Good morning or good afternoon, everybody. It's our pleasure to meet you here today in our Q1 interim results presentation. It is me, it's here, Aavo Kärmas here, accompanied by Veiko Räim, our CFO. That if you allow, we'll just go through the presentations, we are ready to take your questions afterwards. You can leave them in a chat during where we go it through. Of course, you're always welcome to send us an email to investor@enefitgreen.ee, we will certainly answer all your questions and comments. Let's kick it off. How it was in general Q1 2023 compared to last year. Of course, there have been quite significant changes in our surrounding environment, especially when the power prices are concerned. We have seen lower power prices in all our home markets compared to last year. Also, we have been seeing quite significant changes in regulatory environment in order to boost the growth of renewables in whole Europe. Also, our pipeline development has been moving forward and our operational experience has been on in a good level. This is all we gonna tell you about in coming slides. First of all, if we look on the Nord Pool power prices or power price around the Baltic Sea, we see that the prices have fallen in all, almost every country compared to last year, and especially in the Baltic, the price decrease has been between 26%-28%, so the prices have been around EUR 100 per MWh last quarter. The price decrease has been driven mostly, of course, due to lower gas prices, but also because of warmer winter we had in 2022. Also a lot of hydropower compared to first quarter, and nuclear power being on the market compared to 2022. This all has been leading to the prices we saw last quarter. Secondly, which is also to be mentioned, is regulatory environment. As I mentioned, quite a bit of changes both in the EU level as well in our home markets. Maybe just to highlight from here is that from EU level, the European Commission published its proposal for amending the EU electricity market regulation. Those amendments are likely to be adopted at the end of this year. The proposal aimed improving the current regulation, for example, by reducing the risks associated to long-term PPAs, increasing possibilities for reducing electricity consumption, and also, the future subsidies up to be paid are based on the CFDs. This is certainly a great step forward. If we look on our home markets, the main things to be highlighted here is Estonia and Latvia, who have adopted a so-called booking fee for a grid. This is aimed to be, how to say it, against the so-called phantom connections. We see that in like Estonia, a lot of connections are just booked and they could remain for a long time without use, without usage. That Estonia and Latvia now have moved in the same way as Lithuania. That all the developers take a commitment to build ready either solar parks or wind farms or storage by paying those booking fees. If they were not able to do that, of course, they will lose this money. Last but not least, Poland. I think also very important that Poland has changed the law which is about having onshore wind farms closer to households. Previously, it was the minimum distance was 10x tip height. That which was a main kind of a burden not to develop, which actually did help to develop onshore wind in Poland. As of today, the minimum distance is 700 meters. That this will allow certainly will boost onshore wind developments in Poland coming years. We, as Enefit Green, also will have a look or use this opportunity in the future. Wind conditions, which is very important for our business, as wind is a large part of our operations and income and EBITDA. As you can see, traditionally, Q1 has been the highest time in a year in terms of wind speed. What we saw in Estonia, that wind was approximately the same level compared to 2022, which was also a very good wind year. In Lithuania, it was slightly above 2022, but still remained in a high level. Really happy to also see that our availabilities in our wind farms were significantly higher level compared to last year, both in Estonia and Lithuania. Great thanks to our operational team for delivering those good results. Combined with strong wind conditions and good availability, we were able to produce more when than last year. The CHP and solar farms proved again the high availability this quarter compared to last year as well. If we move on to our development pipeline. Our focus has been always what we have promised to all our investors that by the end of 2026, we expect to grow 4x our existing capacity, reaching up to 1,900 MW. Here you see that by the end of this year, we expect that our operational under construction or projects which have got FIDs, the capacity will reach slightly above 1,500 MW. If market conditions will remain for our favor, we are nicely in a way to grow our capacity by 4x by the end of 2026. If we have a closer look on the projects which are currently under construction, with total capacity almost 600 MW. Here we can say that most of the projects, I mean, are going as expected. Already there are projects which have not reached the COD, commercial operating date yet, but they already are producing electricity, which had quite a significant impact to the total growth of electricity compared to last year. Here, for instance, to bring out Purtse Hybrid Park, both wind and solar, we are 100% already producing electricity. Same applies to Ząbrowo PV in Poland and Šilalė II Wind Farm in Lithuania, that 92% of the total capacity is already producing electricity. That maybe one thing I would especially spend a bit time here is our Akmenė Wind Farm case. We had an incident in Akmenė Wind Farm, which is currently under construction, May 2nd. One of the wind turbines fell down. This turbine was not officially taken over by Enefit Green, so this is under responsibility of our technology supplier, but still, it was really very unfortunate situation. We didn't of course expect it. Luckily, there were no human casualties, and currently investigation is going on together with our turbine supplier. The root cause is not known yet, so we in sake of security and possible future incidents, we have also turned off remaining eight turbines in this wind farm. We expect to have the results known as soon as possible. Of course, if we have some news, we will also share it with you and all our investors and then keep you in track. The rest of the project, yes, we are nicely in a way to grow the capacity almost up to 1.1 GW in coming few months. Yes. Now if we move on to our near-term pipeline, development pipeline, which is almost 490 MW split it almost half onshore wind and then solar. Here we have added one project compared to our last presentation, which is Mooste PV in Lithuania. As you can see, that we expect to make quite a significant FIDs in coming two months. By the end of first half of this year, we expect to make investment decision for Kelmė II Wind Farms and Sopi PV in Estonia, followed by two solar projects in Latvia. Currently, our tenders are ongoing and are in a late phase. Also we are now about to seek PPA opportunities for those projects. All in all, the total capacity which is operational under construction and expect to receive FIDs this year is slightly above 1,500 MW, as you can see from this slide. As always, you know, development is our everyday business, we are consistently also working with our long-term pipeline. Our long-term pipeline has increased from previously shown 1,300 MW up to 1,600 MW, which is mostly onshore wind and solar projects in the Baltic countries. Also in the first quarter, we acquired a Liivi Offshore Wind Farm from our parent, Eesti Energia. This is just to remind you that, prior to IPO, we signed an agreement with our parent that Enefit Green has a right to acquire the rights in this project. Now we can proudly say that it has been done and the size of the transaction was EUR 6.2 million. Now our long-term pipeline is in almost in 5,200 MW size. Good to see that the offshore project also moving forward. If you allow me, I will stop here for a second and give it over to Veiko and then our financial results. Thank you very much. Thank you. Good morning from my side as well. To go through this quarter, I mean, of course, we always start from production. Our electricity production was 460 GWh this quarter, which is 10% above last year's. Already quite a sizable contribution came from the new wind farms, Finland, to be specific, and 38 GWh came from there. Essentially the whole growth is coming from already the Finn farms, which we still haven't taken into operations yet, but they're already producing power. Secondly, the price dynamics. Here I'd like to highlight a bit more that the price we're speaking about here is the actual implied capture price per MWh produced. We'll go into a bit more detail what this mean on the next slides. Indeed, it is also a function of the power market prices, and it has been, in the first quarter of 2023, 20% lower compared to last year. As the power market prices have gone down, then it has had an impact. This all together, if we now translate into our results, the operating income was 16% higher, EUR 77.45 million. The EBITDA came in at EUR 41.1 million, by 10% lower, and similar EUR 4 million reduction we also saw in our net profits, which came in at EUR 35 million, 13% below. To speak a bit about electricity purchases this time more. We have drafted here a theoretical 24-hour period, in the left-hand graph. It goes from zero-hour between zero and one until 23 to 24. We have just shown it here how does this have an impact, how our PPAs that we have sold and our production interacts, right? First of all, these white bars, which are stable throughout, these indicate the amount of PPA sold every hour, the same amount. This is the monthly base of PPA. The red line on the graph actually indicates the amount of power being produced. If the red line is above the white bar, then there is also a green bar that reflects that the rest of the power is being sold to the Nord Pool, right? The moment when red line drops below the white bar, you start seeing also these light gray bars below appearing, which is essentially a purchase. In these situations, we purchase power to actually fulfill our PPA delivery obligation. These are the green and gray bars. We made the graph even a bit more complex just to make sure that everything is captured here. We've also introduced these light yellow bars, which actually reflect the balancing of the portfolio. In case the actual production is less or more than what we have envisaged, day before, day ahead sales, then there is some small additional purchase of sale ongoing. This is the balancing energy or open supply. This is how our portfolio operates. In essence, in case the prices were exactly the same every hour, then if you were purchasing and selling on, it wouldn't matter too much. Of course, as we've seen last year and, most of us know, I mean, the prices vary quite a lot between the hours. It becomes important at which price we sell and which price we buy, and also what are the volumes. On the left-hand side, you can see the average quarterly electricity prices do vary. We've plotted these along the last five quarters. Really go through the recent quarter in a bit more detail. In the table below graph, we show that actually the core markets average power price to Nord Pool or Polish Power Exchange has been EUR 100.5 per MWh. This is the sort of the baseline. The price of electricity sold to the market. This was these green bars that were above the PPA that we had excess production, was EUR 82.4 per MWh last quarter. The PPA prices, the white bars, were EUR 89.8 per MWh last quarter. The purchase prices, these light gray bars that were below the graph, was EUR 116.7 per MWh. If we take this all together, we say the price of the power that we've sold into the market, the PPAs, we take away the purchases. We also add the some subsidies that we still have or the guarantees of origin, and divide this by our generation. It is implied capture price, the EUR 101 per MWh that we showed in the last slides. This is how it comes together. If you look at the right-hand side, we also to bring out what are the volumes that we have generated, 406 GWh in the first quarter of 2023. The sales volumes are obviously higher because some of these h-hours that we don't generate, we purchase and sell. Altogether, the sales were coming in at 494 GWh, 260 from the PPAs, 234 GWh from actually sales to the market. Finally, the purchase that we have made in order to actually have our PPAs covered was EUR 92 per MWh this quarter. Indeed, this is having an impact on our captured price. Altogether, negative impacts were in this captured price were from the core markets average price reduction. Secondly, the increased electricity purchase volume, 92 GWh, was more than 3x above last year's. On the other hand, the PPA prices were actually increasing the feed-in tariff average price 14% compared to last year, and then the realized purchase price was also per MWh lower. These all come together into one number, but it is important that we from going forward now show a bit more openness and clarity about this because this stuff is also affecting our, you know, power prices, the revenues that we earn, as well as the power purchase costs that we have. If we now turn into to operating income growth, that where we come from, really from two places. We have actually the bigger production in Estonian and Lithuanian wind farms, about 39 GWh higher than last year and 12% growth from there. Secondly, in CHP segment, the revenues were increased by the higher sale price and sales price, high volumes and sales price. The applied capture price in both segments was below last year, 19% below in wind and 13% below in CHPs. Finally, the negative impact in solar segment, the reduction of revenues actually came from the exit from Turkey solar services business, which actually wasn't, isn't the news. That was what we communicated last year in Q3, in Q1 it's still happening. If I could turn our attention to EBITDA, we turned EUR 41.1 million EBITDA last year, last quarter, compared to the quarter, the same quarter in 2022, we had 10% lower result. The impacts we try to summarize here. Firstly, the lower electricity price gave us minus EUR 11.6 million negative impact. The higher production and the sales volume of which includes also purchased electricity is EUR +13 million. These were more or less balancing each other. The negative result came from higher purchased electricity cost, which I explained, EUR -7.1 million. On the positive side, the cogeneration segment, mainly due to sales of pellets, had better result. Also, one more positive impact this quarter is, and actually also coming in the future quarters, comes from a decrease of the non-derivative liability. It is a more non-monetary impact on EBITDA, and it actually goes back to the year 2021, when we signed first with the PPAs as financial transactions, and then we converted them into the PPAs. The mark-to-market from that time is actually now balance sheet as obligation, and now it starts actually coming through partly in our revenues and partly into the equity reserve. We've trusted a lot about it in the annex number five to the accounting statement. You can read more there, but in the recent quarter, it was EUR 0.9 million positive impact, and for the full year it will be EUR 2.3 million, and the impact will go from 2023-2027 as these PPAs realize. Finally, negative impact also from the fixed expenses as our development activities grow. I mean, there is consultation and studies and consultation costs that are higher, slightly higher also in the personnel side, but not as much. EUR 1.7 million negative impact from here. Quite a few things, but actually the lower price and higher volume and higher cost of purchased electricity is having the most impacts. Turn to segments. In wind, we already spoke about the higher generation, altogether 351 GWh of generation if we add together the Estonian wind farms and Lithuanian wind farms. Actual price, 19% lower at EUR 100 per MWh. This is what we earn in this segment. You can see this higher volume, lower price altogether still have helped the revenues or operating income to grow by EUR 3.4 million to EUR 44.8 million. On the other hand, as the higher higher purchase costs have come in and also have an impact on EBITDA, even there we have actually EUR 3.9 million lower result this year compared to last year. If one looks at the operating expenses per MW of capacity, where we take away the electricity purchase costs and focus on the O&M costs, land costs, such impacts, then you can see that there's some growth, we say the last four quarters here, altogether have average growth of 2.7%. Really, if you look at the two top bars in which is eight last year, 8.6 this year, and 8.9 in the previous quarter last year, and 9.3 in this quarter last, then this year, then actually growth is higher. The indices and the inflationary environment is also building into our results. Altogether, EUR 30.8 million of EBITDA, and then still wind being the largest segment that we have, share of the total EBITDA being 75%. We speak about cogeneration. I already mentioned about the pellet sales. These are the positive influence. We sold 62,000 tons of pellets this quarter, which is 13% more than last year. Really, the volumes shift between quarters. Some volume that we were previously delivering in Q4, now we deliver in Q1, also the volumes growth comes from there. Also, importantly, the higher pellet prices that we have realized. This year it's EUR 253 per ton, last year EUR 149 per ton, substantial growth, 69%, have helped us actually to capture back the higher biomass prices that we had. That is all very helpful. You can see that the operating income in total has grown by 34% on behind these pellet sales revenues, actually the EBITDA growth, +4.8%, is much more measured given that we have had higher biomass costs as well. Altogether, 12.9 million EUR of EBITDA from this segment, this quarter, and 31% on our total result. If we turn to solar. Here, we have several impacts. Firstly, first quarter is always very low production quarter in solar, so there is also a bit of volatility here. We have seen 35% lower production. Small numbers, but if we turn to percentages, they, of course, are sizable. This has actually reduced our earnings. On the other hand, the black capture price has been higher due to the sale of guarantees of origin. This is to help the revenues and actually even helped capture the electricity price quite a bit. In terms of operating income, then, here you can see the influence of the bottom left-hand side is the solar services revenues being not anymore part of our revenues. Otherwise, the revenue picture is a bit more, more stable. The EBITDA side, we actually had actually quite a bit of growth in our development-related fixed costs in this segment. As it comes from really low base, then, and we are developing a very large solar portfolio that has not made the investment decisions yet, then actually these consultations and personnel makes sense, you know, having a sizable impact here. We still want to grow the solar segment importance, as I say every quarter, and we have a pipeline to realize and that is very much we aim to do, as long as it adds value, of course. Total bottom line, 12 cents per share in last quarter, EUR 30.5 million. A little bit of positive impact from the higher interest income because we still have some cash balance from last year. As now the interest rate environment is positive, we are earning also a bit of return on that. Actually, the same level, otherwise similar impacts, not a lot to discuss further here. In terms of Return on Equity, 14%, that is a bit lower than previously due to the slightly lower net profits. Return on Invested Capital also reducing due to higher invested capital base, altogether still 14% and 12% last quarter, quite a reasonable result. If we turn to investments, we had quite a lot of investments here arising this quarter, strong operating cash flow helped us to fund these as well. Altogether, EUR 91.9 million of investment, really the majority, the vast majority went into the wind farms under construction. Sopi-Tootsi Wind Farm and Kelmė that we had just made the investment decision at the end of last quarter, these together were almost EUR 50 million of these investments. Purtse Hybrid Park, EUR 21 million, now I already mentioned the acquisition of Liivi Offshore Wind Farm project for EUR 6 million. Altogether, yeah, we are seeing that our cash balance is reducing. Of course, we need to take out as we are coming closer to zero, then we need to take out additional debt. This is according to our plans, what we have outlined for ourselves. Currently, net activity level 1.3x at the end of the recent quarter. This is growing in a measured way, as we have expected. We have already mentioned last time when we saw about our new loan lines. Nothing new there. Altogether, we have still unused credit facilities of investment loans and liquidity ones, EUR 375 million. We have good basis from where to fund our growth. In terms of also the loan balance, EUR 267.9 million. Of that, EUR 164 million has currently the interest rate fixed. This is what we did about a year ago. Then, of course, with EUR 100 million being open roughly, this has an impact on in case the interest rates go up. Altogether, it is still quite measured. Our current average effective interest rate, which includes the margin as well, is 2.75%. Finally, the PPAs. We have actually outlined our PPA portfolio as usual. In the first quarter, we did not actually run any new PPA competitions because our investment decisions were not near yet. We'll see what we'll do this quarter. As the investment decisions are approaching, we are likely to be active. Altogether, there is still 10.3 TWh of power sold forward, and at average price of EUR 72 per MWh. What I'd like to also draw your attention to perhaps is that, of course, the PPA level is reducing in future years. I mean, currently in this year, we have about 60% PPA levels compared to our operational and under construction projects. Also, next year it is maybe slightly higher even, and then around 2025, 2026, 2027 when we have all the operations coming in, which we're currently constructing, then it actually reduces to roughly 50% of the volume. This all also has an impact on our portfolio balancing. Right. I think I'll stop here, and then I'll hand it back to Aavo Kärmas for the next topics. Yeah. Thanks, Veiko, very much. Here is just a kind reminder for all our shareholders that on 24th of May, it's gonna be our annual general meeting of shareholders. You're all highly welcome to join the meeting in Tallinn at the Kai Art Center. It is held for the physical form, and the registration already starts at 12:00 P.M. You can read more details about the agenda. We have added a link here. We hope to see you there and in person and also have a good discussion with you. To sum up our presentation, all in all, as I said also at the very beginning, the first quarter this year is different, differs from quarter one of last year. We've been doing good in our operations. Our availabilities have been on a high level. Also, we're able to move on with our development pipeline. We have currently six wind farms and four solar farms under construction, which is quite significant for us. I mean, we never had that situation before. The last but not least, of course, we had also some not positive news, especially when it comes to incident with a wind turbine in Akmenė Wind Farm. Once again, we take it really very seriously, and we keep you posted in any news we will have in the future. The aim is once again to find out the root cause of this accident as soon as possible. Maybe last thing to highlight also from Q1 is actually that we'll start to explore strategic alternatives for our biomass assets. Biomass assets is CHPs in Paide and Valka, and also CHP in Brocēni and pellet production in Brocēni. That is basically we will just look for opportunities for selling those assets in order to have more focus on our core business, which is wind and solar, and really to have of a execution and development of resources on those assets. That we are now about to launch a process and expect to have more news in the second half of this year. Saying that, we will now end up here. Thanks very much for listening, and I see that we have also got some questions. Yeah. I'll take the first one. Yeah. The question is that, please, any comment on ECB's rate hike impact on future? Well, yeah, capital is becoming more expensive. I mean, it's now we shall live to see how close they are to the end of the rate hike cycle, whether there is any hope in reduction of rates at some point or whether they will need to stay at certain levels to make sure inflation comes down. Inflation has proved sticky. Mm, let's see. The impact on us is our capital is more expensive for us, loans and also the equity, and our projects need to jump over higher hurdles. We just make sure that we develop projects as efficiently as possible, that they're as efficient and as competitively priced in terms of SP as possible. This is our plan. What's your average interest rate on credits for those 2.75% on outstanding, floating or fixed? 60% fixed, 40% floating. This is the current status. A question came in via email. Can you explain why the production volume estimate for 2026 has come down? This has to do with our projects that we when we expect them to be online. There is a sort of on the new ones that we expect to make FIDs in. We revised the time schedule, there is a bit of delay of them coming online. We expect them online fully in 2027. This has been the reason they become ready later in 2026, and the full impact is in 2027. Yeah. This is our long-term pipeline. Long-term pipeline. Yeah. Everything else is on track. On your slide 23, where you show estimated production and portfolio hedging, it looks like you have 200 GWh of production that has no hedges, and it's solely sold on spot markets in financial year 2023. This corresponds to 12% of the total estimated production for this year. Do you plan to keep the exposure around 12% in the years to come, or expect this to increase as feeding premiums come out? Actually, if you look at the total difference between production and this, it is true. So yeah, the 200 GWh then in 2023 is between 1.7 TWh of production and 1.5 TWh of expected various measures of the support. We have been actually quite satisfied having certain gap there, especially as we look at that, because we can't with these instruments that we're using, we can't go too high with the swaps that we're doing, with the PPAs because there is quite a lot of flexibility and volatility in the winds, variability in the year, hence we need to leave buffers. That is why we have kept it. And we are expecting to keep buffers also in the future. If you look at the further years, 2026, 2027, then from the under construction and operating assets, you can see that we're roughly at, you know, 50%, maybe a bit above, from the various measures. This is roughly where we are. We're quite confident. Of course, you know, we are looking at the market with great interest. How this market is changing, converging, what's the variability, what is the impact on prices on different hours. It is a live process. We always learn to do better. This is our plan. I think that's it. No more questions. No more questions at this moment. Veiko and me, we thank you very much for joining us today. Hope to see you in our shareholder meeting on 24th of May. As we said, you're always