They include forward-looking statements within the meaning of the Private Securities Litigation Reform Act. These forward-looking statements are subject to risks and uncertainties that could cause actual results to be materially different from the expectations contemplated by our forward-looking statements. Those risks include, among others, matters that have been described in our earnings release, as well as in our filings with the SEC, including our annual report on Form 10-K and our quarterly reports on Form 10-Q. We disclaim any obligation to update these forward-looking statements. During today's call, we may discuss certain non-GAAP financial measures, including adjusted EBITDA, adjusted net income, and free cash flow. Reconciliations of these measures to the closest GAAP measures can be found in our earnings release. With that, I'll turn the call over to Nick. Thank you, Evelyn. Welcome and good morning, everyone, and thank you for your interest in our company. As usual, I'll cover the highlights of the quarter with six key points. Number one, fruits of our labor. We've asked a lot from our investors over the past year as we went through a heavy investment cycle. The third quarter highlights the fruits of that labor: three straight quarters of declining CapEx, fewer wells turned on, and yet we've delivered growing oil volumes, and activity is still spooling with a growing D&C list. Even in a quarter of weaker oil and gas prices, we generated record free cash flow, near-record adjusted EBITDA, and drove volume growth in our two biggest contributing basins, the Permian and the Williston. As we noted last year, free cash flow would come with patience, and we're delivering on that promise. Any upfront investment and pull forward of activity has shown its benefits, as has strong well performance. The temptation for investors to focus on our capital spending in 92-day increments and draw conclusions was understandable, but often belies the longer-term benefits of those investments. This quarter's results clearly reflect that, as our capital efficiency shines through and proves the points we made then. Number two, balance sheet power. This is in reference to the all-cash nature of our recent acquisitions, which had many investors questioning if we would issue equity or even some suggesting we were going to be challenged moving forward from a balance sheet perspective versus the clear power of our business's cash generation. We closed Point at the very end of the third quarter and, as a result, received little to no benefit from a cash flow perspective, and yet our net leverage ratio and net debt levels were almost unchanged quarter over quarter. While the larger XCL transaction that closed at the beginning of Q4 will have a modest impact on our borrowings in the near term, we maintain a number of different options and could quickly turn out the debt at any point in time. As we close on both properties and add them to our cash flow streams, we expect to steadily and organically delever over the next year or so and stay well within our stated leverage targets, even as prices have moderated. Number three, growth. Many of you will likely ask about our 2025 plans, and I will say now that we're busy running multiple scenarios, and our planning group is hard at work. Much of the outcome, as always, is return-driven first, so we will evaluate our spending path based on the commodity environment we're in. The counteracting force is that our ground game opportunities tend to increase in weaker pricing periods, so as we plan, we will have to make room for both outcomes. Suffice it to say, while we aren't there yet, we will prepare low-price, high-price, and steady price scenarios for the board's review as we exit the year. Each scenario will likely have differing balances of organic and ground game capital, which will help us determine the appropriate level of capital to budget for the coming year. It's important to distinguish the difference between our overall spending target, which Chad will talk about, and the number of wells we may plan to put to sales, which will be driven by returns. The TIL count will ultimately drive our production guidance, but the total spending will drive our D&C list and our ground game and thus our longer-term growth profile, and those are the decisions we are hard at work on today. We remain busy evaluating opportunities of every kind, from large-scale acquisitions to drilling partnerships to buy-down structures and co-purchases. We see many avenues of growth and remain focused on prospects to take NOG to the next level. But as always, the bar is high, and any of the assets we're evaluating must continue to make for a better and stronger pro forma company. We have had great success of late, as Adam will discuss, with on-the-ground leasing, a slight pivot from the more development-heavy ground game in the past. We always try to skate to where the puck is going. As I mentioned on prior calls, we have historically found that our competitiveness in our ground game is often inversely correlated to the strength in oil or natural gas prices. So importantly, we do believe many opportunities may arise in the event that commodity markets continue to weaken. And importantly, we've also taken notice that duration of capital is important, and our ability, given our long inventory runway and strong balance sheet, to house longer-duration, potentially better longer-term ROI assets has increasingly become a bigger advantage versus those who need instant gratification with shorter-duration capital or companies with short-term development needs. More on that later. Number four, costs. We entered 2024 with a plan to heavily invest in our people and systems at NOG to help support the incredible growth we've accomplished over the past several years and also to prepare NOG for the next stage of growth. We wanted to ensure we could harness every advantage afforded to us from our data and our asset base as we continue to build our business over time. You will note, however, that even as we add employees, our adjusted cash G&A cost per barrel should continue to drop over time. This is a testament to the conscious and purposeful effort we have embraced in striving for continuous improvement, or Kaizen. As we have added talented individuals to the NOG team, we are also reducing our outside services costs meaningfully. It's one of our top priorities in terms of internal focuses, and we believe it will be under an almost evergreen cycle of improvement over the life of the company. You will also notice our well costs were down considerably quarter over quarter. Some of this is happenstance, and on a per-lateral-foot basis, it is less dramatic, but we did see a notable reduction in Williston normalized costs. Furthermore, with commodity prices under pressure, it suggests that pressure pumpers can only stack their equipment and hold price for so long before they need continuity of service. While investors will focus almost entirely on the price of commodities in the short term, there are savings to be found in development costs, and we believe there is potential in 2025 to recapture margin if current trends continue. The weak commodity price environment may also impact other items besides development costs, like lifting costs, should the current outlook weaken further. Number five, shareholder returns. As we execute on our acquisition strategy, we have always said that we would be mindful of the balance sheet without excluding the potential for capitalizing on opportunities to retire shares when market conditions allow. We found those opportunities in the third quarter with a repurchase of just under 400,000 shares. In fact, we're proud to have delivered over $230 million of returns comprised of share repurchases and dividends to our shareholders year to date. It's also worth noting that through the first nine months of the year, we returned approximately 50% of our free cash flows to our investors. As we previously disclosed, while we bumped the dividend early this quarter, the board will still meet in early 2025 to determine the annual dividend policy. Dividend growth is particularly important to our company, as it is a testament to the fundamental underlying mission of growing per-share profits and then giving our investors a growing portion of those profits over time. Number six, outlook. We've now closed on both XCL and Point, and I want to thank both the SM and Vital teams for trusting us as their partners. While it may seem like these joint ventures can happen easily and often, there are plenty of challenges in successfully orchestrating a co-purchase. It has taken the right partners, some luck, and a ton of hard work to get these transactions completed. With these assets in-house, we see the potential for significant development in the near and long term. More importantly, in keeping with our strategy, these JVs are built to weather the storm should we see any wobbles in the price environment. It goes without saying that oil prices have been volatile. While many companies swore off hedging during the run-up in 2022, we have maintained our hedging discipline. If oil prices do continue to weaken this year, we are confident that our balance sheet and debt ratios will remain protected as compared to others that may have sworn off hedging and exposed their balance sheet to potential weakness. We hedge to protect the capital we deploy on both drilling and acquisitions. In doing so, we ensure solid returns on capital for our investors and the ability to countercyclically invest if commodity prices get dicey. We head into the fourth quarter well-prepared for any environment. We're very well-insulated with a ramping D&C list and with the best asset base in our company's history, highly diversified, covering nearly 100 operators in six distinct operating areas. That concludes my prepared remarks, so I'll close out, as I always do, by thanking the energy engineering, land, BD, finance, and planning teams, and everyone else on board, our investors and covering analysts for listening, and our operators and partners for all the hard work they do in the field. As always, our team is focused on delivering optimal total return and growing our per-share profits for the long term. That's because we're a company run by investors for investors. And with that, I'll turn it over to Adam. Thank you, Nick. I will begin with our operational highlights and then turn to our business development efforts in the current M&A landscape. During the third quarter, production remained resilient at over 121,000 BOE per day, despite a nearly 70% sequential reduction in TILs from Q2 as certain operators deferred completions. The wells that were added in late Q2, along with the completions in the third quarter, showed better-than-expected results. Reversing the trend in Permian-weighted completions, the Williston accounted for more than two-thirds of the activity during Q3 and is a testament to NOG's core Williston position. While the TIL count was relatively subdued in the quarter compared to our Q2 highs for the year, drilling activity levels have ramped, setting the table for a robust fourth quarter and moving into the new year. We added over 20 net wells to the D&C list during the third quarter as accelerated activity pulled forward almost 10 net wells relative to internal forecasts. We have also seen our average working interest in the Permian increase from 10% in Q2 to 17% at the end of the quarter, driven by an acceleration of development with our JV partners. Activity on our organic acreage also remains elevated as we reviewed almost 200 well proposals during the third quarter. Consent rates on well proposals held above 90%, both on a gross and net basis, as economics remain strong. Notably, we have seen forecasted well costs show moderate signs of deflation as absolute and normalized costs in the Permian declined for the third quarter and the Williston declined to the lowest cost per lateral foot on the year. In addition, discussions with our operating partners indicate encouraging trends in operational efficiencies and improvements in spud-to-sales timelines. These trends could position us to potentially deliver wells at cost below our AFE expectations and provide incremental capital efficiencies. Looking ahead, we expect a ramp in activity to finish the year as we clear through the DUC backlog, setting up for a strong start to 2025. While we're not providing official guidance at this point, we expect 2025 TILs to see a 40/60 weighting relative to the front and back half of the year. Drilling activity will be commodity price dependent. However, we see a measured cadence of activity throughout the year, taking into account the seasonal pauses that we see in the Williston during the winter months. As such, we expect to see the D&C list build through the first half and then draw down a bit in the second half of the year. We expect the 2025 capital program to be allocated roughly 60% to the Permian, 30% to the Williston, 9% to the Uinta, and 1% to the Appalachian. We are encouraged by the Uinta Basin's early performance, as evidenced by the impressive test rates from our Douglas Creek wells in the Upper Cube, along with additional efficiencies as SM takes over operatorship. Our concentrated acreage position will enable us to extend laterals while the startup of our sand mine will save hundreds of thousands per well. Couple this with the project's capital efficiencies via completion design, and all of this underscores our strategy of partnering with high-quality operators on high-quality assets. Despite changes to near-term completions through the transition period, corporate-wide production for the year should not be impacted given our diversified asset base. Moving to our M&A efforts, the third quarter showcased our ability to replace inventory through our ground game as well as continue to consolidate top-tier assets through larger M&A. During the quarter, we aggregated an additional 1,250 net acres through our ground game, bringing us to over 4,700 net acres and 6.8 net wells on the year. To date, the focus has generally been in the Permian, but we have also been able to find meaningful opportunities in Appalachia as well as the Williston. Now, the Uinta will add one more avenue for us to bolt on additional interest through our ground game as more opportunities flow in. As we have diversified across multiple basins, we're getting significantly more shots on goal, and that has improved our ability to deploy capital to only the areas, assets, and operators that meet our strict hurdle rates for capital allocation. As certain asset classes or basins see waves of competition, we can pivot to other opportunities to replace inventory and maintain our elevated return on capital metrics. Additionally, with the various AMIs that we have in place, we are also leveraging our operators' business development efforts to pick up additional acreage and wellbore interests. Looking at the fourth quarter, and with commodity prices pulling back, we will remain opportunistic. With budgetary constraints from both our operators and our competition, we typically see more actionable opportunities in the fourth quarter than any other during the year and will focus on a countercyclical approach. As I alluded to earlier, the third quarter was very busy closing both the Point and XCL transactions. With both deals now behind us, we're continuing to canvas other high-quality M&A opportunities that will enable us to build not only a bigger NOG, but also a better one. The focus remains on low-break-even, resilient assets that will generate returns even in a marginal commodity price environment. The execution of our actively managed business model, our scale, balance sheet, and the ability to creatively structure acquisitions has afforded us more opportunities than most. We remain active evaluating more than $6 billion in assets across all our respective basins. Structures ranging from joint development agreements, co-purchases, minority interest buy-downs, and the typical non-op package are all in play. Many of the active processes are in the broader market, but as we have conversations with our operators and discuss options at a structural level, we are unearthing more and more off-market opportunities specific to NOG that would not otherwise be a fit for our competition. Post-consolidation divestitures from larger operators are starting to percolate as well, albeit with a mix in quality, and we expect that theme to continue into 2025 as operators review their various options and debt reduction targets. Regardless of how we source our opportunity set, we remain steadfast in our returns-first approach to allocating capital, focused on our balance sheet to withstand any commodity price environment, and staying disciplined to do right by all our stakeholders. With that, I'll turn it over to Chad. Thanks, Adam. Our third quarter results reflected the resilience of our asset portfolio. Average daily production in the quarter was 121,800 BOE per day, down 1% compared to Q2, but up 19% compared to Q3 of 2023. Oil production increased to 70,900 barrels per day, up 2% from Q2, and setting a new NOG record for oil production. Our Mascot Project JV contributed meaningfully as the wells that came online at the end of June fully contributed to production in the quarter. More importantly, our base asset continues to outperform our expectations. Adjusted EBITDA in the quarter was $412 million, slightly lower sequentially given lower commodity prices. Free cash flow of $177 million in the quarter was 32% higher sequentially and up 39% from the same period last year as we benefited from higher TIL count in Q2, coupled with strong well performance in Q3. We anticipate free cash flow to stay strong given the expectation of over 25 net wells forecasted for Q4, as well as the impact of having both Point and XCL contribute to production for a full quarter. Oil differentials came in at $3.45 per barrel for the quarter, better than our expectations as more of our production is weighted toward the Permian, which typically has better pricing than the Williston. Permian differentials were modestly lower on a sequential quarterly basis, with Williston differentials flat. Natural gas realizations were 72% of benchmark prices for the quarter, materially lower, but expected due to weaker in-basin pricing as a result of lower NGL price realizations, coupled with weaker natural gas prices and negative Waha gas for most of the quarter. With nine months of history to point to, we are adjusting our full-year natural gas realization guidance higher to a range of 90%-95%, reflecting current full-year expectations. LOE was 6% higher sequentially to $9.54 per BOE, reflecting elevated saltwater disposal costs associated with newer wells and higher workover costs in the quarter related to the Permian. We do expect LOE to decline in the fourth quarter as XCL comes into play. Production taxes were abnormally low in the third quarter at 3% due to an immaterial out-of-period adjustment related to the classification of state income tax withholding in New Mexico that was previously recorded as production taxes. Excluding the impact of this adjustment, production taxes for the third quarter would have been 9.1%. Given the recalibration of New Mexico production taxes along with the addition of the Uinta into the production mix, we revised our production tax guidance to a range of 8.5%-9% to reflect our expected fourth quarter rate. On the CapEx front, we invested $198 million inclusive of ground game in the quarter. Of the $198 million, 56% was allocated to Permian, 41% to the Williston, and 3% to Appalachia. We continue to see capital efficiencies with improved spud-to-sales timing, even in the light of the lower commodity pricing. If this trend continues, we may end up at the higher end of our 2025 CapEx guidance range. As we anticipated earlier in the year, working capital has continued to improve. We were able to hold leverage flat quarter over quarter at 1.16 times inclusive of the Point acquisition and reduce borrowings on our revolving credit facility by approximately $105 million during the quarter before drawing down to pay for the Point acquisition. As of September 30th, we had over $1.3 billion of liquidity comprised of $60 million of cash on hand, including the acquisition deposit for XCL and $1.2 billion available on our revolving credit facility. We anticipate that our net debt to LQA EBITDA ratio will trend toward the higher end of our stated one to one and a half times range, reflecting the addition of XCL to the revolver. However, given the strength of our base asset and the strong cash flow profiles of both Point and XCL, we expect to be back at the lower end of our leverage range by the end of 2025 based on the current strip. In our Q3 operations update released a couple of weeks ago, we reiterated our 2024 CapEx and production guidance. And in our earnings released last night, we had a few tweaks to line item guidance to reflect our expectations for the remainder of the year. While we are not providing detailed 2025 guidance at this time, I will say that at this point in our budgeting cycle, we do not anticipate coming out with a budget over $1.1 billion at the high end for CapEx. This concludes our prepared remarks. I'd like to open the call to questions. Thank you. As a reminder, if you would like to ask a question, it is star one on your telephone keypad. We ask that you please limit yourself to one question and one follow-up, then rejoin the queue if needed. Thank you. Your first question comes from the line of Neal Dingmann with Truist Securities. Your line is open. Good morning, everyone, and nice quarter. Nick, I was going to ask for a detailed 2025 guide, but I'll refrain for now. My first question is really on what I'd call your operational and financial protection, something I heard you speak about in the prepared remarks. And obviously, with the election, there's a lot of potential for volatility now, both maybe lower near-term and ramping potentially after that. And I'm just wondering, Nick, if this happens, could you talk a little bit about how you could pivot both organically in the ground game? And I guess what I'm wondering is, would that shift in your organic activity just come from largely your operators reducing capital, or is there more to this? Thank you. Yeah, I mean, I think based on experience, I mean, this is the best part of our business model, Neil, which is that really we're not burdened by existing infrastructure, right? It's just money. So what we've observed during periods of volatility in the past is that we tend to be a little bit faster than the operators. So using 2020 as an example, we had a big downward move in price, and we reacted very swiftly. But then ultimately created a lot of opportunities, and about two-thirds of our capital really shifted to the ground game during 2020. And then organic activity started to build as 2020 came to a close and oil prices returned. But that ground game capital obviously became highly productive as it actually converted to sales in 2021 and created a huge windfall for us. And so that's kind of how you can convert those dollars into countercyclical success. I'd say that overall, I think we'll remain flexible, and I think that that's why really in terms of where we are in the cycle right now, it's why we've continued to hedge and why we tend to be very protective. But the flexibility that our model really provides is very different from most operators, and that's one of the best parts about what we do. That includes your ground game as well, as far as the flexibility you would have around it? That's right. That's right. Yeah. And even as it pertains to the ground game, ultimately, you're going to see if prices really unwind, you're going to see deferral of activity. And so that plays into the part of what types of ground game activity you're going to participate in, whether it be longer-dated type stuff, right? So whether it be long-dated acreage acquisitions or development that's going to be timed towards a farther period out. Yeah. Neal, this is Adam. I think the other thing I'd add is that the strip is naturally going to lead you to various operators as well as basins, right? You're going to be looking at what those break-evens are. We're running sensitivities on a real-time basis, understanding what the impact is to the total full-cycle return as we're deploying that capital. Depending on how big the asset is, then the hedging conversation would also come into play. But those are the types of things that we're looking at day in and day out as we're canvassing these types of opportunities and allocating capital. Great point, Adam, and then just secondly, maybe for Chad, just wondering, second is on sort of broad capital return questions specifically. Nick, I think I've asked you or Chad about this before. Has anything changed these days versus, I don't know, a year or so ago when before all these deals, how you all think about allocating a dollar to your organic activity or reinvestment versus ground game versus debt repayment versus dividend versus stock repurchases? I'll answer the first part, Chad. Feel free to fill in. I don't think so, Neal. I mean, I think everything we are truly mechanical and return-driven. I think we really think about this in terms of optimal total return, Neal, and so in general, dollars in the ground have higher risk, but always, almost always have a higher return, and so obviously, organic dollars go the farthest, followed probably by ground game and then ultimately acquisitions. Share repurchases are obviously generate also additional returns at a lower risk, and then dividends obviously provide a different type of return for our investors. This year, obviously, we pivoted some of our shareholder returns to buybacks. Then as we go in to meet with the board at the end of the year, I think one of the things we have to think about is as you deliver that return, while buybacks can provide a permanent type of efficiency, dividends provide a different type of value to investors. We'll have to weigh those decisions as we go and analyze that to the board of what type of long-term value that creates because they are different. We've weighed them differently at points in time, and that's really a board-level decision, but we'll take it in stride. Yeah. Neal, the only thing I'd follow on with Nick's comments is just given that we've flexed the balance sheet a little bit here with both these acquisitions. So I think in the near term, we'll be mindful of probably debt reduction over some of the other things. But like Nick mentioned, everything's on the table. We evaluate it all as one, so. Thank you. As a reminder, we ask that you limit yourself to one question and one follow-up. Your next question comes from Scott Hanold with RBC. Your line is open. Yeah, thanks. I appreciate the fact that you all are going to wait till early next year to provide some more details on the budget. But Nick, you kind of made the point regarding you need to take several quarters to evaluate capital spending and production trends given the business model and the way things are accrued. As you see things building into fourth quarter and potentially into early next year, could you kind of frame up how you guys are set up into 4 Q and into 1 Q as far as that production trajectory as well as capital? Yeah. I mean, the way I would just describe it, Scott, is that there's a number of kind of turn-in lines, call it in the 90-ish range, which is sort of a sustaining number of turn-in lines, right? But the amount of capital we spend around that can vary wildly, right? So especially as we talk about the accrual. So the D&C list, and think about that as the number of wells in process, whether we draw down our existing D&C list and sort of eat through that backlog, or we build it as we build growth for the following year as well as acquire inventory throughout the year can have a big difference. So you can drill and complete 90 wells throughout the year and actually spend less than that equivalent capital, or you can spend a substantively larger amount of money. And it really depends on the environment you're in. I'd also add that we are truly return-driven. And so if oil prices are $50, ultimately, is 90 wells the right number? And if oil prices are $85, maybe 90 is too few. And so I think really what we want to figure out is we want to take the time to go through both the projects that we have in hand organically, inorganically, and as we look through it and both make the right decision in terms of the actual number of wells we want to turn in line. And then on top of that, all of the projects and things we want to build towards the future year as well as the ad hoc spending we want to tuck in there. And that really drives that number. That is why we try to take as much time as we do. I think it's the D&C list, but it's also going to be the nature and the makeup of the D&C list, right? What's the overall well productivity? What's the stage of completions as we exit the year? What does that look like? And then what is the organic asset pulling and the quality of the well proposals on that? And then dovetailing into what we've been talking about with Neal and prior comments on the ground game, right? I mean, if we're going to see a pullback in commodity pricing, then you're typically going to see operators retreating to the core and drilling some of their best stuff and lowest break-evens. And so what does that mean in terms of the organic activity levels in the ground game as well? Okay. Understood. I'm going to just ask for one point of clarification, and I'll add on to my second question. Does that mean 1 Q is going to be relatively flat, you think, kind of to what you look at fourth quarter is kind of the follow-up to that? I would say historically, almost every quarter we've ever existed, we see a minor downtick in Q1 from Q4, and that's just seasonality in the Williston, Scott, so it's usually down a couple percent, I think, almost every year we've ever been here. We've had a few miracles of weather, but as long as the Williston becomes a substantive part of our production, it usually has some seasonality to it, but it's not meaningful, but it's almost always that case, and as Adam mentioned in his comments, we do anticipate, just given the nature of our big joint ventures, that we will be building the D&C list in the first half of the year, and that's just based on what we have at hand today, and so that will have some effect on it, but I don't think it's going to be dramatic. Got it. Okay. That's what I was looking for. And then my follow-up is, I noticed in your corporate presentation when you broke out the commodity by basin, that a little bit of oil popped up this quarter for the first time in Appalachia. Could you give us a little bit of color on what that's from and just give us a sense? It sounds like you're looking at some more kind of Ground Game opportunities popping up in Appalachia. Just give a little bit of color around that. I'm impressed you noticed. Yeah. We have obviously been expanding in the Utica, and we have tapped into the oil window there. We've continued to have success on the ground. As I mentioned, we've had, in my prepared comments and Adam did, we've had really good success in ground leasing. The Utica is one of the areas in which we have been successful. I think we'll continue to be so, Adam. Yeah. I mean, I think we announced kind of our large-ish transaction in Q1 in the Utica this year, and we've built on that, right? I think the press release is best advertisement in order to bring in those opportunities. We're going to treat the Utica no different than any other basin, walk before you run. We're starting to get some of that traction, and we're going to keep that momentum. The next question is from Charles Meade with Johnson Rice. Your line is open. Yes. Good morning, Nick, Adam, and Chad, and the whole energy team there. Nick, you've covered a lot of ground on the CapEx trends here. And I'm sorry if I'm kind of belaboring this point. But if I look at your TIL guide and look at what you've done this year, I just want to make sure I'm understanding what it looks like on your end. Maybe this goes back to Chad's comments. Are we looking at about 30 TILs for 4 Q, which would kind of be about even with what the 2 Q number was and all other things being equal, which of course they never are, but that suggests that your 4 Q CapEx would be about the same as 2 Q? I would say 25+, Charles, right? So it could be as high as 30. Obviously, as a non-op, the timing can vary, but I would say confident in 25+. Yeah. October was certainly an active month. Obviously, we'll see what November and December hold. Yeah. Okay. Got it. And then I wonder, in your prepared comments, and this is about the Uinta Basin, you mentioned those Douglas Creek wells. The operator talked about those last week. Maybe you could share anything. I know it's still early days, but what have you guys seen as you've been getting all the data? And what is it? Does it change anything on what role? You're thinking of what role that Uinta could play in the 2025 plan? I mean, I think the transition of operatorship is really just beginning, Charles. So it's really early days. I think what I would tell you is that SM, obviously, they're just, they talked about how they're changing some stuff and extending laterals. That's really them taking the reins of the plans that we had really underwritten in, which is that we really wanted to go with our own spacing plan and our own longer laterals. And it's nice to see them going and doing that. That will change it up some. So I would say the only thing I would say is it's an affirmation of what we have wanted to do. Outside of that, I think in terms of the Douglas Creek, seeing some positive results in the Upper Cube as we go into full cube development is always a good thing to see. But I think what I'd also say is almost every single joint venture that we've been a part of is that there is, the early days are always the part that you always watch with bated breath, right? Which is that you see a period where a new operator is taking over, and they get their sea legs over a few months. And then really we've seen in the kind of six months post-operatorship transition, we've seen real acceleration of development and huge gains. And we're hopeful to see that. We've seen that on Forge and Novo as the operators have just really taken the reins once that they've had kind of full ownership. And we're not quite there yet, right? Obviously, they've barely taken possession. It's been less than a month here. Early days, but certainly encouraging. You look at the oil cut in the Douglas Creek and then shifting your focus on the cost and efficiency initiatives that everybody's going to be laser-focused on. The sand mine is going to help with that. My prepared remarks alluded to shaving a couple of few hundred thousand dollars off of well cost there, and then Nick alluded to the lateral length. All those types of things are going into how we can optimize overall operations and generate additional returns on top of what was even underwritten. The next question is from Phillips Johnston with Capital One. Your line is open. Hey, thanks for the question. Just to follow up on Charles' question there on the XCL. So it sounds like the six wells that are being delayed, it sounds like that's not going to have any material impact to your fourth quarter production trajectory. Is that the way to think about it? That's right. That's right. I mean, I think that just highlights the diversification across our business. And so where you might stumble in one place, you're going to make that up. We're taking a look at October results and some of the fires within the Williston and the production flip that we saw there and the Permian making up for that. I think we're certainly encouraged. We talked about XCL, didn't necessarily talk about Point. I think we're certainly encouraged about some of the early well results that we're seeing on the new TILs. I think those are outperforming, call it 30% than what was originally underwritten with some of the new wells that those guys are bringing online. So we're excited about that prospect. And just given the overall asset base, you're not going to see that type of reaction at a corporate-wide level when certain things get delayed. Yeah. Okay. Sounds good. And then just the production guidance for the year, it obviously implies a pretty big ramp here in the fourth quarter. Obviously, you've got the two larger acquisitions. But looking at the midpoint, it implies around 87,000 a day or so on oil. You guys comfortable with that implied midpoint, or would you expect things to sort of shake out in the bottom half of the range for the year? I think it's really going to depend on timing, Phil. So obviously, you have a huge number of TILs. And I hesitate to punt, but we have so many TILs. And as always, it really is going to depend on how quickly they come on. And as a non-op, that is the one bad part, which is that we don't control. So it is achievable to the extent that we see things come on extremely quickly. If not, obviously, I think the ranges we're very comfortable with. I think the question will be one of timing. And so that is really the driver. And so that, but from a TIL perspective, we'll get there. It just be a question of the averaging within the quarter. The next question is from Paul Diamond with Citi. Your line is open. Good morning, Adam. Thanks for taking my call. Just a quick one. You guys talked about seeing some more kind of bespoke opportunities you're seeing as you kind of expand beyond the Ground Game traditional non-op. So I wanted to dig in a little bit more there. Are these bilateral negotiations with existing partners, or are these something a bit more specific? I would say that the bilateral or kind of off-market opportunities that we're seeing are largely with discussions with our operators, understanding exactly what they're trying to get out of a particular transaction. And then depending on what they're trying to solve for, that's where we can start bringing up different kind of structural conversations. And so whether that's a joint development program, whether that's a minority interest buy-down, whether they're looking to grow and potentially doing some sort of co-purchase, those types of things, those are generally your off-market types of conversations. If it's a typical non-op package, that's generally going to get put to market. And if it isn't, then you should probably be questioned what someone's paying for it. But I think if it's vanilla and regular way, then you're generally going to see a typical marketed process. If it gets more involved and you've got more bells and whistles and levers that you need to pull, that's where I think we can be more constructive in an off-market type of conversation. Understood. Thanks. And just one quick follow-up. You guys had talked about this quarter and a few prior about kind of increasing activity cadence, 10 wells pulled forward this quarter. How do you think about that in the longer term? Is that more compression, or is that just timing this year? How should we think about if that trend continues? I think we've adjusted, Paul, to the concept that overall speed of development has increased, and I think we've made adjustments accordingly. I think given the change in commodity prices where we are now, I think it's less likely that we're going to be surprised going forward. If anything, I think we start to see some pausing of development just because we've seen lower prices and some, especially on the small private side, you see deferrals here or there just as people wait for slightly better price environments, and so I think it's less likely that we're going to see true acceleration kind of beyond our measure, but I think the other thing is that we have seen, ultimately, to save money, speed of development has been the biggest driver over the last two years, and so it's just been completing wells faster, drilling wells faster. The cutting and shaving days has been the driver, and we've had to adjust accordingly. Adam, I don't know if you want to add to that. I can help it. Your final question comes from the line of Noah Hungness with Bank of America. Your line is open. Morning, Nick and team. I just was hoping you guys could expand a little bit on maybe some of the well deferrals or if you had any insights onto maybe what the criteria is some of these operators are looking for, and if it is just lower commodity prices, do you think at some point, if commodity prices just stabilize at a lower level, then they would turn those wells on line? To your latter point, we've seen exactly that happen over time. We've seen producers, and not to name names, but we've seen a handful of producers at times pause wells only to then turn them on when commodity prices didn't go back up over time, hoping that prices would go up or what have you, and then ultimately just turn them on. And so that's typical, especially with some of the small privates. Yeah. The private operators are generally a bit more sensitive to it and then bring it in the hedge book. And whether or not they have no hedges, no debt will certainly affect those types of decisions. But like the M&A market and volatility, you've got a bid-ask spread. But as things kind of settle out, then that's when people generally get moving. Makes sense. And then just as my last question, could you guys talk about how your decline rate has evolved this year and maybe where it'll end up being or where you think it'll be as an exit rate for 2024? Yeah. Hey, Noah, we came into the year kind of in the high 30s with a lot of activity towards the back half of the year and some of the new acquisitions being pretty steep declines. As we've gone through the year, obviously, it's moderated a bit. We probably exit the year kind of in the mid-30s as Novo and other assets have kind of moderated from their peaks. I think kind of in the low to mid-30s is kind of our go-forward run rate we would expect. Obviously, if there's less large acquisitions with high declines, we'll continue to moderate throughout the year. But that's kind of where we sit today. This concludes the question and answer session. I'll turn the call to Nick O'Grady for closing remarks. Thanks all for joining us today. We look forward to meeting with you in the near future, and thanks for your interest in our company. This concludes today's conference call. Thank you for joining. You may now disconnect.