Hey, so welcome everybody to IPC's Second Quarter Results Update Presentation for 2025. I'm William Lundin, the President and CEO, and alongside me today is Christophe Nerguararian, our CFO, as well as Rebecca Gordon, our SVP of Corporate Planning and Investor Relations. I'll start in the usual format with the quarterly highlights and provide an operational update at each of our assets. Christophe will go into greater detail on the financial aspects for the quarter. Following the presentation, we'll take questions, which can be submitted online or through the conference call. It's another solid quarter for the company with average daily production rates of 43,600 bbl of oil equivalent per day. That was in line with guidance, and our full year production guidance is maintained at 43,000 bbl- 45,000 bbl of oil equivalent per day Operating costs for the quarter were slightly below guidance at $17.80. There are slightly cheaper input costs, as well as some activity re-phasing. Full year operating expenditure outlook is maintained between $18 and $19 a barrel. On the capital expenditure front, our full year guidance is maintained at $320 million. Through the first six months of the year, we spent around $199 million. That represents slightly more than 60% of our full year capital program. With about $138 million out of the $199 million spent through the first six months of the year, that was allocated towards the transformational Blackrod Phase I development. We did host a large investor and analyst site visit in the quarter to showcase the world-class asset, which was very well received. A special hats off to our team for facilitating a great tour to some of our key stakeholders during that period in June. On the cash flow front, Brent averaged around $68 a barrel in Q2. Our operating cash flow for the quarter was $55 million, which was in line with expectation. Full year OCF outlook is forecast between $245 million- $260 million, assuming Brent prices of $60 - $75 a barrel for the remainder of the year. Free cash flow for the quarter, after taking into account all capex that was spent, was - $58 million. The full year free cash flow forecast, for a final major growth spend year at Blackrod, is expected to be between - $135 million to - $120 million, between $60 and $75 Brent. That is - $135 million to -$120 million. On the balance sheet front, our net debt position as at the end of Q2 stands at $375 million, with gross cash available to the business of $79 million. We have increased our revolving credit facility in Canada from CAD 180 million -CAD 250 million, which remains undrawn at this period. The company remains well positioned with healthy liquidity availability. We did elect to increase our oil hedging exposure during the second quarter, and that took place during the price spike while the Iran-Israel conflicts were escalating in June. We added 4,000 bpd for the second half of 2025 in the form of zero-cost collars between $65 and $75 a barrel WTI. It really helps protect the downside in this volatile market for the remainder of this year. On the ESG side of things, there were no material incidents recorded during the quarter, and we're pleased to announce the release of our sixth annual sustainability report, which came alongside our Q2 results. On the share repurchase front, we've made great headway with our NCIB program. We are about 85% progressed through that program, and the average repurchase price for the 2024-2025 NCIB program has been around $140 per share. We intend to complete that program before expiry in December. First half production average for 2025, when you take into account all six months of the year, is right in line in the middle of our guidance at 44,000 BOE per day. Q2 production average again was 43,600 bbl of oil equivalent per day. As can be seen on the production plot, it really highlights the low decline nature of our producing assets, and we look forward to seeing the incremental production boost in Q3 from the short cycle investments that were undertaken, mainly at Onion Lake Thermal in Canada and the Bertam field in Malaysia. You can see some of those investments starting to bear its fruits in the beginning of July there on that production plot, from Onion Lake Thermal as annotated. The full year production forecast for 2025 is maintained between 43,000 bbl and 45,000 bbl of oil equivalent per day. Very confident to be able to deliver in another year within production guidance. Our portfolio is a diversified production mix, and it consists of 1/3 natural gas weighting and then 2/3 oil, with about 55% of that oil mix coming from Canada and the balance coming from France and Malaysia. Of course, those two assets have Brent-linked pricing. Moving on to our operating cash flow. For the first six months of the year, the business generated a robust $130 million in operating cash flow, and the Brent to WTI differential during that period was $4 a barrel. The WTI to WCS differential averaged $11 per barre l through the first six months of the year. It is notably the tightest first half differential we have seen since International Petroleum Corporation stepped into Canada, and this is very much a feature of there now being more takeaway capacity than supply in the Western Canadian sedimentary basin, thanks to the TMX pipeline coming on stream. Full year operating cash flow is expected to be between $245 million - $260 million for the year as we've tightened that. We are forecasting differentials between $3 a barrel and $10 a barrel for Brent to WTI and WTI to WCS in the $60 scenario. For the $75 scenario, we are forecasting a differential of $5 a barrel and $15 a barrel, respectively, for that Brent to WTI and WTI to WCS differential. Capital expenditure, inclusive of decommissioning spend, is forecast at $320 million. Our capex profile is expected to gradually decrease throughout the year as we progress into the second half and as we get closer to the Blackrod Phase I completion and the bulk of our non-Blackrod capex investments that have largely taken place to the current point in time now. Again, mainly relating to the investments at Onion Lake Thermal, as well as in Malaysia, which I will expand on in detail in the upcoming slides. Free cash flow year to date for the first half is $43 million, excluding any capex investments at the Blackrod asset. When taking into account all capex, the free cash flow for the first half of the year is -$101 million. Similarly, to the operating cash flow, we've tightened our free cash flow full year outlook for 2025. Where excluding Blackrod capex, we expect to generate between $95 million - $110 million between $60 and $75 Brent. When taking into account the capex at Blackrod, the full year free cash flow outlook is expected to be between - $135 million and - $120 million between $60 and $75 Brent. Share repurchases, International Petroleum Corporation has continued on its anti-dilution path, and the company has achieved a notable milestone in the quarter where we now have fewer shares outstanding compared to that of when the company was formed. Only 76 million shares have been repurchased since the company's inception, and the average price all those shares have been repurchased at is $0.77 per share or CAD 10.00 per share, which is less than half the price of our current share price today. The portfolio has undergone a significant transformation with material increases to production, reserves, resources, and value, as can be seen on the right-hand side of the slide, compared to that of the portfolio International Petroleum Corporation was sitting on when the company was IPO'd in April 2017. Provided we keep trading at a discount relative to our intrinsic value, the balance sheet stays in good shape, and our net debt to EBITDA is less than 1.75 times, we intend to complete the remaining 2024-2025 NCIB program by the time it expires in early December. The combination of turbocharging production growth through the Blackrod investment and canceling out the shares should prove to be a winning formula for our stakeholders. On the net asset value side, we have at year end 2024 a net asset value based on our 2P reserves in excess of $3 billion, representing a fair share price of $287 per share or CAD 37 per share. Again, no value is assigned to our large contingent resource base in this NAV calculation. Based on this NAV, where we're currently trading, it represents approximately a 40% discount to our intrinsic value, which really underpins the strategy for our shareholder returns being buybacks as opposed to dividends. The Phase I development at the Blackrod asset is very much on time and on budget. Great progress has been made on this project since it was sanctioned in February 2023. We've greatly de-risked the overall project. Around $729 million of growth capex has been incurred since the project was sanctioned, or around 86% of the total growth capex to First Oil. As prime contractor of the site, I'm especially proud that there have been no material safety incidents since responsible development activities began. A notable milestone was achieved at the end of Q2, where the final central processing facility module was delivered to site. Now all fabrication for the CPF is completed at this stage. Mechanical, electrical, and instrumentation work scopes at site are the key focus for our project, and the construction and operation teams at site remain diligently working well ahead on those fronts. Well-pad facilities, drilling, and completions, third-party pipeline systems are all progressing according to plan. We are very pleased with the status of the project at this stage, and we feel really confident to deliver within the guidance that has been set out. Overall, on the schedule, I had noted the main scopes that are advancing. It is very exciting to see as we get closer to this asset about to come on stream. As we get closer to the startup of the Blackrod Phase I development, we will initiate a progressive turnover strategy in the coming time to position us well for the overall startup of this asset. Moving on now to our producing assets at Onion Lake Thermal, we had stable production performance for the quarter. You can see on the production plot that we began benefiting from some of the short cycle investment opportunities that were undertaken, whereby there are four infill wells planned this year at Onion Lake Thermal. Two of those started producing at the end of Q2, and the other two infill wells are coming on stream just after Q2. We also have the final two well pairs on L-Pad also ramping up to keep production levels as high as possible at this asset for the remainder of 2025. Moving on to the Suffield area assets, valuable low decline production here, as can be seen on the production plot. There is no major development activity planned for 2025, but there is a large inventory of drill-ready opportunities that sit within the portfolio that could be sanctioned at the discretion of the company. The gas production here is a strategic benefit to have within the portfolio, especially as we look to ramp up Blackrod in due course, which helps as a natural hedge relative to the gas consumption at the other assets in Canada. On the other assets in Canada, seeing good performance through the second quarter. There was some planned maintenance activity that successfully got completed in May. We are seeing a nice response from the polymer flood at our Mooney asset. Again, here there is no major development activity planned at the other assets in Canada. Moving on to Malaysia for the second quarter is another great quarter of operational performance where we had high facility uptime, excluding planned maintenance, which was greater than 99%. We also successfully completed the drilling and workover campaign that just finished after Q2. Encouraging results to start out, whereby we have a new well, A21 on stream, and we also brought A15 online after the workover. We are in a cleanup and stabilization period, but we look forward to coming out with the next quarterly results where you can see the arrow signaling an increase in overall production here thanks to those investments that were undertaken earlier in the year. There is planned maintenance activity also scheduled for late September and also going into Q4, and that is very much on track overall to take place. In France, in low decline production here as well, stable operations through the second quarter of 2025. There is quite a lot of maintenance well workover activity. As you can see in the production plot, we benefited from a slight production boost there, and a robust pipeline of investment opportunities also sit within the France business. That is shown on the graphic on the right of the slide where in the Fantôme et Brune field, there are multiple sidetrack opportunities that we are excited to unleash when appropriate. With that, I will pass it along to Christophe Nerguararian to go through the financial highlights for the second quarter. Yeah, thank you very much, Will. Good morning, everyone. A good production, just 2% below the one for the first quarter. We were producing on average 43,600 bbl of oil equivalent per day during this quarter and just at 44,000 bbl, right in the middle of the guidance for the first six months of this year. We're very happy to reiterate the guidance in terms of our production forecast for the whole year. Actually, we reiterate the guidance on all matters. We keep the 43,000 bbl- 45,000 bbl of oil equivalent per day production guidance for the year, as well as the OpEx guidance and the CapEx guidance. Oil prices were slightly lower, $7 - $8 lower than during the first quarter, and with a mildly lower production. The operating cash flow was as well lower in the second quarter, but still strong at $55 million, $130 million for the first six months of the year. Interestingly, we were still before the Blackrod Phase I CapEx. We posted a positive free cash flow for the quarter. The base business is running smoothly and very well. As you can see here on this first slide, reasonably high CapEx, still lots of investments, mostly on Blackrod Phase I projects. We spent actually $100 million during the first quarter this year, another $100 million during the second quarter. We almost spent 2/3 of our CapEx guidance for the year at $320 million by the end of this year. We signaled before that this year the CapEx program would be front-loaded during the year, and that's exactly what's happening with almost a third in the first and the second quarter. With a net debt of $375 million, the leverage of the company is now at around 1.4 times, which is still very reasonable when you think that on aggregate, we've already spent 85% or $730 million of CapEx cumulatively on the project. As I mentioned, the realized prices in this second quarter were a bit lower, with Brent and WTI almost $8 per barrel lower. The interesting point is that the WTI to WCS, the differential there was very, very good, very tight at - $10. It's reassuring to see all the positive benefits finally of having the expansion of the Trans Mountain pipeline on stream. There's ample egress capacity now from the western side of Canada with oil flowing freely to the U.S. without any tariffs. It's very supportive of our ongoing investment at Blackrod to see that the differential remains very tight at -$ 10. The Brent on average was at $68 this quarter. It doesn't look like it, but we continue to receive very strong premium in Malaysia. We only had one lifting this quarter. In France, we're selling again on par with Brent. The WTI was at $64, WCS $10 lower at $54 per barrel, and we're selling oil from Suffield and Onion Lake essentially on par with WCS. Gas prices, as you know, in Canada, there is a reasonably strong seasonality with gas prices, and gas prices are traditionally lower in the summertime. No difference this year with reasonably low oil price or gas prices. The good thing is that the LNG Canada project started with the first LNG trains on stream, and we believe that this should help the market by rebalancing the egress with the production. We hope to see improved gas prices towards the end of the year when the storage level starts to improve. Looking at the cumulative operating cash flow and EBITDA of $130 million and $123 million for the first six months, you can see that despite slightly lower production this year compared to the first six months last year and much lower oil prices, the base business continues to deliver very strong cash flows to fund our investment and our share buyback. Operating costs, as I mentioned, the guidance is maintained at between $18 - $19 per BOE for operating costs. The second quarter was a bit lower than anticipated, driven by lower electricity prices. You can see that we anticipate slightly higher operating costs per barrel. There is some upside for the third and the fourth quarter, but we're expecting higher OpEx per barrel for the rest of the year, including with some maintenance costs in Q3 and Q4 in Malaysia, where we have to shut in production for a few days and spend some normal maintenance OpEx there. In terms of netback, you can see that for the first six months of the year with $42 per BOE of revenues, that translated into a cash margin of $16 per BOE and $16 per BOE as well for the operating cash flow for the first six months of the year. EBITDA just above $15 with G&A maintained at $1 per BOE. The costs remain under control while the production is reasonably flat. When you look at the net debt from the beginning of this year to the end of the second quarter, you can see that our operating cash flow of $130 million almost fully funds the Blackrod Phase I investment of $138 million. If you exclude that, our operating cash flow actually fully covers and a bit more all the rest of our costs, including the CapEx for the rest of the business, all G&A, all net financial items, and the share buyback. We added around $167 million of net debt during the first six months of this year, and we had $375 million of net debt at the end of the quarter, with a leverage of 1.4. The net financial items and the G&A on this slide, you can see that it's a bit misleading. It's not misleading. It's obviously correct, but we had a non-cash gain in terms of the FX movement, which offsets some real cash financial costs. The total net financial items are essentially zero this quarter, but we're continuing, obviously, to pay our coupon under the bonds. The rest of our finance costs, which are very stable quarter to quarter, just look small this quarter with this non-cash gain on the FX front. G&A, as I mentioned, remained under control at below $4 million or $1 per BOE for the quarter. Financial results for the first six months were $338 million of revenues and $207 million of production costs. We had a cash margin of $130 million, gross profit of $68 million, and net result of $30 million for the first six months. The balance sheet remains strong, and the common theme is that we are using more and more of our cash to invest in the business and Blackrod in particular. You can see the cash position going down while we're increasing the value of our oil and gas assets on the balance sheet exactly as you would expect. The capital structure of the business has not really evolved. We still have, obviously, our $450 million worth of bonds, which are maturing in February 2027. We are following very closely with our banks and brokers the state of the debt capital market. We remain very opportunistic, and if the right window opens, we'll contemplate refinancing, extending the maturity or the best solution for the business in the next few months. There's no rush, but of course, we remain very focused on the state of the market. We were able and willing, and we welcome another bank in our bank syndicate in Canada. While our revolving credit facility was fully available and drawn at the end of the second quarter, we increased that RCF in Canada from $180 million to CAD 250 million, or roughly $180 million, which is fully available, and we extended the maturity until May 2027. We have a lot of credit facility, which of $40 million, which is going to go down once the Blackrod pipeline are fully up and running, which is expected during this year. Still a very small French unsecured loan, which will be fully repaid by the end of May 2026. A solid balance sheet and lots of liquidity with a fully available and drawn Canadian revolving credit facility. In terms of hedging, while there were some very high geopolitical tensions between Israel and Iran during the second quarter, we used that opportunity to add a bit of downside protection on our WTI-linked production. We added 4,000 a day of zero-cost collars between $65 and $75 a barrel for the second half of this year. Otherwise, we remain reasonably well protected as well for the Brent, with around 40% of our exposure hedged for the second quarter this year. The WTI swaps and the Brent swaps are unfortunately in the money, as well as our gas swaps for the moment and potentially for the second half of this year based on the current forward curve. You can see here the FX protection, which we entered into earlier on, no change there. We were pretty happy with the hedges we did on the FX fronts on the Canadian dollar to protect our investment in Blackrod. Thank you very much, and I will let Will conclude. Thanks, Christophe. In summary, for the six months highlights for the business, we've invested $199 million in capital expenditure. $138 million of that has gone to the Phase I development. On the production front, 43,600 bbl of oil equivalent per day for the second quarter. Full year production guidance is maintained at 43,000 bbl-4 5,000 bbl of oil equivalent per day. Operating costs, $17.80 for Q2. We maintain our full year outlook of OpEx per BOE between $18 and $19. Strong cash flow in Q2 of $55 million through operating cash flow. Free cash flow for the quarter was - $58 million in free cash flow. The balance sheet, again, to reiterate, a net debt position of $375 million and gross cash resources available just below $80 million as at the end of June 2025. No material safety incidents or environmental incidents through the quarter or throughout the year. The sustainability report we issued, we encourage our audience to read that prescriptive write-up in terms of some of the initiatives and performance highlights on the sustainability front that the company has undertaken. Share repurchases, we are 85% of the way there progressed through this NCIB program, well positioned to complete that, and the intention is to do so. With that, happy to turn it over to the operator to take questions. Thank you. Thank you. Ladies and gentlemen, if you would like to ask a question or make a contribution on today's call, please press star one now on your telephone keypad. To withdraw your question, it's star two. First question comes from the line of Teodor Sveen-Nilsen calling from Sparebank 1 Markets AS. Please go ahead. Good morning, Will, and good morning, Christophe. Thanks for taking my questions. A few questions there. First on hedging, you obviously have been pretty successful on your hedging on timing there. I just wanted to know how you think around putting on new hedges right now. Second question, that is on production guidance. As you said, here today, production is just in the middle of your current production guidance. We know that Malaysian production will most likely increase in the second half, and probably there will be less maintenance going forward, and we have the second quarter or so. In my view, production guidance seems a little bit low. Please comment on that. The last question for me, that is on tariffs and Canada. We discussed this during the site visit in June, of course. As far as I Blackrod Phase I development is not very impacted by the tariffs. Could you just share your thoughts around what we now know after the latest changes on U.S. tariffs and if there will be any impact, and if yes, how? Thanks, Teodor. I appreciate the comment around the hedging. We've been pretty pleased with our hedging position, which, as you know, is very much an opportunistic one that's set out. When we look towards new hedges, we view that flat price is pretty low. The curve has flattened off quite a bit, but we're happy to reel off that zero-cost collar at that price spike in June. With all the hedges that we have in place for 2025, I think we feel confident and comfortable with what's set out right now. No firm plans in place to add on for the hedges for the rest of 2025. Again, we're opportunistic at our core, and if there's an attractive item to hedge, we will look into that. No firm plans to add at this stage. On the production guidance, where we're at right now at 44,000 bbl of oil equivalent per day for the first half of the year and full year guidance of 43,000 bbl- 45,000 bbl of oil equivalent per day. You are right. We do have some incremental production coming in from Onion Lake Thermal as well as from the Bertam field. That is largely going to offset some of our natural decline at our entire business. To take the position that it's a bit low or to up the production guidance would put us in a difficult place to try and meet that. That's why we've set out our production guidance and maintained that overall, and we feel well positioned to deliver within it for the full year. The tariff situation, I must confess, it's difficult to keep track with Trump and all of the tariffs that are being laid out in front of us across everywhere. Of course, we have a key focus in Canada, but the key element there is that there is no impact to tariffs being applied to crude imports into the U.S. from Canada. Earlier in the year, that did come out, but it got reversed quickly because the vast majority of those refineries in the U.S. are geared to take that Canadian crude, and there's not a lot of alternatives, especially on the inland refineries. We don't anticipate Canadian crude to get tariffed based on those circumstances. Thank you. Yeah, definitely a real no point on tariffs. Difficult to keep track. That's all for me. Thank you. Thanks, Theodore. Ladies and gentlemen, we currently have no question coming through. As a final reminder, if you would like to ask a question, please press star one. The next question comes from the line of Mark Wilson calling from Jefferies. Please go ahead. Thank you, James. It's all very clear as usual. I just wanted to check on one detail, and that was the way Bertam, and it's a smaller part of the portfolio, but the way that evolves in Q3 and Q4 because of the new wells versus maintenance. If you could just give us a bit more clarity on the details of how that plays out for the rest of the year. It may also tie into this production guidance question, yes. Thank you. Yeah, exactly. We completed, as I had mentioned, the drilling and workover program in Malaysia, which was successfully executed. It's early days right now to draw any conclusions in terms of what to expect for the second half production rates coming from those two wells specifically. We did just rig release the Naga 6 rig two days ago. When we did that, we started up the wells, and then the rig was released. We had to turn the wells down in the field. Once the rig was released, we turned the field back on. There's been some up and down activity, but we feel confident with the initial indications in terms of what we're seeing and where we guided our overall expectation for Malaysia production for the second half of the year. Within the Malaysian asset, of course, we own the FPSO there, and there's a wellhead platform. When we had a jack-up rig connected to the asset, we weren't able to in parallel complete our planned maintenance activity at the same time. That's why it's scheduled in late Q3 going into Q4 there. We'll look to get to this production benefit from the incremental investments coming into Q3 there. At the end of Q3, you'll see the production going down slightly for around a two-week planned shutdown where production will be turned down during that period of time. Okay, thank you very much. Do you want to go back to? Thank you. Are you finished, Mark? You were cutting out. I decided I wasn't actually being heard. I was going to actually ask, now you're back at the share dilution, and you've committed to finishing the share buyback, provided leverage below 1.75, which looks like it will. Obviously, funders have discount to net asset value, with the cash flows coming on from Blackrod in the future. What would be the longer-term vision of what that share buyback evolution would run to in the next few years with Blackrod coming on? Thank you. Thanks, Mark. I think it is a notable achievement that the company's been able to grow its production in terms of its ambitions through our Blackrod investment. When we look at the time when we sanctioned the Blackrod project, which was in the beginning of 2023, if we compare the shares outstanding at the beginning of 2023 relative to our current shares outstanding right now, that represents approximately a 17.5% reduction in the overall share count. There's been significant anti-dilution through reducing our share count in the share buyback programs. We do intend to complete that program under those conditions that you had mentioned there, Mark. When we look towards the big cash flows coming in from Blackrod, we're going to remain opportunistic. I think our core principle where we're trading at a material discount relative to our net asset value, the shareholder distributions are likely to remain in the form of buybacks because we feel that that is the best way to create value for all our stakeholders. If we start punching above our weight in terms of trading at a premium relative to our intrinsic value, at that point in time, we'd be more interested in a dividend type of format. It would really depend on where we're trading at as a company, which will dictate the form of shareholder returns going forward. I think overall, we're in a great position as a company, and we have a lot of flexibility, and everything that we're going to do is going to be from a lens to maximize value for our stakeholders. Very good. Thank you. Well done with the results. Over. Thank you, sir. Ladies and gentlemen, there are no further questions. I will hand you back to your host to conclude today's conference. Thank you. Thanks, operator. We've got a few questions here from the internet. Maybe I can start with this one, Will, from Oliver Dunvale. As Blackrod Phase I progresses, what synergies from the initial development can be leveraged in subsequent phases? Thanks for that. I mean, with Blackrod being a massive resource base where we have greater than a billion barrels of contingent resources, we very much believe in future phase expansions. There will no doubt be a lot of key learnings and takeaways from this major Blackrod Phase I development that we are in the midst of right now. We haven't laid out our detailed phase II expansion plan at this point in time. It's still being worked internally. However, when we were to think about synergies that could be realized, you know there's going to be transport cost synergies to be realized through our pipeline tools that exist in place. A commercial road has been developed, which wouldn't need to be done again, provided we use the same third-party contractors. There could be synergy realizations on the overall engineering design on multiple components of the facility if we were to use a similar facility that we have designed for Phase I. I think there would be a range of synergies that would be realized, but you would also likely be doing a brand new facility development. I don't think we're talking about synergies in excess of 25% of capex savings type of thing, maybe ± 10%, but it's early days at this point in time to be granular with the specific savings to be realized. Okay, thanks, Will. Christophe, maybe you can tackle this one. What are your thoughts on bond refinancing and the possibility to increase the ticket on the next bond program? Yes, no, the bond market was in a relatively good shape before the summer. It's kind of off right now because most people are on holidays, but we're in constant dialogue with our banks and brokers, as I mentioned. Our intention is to be able, in a very, very short order, to jump on any market opportunity. As I said, we have until February 2027 to refinance, but we obviously don't want to wait until the very last minute either. In terms of the ticket, I'm not sure you're talking about coupon size of the overall bond issuance. Size, yeah. We don't want to increase the coupon, but certainly, there's a possibility where a refinancing could encompass a $500 million number instead of $450 million, but that would only be a marginal increase to where we are today. Great, thanks. A question from Daniel Stenslett from Arctic. Just a question on the production profile for Blackrod. How do we expect that to evolve through time from first oil to plateau, Will? Yeah, the guidance hasn't changed in terms of the production expectations Phase I development relative to when we sanctioned the project in early 2023, where we're expecting oil in late 2026, first oil, and then production to be ramped up at plateau production rates of 30,000 bpd come early 2028. That's the current conditions and expectation for the production profile at Blackrod. In any scenario where if things improve, whether it be schedule or ramp up-wise, we hope that there's a little bit of upside beyond that. However, we've put in the best technical estimate case at this point in time. Great. Christophe, another one for you. Is there a plan to deleverage, or are you happy with a net debt to EBITDA of 1.4? Is that reasonable going forward? I think given where we are, 1.4 is actually very reasonable because, again, we're in the midst of the heavy investment program on Blackrod. I think we mentioned in the past that we like a leverage of one time or less, and that is certainly where we will be heading towards once Blackrod is ramped up. In the short term, you should expect the leverage to increase a bit more before it reduces again. Very good. Will, perhaps we'll take this as the last question on time. Is M&A an alternative, or is there too much internal opportunity for growth? Again, we're opportunistic at our core. The three key strategic pillars for the company are organic growth, M&A, and stakeholder returns. We look to create value for our stakeholders through all three of those avenues. We're constantly reviewing different opportunities in the M&A front, and there's a rubric that sits behind that. Being opportunistic at the right size and shape of an asset, the opportunity that comes available, we're not shy to looking into that. I think, upon Blackrod Phase I coming on stream, production ramping up, and free cash flow generation increasing materially, I think that will put us in an even stronger place to be able to do material acquisitions following that period of time, but really opportunistic at our core. Okay, thanks very much, Will. That's all we've got time for today. Do you want to close it out, Will? Great, thanks very much. Pleased with the second quarter results and especially exciting as we're getting closer Blackrod Phase I development coming on stream. Some key work scopes to be undertaken, especially in this month of August here with a lot of man hours to take place and electrical and instrumentation works. However, we feel really well positioned on this project overall. We'll look forward to informing the market in the next opportunity there. Otherwise, thanks for tuning in. Thanks, everyone. Thank you.