Good day, and welcome to the Kolibri Global Energy First Quarter 2024 Earnings Conference Call. All participants will be in a listen-only mode. Should you need assistance, please signal conference specialist by pressing the star key followed by zero. After today's presentation, there will be an opportunity to ask questions. To ask a question, you may press star then one on your touch-tone phone, and to withdraw your question, please press star then two. Please note, this event is being recorded. Also, this call may contain forward-looking information regarding Kolibri's strategic plans, anticipated production, capital expenditures, exit rates and cash flows, reserves, and other estimates and forecasts. Forward-looking information is subject to risks and uncertainties, and actual results will vary from the forward-looking statements. This call may include future-oriented financial information and financial outlook information, which Kolibri discloses in order to provide readers with a more complete perspective on Kolibri's potential future operations, and such information may not be appropriate for other purposes. For a description of the assumptions on which such forward-looking information is based on, and the applicable risk and uncertainties in Kolibri's policy for updating such statements, we direct you to Kolibri's most recent Annual Information Form and Management Discussion and Analysis for the period under discussion, as well as Kolibri's most recent corporate presentation, all of which are available on Kolibri's website. I would now like to turn the conference over to Mr. Wolf Regener. Please go ahead, sir. Thank you. Thank you, everyone, for joining us today. With me on today's call is also Gary Johnson, our Chief Financial Officer. We released our 2023 first quarter report last night, and I'll assume you've all had a chance to look over the report. Hopefully, you also saw our announcement this morning regarding a line of credit increase from Bank of Oklahoma. So we're very pleased with the accomplishments we've achieved this quarter and last year. We've had strong financial results, continued to make progress on our development program. Nice production increases for the field, which you can actually see on Slide 11 of our presentation. Kind of gives you a nice visual on it. I want to take the opportunity to thank everyone in the company who's worked hard to grow the company quarter after quarter. With that, I would like to turn the call over to Gary to discuss our financial results. Gary, take it away. All right. Thanks, Wolf, and thanks, everyone, for joining the call. I'm going to go over a few highlights of the first quarter results, and then we can take questions at the end of the call. All amounts are in U.S. dollars, unless otherwise stated. As you can see from the earnings released yesterday, we had another good quarter with strong production and Adjusted EBITDA. Average production was up 3% to 3,305 BOE per day, compared to 3,194 BOE per day in the prior year quarter. The increase was due to the wells added in 2023, partially offset by lower production from wells that were impacted by the offset fracture stimulations last year. Production is tracking above our third-party reservoir engineering firm's year-end forecast, and we look forward to adding new production from the Nickel Hill wells by the end of this month. The production mix for the first quarter was 70% oil due to some true-ups and adjustments in the quarter, but we expect the oil mix to trend in the mid- to high 70%s for the rest of the year. Adjusted EBITDA was $10.4 million, compared to $11.4 million in the prior year quarter, which was a decrease of 9% due to lower prices and higher OpEx, partially offset by higher production. Net revenue was flat at $14.2 million, as the higher production and lower prices offset each other. Operating expense was $8.36 per BOE for the quarter, compared to $6.04 per BOE in the prior year first quarter. The operating expense included prior period cost adjustments of about $600,000, although the net impact of those adjustments was only about $200,000, due to offsetting prior period revenue adjustments. If we subtract out the prior period cost adjustments, our operating expense would have been $6.43 per BOE. Net income was $3.3 million, and basic earnings per share was $0.09 per share, compared to $7.9 million or $0.22 per basic share in the prior year first quarter. The decrease was due to a $2.3 million swing in the non-cash unrealized mark-to-market adjustments on our hedges between first quarter of this year and last year. We had a $900,000 unrealized loss on hedges in this quarter, versus a $1.4 million unrealized gain on hedges in the prior year first quarter. In addition, we had $1.2 million of deferred income tax expense in the first quarter of 2024, as the difference between the tax bases and book bases of our PP&E has increased over the last two years. Since our year- to- date still has existing NOLs, no cash taxes, no cash taxes are expected to be paid this year, but we do expect to continue recognizing deferred income tax expense for the rest of the year. Our net back from operations decreased to $38.94 per BOE, compared to $43.67 per BOE in the prior year quarter. This was due to lower average prices of 4% and higher OpEx. Net backs, including the impact of hedges, were $37.81 per BOE, compared to $42.23, which was a 10% decrease. And then, I just wanted to point out, as Wolf mentioned as, as well, our credit facility was just redetermined, which increased our borrowing base from $40 million to $50 million, which was a 25% increase. This will give us more flexibility in managing our working capital and also demonstrates the value of the field. And with that, I'll hand it back to Wolf. Thanks, Gary. As you can tell, we've had some excellent growth over the last few years. Revenue and cash flow growing, keeping our leverage low, and we've been executing well in the field. I can't emphasize enough about our great team. Where last year we went in expecting our well cost to be about $7.2 million, and now we're budgeting our wells to cost around $5.6 million. So a huge decrease, and we're actually hoping we can beat that to keep dropping that a little bit further this year, but we'll see how the year goes. We always strive for constant improvement, and this is a shining example of that. We are, we have and are taking steps to have more people recognize the value of the company. That includes last year of our uplisting to the Nasdaq, where we now qualify for the Russell Index this year, and we'll have marketing and plans in place to be able to tell more people about our, what we feel is our undervalued story. Since, we had our 2023 financials out and we didn't have a call, I just thought I'd point out a few things. Our production last year from difference between 2022 and 2023 increased by 70%, and that also increased our Adjusted EBITDA by 56%. So we're building, and we're growing. We're growing company value, and we look forward to continuing to do so. With that, that concludes the formal part of our presentation, and, we'd be happy to answer any questions that, anyone may have. We will now begin the question-and-answer session. To ask a question, you may press star then one on your touch-tone phone. If you're using a speakerphone, please pick up your handset before pressing the keys. If at any time your question has been addressed and you would like to withdraw your question, please press star then two. At this time, we'll pause momentarily to assemble our roster. Our first question will come from John White with Roth Capital. Please go ahead. Good morning, and congratulations on a nice quarter. Well, thanks, John. Appreciate it. Yeah, Gary, did you say, in the subsequent quarters, the oil cut's gonna go back to 79%? Yeah, I mean, maybe not that high, but we're expecting it to go, you know, 76%-77%. Kind of what it's been trending at. It kind of get down this quarter, but we expect it to go, like, like I said, mid- to- high 70s. Okay. Thank you. I was a bit distracted when you were talking about that. Oh, no worries. And LOE came in at $2.2 million, and I had estimated $2.7 million. What do you think. Why do you think I overestimated? I'm not sure. You know, yeah, I mean, we did make comments earlier that we do have more flow backs and things like that. That's, you know, will increase our OpEx a little bit. But I think we've been able to handle that, where- Yeah, I think some of the water hauling that- Things just came down. The water hauling was up for a while, but that's what's come down as well. Yeah, so that's true. Okay. It was a- So I think that's. Very nice reduction in, compared to my estimate, so congratulations. I saw in your updated May presentation, you've got the same 2024 guidance that you had in January. Correct? Yeah. We haven't changed anything. You know, we'll see how these wells come on, and hopefully they come on as expected, and we can bring the rest of the wells that we have planned on in the year on, on time, and they perform as expected, then hopefully, we're in our guidance band. So if something changes, then we'll definitely announce that, though. Of course. Okay, thanks for your responses, and I'll turn it back to the operator. Oh, good, John. Take care. Thank you. Again, if you have a question, please press star then one. Our next question will come from Jeff Robertson with Water Tower Research. Please go ahead. Thank you. Good morning. Well, I was looking at Slide 13, which addresses drilling efficiencies, and you touched on this- Yep. I think, in your remarks. Can you provide some color around what is contributing to the fewer days and as a result, the lower costs for drilling your wells? Yeah, sure. We've not to get too technical, but we basically, we used a different downhole assembly. We're using more rotary steerables now, and we found one that seems to be working well from one company. And we've also, just over the years, improved, you know, how we deal with certain things out here, what we have to do, what we have to stay away from in order to avoid having issues. You know, you never, you never know when you're gonna have a, a tool failure, and that's really the only difference right now when, when a well is, you know, coming in around the 10-day mark versus the, 11 or 12-day mark, if you have less trips. But, we've been fortunate enough to have some wells that we can drill from almost top to bottom without coming out of the hole for one of my laterals. So that's, you know, 15,500 ft-16,000 ft that we're drilling in one trip, which really saves a lot of time and money. So it's a long way from when we first started drilling these wells. Experience teaches you a lot of things, I suppose. It really does. Every field is different, right? So you have to kind of, and you can only change one thing at a time, because if you change more than one thing in the well, then you don't know what, what worked and what didn't work. Have you experimented, or maybe experiment's not the right word, but have you looked at different lateral lengths as a way, or and would that add anything to your capital efficiency in this area? Yeah, we are looking at that. We're considering, we just had a meeting with our team last week. In a couple areas of the field, we think it may make sense to do 2-mile laterals. We do have fairly steep dips out here, and so when you start getting longer than that, you start having more challenges, just from the elevation. If you're drilling up dip, you're making the turn and then having a, you know, almost 1,000 ft of rise, maybe 1,500 ft of rise, as you're drilling that, and drilling down dip, the same thing. So, in an area where it can work well and we can stay in interval, we do find a difference that as long as we stay in our interval, we make better and better wells, and we even drift a little bit out of our interval, the wells don't perform quite as well. So, the longer the lateral, the more challenging, you know, that becomes too, as far as just operation. But we are looking into it in a couple areas, and you may see us proposing a few longer laterals here, as time goes on. I presume the downhole assembly you referenced is also meant to help you stay in zone? Absolutely. Yeah, it's where all the tools are that tell you where they are, that, as close to the bit as possible, and, getting readings as often as possible. So because, you know, there in any oil field, there are complexities, that, as much as you know. So the second well in a section is always a lot easier than the first, and, the closer you went to the previous well, the, the better chance you have of staying all the way in. But our guys have been really good and doing a really good job in, geosteering, so that's been good. And, you know, balancing that off with how fast we drill, and like we said, we're getting better and better at it. Thank you. Thank you for taking my questions. Absolutely. Thanks for the question and the time. This concludes our question- and- answer session. I would like to turn the conference back over to Mr. Wolf Regener for any closing remarks. Please go ahead, sir. All right. Thank you. I just wanted to say thank you, everyone, for participating and joining us today. It's appreciated, and I always look forward to input and to answer questions from everyone. So thanks, everyone, and hope you all have a great rest of your day. Take care. The conference is now concluded. Thank you for attending today's presentation. You may now disconnect.