All right. Hello, everyone, and thank you all for continuing to join us throughout the day here at the Lytham Partners Fall 2026 Investor Conference. Again, my name is Robert Blum, managing partner at Lytham Partners. Up next, Wolf Regener, Chief Executive Officer of Kolibri Global Energy, will take us through the company's slide presentation. Wolf, thank you so much for your participation today. The floor is all yours. Thanks, Robert. Thanks everyone for being here today with us. Appreciate your time. Kolibri Global Energy, I'll go through our forward-looking information and our disclaimers. You can find that all on our website in our corporate presentation, which you can find there as well. Kolibri Global Energy, for those of you that don't know who we are, we're an oil and gas operator for North America. Our operations are in Oklahoma. We operate the Tishomingo Shale oil field there, and we run what we consider a very financially stable oil and gas company. Try to keep our debt down low. We've had really good cash flow growth that we're looking to continue, have high netback production. So how much we make per every barrel of oil that comes out of the ground. Fully funded for our 2026 program as we have been for the past few years, and we continue to look to do that in the future. Basically using our existing cash flow and our existing line of credit with Bank of Oklahoma. We have a $75 million line of credit with Bank of Oklahoma. We have what we believe is a really high-quality asset. We have over 57 MMb of proved and probable reserves and about over 40 MMb of proved reserves. Those are all done by Netherland, Sewell which is a very reputable third party reservoir engineering firm. Our reserves are proved, are split into proved producing, which is 29%. This was at the end of last year before the wells that we're just bringing on would be incorporated into it, and 71% of that is in proved undeveloped reserves category. You can see that Netherland, Sewell believes we have a lot of reserves yet to go get. We trade on the Nasdaq under KGEI, on the TSX as well in Canada up at KEI. Lately, stock price has been floating in between $6 and $7 basically, depending on where the price of oil is that day, a lot of it. 35.7 million shares outstanding. Gives us a market cap of about $230 million U.S., and our net debt has been about $42 million roughly in the end of last quarter. Gives us an enterprise value of $276 million. Debt to EBITDA less than one. Our proved reserves that I mentioned earlier with Netherland, Sewell with oil prices that were down in the estimated they were $58 in 2026, $63 in 2027, $68 in 2028. You can see much, much lower than where oil prices have been this year. Still gave us a $440 million proved number compared to our market cap of $234 million. Tishomingo Shale field history. We had originally drilled for the Woodford Shale. We are located about halfway between Oklahoma City and Dallas. We have drilled and participated in about 40 wells drilling for the Woodford back then. We had about 12,500 acres. It was only about 15% oil back then, coming from the Woodford Shale. We sold the rights, our Woodford rights to Exxon/XTO that were accumulating a lot of acreage in the area. They have about 280,000 acres in this trend. You can see all the pink/purple down here is all them. We were the last holdout actually, and we sold to them for $147 million, but we kept the rights to these intervals that are a little bit shallower called the Caney Upper Sycamore. They did not want to pay us for what we felt they were worth, and we were the last holdout out here. They agreed to let us keep those rights, and that is what we have grown to now, where 71% of our production now is coming from oil. That is that 40 MMb of proved reserves and 57 MMb of proved probables, and we have grown that acreage position to about 17,000 acres. We have really transitioned from a natural gas producer into an oil producer, all by holding on to those rights that other people did not hold on to. Everyone around us is basically Exxon, and they have the rights to those intervals. Forecast for the year. We are estimating 4,700- 5,200 BOE a day, which is a 17%-30% increase over last year. Revenue, $78 million-$84 million. Again, a 37%-48% increase. Adjusted EBITDA $56 million-$62 million, which is a 33%-47% increase over last year. We are estimating that on a forecast based on $70 oil. Oil has obviously been higher than that, so hopefully we will do better than that, but we will see how these wells come on that we are bringing on now. Giving a history of our adjusted EBITDA over the years. The boxes here, which are important, are what the blended oil price is. What we get for our blend of oil, which is about 70% natural gas and natural gas liquids. You can see over the last few years how that had been trending down while our adjusted EBITDA has been holding in around $40 million. As our production has been growing, it has been offsetting the price declines. This year we had estimated about a $58.50 blended price. Hopefully, that is higher with the oil prices where they have been. That is what leads us to our forecast of our $56 million-$62 million in adjusted EBITDA. We do have a Normal Course Issuer Bid in place, and we do buy shares out of the market as well. We just renewed that here a little while ago. 2026, we entered it with a very strong exit rate because we brought a number of wells on at the end of 2025, continuing to develop the field. All of our reserves currently are coming from what is called the Caney Formation, and we drilled three more Caney wells that are in the very southwest corner of our property, called the Clifton Mack wells, and those are in flowback right now. We are also testing a new bench, so a new interval that is not in the reserve report. That is the False Caney well. We recently finished drilling that one, and the hydraulic fracture stimulation is estimated to be early in the fourth quarter. We're just waiting on the hydraulic fracture stimulation crews. I mentioned buying back shares, and we're continuing to plan and permit additional locations throughout the field. These additional benches that I mentioned, all of our proved undeveloped reserves right now are coming from this interval called the Caney. We have about 11,500 net acres to us, which is for those proved reserves. What we're testing in that False Caney well is this upper region here that is, we believe, separated from the Caney itself. And we have about 9,000 net acres that we think we can potentially make economic wells out of. You can see if this well works economically for us, that we have a lot of acreage that we can add to hopefully the reserve reports and have a significant impact on the number of wells we can drill in the future, and also on the reserves in general. We also have, down below us, the T zone that we've proved up in a number of locations. We believe that we can make good wells here as well. Every once in a while, it interferes with the production from the Caney, so we're holding off on developing that until later on in any particular area where the Caney production has declined down and we can come in and drill other T zone wells. And there's some other operators in the area that have made some really good Sycamore wells just to the north of us. We're tracking that progress and, at some point in time, we'll be testing that bench as well. Additional upside for us. And this slide just goes through everything that I just said. A little bit more on the False Caney. The reason I like it, though, I'll touch on is, as I mentioned, it's above the Caney, separated by a higher clay shale, which should act as a frack barrier between the two. We have a whole core through it, which is highly oil-saturated, has excellent characteristics from a number of logs as we've drilled numerous wells. And this is our first test well that we drilled in the first quarter. I should change that from drilling to drilled, which is the Lovina 5-8-1HF. The other zones that I spoke about on the previous slide, I'll just move on. Infrastructure's all in place out here. The gathering system is less than 1 mi from all of our approved locations. Oil is priced at West Texas Intermediate, less than $1.85 a barrel, and that's been consistent like that for years. So net oil in spool just from the Caney itself had given us 89 additional potential locations out here, 48 of those from the proved category, 24 in the probable, 17 in the possible. And those are mainly 1.5-mi and 2-mi laterals. I mentioned that we have over 17,000 net acres already. 45 Caney wells on production, not including the three that we're just putting into flowback, or that just is in flowback right now, I should say. And 99% of our acreage is held by production. That means we do not have to drill in any particular spot nor to hold leases, but we have the ability to drill when we want to and which areas we want to go to, whenever we want to. Then the additional upside we mentioned already here. Production growth, showing what I spoke about earlier. Nice growth year-on-year. This is quarter-by-quarter production growth that we have had. Net Operating Income, same thing. We have had some nice growth. The red line is much like those boxes that I spoke about earlier, the blended oil price just on a quarter-by-quarter basis, or BOE price. Drilling efficiencies. We have gotten better and better drilling wells out here in general. Back in 2016 and 2017, when we were drilling our first Caney wells, it was taking about 30 days to drill those for a 1-mi lateral. We go drill down to between 8,000 ft and 11,000 ft, then we go horizontal, and we were only going horizontal about a mile. Now we are going horizontally for a mile and a half and potentially longer as well. Those 1-mi laterals, we had gotten down to about 12 days of drilling. Going into 2023, our forecasted cost for those wells was about $7.2 million, and the average cost for the last wells that we drilled in those 12 days was about $5.5 million. The Lovina laterals, some mile-and-a-half laterals that we drilled here a while ago, we drilled as little as 10 and a half days. Our typical Caney well of a mile-and-a-half lateral has a budgeted cost of about $7.2 million. Operating expenses per BOE. These are numbers taken from other public companies, their reporting. This is from 2025, and you can see that we are at the very low end of the range of what we consider our peers. A number of the operators that are right around us that are in the low range as well are natural gas producers. The gas just flows out of the wells on their own. They do not need any kind of lift mechanism. We are really competing well with all the other operators. That leads us also to our SEC case of operating netback. Again, how much money we make per barrel that comes out of the ground. This is from 2025 as well, from those same peers, and you can see we are at the very upper end. We are the best in class right from 2025 on a netback basis. Our G&A has been coming down year after year, so that has been going well. Yearly net revenue, which very much mimics a lot of our adjusted EBIT and things like that as well, which our forecast is up for this year. The red line, again, is the on a year-by-year basis prices of the BOE. A little bit on the management team. I have got over 36 years of oil and gas experience, in multiple different companies. Done everything from land acquisitions to lots of operations experience, financing, M&A, et cetera, through numerous different companies. Gary Johnson, our CPA. He is a CPA. He is our CFO, and included roles with Occidental Petroleum, where he was Director of Technical Accounting. Dan Simpson, our Director of Engineering, has over 30 years of oil and gas experience all around the world as a petroleum engineer in the petroleum engineering field. Allan Hemmy, our geologist, has over 16 years of oil and gas experience, working in our field, a lot of that. Board of directors, David Neuhauser, our chairman, runs Livermore Partners, where he's a significant shareholder in the company, owning about 16% of the company. Leigh Kennan is chair of our audit committee, has lots of public company experience and industry experience, including she's on the board of directors of EQT. Glen Brown, lots of oil and gas experience in the MidCon. He was the Senior Vice President of Exploration for Continental Resources before he retired. Murray Grigg is very much on the technical side of things. We'll call him our scientist on the board and brings lots of experience in just general shale all over the world. In summary, why us? We think we have an excellent asset that we've been demonstrating. We're an efficient operator. We keep our debt down low, run our company in a good fashion. We've got lots of drilling inventory, years of drilling inventory left, and then additional upside from these other locations, other benches that we're trying to test right now. We've got catalysts coming on with the three new wells that are in flowback right now, and then the False Caney test that we're really looking forward to as well coming in the next month or so. We were added to the Russell 2000 here about a year and a half ago, buying back stock with excess cash as we have it, and we're looking to keep doing our knitting, so to speak, running the company in a good fashion, being conservative on drilling wells, and then also taking a little bit of risk every once in a while to prove up new horizons and add more reserves as we go forward. With that, I will turn it back over to Robert. Very good. Wolf, thanks so much for the participation here in the conference, the presentation. Of course, thank you to everybody here for watching as well. If you would like to schedule a meeting with Kolibri, either here at the conference this week or perhaps in the weeks to come, please shoot me an email. That's blum@lythampartners.com. To learn more about Lytham, make sure you visit our website, follow us on LinkedIn, and subscribe to us on YouTube to stay connected on future events coming up, such as the one here with Kolibri here. We hope you all enjoy the rest of the conference. Have a great day. Wolf, again, thanks so much for your participation. Thank you very much. Thanks, everybody.