Hello. Good morning, everyone. My name is Kevin Andrus with EnerCom. I am happy to welcome the Prospera Energy team here today to talk about their opportunities. It is a smaller company, and that creates a tremendous opportunity in the early part of their business cycle that they are developing rapidly. They are developing, I would say, a low-risk, high-growth development play, and it just creates a unique opportunity in their investment offering. Without further ado, I would like to introduce Shubham Garg, Chairman and Chief Executive Officer, and Chris Ludtke, Chief Financial Officer. Gentlemen. Welcome, everybody. Good to see some familiar faces. Just trying to get the slide deck worked out so we can move to the next one here. Yeah, good to see some familiar faces here. It is our fourth year here at EnerCom. Myself, a petroleum engineer, worked operating wells in the field, came into the story as an investor, and we eventually have come in as an operator. We are about 50%+ owned by the board and key insiders, so very happy to present here. As a smaller company with the commodity price tailwinds behind us and a very capital-efficient heavy oil producer up in Saskatchewan in Canada. Yeah, looking forward to share. Last year, we presented at EnerCom with our reactivation play. We are a heavy oil company that has no drilling, no exploration at the moment. We focus primarily on reactivation. Going into wells, vertical well bores that have been down for 20, 25, 30 years, bringing that back online with the latest heavy oil technology, PCP pumps, progressive cavity pumps, and a focus on low-producing wells in the eight to 20 barrels per day range. Last year, we were only about 60 - 75 days in on some of those wells. This year, we have 14 - 16 months of history to prove it. Our legacy fields, modern solutions, and proven results this year. The EnerCom 2025 report card. We presented four wells last year that were just early in their reactivation cycle. Those wells now, over the past 365 days and more, have produced over 30,000 bbl. I remind people that these are CAD 150,000 each, so compared to some of the unconventional wells and even the conventional drills you may have heard earlier this week, we are very cheap, capital efficient, CAD 150,000 per well, six to eight-month paybacks, and the wells hitting peak rates at month 14 or month 16, as opposed to these heavy decline rates. These four wells have produced over CAD 800,000 of net revenue and have resulted in a 352% increase in our prolific Luseland pool. The thesis has not changed. We are absolutely running on the same program. We did 17 wells last year, a total capital spend of CAD 1.64 million, and by the end of June of 2026, those wells had produced CAD 1.7 million of net operating cash flow in a much lower oil price environment than where we currently sit, and we have the next 140 wells to go now. We're a Canadian junior heavy oil company built on reactivation, 745 BOEs per day in Q2 2026. Primarily heavy oil, 99%. 400 million barrels in the ground at only 3%-8% recovery. These assets have been flip-flopping through previous operators and poor operating cycles, leading us to have 100% net ownership and operating status. Now, with 140 reactivations still to go, 41 have been identified as Tier 1 candidates and almost a CAD 30 netback per BOE, up 170% from Q1. The Q2 that we printed was the highest revenue quarter in the company's history and the highest operating cash flow in many years as well. We operate primarily in Saskatchewan there, as you see, with two waterflood pools and then our Luseland property, which is our reactivation play. We don't drill for growth. We restart it. We don't take geological risk. We have six 3D seismic shoots across our property that we have gone and looked at. We have multiple well bores on 40-acre spacing. We've specifically targeted reactivations in specific sections of the pool, proven those wells out over the last 14 - 16 months, and now we are ready to scale. Pretty simple. High operating costs, poor sand management, lower oil price, higher WCS differentials had left this pool in a very poor state. We've now proven that with the 352% growth in Luseland and continuing to accelerate from here. We screen for wells. We reactivate the wells. We're 36 hours from service rig on site to well spinning and producing cash flow and revenue. We then optimize the wells over the first three to six months with daily fluid shots, wellhead cuts, sand management, recycle pumps, and then we compound. As those wells pay back, they allow us to then go and reactivate the following wells, which are already on our balance sheet. There's the growth engine that we see here. A heavy reactivation program in Q1 and Q2 of 2025 when we were last at EnerCom, that consistent growth there. We've since stabilized the pool with very little capital investment in there. Now we are ready to scale with the next 41 tier 1 wells that we would like to bring online. Over this period of time, we've iterated many of our production engineering techniques. We've installed specific recycle pumps where we inject oil at 80 degrees Celsius into the reservoir. It dilutes down the sand content, and it breaks the clumps of sand, brings them up the wellbore. We've gone and changed up our speed up strategy. We no longer do any more than five RPMs at a time. Watch that reservoir, see how it does, and really iterated some of the pump sizing as well to the 13 and 18 series pumps with higher lift capacity to lift those sand slugs when they do come in. As you can see, continuing rising from here. Very excited to scale the reservoir, not just with the new wells, but also keep optimizing some of the existing wells, which I will talk about here very shortly. The company itself is growing with a stable base. We are, as we mentioned, about 745 BOEs per day, which makes us very unique in the Canadian landscape. In 2015, 2016, there were 93 companies with a sub CAD 50 million market cap with Canadian assets on the TSX Venture. Today, there are 10. That makes us a very unique opportunity set with the existing assets in place where we do not need to do high-risk drilling or any type of exploration as we go. A bit more about the class of 2025. At EnerCom 2025, where we sat with 40 -7 5 days online. July 2026, we sit with 14 - 16 months of history. As you can see, the year-to-date revenue far eclipses the capital cost we spent on these wells to bring them online, which I will get into some detail here. The 10-7, our top producer, our most consistent producer. We spent about CAD 157,000 on this well when we first brought it online. You can see the consistency of barrels there. Currently producing 36 bbl a day for CAD 157,000. Excellent capital efficiencies. This well is flow lined as well, so it goes directly into our battery with no trucking cost. As you can see, the latest month we have here, we produced over CAD 100,000 of free cash flow out of this well. So a testament to what we can do. This well paid back in six months and has now paid back 2.4 x at the end of June. Looking at almost 3x payout here at current time and very excited to see wells like this. The part of the next 41 reactivations includes multiple wells in section seven because this section has proven out to be very profitable for us. The 10-8 well is a bit different. It started off slow at 8 bbl - 10 bbl a day. It started off at 60% oil cut. We now have this well making almost 30 bbl a day at an 80% oil cut. So very happy with the performance here. It continues to pay out, and it continues to have optimization potential. So we speed up 5 RPM. We watch the well for 30, 60, 90 days until it completely stabilizes. We add another five RPM. We add another 2 bbl. This is not just a production story, but our cash flows continue to rise, and our reserve base continues to rise backstop by the excellent performance of wells like this. This well is now at 2.5 x payback, CapEx returned, and has also, again, cleared up significantly other wells in section eight for us to bring online. 7-33 well, a bit different. This area of the pool has only 2%-2.5% recovery. So very early in its primary CHOPS state. We do see a lot more sand content here because those wormholes are still developing. They are still propagating. We are really playing around with the recycle pump strategy on this well. As you can see, we had consistent production of 18 bbl - 20 bbl per day for many months, and then that massive sand slug came in as that wormhole collapsed. Over the past six months, we are actively working through this wormhole. Once we get through this and bring all of that sand online, well, uphole, we expect there to be massive optimization potential here. When this well went down in 2017, it was making 65 bbl a day. We see a big potential here. These wells, they did not slowly die off because of depletion. They went down because the sand became too hard to handle and companies just gave up on it. Very excited to come back and bring some of these wells back. The 3-2 well is a part of our Cuthbert waterflood. We shared this when it was making about five or six barrels per day at EnerCom 2025. We made some small adjustments to the waterflood and injection patterns, increased the RPM of the well by 3x, and as you can see, it is now a consistent 15 bbl-18 bbl per day producer. Very happy with this one. Over CAD 200,000 of revenue this year so far and just continues to provide stable production. The 16-7 well, our naughty one. It started off at 99.9% water cut. It was making one, 2 bbl per day. We really spent a lot of money trucking water out of this well, making up to 8% sand out of this well. As you can see, it has now become our superstar, upwards of 47 bbl per day at certain times in May and June. Consistently provides really high operating income. Paid out 2.6x already, and we expect this to be further optimized into the 50, 60, 70 barrels per day range here as we continue to go. One that the reserve auditors were quite shocked by, and we just continue to demonstrate these results. Again, section seven has been fantastic for us. We are very excited to get the 9-7 well, along with several other wells in section seven online. What makes our story very exciting is that we do not need to drill. We do not need to keep bringing wells online to keep production flat. Our wells are actually inclining as the year goes on. The capital efficiencies of these projects continue to get better and better as we get into month six, month 12, month 18. The learnings from these wells have allowed us now to take the existing reactivation play and be able to scale them up faster. Some of the learnings we have had, do not run five series pumps. Do not run 1,200 meters lift. Run bigger pumps right off the bat so you can handle the sand and get to your peak rates a lot faster, which will be our fall and winter 2026 strategy. Lastly, the one of 17 well, our steady eddy producer, continues to chug at eight to 10 bbl per day. These wells have been online for 45 years, and they still continue to produce at these 8 bbl, 10 bbl, 12 bbl per day, which gives us a lot of confidence in the wells that we are bringing online. These are not going to be wells that come online for a year, they make 10 barrels per day, then they die. We've got wells that have multi decades of production. It's a very similar reservoir, and most importantly, a large part of the reservoir has no bottom water. We're not encumbered by water coning or water channeling. We're able to really push these wells over the next few years to their maximum limit, because there is no bottom water. It's a pure oil column, 40% porosity, up to four Darcy rock, and up to 14 m of net pay. So really high quality reservoir. The last one, our three of nine well, which we continue to work on. This well sits right adjacent to the top producer of the pool, which has made over 700,000 barrels of oil over the last 45 years on an 800 m vertical. This well sits kitty-corner to it. We're looking to really optimize this well. It's got way less production than the wells in its area. We're really excited to get these wormholes propagating and move forward. Finally, a slide on the entire program. As mentioned earlier, we did 17 wells last year, CAD 1.64 million of total capital, CAD 1.7 million of operating cash flow has been recovered in a much lower oil price environment. Wells that are now approaching 3x payout, five wells that have paid out over 2x already, leading to this reactivation staircase. Rather than the shale treadmill, we have a reactivation staircase upwards instead. We're very excited to scale for the next 41 wells backstopped by some of these results. Some of the wells from the 2025 program haven't paid out yet, but they continue to produce five, six, seven barrels per day. As that sand content starts to come down, we will then ramp those up. We are not in the business of maximizing IPs. We're not in the business of showing graphs that then result in the wells going down and needing a service rig. Really keeping these wells online is our top priority, even if that means we have to be a little bit slower than we need to be. With that, I'll pass it on to Chris Ludtke, our Chief Financial Officer, for the Q2 update. Thanks, Shubham Garg. I love the passion that comes from our Chief Executive Officer and the engineering and operations team as we grow this field. From a field that was only 50 bbl a day, 18- 20 months ago, we've seen considerable progress and expect to continually grow that field here in the near future. We're starting to see that in the financial results. Q2 was the best quarter that Prospera Energy has published over the last five years. We've seen CAD 6.2 million of revenue, which is up significantly from previous quarters, up 37% from Q1 2026. It was the best quarter in terms of profit margin or net field operating income over the last eight quarters. A lot of the capital that has been spent over the last couple of years going into well reactivations, plant maintenance, infrastructure, and so on, is really starting to pay off. We are seeing that the company is now foundationally structured to be able to support considerable growth that we will talk about here over the next two to three years. We are seeing operating income or operating netbacks of approximately CAD 30 a barrel. Those are up considerably, and the heavy barrel that is being produced is definitely leveraged. When we are seeing prices of CAD 90 + per barrel, we are seeing that operating income is considerably leveraged against those prices. T his is what the operating engine does at really only CAD 600,000 of capital that was spent in Q2 with fixed costs that were relatively flat or declining, and the remaining reactivation inventory essentially untouched. A little bit more of a graphical representation of the rising quarterly revenue, like I said, CAD 6.2 million for the quarter. Recognize that a lot of that was price driven. However, stability around operating costs, actually a reduction in operating costs and an increase in production were also driving factors to that revenue number. A little bit more along the same vein. Same barrels, more dollars, so realizing revenue per produced BOE. Q2 2025 was approximately CAD 70. Q2 2026, CAD 91. So an increase of 32%. So three forces all pointing in the same way, which I mentioned. Price increase, cost controls leading to higher margins. This is an important slide here, the reserves slide, and there are a couple touch points here. You can see the growth in the 2P reserves. You can see every category of reserves is actually increasing. The 2P is approximately 228 million at Q1 2026. Just as importantly, the PDP has grown 37% since the beginning of time here in 2024 as well. That is driving increased ability to provide debt funding, and to leverage the existing cash flows. Based on the model of reactivations, what we are doing is effectively converting PDNPs to PDPs through that process. More importantly, we are converting NRAs, which are no reserve-associated wells, that the reserves evaluator has not been able to tie reserves to, into the PDP category, and so those are coming outside of the graph that we are seeing here. Seeing some presentations yesterday where the reserves evaluator actually has a tough time establishing decline curves associated with these wells, because there is not a lot of recent producing history. So we are seeing some fairly steep declines associated with that from the reserves standpoint. What we expect to see on a go-forward basis is that those reserves are re-evaluated, and we are seeing longer tails, and increased life associated with them. When we look at it on an RLI or reserves life basis, effectively the 2P reserves are out about over 30 years, and so we would expect to see that on a go-forward basis as well, as we continue to produce these wells and bring on more reactivations. Tying this back to a little bit of the blue sky and why this is important. The company has effectively 400 million bbl of OOIP with 3%-8% recovery. This is what drives that extended reserve life, and does not require us to continually drill to keep up with that hamster wheel. We are seeing that a lot of these wells are actually increasing year over year as we control that sand, produce more of the sand from the reservoir, and increase the RPMs on the wells. Shubham mentioned that we've got approximately 140 reactivation targets just from existing vertical wells. This doesn't talk about any of the uphole optimizations or perforations or infield drilling or any of the enhanced oil recovery, polymer flood, et cetera, opportunities that exist in the reservoir. I'd like to highlight the Luseland growth here. That's really been the main growth from the asset overall, 350% over the last 20 months. With the target reactivation cadence of about six wells per month on existing cash flow. What's extremely important in this situation is the risk profile that the company has adopted. We're not in the business, as Shubham mentioned, of drilling new wells. We're effectively in the business of replacing pumps and tubing and more day-to-day service rig-related operations. That's allowed us to achieve this really attractive capital intensity of about sub-CAD 10,000 per flowing barrel. We've been able to realize that, and that leads to attractive paybacks, and continued increased production and cash flow. The company is currently in the midst of raising through private placement, non-brokered private placement. We're in the process of raising CAD 12 million of equity. That is expected to drive the growth that we're wanting to see of about five times growth over the next two to three years, with approximately a double up or 100% increase of production by end of Q1 2026. That CAD 12 million, of that, CAD 10 million is expected to go into the ground, and that CAD 10 million is expected to drive PDP reserves from about 37 million to over 60 by end of 2026, and achieves the reactivation of the 41 wells that Shubham has mentioned. You can see the growth profile that's been modeled and seeing a growth profile of increasing revenue from CAD 3 million to CAD 4 million of a quarter in Q1 2026, to the six that we realized in Q2, to somewhere around CAD 20 million to CAD 25 million in the 2028 timeframe. From an investment standpoint, we're targeting returns of about four times. Through that point, the company's stock is currently traded on the TSX Venture Exchange at CAD 0.04 today, and we're looking at increasing that to somewhere north of CAD 0.10 over this period of time. We're looking to increase production to about 3,300 bbl a day as we really start to scale this reactivation strategy. Obviously, that's going to come with considerable reserve growth, about 4.2 x. From 27 at the end of 2025 to 37 million in Q1 2026, moving it upwards north of 100 million. That then provides considerable or attractive returns across the price decks, and so we've done some sensitivity evaluation. All of that was modeled at a $75 price deck. Shubham, I'll hand it over to you for closing. Thank you, Chris. We are very excited to share that this is not just a technical success on the wells that we have gone after. Canada has been under-capitalized for over a decade, especially the heavy oil plays up there, the conventional heavy oil plays. There is a lot more interest now with the commodity price tailwinds, with the TMX pipeline online, really reducing that heavy-to-light differential. And the Canadian dollar being weak results in us getting about a 40% increase because of the 1.4 CAD to USD range. We are really excited to share that it is not just a technical success, it is a financial success. We are now moving forward with some of these wells continuing to rise. They are producing the cash flow to go and do the next reactivations. The company generated exceptional cash flow in Q2 2026, and we are taking that momentum to keep bringing on more wells with our own organic cash flow. But with the success we have had, looking to scale this a lot more aggressively because we are confident in the technicality of these wells. We are confident in the field operations ability to go and bring these wells online. And from my time operating wells, I saw these wells just sitting around for years and years and years, and looking forward to really bring them back, not just at lower rates, but actually show what they can do. So we are very excited to scale this company. Happy to chat with investors that are interested in the equity financing or nerd out over some of the technicals of some of these wells as well. Thank you.