there'll be a new president in place. Make it through with this president. Obviously, we'll then be pursuing, the transaction into the next, president. Thank you. Ladies and gentlemen, another reminder, if you would like to ask a question, please press star one on your telephone. Our next question is from the line of Alex Sacher from NNIP. Please go ahead. Hello, gentlemen. Thank you so much for the presentation. I'm sorry my line wasn't particularly good during part of the answer, so I didn't really get the entire answer on MPNU transaction. I had a follow-up on that. I'm just wondering, you know, if there is any kind of long update to the agreement, or it can be rolled for an indefinite period of time. If there are any milestones we're looking at, be it under current President or next President. Do you expect any kind of change in how the government may be looking at it under new President as opposed to how it's been going now? Secondly, on production, so I'm just wondering what's your kind of expectation, and what you have in the budget for the downtime and for reconciliation losses for this year? How do alternative routes you're putting in affect those as opposed to performance last year? Thank you. Okay. Thank Thank you. On the MPNU transaction, the focus is getting the transaction complete with this current president. This current president will be in office until the end of May when the new president will be sworn in. We don't see how that is yet. It's hard to say much about the new president coming in. Our focus is to get the deal of the line before the end of May. To the extent that that's not poss, of course we will be in discussions with the incoming president. We don't know who's going to be at this point, we don't know what requirements that will have. Let me just say one thing. In terms of the history of Nigeria, you know, these transactions have gone through and got approved, which is, you know, we obviously go back to a rate of approval from this President. Yes, there's a difference of view with the national oil company, but we just need to work our way through that. In terms of what benefits this brings to Nigeria, Seplat is a proven track record in terms of operating financial robustness, et cetera. We're a big operator and big partner to the government in country. We have raised this money ourselves as a company and it's a significant amount of inward investment into Nigeria. Our ability in gas is proven, and these assets have got a lot of gas that have not been utilized. Therefore, our focus will obviously be to monetize that gas, obviously ramp up the production. There has been little drilling in the asset for quite a number of years now. Success, you know, whether it's this President or the next President, our offering is still the same, that we offer a capability, indigenous capability, which is needed more within Nigeria, of more and more strong indigenous players. So we're confident if we have to go to the next President, we'd be able to take the case across so that. Our focus is with the current President to get the deal over the line. In terms of your pre-question on the losses, like we, you know, typically project in our budget, you know, it's between 20%-25% downtime assets. Sometimes it's more, you've seen that this year, obviously the Q3. The Amukpe to Escravos pipeline system, you know, we're budgeting in around 10% or lower. We believe to get this pipeline into certain 10%, probably more like 5% losses over time. We just had a couple of issues. One was obviously there's some tap points in that pipeline which we had to remove. The other thing is within Chevron, it's a new offtake, and because we have condensate in our, in our oil from the gas production, you know, that has a higher vapor pressure and we're just dealing with the terminal operator of how we've done. We have to play around with the volumes to go through it. But we're confident that we'll be able to get 35,000 through that pipeline, with a sub 10% downtime. If we can get comfortable with that long term, then maybe we get more volume through it. In the east, it's probably been the worst for us in terms of the TransNiger pipeline, which is the pipeline takes the eastern production into Bonny. That's been pretty bad. The upper section is now just opening up, so we're confident we'll be able to get our volume through there in addition to supplying a local refinery into the country. Also OML 40, which is coming past the Escravos into Forcados. That was also impacted by it. We are looking at a longer-term barging solution for OML 40. We're also looking to connect the Trans-Escravos pipeline system, which is into the Magbale to Escravos pipeline system. So we're putting a spur line in there, and then we'll be able to connect those two pipelines. Longer term, our focus is to get the downtime reduced dramatically, and I think it will boost straight to the bottom line. Thank you. Thank you so much. One additional question, if I may. In Emeka's comments, I think, there was mentioning of net debt of 2x. That's probably like company's policy, but I'm just wondering, you're now at like 0.9x, going to 2x. Is it just MPNU transaction or are we looking at anything else? It's the policy we had. I mean, obviously we're well policy, and actually our covenants are, is higher than that, I think it's 3x. Look, we are looking at our capital allocation at the minute. The MPNU transaction's a ring-fence transaction. I think that was maybe one of your earlier questions. It's a ring-fence transaction, so it's aligned. The funding sits at a level below the group, and that then going to be serviced and paid back from the revenues from MPNU. That doesn't really necessarily impact your leverage as a group, because it's gonna be consolidated. But over time we're confident with the cash flow capabilities of those assets, that will service that debt and bring the debt down accordingly. In terms of our covenant 2.2x, we're well under it. We'll relook at it now, okay? We're looking at capital allocation now, and later on this year we'll come up with some revised, you know, covenants and also some more revised direction of how we're thinking about allocating capital going forward. Thank you. The next question is from the line of Ayodeji Adelagun from Standard Bank Group. Please go ahead. Thanks for the call and congrats on the results despite the difficult operating environment. I just wanted to ask, I think I heard you mention, Roger, pardon me, barging of Western production. Could you elaborate a bit more on that, maybe touching on some of the cost implications on a per barrel basis? And then lastly, sorry to keep hammering on the Mobil shallow water assets acquisition. I mean, just judging by the body language of the administration, how confident are you in terms of receiving the required approval under this administration, or it potentially being something to be considered by the next administration? Thank you. Okay. Thank you. Yeah, in terms of the. By the way, we've aligned and we're in separate places. I'm in America and Sam is in Lagos. Why you're hearing my voice a lot is because of some technical issues with Lagos on the line. Just going back to the barging. We're looking to as a long-term solution because of the uncertainty of the operations of the Trans Forcados Pipeline System. If the TFP Pipeline System is really functional, it works well, long term, we can rethink this, the main need is a certainty for our volume coming out of the West. Particularly because we've got compensate and we have some issues around that's why we have it. You know, it all kind of go through, and we'd be distrustful at this yet. In terms of the cost of barging, it's more expensive. It's, you know, circa $10 a barrel to barge, whereas $5 a barrel thereabouts in pipelines. If you factor into downtime, implications and also losses that you... particularly into the Forcados system, it more than compensates for the additional barging cost. We don't really wanna be barging long term. We'd rather use pipelines, but the pipelines are not reliable. We need reliability in our ex. Going back to the Mobil transaction, lot of questions on it as expected. Look, we, you know, our view is that the Minister of Petroleum has approved it in August. We continue to push that. It's not for an approval that have yet. What we're trying to do is push the re-affirmed approval. We're confident we can get that through this administration. We did say that to the extent that we can't get it through this administration, we will certainly be working for the next administration for these assets. You know, we've been through a lot of due diligence with the seller, and what the seller is really focused on is any incoming buyer is able to operate these assets as a standalone entity, i.e., not with any support from the seller long term or even post-completion. The seller needs a party that can proven track record of delivering it. We're confident that Seplat is more than fit that bill, which is why they signed the SPA. Our focus is to get it over the line with this President, to the extent we have to, it will go in next President. This concludes our Q&A session, and I hand back to Roger Brown for closing remarks. Okay. Thank you very much. This concludes our 2022 Results Presentation. Everyone have a good day. Thank you.