Good morning. My name is David, and I'll be your conference operator today. At this time, I'd like to welcome everyone to Civitas Resources Q4 2021 earnings conference call. Today's conference is being recorded. All lines have been placed on mute to prevent any background noise. After the speaker's remarks, there'll be a question-and-answer session. If you'd like to ask a question during this time, simply press the star key followed by the number one on your telephone keypad. If you'd like to withdraw your question, press star one once again. Thank you. John Wren, you may begin your conference. Well, thank you, operator. Good morning and welcome to Civitas Q4 and full year 2021 earnings conference call. I'm joined today by Ben Dell, Chairman and Interim CEO, Marianella Foschi, CFO, Matt Owens, COO, and other members of the executive management team. Yesterday, we issued our earnings press release, filed our 10-K, and posted a new investor presentation, all of which are available on the investor relations section of our website. Please be aware that on today's call we may make forward-looking statements. These forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from projections. Please read our full disclosures regarding forward-looking statements in our 10-K and other SEC filings. On today's call, we may also refer to certain non-GAAP financial metrics. Reconciliations to certain non-GAAP metrics can be found in our earnings release and SEC filings as well. I'll now turn the call over to Ben Dell. Thanks, John, and good morning, everyone. The Q4 was a transformational and highly successful one for Civitas as we closed the merger with Extraction and the acquisition of Crestone Peak on November first and began building the future of Civitas. Before discussing our performance, I want to thank all the employees for their hard work over the last several months in diligently integrating the three companies and beating expectations on the Q1 as a combined company. As Colorado's largest pure-play E&P and the first carbon neutral E&P company on a Scope 1 and Scope 2 basis, we are very excited about the company's future. Civitas is leading the industry in executing on the new E&P business model. We have a simple business model focused on optimizing the development of our high-quality assets, a relentless focus on costs, expanding our cash margins, protecting our balance sheet, and returning excess cash flow generation to shareholders. This is also being done with an acute awareness of our environmental footprint, which we continue to minimize. As we stated in conjunction with the closing of the mergers, we are firm believers in the value of disciplined consolidation. On this note, we recently closed our acquisition of DJ Basin operator Bison Oil & Gas II. While small, this acquisition is a perfect case study of the rigor and discipline that goes into our acquisition evaluation. The Bison assets, which are expected to add an annualized average of 9,000 barrels of oil equivalent per day of oily high margin contribution to our March to December 2022 production, were acquired at a discount to PDP PV-10 and 1.6 times 2022 estimated EBITDA in an all-cash transaction. Civitas does not expect any additional G&A headcount from this transaction, further highlighting the synergies and cost savings we're able to extract through consolidation. Civitas will integrate these assets under its carbon neutral policy, further reducing basin-wide net emissions. On the ESG front, Civitas is committed to producing energy in the most responsible manner and will always strive to be a part of the solution for challenges faced by our communities. Civitas is a clear leader in the industry when it comes to emissions intensity, and we're very proud of our recently announced commitment to voluntarily plug 42 wells that were orphaned by previous operators in and around our operating areas in the Adams, Arapahoe, Elbert, Larimer, Broomfield, and Weld counties in Colorado. These wells represent roughly 10% of the 410 total orphan wells in the state of Colorado right now. Lastly, before I turn it over to Marianella, we're excited to follow through on our commitment to have an industry-leading shareholder return policy with the announcement of a $1.21 per share total quarterly dividend to be payable on March thirtieth to shareholders of record on March eighteenth. This is composed of our previously announced and paid $0.4625 per share base dividend and our inaugural variable dividend of $0.75 per share. This is one of the highest payout ratios in the industry and at our current share price implies a top-tier roughly 10% yield, all while maintaining our pristine balance sheet. Now, I will turn the call over to our CFO, Marianella Foschi, to walk through some financial highlights. Thanks, Ben. We had a solid Q1 as a combined company, exceeding expectations on all fronts relative to guidance. On a pro forma basis, average sales volume of 153.5 MBoe per day during the quarter came in at the high end of our total guidance range of 148-154, as well as the high end of our oil guidance range. Total capital expenditures in the quarter of roughly $225 million came in at the low end of our guidance range of $220 -$260 million on a pro forma basis. On the G&A front, we are proud to report that almost all transition employees have been released We're down from almost 500 employees at the combined companies to just over 300 as we sit here today. On this note, our go-forward cash G&A and LOE on a per Boe basis is expected to be over 30% less than on a standalone basis on an oil-heavy production mix, solidifying Civitas' position as the cost and margin leader in the basin. Our 2022 guidance is consistent with our messaging since the formation of Civitas of keeping production broadly flat, delivering a low-cost structure, and limiting reinvestment rates. Our 2022 operated plan reflects 3.5 rigs and three frac crews to deliver total production of 156-167 Mboe per day, composed of approximately 45% oil and 70% liquid. This guidance reflects 10 full months of contribution from the Bison transaction, which we closed last week on March first. You will notice a higher percentage oil in our 2022 guidance, which is due to a large portion of 2022 production coming from our lower GOR areas, as well as the newly acquired Bison assets. We expect this trend to continue in 2022 and beyond. We expect our all-in controllable costs, which include OpEx, gathering and processing, and cash G&A to be under $8 per Boe in 2022, which positions us as a cost leader versus peer companies with a similar commodity mix. Given our slightly higher oil mix combined with this low-cost structure, we expect 2022 unhedged margins to be higher than Q4 2021 levels. This capital program implies 2022 unhedged free cash flow yields of over 20% at $75 oil. I'd note that the Bison assets come with a higher 2022 reinvestment rate than Civitas targets. We plan on finishing up the Bison 2022 program and then bringing reinvestment rates in line with Civitas' strategy in 2023, further increasing free cash flow yields. Regarding inflation, we have seen total well costs increase roughly 15% from this time a year ago, mostly relating to steel and fuel price increases. We have recently completed new rebidding out of all of our major equipment and services, and our capital guidance reflects the results of this process. The operations team continues to find efficiencies to offset these cost increases through securing alternative materials, utilizing existing facilities, decreasing cycle times, and additional operating scales. Excluding the recently completed Bison transaction, our year-end PDP reserves came in at just over 300 million Boe with an associated PV-10 of $4.3 billion at SEC pricing of $66 oil and $3.60 gas, and $4.8 billion at $75 oil and $4 gas. Our total proved reserves are approximately 400 million Boe at year-end and have an associated PV-10 of $5.3 billion at SEC prices and $6.1 billion at $75 oil and $4 gas. Our proved reserves at year-end are approximately 80% developed. I'd like to point out that our proved undeveloped reserve bookings are extremely conservative at 234 growth locations, or less than two years of inventory at a flat three rig pace. None of these reserve figures include the Bison assets. Inclusive of Bison, our PDP PV-10 value at $75 oil and $4 gas is $5.2 billion. We consider our balance sheet a core strength and strategic advantage that we're focused on maintaining. As of March 1st and pro forma for the Bison transaction, Civitas' balance sheet consists of $500 million of total debt and approximately $140 million in cash, with liquidity exceeding $900 million. Our fortress balance sheet, consisting of 0.2x leverage, positions us as one of the least levered companies in the industry. In addition, we have minimal midstream volume or other commitments, affording us significant flexibility in our capital program. We will be committed to maintaining low leverage and a high degree of financial flexibility with a stated leverage target of 0.5x. I'd like to thank you all for joining the call this morning and for your interest in Civitas. With that, I'll turn the call back to the operator for Q&A. Thank you. At this time, I'd like to remind everyone in order to ask a question, press star then the number one on your telephone keypad. We'll pause for just a moment to compile the Q&A roster. We'll take our first question from Neal Dingmann with Truist Securities. Your line's open. Morning, all. Thanks for the details. Ben, maybe my first question, just overview how you think about things. I love the shareholder return. You know, prices stay here, going to continue to free cash flow. Story is tremendous. I'm just wondering about shareholder return sort of allocation, how you think about continuing to walk up the variable dividend versus buybacks or whatever else you might want to use that free cash flow for. Sure. Neal, I appreciate the question. I think, as we've stated before, obviously, we have a high base dividend. We've outlined our structure and calculation for the variable dividend, where if commodity prices obviously are sustained, we'll continue to grow. I think after that, the real question is how do you think about buybacks, how do you think about consolidation, and infill M&A, and then how do you think about a special dividend? You know, what we said is we'll continue to look to do accretive transactions and consolidation in the basin. I think we demonstrated that with Bison. You know, after that, it's going to come down to a discussion about what's best in terms of the easiest way to return capital from a buyback strategy or additional dividends. No, I think that makes sense. Just on operations, the 3.5 sort of rigs, I'm just wondering maybe for you or Matt, is that, you know, when you look at sort of the optimal, you know, efficiencies with a lot of your rigs, a lot of just the operations in general, with that plan, are you getting that, you know, or is there would you prefer to maybe ramp that up a bit to four or five rigs in order to get more optimal? I'm just wondering, when you talked about, max sort of efficiencies, you'll definitely have seen a notable upside there. I'm just wondering, are you seeing that at the current plan or are there things that you could do to even push that efficiency further? Yeah, Neal, maybe I'll start and then hand over to Matt. I mean, I think we've seen significant synergies in our operations from the consolidation of the companies, both from a capital standpoint, operating, midstream, and land. I think we're very comfortable with our capital program for the year that we've already outlined. I don't think you'll see our strategy meaningfully divert from that. Yeah, I'd say, Neal, to add onto that, 3 rigs is a pretty good sweet spot for us. It makes us one of the most active operators in the basin. We're able to keep up with all of our needs at that. We're obviously able to flex up a little bit more like we are with Bison. You know, I think something around 3, maybe 4 rigs at most is what I'd say pretty optimal is for what we're planning to do in the basin right now. Thank you all. Next, we'll go to Michael Scialla with Stifel. Your line's open. Good morning, everybody. Maybe to follow on to Neal's question. Ben, you mentioned, you know, you'd weigh buybacks versus a special dividend versus further consolidation. Just wondering how you see the remaining landscape. You do have a slide in your presentation, slide 9, showing some of these other companies out there. You know, after you've acquired Bison here and PDC acquired Great Western, are these other privates in the DJ still worth pursuing? Is there any inventory there that's worth pursuing? Or I guess just some more color on how you view the potential consolidation going forward. Yeah, Michael, I think my short answer to that is it depends on price. I mean, if we think we can consolidate additional players in the basin, where it's accretive to us, both on EBITDA, on free cash flow, NAV on production and on proven reserves, then we're going to continue to pursue those types of options. I think obviously there's less players left than there were six months ago. That's fairly obvious. But look, we're going to weigh those transactions up against the economics of buying our own stock. You know, we have a very significant free cash flow yield. I think the return of buying back the stock is, you know, meaningful, and I think we'll compare those A&D or M&A infill opportunities versus, you know, buying back the stock or paying a dividend. You know, ultimately, when you look at the management team, the board, and the shareholders, there's a very high degree of alignment here to do what's in the best interest of all equity holders. Makes sense. Want to get an update on the permitting process as well. Any update on the Lone Tree OGDP or that Watkins CAP? Are you still planning on a hearing in the H1 on the CAP? Any update there? This is Matt. I'll take a crack at that. We've had first of all 46 Form 2s wellbore permits approved for the company so far this year. The majority of those have to do with older pre-approved Form 2A locations. On the OGDP front under the new rules we have had 2 OGDPs approved in the last couple of weeks. We had the Lone Tree OGDP approved for 14 wells down in the Watkins area and the Blue OGDP approved last week down in the Watkins area as well for an additional 7 wells. So those now have been submitted for Form 2 approval. We're hoping to get that in the next couple of weeks to continue adding to the amount of permits we've gotten approved so far. In terms of other projects that we're working on, just to give you a little bit of color on what we have going on internally, we plan to submit in the near term another 6 OGDPs. When I say the near term, I mean through the first and Q2. That should encompass somewhere around 150-170 wells. Various OGDPs we're working on across various different areas. The majority of those will be in the near term in the southern area. Then we have a couple other OGDPs, about 6, that I call midterm OGDPs that we're looking to submit sometime after mid-year. That would be another 65 well bores. On the OGDP front, for what we've gotten approved already and what we're planning to submit over the next couple of quarters is a couple hundred wells. That's all in addition to the CAP that we're working on. The CAP, as you mentioned, was resubmitted by us addressing questions a few weeks ago. It's still around 160 well bores, two-mile-long equivalents, in total. We're planning internally right now to hopefully pass completeness with that by the end of the Q2, and then possibly have a hearing sometime mid-summer on final approval on that CAP. Sounds good. Appreciate the detail. Next, we'll go to Phillips Johnston with Capital One. Your line is open. Hey, guys. Thanks. Just a question on the variable dividend framework. Obviously, the first one out of the gate here was based on trailing twelve-month free cash flow. Is that going to be the approach going forward indefinitely, or is that at some point going to, you know, shift to a function of the prior quarter's actual free cash flow? Hey, Phillips, this is Marianella. Thanks for the question. I think we're going to stick to the 12-month trailing. I think it's our intention to remove variability from the variable dividend, if you will. So yeah. Yeah. You can expect that framework to be held on a go-forward basis. I'm just wondering, I guess, maybe how we should model it out for the next three quarters or so since I guess, you know, we don't have actual free cash flow for the combined three companies for 2021. Is that something you guys might provide? Yeah. I mean, I think if you look at the Q4, you know, we have a strategy of keeping production flat, you know, now inclusive of the Bison CapEx. You know, the CapEx for the full year is not really going to be all that different from what it was in the Q4. I think you can look at least for the next two to three quarters while we roll into a full Civitas pro forma 12-month basis. I think you can look at the Q4, specifically production, EBITDA, and CapEx as a good run rate for those next few quarters. Okay. Perfect. Appreciate the clarity that you guys don't expect to pay cash taxes this year. Can you just remind us, you know, what your tax situation is and at what point you might start paying cash taxes? Sure. Yeah, obviously, we gave guidance of 75. In Q4, you know, we've been refreshing the analysis, putting the combined companies, as you might imagine. I would say for 2022, we think we are going to be fully shielded from a cash tax impact up until about around $90. After which, you know, we start capping out of different limitations from a kind of a legacy company, Section 382 standpoint. I would say, you know, free and clear to 90. Above that, partial cash taxpayers for 2022. Okay. Sounds good. Thank you. Yeah, of course. Okay. Next, we'll go to Leo Mariani with KeyBanc. Your line is open. Hey, guys. Wanted to follow up a little bit on the permits here. So nice to see that you got some you know recently, appreciate that update. As you look at 2022, you look at the program this year, and is it kind of fully permitted at this time in terms of the 3.5 rigs, or is there still a little bit more you know to go here? Just you know looking into kind of next year, do you have any permits that extend into maybe a longer-term 2023 plan? Leo, this is Matt. Thanks for the question. This year is not fully permitted, but we're fully permitted through probably the fall. We've got the permits submitted, and they're pending for everything else. As we've been getting some of these approvals that I just mentioned in hand, that's what will be sliding into the schedule. For the plan or the rig schedule that we currently have laid out, we do anticipate getting approvals or final approvals on those in the next you know, hopefully the next couple of months. Some of those are obviously the OGDPs that we just recently had approved as well. Okay. Can you just maybe generally speak to what you're seeing out of the state? Obviously, they kind of just started approving permits under new rules, kind of end of last summer, last fall. Have you seen, like, any pickup in terms of, you know, state response times? Just kind of any color on maybe what you're hearing there. Yeah, Leo, it's Ben here. I'll make a couple of comments, and then Matt can follow on. Look, I think it's dangerous to make blanket statements across what we see in the state. Civitas has defined a pretty unique position in terms of who we are and what we're trying to do as an operator, both from a net zero standpoint and our commitments we've made to the orphan well program. I think we've had very good dialogue, you know, with multiple members of the state on the county level and local level about what we're doing, and I think there's a general appreciation of that. I think it's very difficult to look at, you know, even two OGDPs and compare them against each other and make blanket statements about what you're seeing in the, in the state. Can I just add on to that, Leo? I mean, we like the permits and the pads that we've chosen and selected and that we're currently working through the process on. We have only had the two approved that we've submitted so far, but they were unanimous approval. We're confident with the other locations that we have submitted and are working through the process as we speak. Okay. No, that's helpful for sure. Then, is there any update, I know it's a little bit early, on the CEO search, that you guys are, you know, working on? I mean, the board's actively engaged in that, Leo. We're seeing a number of candidates and talking to them. I think we've made good progress, and we think there's a high-quality pool of talent out there to pick from. I would expect, as we guided before, in the next 2-4 months, we'll have more color on who that individual is going to be. Okay. Thanks, guys. Next, we'll go to Joe MacKay with Wells Fargo. Your line is open. Hey, good morning, guys. Just wanted to follow up, I think it was on slide 9, talking about kind of the target reinvestment rates being a little bit elevated this year, obviously, with the Bison program, but returning back to normal in 2023. Just looking to get a little bit more color on that. Are those reinvestment rates kind of in line with the ones previously outlined, you know, back in November? Hi, Joe. Thanks for the question. I point you to our February 1 release. You know, we're going on the path on a standalone basis, ex Bison running right at three rigs. I think the Bison program, if you look at how much production is brought relative to the CapEx, you know, it's quite significant. For 2022, you know, it's quite a bit of CapEx. On a standalone basis, you'd probably expect us to get back to that three-rig level in that announcement on the standalone guide. That's probably what I would guide you to for 2023 and beyond. Okay, thank you. My other questions were answered, so I'll hand it back. As a reminder, ladies and gentlemen, to ask a question, it's star one on your telephone keypad. Next, we'll go to Noel Parks with Tuohy Brothers. Your line's open. Hi, good morning. Morning. You know, I'm just thinking about so much has really changed just in the last few weeks. I probably. This is something you already touched on. If we saw some big shift in the relative strength of product prices, oil, gas, versus NGLs, I mean, sort of something dramatic that looked like it might be sustainable, sort of out of all the sort of global energy unrest we have now. Over what sort of kind of planning horizon, you know, do you think you could incorporate that and maybe could lead you to make some sort of shift in sort of your drilling plans, just given the various product mix across your, you know, the different operating areas? I'm sort of assuming you've got, you know, a 2022 plan that's all set. But looking beyond that, when might you be able to filter in some major changes if they happen? Yeah, look, no, I think at a high level, we as a board and as a management team have a very clear plan about what we want to do the next 2, 3, or 4 years in terms of the overall framework for reinvestment. As you know, with the acquisition for Crestone Peak and the Watkins asset, that's significantly more oily and Bison's more oily. So as a firm, we will gradually become a higher percentage of oil over time. Obviously, in that environment, that's pretty accretive and improves our cash margins and improves our recycle ratios and capital efficiencies. So we like that. That being said, I don't think you're going to see any other major changes to our program. You know, I made this statement earlier today. You know, the curve's heavily backwardated. You know, we look at returns on a multi-year basis. It's clearly a highly cyclical and highly volatile industry. I think the base assumption is that we're going to stick to our existing plan, and that you're not going to see a material shift in that over the next 12-24 months. Great. That's all for me. Thanks. Okay. Next, we'll go to Will Dezellem with Tieton Capital Management. Your line's open. Thank you. Relative to the Bison transaction, the initial announcement, relative to the final announcement, there was a change in terms of, shares versus cash. Would you walk us through, number one, how that negotiation and change took place and ultimately what you were trying to accomplish, or potentially what Bison was trying to accomplish with that change? Yeah, I mean, I won't go into too many details, but obviously we had made the original proposal with a combination of assuming their debt, a small portion of cash, and the shares. Since the announcement, the shares traded down, the commodity traded up. The returns for us converting that into a cash transaction were pretty attractive. I think, I can't speak for the seller, but I think they had a desire for liquidity. Also, by converting it to cash, we obviously avoided having to pay the dividend on the incremental shares. The net benefit to us was significant of doing that. I think also, as you look at the framework for the company down the road, you can obviously model out the cash position that Civitas gets to as we go into the H2 of the year. Given that cash position, there will be a discussion about what we do with that excess cash. As we've been asked before in this call about the role of buybacks. The way I looked at that transaction was an opportunity to essentially, you know, avoid the dilution and not have to buy back the shares later on. We viewed that as pretty attractive. When you looked at it improved the overall returns of the transaction. Thank you for the color. Okay. Next, we'll go to Phillips Johnston with Capital One. Your line's open. Hey, sorry. I just wanted to follow up on the 22-reinvestment rate falling next year. I guess in addition to dropping back to three- rigs, I notice you're planning on drilling 200 wells this year but only planning to bring 160 online. Is that also a tailwind that should help improve capital efficiency and the reinvestment rate next year as just the number of wells brought online ultimately catches up with the number of wells drilled? Yeah, look, I think, Phillips, if you look at what happened in the H2 of 2021, we brought three companies together. There was a lot of operational work we did. We kind of had a brief hiatus in some of our activity, which we sort of have now ramped up and are getting back on track. I think the other thing I'd point out is we changed some of our flow back designs, completion designs, you know, gone towards more of the slow back model. So that impacts how production comes on relative to CapEx. You know, the goal of the board is to continue to improve capital efficiency, to drive down capital costs, improve EURs, expand cash margins. You know, I think we're confident as a management team, we can continue to do that as the year goes on. I think part of that will be there's a slight, you know, DUC buildup that will occur as we roll through the year. Yeah, to add on that, Phillips, this is Matt. We're not intentionally trying to build DUCs. We're letting it, you know, kind of be guided by the development plan that we have in a specific area. And with the bigger blockier positions that we have, sometimes we have to drill a couple of pads before we can start completing one and turning it on to avoid interference. And so that will kind of ebb and flow and kind of dictate what our DUC carry forward is at the end of each year. Yep. Okay. Makes sense. Thanks, guys. Next, we'll go to Doyon Cha with Macquarie. Your line's open. Hi, thanks for taking my questions. I just have two questions. First, if you could give us an update on how you're thinking about M&A, what the opportunity set looks like out there. I'm just wondering if this talk about returning capital shareholders or this emphasis on it might be interpreted as activity kind of slowing down on the M&A front. The second question is more housekeeping. If you could comment a little bit on the derivative cash settlement in the quarter and how that may or may not relate to the cash acquired as part of the Crestone Peak and Extraction acquisitions. Thank you. Sure. I'll take the first part of that. I don't think you should interpret our comments as, you know, anything around the M&A landscape or a change in the dynamic. You know, we continue to see consolidation opportunities within basin, we continue to evaluate them. Again, our framework is they've got to be accretive across the board for us, on EBITDA reserves, NAV production, etc. I think where we see, you know, accretive, attractive opportunities, we will execute on them, and we see a lot of benefit from that, and we've obviously seen it, through the Bison transaction. Nothing's really changed there. Our framework stays the same. For the hedges, I'll let Marinella take it. Sure. I guess on Bison, are there other acquisitions like Bison available still? Or I'm just trying to understand, like, the size of the opportunity set that you have right now. Yeah. I think if you look at slide nine, you know, we highlight some of the other players in the basin, you know, Bayswater, Confluence, Mallard, Verdad. I would say they range in size, you know, 10,000-30,000 barrels. You know, I can't speak around any of the specifics about them, but each of them have different pros and cons, right? Got you. Again, at the right price, we'd be active participants in further consolidation. Thank you. I'll take the one on the unwind. This is Marianella. We spent $110 million roughly all in the Q4. You know, to your point, it did not have to do with anything related to the legacy companies. It was a decision that this current board and this current management team undertook. When we inherited, you know, the hedge book from the legacy companies, you know, it was a hedge book that was reflective of different balance sheets, right? You know, we ended up unwinding roughly 6 million barrels, you know, and at a weighted average cost of, like, around $62-$63. Sure. No, nothing related to the legacy companies. It's just a decision of, you know, we looked at our balance sheet, we looked at our cost structure, and we really felt like we could optimize pricing received from that perspective. Obviously it ended up being a good decision in hindsight I guess, you know, everything with hedging is, you know, hindsight is 20/20. No, it didn't have anything related to cash or hedge positions with the legacy companies necessarily. Of course. The cash that was acquired, that was kind of predetermined and so unrelated to the decision to unwind as many of the hedges as you did? The cash that was inherited from the legacy companies was just cash that sat on our balance sheet at $111 as of closing. Those expenses actually came in December, you know, after some rigorous evaluation of the pro forma hedge book. Okay. Can you say again how much was unwound? Because I thought it was in excess of $200 million. No, the actual unwinds were roughly $110 million. I think what you're thinking, the $200 million, there was an excess of just normal course settlements of positions that did actually settle during the period. That's how you get to the $200 million. We spent the roughly $110 million unwinding roughly 6 million barrels of oil. Okay. Thank you. Of course. Thanks. Go ahead. What were you going to say? No, I was going to say that the positions for what it's worth, those 6 million barrels were out of period positions, so they're covered 2022 through 2025. Got it. Thank you. You're welcome. There are no further questions at this time. I'll now turn the call back over to Ben Dell for any additional or closing remarks. I'd just like to thank the team for all their hard work through this consolidation. I'd also like to thank you investors for making the time to listen today. If there's additional questions you'd like to take offline, the management team will be available. We look forward to continuing the dialogue. Thank you. This concludes today's conference call. You may now disconnect.