Thank you very much. Good morning, everyone. It is good to have you with us for yet another quarter to be presented from Tethys. It feels like it was only three days ago or so since we talked to you last time. Let's dive straight into the presentation, and if I could have the first slide, please. We can happily see that for as much as 2020 turned into a year that I don't think we could have imagined such a year ever occurring, Tethys Oil prevailed and sailed through the year with quite high mast flags. Production came in at 11,000 barrels of oil per day for Q4, which is considerably better than the low points of close to 9,000 that we saw in the middle of the year. The Blocks 3 and 4 assets continue to perform brilliantly. For the 10th year in a row, we now have reserve replacement ratio above 100%. Actually, the highest reserves in the company's history. While we keep producing, we also keep growing. That's of course, key to where we're trying to take Tethys over the next couple of years. Despite all the turbulence, we came in the quarter with a free cash flow of $9 million, which I must say is certainly not bad given the circumstances. We have had a very active year also in expanding and rearranging and optimizing the asset portfolio. Apart from Blocks 3 and 4, we now have a 65% interest in Block 56, and we couple that with a farm out of Block 49, where we dropped from 100% to 50% interest. This happened more or less on the eve of spudding our first exploration well in Block 49, the Thameen-1 well, which is currently in drilling phase. We hope to have a result within the next couple of weeks. Last but not least, certainly, we continue to distribute cash to our shareholders. We generate cash. We have cash in the bank. We need cash to expand, but we have enough cash to do that, and therefore, we are still able to share cash and distribute cash to our shareholders. The ordinary dividend stands at SEK 2 per share. We are doing an excess dividend distribution of SEK 2 per share as a redemption scheme as we have done for the last four years. That really summarizes what the quarter has been all about. Of course, a very strong quarter, not least given the circumstances. Unless you want the details, now you feel free to do something else. If you want to continue to listen to us, let's have the next slide. Q4 financial highlights. Petter will give these in much more detail, healthy revenue of $22 million. EBITDA of $10 million. It's a lot less than we had last year but it's a lot better than it could have been. Operating results, slightly negative. Free cash, $9 million. Average selling price came back nicely at above $40. Obviously, $42 if you compare this to a forward month currently above $60, looks quite measly, we should be very cautious as to how the oil price actually will develop over the year. We are still in a pandemic, in particular, the OPEC+ countries and the lead OPEC nations have implemented rather severe cuts. OpEx, though, came down. We're sitting at $9.8/bbl for the quarter compared to $10.50/bbl for the full year in 2020. It's risen a little bit compared to Q3 in line with production, I'd say. Production, of course, up from the previous quarter. The details will come from Petter. I'll move into the next slide where we will comment a little bit on our reserves. Record reserves as usual. The end number for the 2P is 26.9 million, almost 27 million barrels of 2P reserves from Blocks 3 and 4. That's the highest recorded number. If we add on the 2C at 13.9 million, almost 14 million barrels, we can also conclude that the resource base stands at the highest point in the company's history. Combined 2P and 2C numbers are the highest combined resource base we've ever had. Blocks 3 and 4 as the assets continue to deliver increased reserves while we continue to produce. 120% reserve replacement ratio is something we are quite proud of. We have a quick look at the development of reserves. You can see from this slide, which is a little bit complicated, but if one does penetrate it shows a very nice trend. While, as I say, we continue to deplete the Blocks 3 and 4 onshore Oman, we also continue to increase recovery ratios and find more oil. Reserves, of course, the backbone of any oil company. If your reserves diminish, you will eventually disappear. Therefore, we are quite proud that we are maintaining this reserve replacement ratio. Turning to the next slide. We just want to remind you, of course, current cash is what's most interesting to our shareholders. Ordinary dividend of SEK 2, been stable since 2018, and the extraordinary distribution down a little from last year, but still a quite significant, I'd say, SEK 2 per share for a total of SEK 4 per share. Of course, it reflects both our ramped-up exploration program and investments in future growth, but also maintaining a bit of extra cash on the balance sheet, given that we still face a 2021 that could turn out to be volatile. On that note, I'd like to hand the floor to Petter to give you a much more detailed discussion of the Q4 numbers. Thank you, Magnus. We can start off by looking at the production, the quarterly production for the past few quarters. The Q4 production was just above 11,000 barrels per day, which is up 4% from Q3, and significantly up versus the low point around mid-year, as Magnus mentioned earlier. We'd like to remind you that Oman oil production is still subject to the production limitations under the OPEC+ agreement, and Blocks 3 and 4 are, in fact, formally under production limitations since May. However, we have been permitted to produce at a slightly higher level throughout the fourth quarter. For the full year, we had production of about 11,300, and that was boosted by the high production under the first quarter of 2020. The oil price achieved in the quarter was $42.3. That is just down very slightly versus the third quarter. Full year ended on $47.7. That's, once again, very much influenced by the higher numbers in the first quarter. As I'm sure most of you are aware, there is a two-month lag in how the achieved price comes into our numbers. The acceleration of prices that we saw towards the end of November has yet to make its mark in our accounts. You can see on the next slide here with the official selling price, exactly how that works, how the official selling prices during the fourth quarter were, in fact, the market prices for August through October. The Q4 prices are mainly influencing the current quarter, the first quarter. Looking at the current quarter, the effects that came through in December and now in January, they will be influencing the first quarter achieved price. Just looking at an unweighted average OSP, it's roughly $50 per barrel. I would like to remind you that in our accounts, that would be influenced by the production levels in the respective months. It doesn't translate exactly to the expected achieved price, but it will be thereabout, I would say. That's not the only factor. Moving on, net entitlement, of course, is the amount of oil produced that we are permitted to sell, that is governed by our exploration and production sharing agreement. The full amount that we are permitted is 52%. As we could see during 2020, if we do not utilize the full 52% early in the year, we have the ability to catch up in subsequent quarters, until the end of the year. However, year-to-date entitlement can never exceed 52%. There is a number of factors influencing this, of course, which is the production levels, the oil price, the cost incurred, and the balance of unrecovered cost in the cost pool. At the end of the year, we had approximately $1.8 million in that cost pool coming into 2021. Moving on to over and underlift, another factor that can influence particularly the cash flow. As we nominate the liftings, the actual oil sales, two to three months ahead of the actual month, it means that they will not always correspond exactly to the production in the month. That can result in this over and underlift situation where we in fact have sold more or less oil than we are in fact entitled to. This is a situation that became very clear throughout the year, not least due to the imposition of production restrictions, which of course reduced production while there already had been nominations made. That resulted in extraordinary volatility in the over/ underlift position throughout the year. This influenced the Q3 numbers in particular, where we had a significant underlift position. As we are contractually obliged to neutralize this over time, this was reversed in the fourth quarter, and we have ended the year with a slight 3 million barrel overlift position. Moving on to revenue and other income. Fourth quarter, we had $22.3 million, up 9% versus Q3, and that is mainly due to the higher volumes oil produced offsetting the slightly lower price, which is a level significantly lower than a year ago, but we see it steadily improving in the past quarter. Coming to expenses, this is, I think, something that has been one of the strong points of this year in reacting to the effects of the pandemic. While there's very little we can do about the oil price, and with production levels being impacted by the OPEC+ agreement, which is ultimately beyond our control, expenses is something that is much closer to home and control, and we've seen the partnership on Blocks 3 and 4 reacting very, very positively to this. You can see that the fourth quarter, we had OpEx of $10 million. That's a significant improvement year-over-year and slightly up versus the third quarter, but that's influenced and mainly due to the increased production. When it comes to admin costs, they are up slightly in the quarter, that's mainly due to currency effects due to the Swedish krona and US dollar, as well as a change in timing of the recognition of variable compensation, which is something of a one-time effect this year. Which brings us to the OpEx and netback per barrel, which I think is a good metric to look at under the circumstances, seeing that we can achieve a netback of $12 per barrel under these very low prices. You can see the history of what the netback has been under some of the higher prices. That's a positive and shows the resilience in the license and the operations. We are particularly proud of the OpEx per barrel, which in the third quarter came down to a very low level of $9.5-$9.8 in the fourth quarter. Still very, very good. That is driven mainly due to the increased production. As mentioned, in cutting back production, it was prioritized to cut back in particularly the high-cost production. As more wells are being brought online, the incremental effect is a slightly higher OpEx per barrel. We have also seen some savings that we hope to be able to keep as we go forward. Moving on to EBITDA, we had $10 million in the quarter, as Magnus mentioned, of course, this is significantly lower than what we've seen just a year ago. However, under the circumstances, we're very happy to see these levels, and we saw it improve in the fourth quarter versus third quarter, driven mainly by the improved revenues. Moving on to free cash flow. We're very happy to have achieved our goal of positive free cash flow in the fourth quarter and for the full year. We saw the third quarter being particularly negative, but that was in no small part due to working capital relating to the timing of liftings and the over/ underlift situation. In the fourth quarter, we saw working capital situation normalize and thus getting positive cash flow effect of that in the quarter. Over the full year, working capital effect on cash flow was neutral. We have a free cash flow of $6.7 million, which is something we're very happy about given the very tough circumstances that the operations were dealing with throughout the year. Part of that free cash flow, or part of what impacted that cash flow is, of course, the investments we've made. In the fourth quarter, we saw a slight rise in investments versus the third quarter, particularly in Blocks 3 and 4 and Block 49 as we initiated the drilling operations on the Thameen well. That did come very late in the quarter, and some of those investments that we were expecting this year have in fact been moved into 2021. Here you can see the quarterly cash reconciliation from the end of the third quarter to the fourth quarter cash position of $55.4 million. You can also see we spent about $1.8 million on share buybacks. The balance sheet remains solid. Strong cash position of $55 million. No debts. Very straightforward, giving us a very comfortable position to not only be able to weather the storms of volatile oil price and environment, but also being able to distribute and invest at the same time and keep having plenty of options open in how to capture value and produce returns. This is something we are very, very proud of. With that, I conclude the financial review and hand over back to Magnus. Thank you very much, Petter. Let us turn to the operations section. The main take I really want to convey here today is that with the strong backbone of the Blocks 3 and 4 assets, which has shown remarkable resilience in 2020, and continue to generate positive cash and continue to increase reserves. We have also, over the last couple of years, assembled an increased portfolio of other assets in Oman. We are, as we have now entered 2021, in a position of starting to seriously explore for new resources in these blocks. We are actually poised for the largest increase in exploration efforts in Tethys since we entered in Oman more than 10 years ago. You know, of course, where we are, Oman, bordering United Arab Emirates and Saudi Arabia, Block 49, where we are currently drilling the Thameen well, borders directly Saudi Arabia, we are actually drilling a well in the Rub'al Khali Basin, which is home to most of Saudi Arabian reserves. Although very little production has come from the Rub'al Khali Basin in Oman. Hopefully, we'll be able to change that with the well we are currently drilling. Block 49, we should have a result within the next couple of weeks, at least before the end of February. If you look at the map also, you can see that we actually cover a fairly large part of Oman. Apart from Blocks 3 and 4, we've added 49, 58, and 56. We actually hold almost 18% of Oman's total aerial extent under license at the moment. Oman remains a very potentially more prolific oil region than Oman has been for, say, the last 10, 15 years. The country was quite out of fashion in the mid-2000s, 2005, 2006, 2007, when Tethys entered. Has come back in fashion as new discoveries have been made over the last four or five years. Let's turn to the next slide, and let's look a little bit more at the details of our asset portfolio. It is a portfolio, and we've tried to optimize it both from a geological exposure, but also to have good partners and to diversify our interests while maintaining operatorship in areas where we know we can make a difference. In Blocks 3 and 4, we have 30% operator remains our friend, as ever, CCED and Mitsui. We've been a joint venture now since 2010, and obviously, the joint venture has performed extremely well. In 49, we got that block three years ago and took it through the first exploration stage by doing seismic and coming up with a nice prospect that we are currently drilling. We had 100% and had the opportunity to farm out to the American company, EOG, which apart from adding all their experience, they are also a very skilled operator when it comes to unconventional resources. We hope that the current well, Thameen-1, or whatever results will be, it will also add a lot of knowledge as to how the Rub'al Khali Basin can best be understood and possibly produced, both from a conventional and an unconventional perspective. Unconventional oil is not produced, with unconventional we mean mainly shale and that kind of technology, is not really produced in Oman today, whereas we have seen a number of tight gas fields come in production and doing very well indeed. The star performer there being the BP-operated Khazzan field. We do believe there is substantial potential also on that side, and we are very happy to have EOG as partner. Block 58, I'm sorry, 56, if we look at that. Let's look at Block 58. It's adjacent to Block 49. It's actually an extension. However, we are leaving the Rub'al Khali Basin behind and moving into the normal Omani basins that we are familiar with from Blocks 3 and 4 and 56. Block 58 is a recently compiled block, and we are very happy to have been able to sign it last year. We see some significant potential from known Omani plays and where also our experience from Blocks 3 and 4 can play in very well. We just signed the block. 2021 is going to see a lot of desk work, and towards the end of the year, we may get ready to do some seismic. We do have quite high hopes for the block, and we will spend a fair amount of money on it over the next couple of years. Block 56 is a little bit different story. Borders the producing field operated by our partner Medco. We believe that the producing field play continues into Block 56, and a large part of the work program the current year will be to evaluate the potential of that play. We also think that there is a substantial upside in the central parts of Block 56, where we will interpret, reinterpret existing seismic, and then design our own seismic program the same way we did for Block 49. We are going to perhaps see some interesting investments in 56 also this year. With this summary, I would like to say that we are actually entering a new phase in Tethys history, where the focus on exploration also outside of Blocks 3 and 4, while that still continues, is going to be much more prevalent in how we spend the money that we do not distribute to shareholders. Let's move on. I'll be a little bit briefer as we move on to Blocks 3 and 4. We've had the block now since 2008, it is the mainstay of our production, of course, and the backbone of the cash that we can spend, both distribute to shareholders and spend on other assets. Exploration activity was very limited for obvious reasons in 2020, the one exploration well we did drill, the Anan-1 well, came in with good oil flows. For 2021, we'll continue to do development, drilling, continue to try and mature contingent resources to reserves, continue to upgrade the infrastructure to be able to maintain and possibly increase production. We will continue to interpret seismic and drill. We expect more exploration wells in 2021 than we did in 2020. As the good reserve replacement ratio and the success of the Anan-1 well shows, there is still strong exploration potential in Blocks 3 and 4. Let's turn to the next one. Block 49, southern part Rub'al Khali Basin, farm out from EOG. Next slide. We are drilling the Thameen-1 well in the northwestern corner of the block. We have some six, seven wells that have given us data to pick this location. We have good seismic 2D and 3D adjacent. Targeting in particular two targets, a Late Ordovician sandstone and a Mid-Ordovician sandstone. Reasonably deep, close to 4,000 meters. Previous wells have had oil shows, although no oil has flown to surface. We've learned quite a lot about the Rub'al Khali Basin and how the geology works in this part of Oman. We'll see what the well will teach us. We should know before the end of February, as I've said, and this is our first milestone in 2021, where we may have some exploration excitement or not, as the case may be. Whatever happens, we learn a lot about the Rub'al Khali Basin. As you know, it is quite a prolific basin on the Saudi side, and it's fairly underexplored in Oman. Whatever the outcome of Thameen, we are hopeful that we will be able to do more work in this block. Let's move on to show you what's going on here. We are actually using a rig from the Abraj company, and it's a rig that has drilled a number of wells for us in Blocks 3 and 4, and incidentally also drilled Tethys' first wells in Oman drilled in 2007 and 2008. It's a rig we are quite familiar with and are very happy to work with. Turning to Block 56. We are getting our heads around the block. We first got the block over one year ago now. We have consolidated the operator group, the partner group, and we will be able to take over operatorship as soon as we get government approval for all the transactions involved in increasing our interest. Turning to the next. It's a geology we're quite familiar with. This is a continuation of what we have in three and four, but it also gives us exposure to several potential plays in several basins. Whereas the Eastern Flank is similar to what we are dealing with in Blocks 3 and 4, and the much younger Tertiary Basin has a potential system of its own. And in particular, in the middle, along that thick fork, you see where the so-called Umq-2 well was drilled. It shows some very good potential. As you can see on the next slide, we have a number of leads identified on 2D, and we will try and mature those as best we can from the existing seismic, and then we will come up with a seismic program for later this year. In parallel, we're evaluating the borderline to the northwest, where we have the potential extension of the producing field on the other side of Block 56. Block 58, somewhat similar situation to 56. Different basin, close to 49. If we turn the next slide. We have two wells drilled that has given us a lot of interesting information. In particular, we also have some interesting leads that we are also trying to mature. Most likely, we will see the need for additional seismic, and we will develop a seismic program here in line with Block 58. You should expect more updates here on the seismic side as the year progresses. With three blocks outside of Blocks 3 and 4, where we now see some quite increased activity, we do believe we will be in a position to take Tethys to a new level of both production and reserves if we have exploration success over the next couple of years. Turning back to what we can expect on the financial side from 2021. I will actually hand the floor back to Petter to guide you through where we hope to see our financial numbers from some of the most salient parameters. Petter? Thank you, Magnus. I'd just like to say that given the circumstances, we're currently operating on with the production limitations and the uncertainty in the overall macroeconomic environment. We have elected not to provide the customary production guidance this year. Instead, we will continue to issue the monthly production updates. We will provide guidance on the investment we are expected to make on the various licenses that we have interest in. On Blocks 3 and 4, we expect $32 million of CapEx relating to our share of the operations. On Block 49, on 100% basis, we expect $5 million to complete the drilling and the testing of the Thameen-1 well. On Block 56, under the assumption of completion of the agreement with Medco and obtaining 65% interest, we expect to spend $5 million on operations there. That is particularly relating to drilling of three wells towards the end of the year. On Block 58, on 100% basis, we expect $5 million of expenditure in preparation and execution of a 3D seismic survey. That all totaling $47 million for 2021. That is what we have to provide in terms of financial and operational outlook on that. Thank you, Petter. To conclude, we have had a very strong end to a turbulent year, with positive free cash flow and reserve replacement rate of 120%, and the highest 2P reserves number ever at 26.9 million barrels. We continue with our significant cash distribution to shareholders. We have a very comprehensive exploration program on all Blocks 3 and 4 in 2021. The first milestone, the first result should be the Thameen-1 well, where we expect to have results in before the end of February. The main take of the presentation today is that Tethys is embarking on a strong growth path, and we are able to continue our distribution to shareholders without holding back on our plans for growth. We see that we will be able to offer both interesting exploration, continued distribution from a very interesting asset mix in Oman. I do hope we will have the opportunity of addressing you again with new financials and exploration update about three months from now in May. Before that, let's see if we have any questions from the participants. Thank you. If you wish to ask a question, please dial zero one on your telephone keypads now to enter the queue. Once your name has been announced, you can ask your question. If you find it's answered before it's your turn to speak, you can dial zero two to cancel. Once again, that's zero one to ask a question or zero two if you need to cancel. Our first question comes from the line of [Siegfried Flachare] of [Flachare Investments]. Please go ahead, your line is open. Hello. I have a question for the production guidance. As far as I understand, OPEC+ is talking about easing the cuts in 2021. Maybe you can't give a production guide, but can you maybe say that the production maybe would not be lower than in Q3 or Q4 2020? Or is that too much, because just no production guidance, a little bit fog for us as investors. That's my first question. Thank you, Siegfried. No, it's a little bit of fog for us also. If past experience is anything to go by, we can conclude that all of the third quarter, we were allowed a higher quota than originally communicated. If you are right that OPEC+ at the next meeting would reduce the quotas, we would be hopeful that would mean that we also could continue to produce at current levels or possibly more. It is really all speculation, and we don't feel that we have enough hard data to actually offer a guidance. That's why while we remain hopeful and we can conclude that during the third quarter, we were allowed to produce as we noticed, around 11,000 barrels of oil per day throughout. We'll follow, of course, what happens, and we would certainly welcome an easing of productions. We are not in a position to really offer a meaningful guidance. Of course, we are also happy that the oil price is at $60 per barrel now. Of course, there is a trade-off both for us, for OPEC+ and the entire market, where obviously we'd rather do 11,000 at $60 than 12,000 at $35. With that said, keep following our monthly updates. We remain hopeful we can continue to produce at higher numbers than the original quota allotted, but we have no guarantees. Okay. Thank you. I have another question. Is it a problem for you as a company that you maybe not get the persons to Oman now? Can you guide your people quite good from video conferences? We have not had any problems at all. We are fully staffed in Oman, and we have also had an exchange of people going back and forth between Oman and Sweden. The Oman office is fully staffed, and they are an autonomous unit doing their technical work with a little bit of financial guidance from Stockholm, which is easily transmitted by video conference. The entire technical team is 100% intact, and we've also not had any problems getting people in and out, either in and out of the fields or also in and out of Oman in connection with the drilling of the Thameen well. No restrictions. Okay No impact at all. One more question from me. This electric vehicle movement around the world is gaining traction, maybe one day or now it a little bit influence oil demand. What's your position as your company to this? Is there a scenario that you cash out of your investments as an oil company, like maybe big oil likes to do it now? Do you see in every scenario, you as a company investing in Oman and producing there for the next 20 years? Obviously, we will adjust as the world evolves, but our expectation is that there will be demand for our product for many years yet to come. We certainly do not expect that any oil that we will find in Oman now will become stranded. I'd rather say that with the trend where you see some of the majors get out of the oil business and into renewables, that will just create more opportunity for specialized niched companies like ourselves to maintain an environmentally friendly production of lighter oils for as long as that's needed. Tethys also is very much of a niche player in that sense. We are an exploration production company. We do not have expertise to go build offshore wind farms or things like that. We happily leave that for the majors. We will happily continue doing what we do, if it is so that the majors are divesting assets, leaving value on the table, it's certainly something we would contemplate also maybe picking up. For the time being, Siegfried, we are quite confident that this business model will have many years yet to deliver value. Thank you. One more question to the buybacks. It's great that you do buybacks in a bad environment. That's very good. I appreciate that. The timing of the start of the buybacks you've done in, I think, mid-December or something like that. The timing was not that perfect. I don't want to criticize it, you approved the program way before the Q3 numbers were out, then were big volume to very cheap prices, you were not on the market as far as I can see. Why was there a lag to mid-December? I don't want to criticize it, just a question. No. Just to say also, we are not in the market really to speculate on the share price. The buybacks is just one of the tools we have for distributing value to shareholders. It's not so much about timing as it is should we do buybacks and buy more of our own assets, or should we distribute pure cash as dividend and redemption shares to shareholders. The timing for buybacks is actually less of a parameter. It's more having a overtime and optimize the capital structure, which is also entirely in line with the rules and framework for buybacks and other distribution. I understand. You focus on the company, not on the stock price. Thank you. Thank you. That was my question. Thank you. Thank you. Our next question comes from the line of Stephane Foucaud of Auctus Advisors. Please go ahead. Morning, Magnus. Morning, Petter. Congratulations for the performance of the Q4. A few questions for me. First, a bit of clarification for Block 49. I think I know the answer, but I want to make sure I've got that right. The CapEx for 2021 is $5 million, assuming 100%, but then you expect the $15 million reimbursement associated with the carry from EOG. Net-net-net, rather than a cash outflow of $5 million, that should be a cash inflow of $10 million. If you could confirm that would be great. My second question is around Block 56 and the Al Jumd area. I wanted to know to have a sense of the sort of size of what you're targeting by the drill bit out there, and whether you are looking at individual independent prospect or whether it's all related so that if the first well comes good, then there will be another two wells. If it doesn't, then you might be doing something else. Thank you. Thank you, Stephane. I think I can take the first question with regards to the Block 49 farmout. Yes, you are correct in your assumption that we are budgeting it on 100% basis. Simply is that is the budget that also has been put to the ministry and been approved. Irrespective of the timing of the actual closing, that is what will be spent. At closing, we will be reimbursed by EOG under the terms of the farmout transaction, where we can be reimbursed up to $15 million for the incurred costs and drilling. That's right. It will be offset with a positive consideration at some point during 2021. Thank you. I think for the second question, Magnus, if you want to. Certainly. What we have is the Al Jumd is a structure in its own right, where we have good indication that it could turn into a commercial opportunity. We're not quite there yet, but we are, of course, hoping to get it there. There isn't a cluster of similar structures, prospects along the border which in effect is Block 6 and the Karim Small Field area, which is immediately the other side of the border. Of course, what we have to do is to show that the Karim field, which has been in production for a good 10 years in Block 6, that it doesn't extend into Block 56, but that the same kind of play within the prospects and structures that have been identified will work also in 56. That's going to be one of the main focus areas for the block. To answer your question, it's a whole set of prospects and if they work and if we can get them into commercial significance, it's something that would be of interest to develop. Does that, at least, may I answer your question? What would be the typical size of a prospect at Al Jumd? I think we'll hold off a little bit on defining that until we are a little bit further along with our seismic interpretation. It's certainly a question we should be able to answer. Give us a couple of months. Okay. Thank you. Thank you. Our next question comes from the line of Teodor Nilsen at SB1 Markets. Please go ahead. Your line is open. Thank you, good morning, Magnus and Petter. A few questions from me, please. Petter, you mentioned the cost oil pool of $1.8 million for Blocks 3 and 4. Could you just confirm that number? Second question, I acknowledge it is difficult to provide some guidance for 2021 production, but would a fair working assumption be that fourth quarter production 2020 is a fair estimate for the full year 2021, assuming that nothing changes on production limitations? My third and last question is just on timing of CapEx. Which of the quarters this year will be most CapEx-intensive? Thank you. Thank you, Teodor. Yes, I can confirm that in the cost pool at the end of 2020, we had an approximate $1.8 million, and that is net to Tethys, so it's Tethys' net share. When I say approximate, there is always some reconciliation that can be made as the year is closed. There might be some slight movement from that, but that should be a good starting point. Otherwise, when it comes to the production guidance, well, of course, our ambition would always be to try to produce more, but we are working with uncertainty and under limitations. Hence, I think looking at the current production levels is a good indication of at least a starting point. Thus, we have our monthly disclosures. When it comes to CapEx timing, when it comes to Block 49, of course, we would expect most of that CapEx in the first quarter. Block 56, towards the end of the year. Likewise for Block 58. Blocks 3 and 4, we would probably see a step-up throughout the year with sort of accelerating CapEx is our expectation. If that gives you some clarity. Okay. I saw a little bit back-end load CapEx. Yeah. That would be the expectation. Okay. Thank you. Thank you. Our next question comes from the line of Jørgen Torstensen of Fearnley Securities. Please go ahead. Your line is open. Thanks. A couple of my questions have actually been answered, specifically relating to the CapEx situation on Block 49. Maybe I can ask another one. In your previous presentations, you had some slides showing leads and prospects on Blocks 3 and 4, which has been taken out at some point. Could you just give us an update on what this looks like today? Has the potential in general dropped or grown over the past year or so? Thank you. I'd say the potential is reasonably stable in that not much exploration activity was carried out in three and four in 2020. In the first quarter, some new seismic was shot, and we expect to have that interpreted before the end of the current first quarter. I would expect that leads and prospects map to be part of the show in May. Then with some updated seismic coverage, and hopefully also with a little bit more guidance as to what leads and prospects, or I should say then, what prospects we will be targeting for the current year. Okay, thanks. I'll turn it back. Thank you. Once again, if there are any further questions, please dial zero one on your telephone keypads now. Okay. As there are no further questions coming through at this time, I'll hand back to our speakers for the closing comments. Thank you very much. We hope to address you in this forum in May with a Q1 report and an update on our exploration efforts in all the blocks. In the meantime, stay tuned for any announcements as to how the operations evolve. Thank you very much and talk soon again.