Good morning, or good afternoon, dear ladies and gentlemen. It's our pleasure to see you here today, in our Q2 interim result presentation. It is me, Aavo Kärmas, together with our CFO, Veiko Räim, who is giving you an overview about results of Enefit Green in Q2. Happy to take your questions after the presentation. Of course, all- as always, that if questions which will remain unanswered or you wanna ask it, ask them later, you're always welcome to send them to email address investor@enefitgreen.ee. Also, current presentation is available on our website. If we start the presentation, as as usually we, we, we speak a bit of external factors or external environment around us, which had an effect on our results. If we start from a power crisis, you see that here we have brought out the comparison with Q2 last year. What we can see from here is that there has been really a significant drop off of power prices in all countries around the Baltic Sea. We see that the prices have dropped to, to, I mean, by, by 40%-60% in our main, main home markets, which certainly had an impact on our results as well. The reason for those, those power prices, let's say, being normalized compared to real significant high prices last year, the reasons are brought out here. Of course, it is mainly because of a very, I mean, low power gas prices. Gas prices have dropped two times compared to last year. Last but not least, the launch of a, of a, or start of a production in Olkiluoto 3 nuclear power plant. Those are the main, main reasons. If you, if one would ask me or ask that, that what is our prediction for the rest of the year, so it is. As, recent history has shown, it is really tricky to predict power prices for coming period. Usually the second half has shown higher power prices than the first half. Of course, it all depends on the weather conditions with winter, it depends on the gas demand and gas prices in Europe. The... This is actually the picture which has an impact on our activities in Q2 last or this year, sorry. Secondly, if we look on a regulatory environment, and then changes there. We have rolled out here a few changes or a few impacts. At the first of all, if you take European Union level, there have been discussions in European Commission regarding a market design in the future. There are a lot of discussions and a lot of topics still, still ongoing, but just to bring out a few, which may have an impact on renewable business are, for instance, that they are kind of contemplating on including what so-called power price cap mechanism into a main framework of regulations, as last year it was kind of a one-off of a decision to implement this price cap. That we think that maybe this could be also can be implemented easier in the future. The second, second thing is that 2-sided CfD is foreseen as a most favorable support mechanism for renewables in coming future. Once again, nothing has been decided yet with the talks and discussion are still ongoing. When we talk about Estonia, as you probably may know, that we had a parliament, parliamentary elections in Estonia this March. The new government has introduced the long-term action plan up to 2027, which has a significant points on renewables. Just to bring out here a few: first of all, Estonia wants to become an net exporter of the power by 2030. In order to, to, to become, so we see that we need more significant and more renewable capacity in, in Estonia, coming, coming online in, in few years. In, in order to boost it, from from a state side, our government has also foreseen to launch a support mechanism auctions for both for onshore and then offshore, offshore wind in, in, in coming, coming years. Maybe last but not least, from this slide, to highlight here is Poland and and the changes in the legislation regarding onshore wind. As we know, that some years, basically, the development of onshore wind in Poland has stopped because of a this so-called 10x tip height restriction, which now has been changed so that the turbines can be closer to the households, so the minimum distance is 700 m. We see that this will now significantly boost development of onshore wind, also in Poland, which is one of our core markets, and certainly Enefit Green will be part or will wanna be part of this process going forward. The last, or not the last, but the third external factor, which has a really significant impact on our activities and results, is a wind speed, as a wind is a largest part of our business. As you can see, here, the wind speeds in Estonia and Lithuania in second quarter, this year have been historically low. If we take in comparison, last three years, we see that it has been only 5.2 meters per second as an average. Yeah, I mean, usually the second quarter is lower than the first quarter, but that this year it was significantly lower than our first quarter. I mean, this is something we, we as a company, of course, cannot impact, cannot impact in any, any, any, any ways. Last thing, what we can do is, is actually our availabilities, how we operate our, our power plants. If we take first our wind farms, we see that, that Estonia has gained really a high, good results. The availability of Estonian wind farms was almost 98%. We see a slight decrease in, in Lithuania. Of course, our reasons behind... The main reason was actually the change of main components in our Šilutė wind farm. Main components is, for instance, gearboxes or generators, so those are really a, a massive and long-term, long-term repair works. The Šilutė wind farm is under full service agreement by turbine manufacturer, who also has taken an availability guarantee on a yearly basis. That we see what will be a final availability result of Šilutė wind farm by the end of this year. Our CHP power plant showed an excellent result, so remaining on the same level compared to last year, and same goes to our solar parks, which were operating in almost 100% level. Now, if we move on to our pipeline, I mean Enefit Green has said that we expect to grow four times by the end of 2026. Let's see, how did it go with our last quarter? Last quarter, our operational and under-construction capacity has increased almost to 1.13 GW. Addition is 74 G, sorry, MW, compared to Q1, which was mainly due to investment decision we made for Sopi, Sopi solar park, PV park in Estonia. Then now, as, as usually, in the second quarter report, we have also disclosed our near-term pipeline. We see that the by way... Or we expect that by the end of 2024, our operational and under-construction capacity will reach up to almost 1.8 GW. Nicely, nicely on the way to 1.9 gigawatts by the end of 2026. Of course, disclaimer is that all, all depends on, on the market conditions, and external factors, which may impact this, this, this growth. If we now look closer, our current under-construction projects, so here have been some changes compared to Q1 results when we met the last time. First of all, to point out here is that during the last, last quarter, three of our wind, so, power plants became operational. So this is Purtse PV and Purtse Wind in Estonia, and Zambrów Solar Park in Poland, which altogether are 62 MW. Currently, our operational capacity is 519 MW, as you can see on this blue, blue bar. Then there are a few other projects currently under construction. Let's go and through very quickly, one by one. Šilalė Wind Farm in Lithuania, last time we said we expected that the COD time is the 3rd quarter of this year. This time we see that unfortunately, the blade installment of one of turbines took a bit of longer time. Also, in order to reach a COD, we need to make a grid test. As I showed you before, there were unfavorable wind conditions in Lithuania, so we were not able to carry on with necessary grid test. All 12 turbines are currently up and running, producing electricity. Currently, the grid test is ongoing, and we expect to finalize them in really near future, coming weeks. This is, which will then bring us closer to a COD at the end of this year. The next wind farm is Akmenė. Here I would maybe stop a bit longer just to give you an overview or current status of Akmenė. As we also announced the beginning of May, that there was a collapse of one of the turbines in a wind farm. Current turbine, which collapsed, was under construction, so it was not owned by Enefit Green. Altogether, we have 14 turbines in the wind farm. Out of this, out of that, six turbines are currently kind of owned or handed over to Enefit Green. We stopped the operation of those six turbines after that incident in order to, to restart them after we have got known what has been really a root cause of this collapse, in order to avoid it-... this happened also in the future with our turbines. Currently, the report is of the root cause has been, is under preparation. We expect that in few weeks' time, the root cause will be, will be, will be known in order for us to make a decision of restarting the rest of the six turbines and reinstall the collapsed turbine. Of course, we will let you know as soon as possible, the results are known of a root cause in a due course. According to current knowledge, we expect that the park will be given to operation, first quarter of next year. Of course, we try to do everything which is in our hands in order to start the operations sooner. We are in a very, very close contact with a turbine manufacturer, in order to really, first of all, find the root cause, agree on a root cause, and secondly, find the ways how to boost the construction of the remaining wind farm. If we move on to Tolpanvaara, we have good news here, so that we expected to have a COD for Tolpanvaara, first quarter of next year. Currently, we see that we can make it actually fourth quarter of this year in order to as a construction has been developing well, and we see that also we can gain from the time spent on a grid test. Last from that slide to mention is our Sopi PV investment decision of 74 MW, which is current under construction. We made a decision this May. All in all, as you can see, our current operation around the construction capacity is 1.13 MW. If we move on to our pipeline of this year and then the first half of next year, we have brought out here new projects with what we expect to make investment decision this year. With total capacity of 424 MW, so this is 240 MW of wind and 184 MW of solar. Here, we have, do not have any major changes as of today, only to bring out is a Kelmė II and III. We, with both projects, we expected to make investment decision in the first half, at the end of first half of this year, as a, as a procurement, that has been, has been both for BOP and, and for turbine, has been taking a bit of longer time. We expect to make investment decision at the beginning of or in the middle of Q3 this year. We have, as of today, we have received all the offers, and the validation is undergoing, and then we'll also start about to investigate the PPA opportunities for those projects as well. If we move on to investment decisions for our projects, beginning of or first half of next year, both are new projects. We have not highlighted the names for most of those projects before, our total capacity is 240 MW. It's 60 MW of wind in Estonia and 180 MW of solar in Poland and also in Estonia. We expect that if we manage to realize the whole pipeline, what you can see at the. In front of you at the moment, that we expect that by the end of the next year, our capacity, both operational and under construction and with FIDs, is around 1.88 GW. Yeah, maybe one thing to, it's a good time here to point out is that, of course, we are very closely looking what is happening around us, what our forecast for our power prices in the future. We are very carefully picking up the projects. We still stick to our investment criterias, and also with all investment decisions, we will deliver a promised return on the capital. That, that we, we will not give up, give up on those terms, by, by, by any means, just, just maybe to say here. Last, but please, on our long-term pipeline, happy to say that, we have, in Q2, we, we have increased our, our long-term, capacity up to 2,100 MW. When we met the last time, it was, I think 1,007 MW, 1,006 MW. This is mostly offshore wind and then solar in, in, most of our, our home markets, so that, our development team has done a great job in order to, to find the ways how to, how to, increase, our capacity. Also, there have been, has been news on, on, on offshore wind, projects. Maybe to bring out here is a Loode offshore wind. Now we have completed our EIA studies. The report is, is ready, and the report has been has been given or forwarded to Minister of Climate in Estonia, who now goes it through, and then, then it's fair, kind of, obligation to give a go or no-go for, for this project to, to next stage. I mean, next stage is kind of a technical design and this, and stuff like that. With Liivi offshore wind project, we've been nicely moving forward with our studies. All the EIA studies are, are nicely, nicely, nicely on, on track, and expect also to, to start the seabed studies quite quite soon. All in all, we expect that, in, in the longer run, our total capacity will reach up to 6 GW. Saying that, I will stop here for a while and then give it over to Veiko, who will elaborate on our results in Q2. Thank you. Yeah. Thank you, Aavo. Quite, quite key changes compared to our exceptional 2022 results this quarter, so it deserves to go through all of them in detail. First of all, I think we would like to start from production, electricity production, as we, as we have shown, we have delivered 265 GWh of power in this quarter. Really, we're quite happy to see that there is already some, some production giving, giving from the new parks, less than we hoped for, due to, due to the incident with Akmenė a nd so on. 56 GWh was already, already coming from new parks. If one strips that out, then compared to the last year's production for the existing farms, we actually see that there is -23% of production decline. All in all, the low wind this quarter has really delivered quite a bit less, less power for us than we would expect on a regular, regular wind year. Secondly, what we can see is the implied capture price, as we have always discussed. This is all the power revenues minus purchase cost, divided by our production. Essentially, every megawatt hour that our production generates together with the guarantees of origin and support. This is EUR 90 per MWh, or -29% compared to the same period last year. One now think back, what Aavo just said, a few, a few slides back, then the market prices have been 50% lower, essentially, in our target markets. One can see that, that the way we hedge and the way we, we sign power purchase agreements actually reduces our power price volatility. That is essentially a beneficial effect of hedging. All in all, our revenues, or operating income, which includes also other operating income, is EUR 41.2 million this quarter, minus 13%, mainly due to the electricity revenues. The costs were higher as well, the EBITDA came in at EUR 19.3 million, or 37% lower. Finally, the net profit, of course, has some certain one-off items or, or kind of periodic items also in it, namely the increase in dividend taxation. This is every second quarter, we pay a dividend, we'll discuss that, but there is, there is also an impact of that in, in there, that we, we earned only EUR 1.1 million of net profits in Q2. Sorry, Veiko, interrupting you. Sorry, I think I forgot to say that, that, please, you can also ask a question during a presentation in a Q&A window. We'll take them after we have finished our presentation. Sorry, Veiko. Indeed. Thank you. If we first of all, look at the Q2 electricity prices, as we have seen them realize, then there are quite a few prices we discuss here, but I'd like to start from the volumes on the top right-hand side. You can see, first of all, that while our production was slightly below last year, 2% below, actually, our sales volumes increased 73 GWh, and then also the purchase volumes increased 79 GWh. The reason for that is that as we deliver on our PPAs and our production is significantly below our expectation in certain hours, then we need to buy more. So, so it essentially boosts both the sales side and the purchase side. But yeah, this is, this is the regular, regular feature of baseload hedging, in fact. What also comes out from here on, on this graph is that compared to last year, when actually almost 60% of our power sales volumes were done on market price, price basis, we were very exposed to the market price. As the price was going up, then our revenues were increasing. Whereas actually this year, you know, the size of PPAs in our portfolios or fixed price sales in our portfolio is quite a bit larger, which means that our, our exposure to the power price was, was significantly less. This is a clear, clear change compared to last year, that we have undertaken. In terms of prices, when you can see that, lower left-hand side of the table, when, when both the core market average prices in, in our target markets, the price of electricity that we sold to the market, also the realized purchase price, is roughly half of what it was last year. Maybe a bit more, maybe a bit less, but roughly half. Whereas our PPA prices, or the fixed sales prices, have actually increased by about 6%. This shows how the PPAs are actually delivering, delivering on their, their promise. On the other hand, the implied capture price, which again, where we take away all the sales, sales revenues, or, or take away all the purchase costs from sales revenues, has reduced to EUR 89.9 per MWh. This is, this is the impact of our results this quarter. Finally, what I'd like to point out is that, that in Q2 last year, when core markets average was still EUR 151 per MWh, then, then actually in Q3 and Q4 last year, when we were also quite a lot benefiting from the power prices in the market due to our sales, then actually the power prices were about EUR 300 and EUR 200 per MW, respectively. These red dots on the top left-hand side show you where, where we were in Q3 and Q4, respectively, last year. Depending what we'll realize this year, of course, our, our comparison base is very high in 2022. I think this deserves to be kept in mind. If we move on to operating income in its entirety, the biggest impact indeed has been by the captured electricity price. It has realized slightly differently in different segments, the wind, wind CHP, and actually solar, solar as well. The Wind segment, mainly the reduction in revenues behind it, is 9% drop in production, and then the realized price drop of earned price of 26%. In pellet side, CHP segment rather, we have had pellet performing well with increased volumes and higher sales prices, so this has boosted the revenues. On the other hand, there also the power price has reduced it, so altogether, net, net, it still was on a negative territory, the prices. Finally, Solar, there we have two, two features, namely the production was almost doubled or even more than doubled in the recent quarter. Of course, the prices were also lower for Solar, the main impact, why here we have Solar revenues declining is actually the exit from Turkey, low margin Solar Services business in Q2 or end of Q2 last year. There it is still having comparative impact on our revenues. We'll speak about this in a moment on the solar side as well. In terms of EBITDA, of course, dropping power prices have had also an impact on EBITDA. While we earn more from BPA side than on the price front, actually the power prices and sold to the market were, of course, dropping. There, if we take that, also net of the purchase price impact, then, then it's minus EUR 10 million totally, and this is the main reason behind the power or EBITDA drop of EUR 11 million that we had this quarter. When we look at the quantities, then, as I mentioned, both sales quantities and purchase quantities were higher. These have netted each other out to an extent, and altogether, the negative impact of minus EUR 0.3 million is brought about mainly by the lower production. Finally, the ex- fixed expenses impact, minus EUR 1.6 million in this quarter. The fixed expense increase of around 20% has been a feature both in 2022 for the full year as well as in Q1 2023. This is, behind it is our drive to increase our, our development activity, development team, actually go through the development, actions where we, where we have costs before we start construction. We have a bigger team, we have, more consultation costs, and this is really the, you know, roughly 65% of the costs increase is, is behind labor and consultation. So, yeah, we'll of course, need to deliver results on the development side, alongside the higher, higher costs, but, but the well, portfolio that we have is, is sizable, and, and we look to, look to realize that if the market opportunities allow. Finally, the other Cogeneration segment result, EUR 0.6 million positive, so this is really the higher sales of pellets and, and better profitability as well. This has helped our revenues a bit and EBITDA a bit as well. A positive impact from there. We now move to Wind segment, our largest segment, 60%, is actually of our volumes and, sorry, operating income and EBITDA. Here, indeed, on the left-hand side, top, you can see a -9% volume drop if one adds Estonia and Lithuania together. The Lithuanian production was higher due to new wind farms, while in Estonia, there is just the existing wind farm production drop had a bigger impact. The price increase, reduction, rather, from EUR 118 to EUR 87 per megawatt hour, was a sizable feature in the revenue decline. Finally, I would like to bring out also the OpEx per megawatt of operations. Here we, which is this stacked bar, second from left in the bottom, and here we have built it up via quarters, and one can see that while four quarters in total were about 6% higher, then actually this indexation of maintenance costs via wind farm operating agreements, actually has increased the costs in the latest quarter by 11%. Altogether, these haven't had so big impact yet, but it's altogether about EUR 0.2 million for this quarter, but this increase is actually feeding into these operating and maintenance costs as well. Finally, EBITDA then coming in at EUR 11.8 million or 42% lower due to all of these main impacts. I won't stop too long on, on CHP, because slightly lower volumes, substantially lower price, as, as this has been exposed to the market price reduction the most. Electricity revenues going from 7.4 to EUR 3.7 million, as you can see in the bottom left. Finally, as a result of that, also EBITDA dropping by EUR 3 million or 27% to EUR 7.8 million. Really, the, here, the, the pellet impact, as I've said already a few times, has, has been good, but, but all in all, the, still, the reduction of revenues from the power sales has been prevalent or, or dominant, dominating. Finally, Solar segment, as I've said a few times over the last, well, 12-18 months, really, so we're building solar out to be a big segment, and here we, is something where. First time where we can see it in earnest. Our production volumes have doubled from 13 GWh to 29.5 GWh. While our captured electricity price has dropped alongside others, then still our revenues have doubled as well. From the operating farms, especially, from EUR 1.5 million-EUR 3 million. In terms of solar services, as mentioned, this EUR 2.2 million, we don't earn any more than we did last year, but as it was a small margin product, then still our EBITDA grew by 54%. Altogether, our EBITDA of EUR 1.9 million made up 10% of the EBITDA in Q2, this is the highest that Solar has seen. In terms of net profits, as mentioned already, the reduction from EUR 16.9 million to EUR 1.1 million is sizable. EUR 11.5 million from that reduction comes from EBITDA reduction that we've covered. The rest of it is EUR 4.3 million of reduction, really, the main feature there is the corporate income tax that in Estonia gets charged on the time when you pay out dividends. This is in Q2, as we've distributed dividends of EUR 55 million, we have paid 9.3 or, you know, costed, expensed EUR 9.3 million of corporate income tax, which is EUR 4.7 million larger than last year. This is really the, behind the, the cost, cost increase. Sizable profits we earned from last year, most of them were from Estonian operations, hence the dividends paid out come from Estonian profits. Some part we paid from Lithuanian profits, in that sense, it was lower than if we paid everything out of Estonia, altogether still a EUR 4.7 million negative impact. We've also had interest cost increase, or interest expense increase of EUR 1.8 million from EUR 0.6 million-EUR 2.4 million. As we capitalize all of these interests into the construction, due to the regulation, then actually it doesn't affect our profit and loss at the moment. Altogether, returns that have come in on, both on the equity side, have been low at 12.9%, due to the net profits being small. Right. In terms of investments, we have had a sizable investment quarter, EUR 24 million investments coming from new wind farms and new solar parks, predominantly. Especially Tolpanvaara, saw more than EUR 30 million of investment in the recent quarter. Sopi-Tootsi had EUR 13.9 million, and Vantaa Solar farm actually saw roughly half of our total solar investments. Altogether, we are progressing well. In terms of financing cash flow of EUR 30.9 million that one sees on the top left-hand side, then there is actually two features. One is the dividend payment of EUR 55 million that we conducted during the quarter. To finance that and investments, we took out the loans of EUR 90 million, and really, our loan level has increased, net activity level rather, has increased to 2.2 times. Behind that is EUR 353 million of, you know, new or total outstanding loan, loan balance. We still have EUR 285 million left to draw on an existing line. Of course, we are in discussions with the loan providers for the next features or next, next loan limits as well. It will take us nicely through 2022 and our investments this year. Of course, interest rate environment is higher. 40% of our interest costs have been hedged. What we are paying at the end of the quarter is 3.4% of interest costs in total. Right. Finally, from my side, is the power portfolio. We haven't seen much change in the hedged levels in recent quarter. We did small amounts in 25, six, seven, quite close to our portfolio average prices, so not a lot of change in the PPA markets or PPA side for us this quarter. Of course, as our bigger investment decisions approach, then we expect to do more to hedge also the production, expected production from these from these new parks that are expected to be invested in. Of course, that we can disclose when we speak again. I think without further ado, I can give over to Aavo for final words. Thanks, Veiko. Just to sum up, last, last quarter, as I think the word we can use is it was really challenging. I mean, due to all the reasons we have been discussing previously. I mean, weak wind conditions, lower, lower power prices, slight increase in cost. Still, we've been able to move on with our pipeline, extra or additional 62 MW we brought on, online, and we still keep going on a growing growing our pipeline for for long term. Our development team has a focus on lowering LCOE for our future, future projects, because We've seen also in last, last quarter, that that market, the conditions are really challenging and can change very rapidly. In order to lower LCOE for our future projects, we mostly deliver or develop them, sorry, as a hybrid project, so wind and solar in the same locations, coupled with possible storage solutions in the future. I mean, talking about storage, we didn't mention, but that also in our first hybrid park in Purtse, where solar and wind already operational, we expect also to add the storage for next year, in middle of next year. We basically made a decision to acquire 4 MW or 8, yeah, 4 MW storage for-... Of course, the Akmenė case, which had an impact on our activities last quarter. We, we still have a very strong focus on, on finding out the root cause together with turbine supplier and our advisors. Then, then after we have done it and feel secure, we, we expect to relaunch or restart six turbines, which are currently standing. After that, do everything what is possible to build a wind farm ready even faster than we, we said, few, few, few moments ago. All in all, we, we still have in a focus on our pipeline. In order to realize the pipeline, we follow existing financial criteria in order to deliver the return on the capital we have promised. Saying that, we will stop here now and then ready to, to take your questions. Thanks very much for listening. Do you have any, any questions here? Mm-hmm. Does Enefit plan to get involved in hydrogen economy in the foreseeable future, i.e., use the surplus electricity not reserved for our customers to produce hydrogen when prices in Nord Pool are low? Yeah, that's true. That's a good one. I mean, we will see fluctuation of the prices, power prices in the future more often than today. Certainly, storage plays a role in this game. Especially, when offshore wind farms will become online in the future, we need really a large-scale storage opportunities, and certainly hydrogen is the best one of the best ones. When you ask, do we have any plans, the answer is that we are- We're currently thinking of launching a so-called pilot project of producing hydrogen in one of our onshore wind farms. In order to be ready once we start the construction of offshore wind farms, that, that, that we're more familiar about production of hydrogen. Cannot disclose any concrete dates here at the moment, but, but, as I said, that, that we, we have started an initial, initial preparations already. Yep, I'll take the second one. Have you made power delivery agreements with too high production assumptions, or what is wrong on your hedging policy? How long these problems related to power purchases will last? This, essentially, what we do, when always when we look at our portfolio, we look at the PPAs that we sign versus our total portfolio. In that sense, we're careful that we don't sell more than what we plan to produce. However, in these quarters, when production is really low, then of course, the power purchase agreement sales will form a larger part of the production than on average quarter. If it's a big production quarter, then the PPAs will form a smaller part. This is the fluctuating nature of our business. How long these problems related to power purchases will last? Well, power purchases are actually a regular feature of a baseload hedging as we do it. We can reduce the purchases by reducing the amount of power purchase agreements that we sign, but then we will be more exposed to the market price themselves. Essentially, we are trying to find a balance between the right setting level and the risk of purchases. Unfortunately, the pay as produced or where you don't bear this production level risk, market in Baltics hasn't been so developed yet as in certain other countries. We are, of course, looking to develop that as well. There are a few things we can do, but of course, the main thing still is that the purchases for baseload production is a regular happening. Mm-hmm. Next one: Purtse and Zambrów have moved from construction to operating portfolio. Am I correct to assume that the production figures have been included in additional 56 GWh of the production from new plants? Yes. The answer is yes. This production is included, so that I think it is also. Mm-hmm Goodly shows that, that these new, new power plants have, have been helping us in this low, low wind conditions, to, to produce more, compared to last year. The second part of the question is, is there anything else in that figure? We should have Šilalė, too, as well in that figure. Yeah. They have been contributing as well. Šilalė wind farm, a bit of wind power from Akmenė as well in, from April, was involved. Actually it's a combination of the total. I'll take the last one that, as they now move to operating, does that mean that the related interest expense will start appearing in the P&L? We generally compare our total interest costs and, how much we have on the construction of the assets. We take total portfolios. It may not appear so fast, but of course, in case the, these production assets start being captured as operating assets in accounting, then they would actually have, you know, all the, all the amortization costs, all the, all the operating costs that you regularly really have for operating assets. What would have been implied captured power price in Q2 without the external power purchase effects? It's a bit of a theoretical question for me, because in case we don't have purchases, that would mean that we, we wouldn't have the PPAs, right? Because if, if you don't purchase, you can't rely on PPAs, or if you would have a different kind of PPA, then the PPA price would be lower. In a way, one can calculate that our, our power, total power purchase costs have gone up by EUR 4 million, right, quarter-over-quarter. If you divide that by 265 GWh of production, it's about EUR 16 of impact, right? If purely theoretically speaking, if there was not an power purchase cost increase of EUR 4 million, one would have earned, instead of EUR 90, EUR 106 per megawatt hour. Again, then we would not have that kind of PPAs or that price PPAs, and it would not, it would not, you know, have had such a, such an impact. One can calculate that, of course. Yeah, finally. Mm-hmm. As Akmenė is not producing any revenues as it should be have been, could it actually be that you can claim those unearned revenues from a pipeline supplier? Our current focus is on agreeing on what has been a root cause of this collapse. Secondly, we want remaining six turbines, which are currently standing, to then produce electricity as soon as possible. Thirdly, to build the park, wind farm, ready as soon as possible. Of course, yes, I mean, there are terms and conditions in our agreements, which will allow us to co-cover secure costs. Of course, I, I cannot disclose it this at the moment in, in, in the details, but what I can, of course, say that all, all our activities have insurance coverage in Akmenė as well, this is not our priority at this moment. Of course, we will take it on the table in, in due time and do everything, all our, our costs get will get covered in what happened or have occurred so, so far. It seems that this is it. Thank you very much. Once, once again, you're always welcome to send any questions, comments to investor@enefitgreen.ee anytime. If you have any, any, any closer questions and you, you wanna know more in detail than we, we spoke today, once again, this presentation is available on our website, and you, you have a chance to, to, to, to, to go it through. Thank you very much once again, and then see you all the next time in our Q3 presentation.