Good day, ladies and gentlemen, and welcome to Denbury's first quarter 2022 results conference call. My name is Juan, and I will be coordinating your call today. At this time, all participants are in listen-only mode. Later, we will conduct a question-and-answer session. To ask a question at that time, please press star followed by number one on your telephone keypad. I would now like to turn the conference call over to your host for today's call, Brad Whitmarsh, Head of Investor Relations. Please proceed, sir. Good morning, everyone, and thank you for joining us today. I hope you've had a chance to review our news releases this morning and the supplemental materials that are available on our website at denbury.com. We're certainly very excited to announce not only strong first quarter results, but also a significant new CCUS transport and storage agreement, as well as an authorized share repurchase program. I wanna remind everyone that today's call will include forward-looking statements that are based on the best and most reasonable information. There are numerous factors that could cause actual results to differ materially from what is discussed on today's call. You can read our full disclosures on forward-looking statements and the risk factors associated with our business in the slides accompanying today's presentation, our most recent SEC filings, and today's news releases. Please note that during the course of today's call, we may reference certain non-GAAP measures. Reconciliation and disclosure relative to these measures are provided in today's earnings release as well. This morning, our brief prepared comments will come from Chris Kendall, President and CEO. Mark Allen, CFO, David Sheppard, SVP of Operations, Nikulas Wood, SVP of Carbon Solutions, and Matt Dahan, SVP of Business Development and Technology, are all here to participate in the Q&A. With that, I'll turn the call over to Chris. Thanks, Brad. Good morning, everyone, and thank you for joining us on today's call. It would be an understatement to say that the start to this year has been dynamic. Russia's activities have created turbulence in the energy markets, and combined with demand growth, have taken oil and natural gas prices to levels not experienced in many years. Further, increased energy costs are adding to already high levels of inflation, and supply chains and services continue to be challenged with rising demand. Considering that backdrop, I'm especially proud of what our teams have accomplished to start 2022. We are making great progress on all of our objectives, and most importantly, we have continued to operate safely with our key metrics either at or near record levels. While we are all experiencing the effects of supply chain breakdowns in our daily lives, our team's careful planning and diligence have thus far mitigated any significant impacts on Denbury's business, keeping us firmly on track with our key development projects. This morning, I'll focus on four primary topics. Highlights from our first quarter results, as well as updates to our annual guidance, the $250 million share repurchase program we announced this morning, continued progress on our capital developments, as well as increasing momentum in our carbon solutions business. Denbury delivered robust financial and operating results in the first quarter, enhanced by our high leverage to oil prices. Operating cash flow before working capital changes totaled $131 million for the quarter, resulting in free cash flow of $51 million. Sales volumes, differentials, and operating costs were all in line with our expectations and guidance, and we exited the quarter with only $35 million in debt. Also, we concluded an amendment to our bank credit facility that increased the borrowing base by 30% to $750 million, while extending the facility's maturity and relaxing various restrictive covenants. Looking forward, we are maintaining our full year guidance ranges across sales volumes, capital, and expenses. However, with the increased outlook for commodity prices and recent inflationary pressures, we anticipate that some of our cost items will trend toward the upper half to upper end of those ranges. Also, we have updated our income tax expense outlook for the current oil price environment, which reflects a higher anticipated tax rate and some cash taxes in 2022. Regarding production, we anticipate that second quarter volumes will be slightly lower than the first quarter due to recent downtime for unplanned maintenance and late winter storms that occurred early in the second quarter. Production should ramp higher in the second half of the year as we see initial results from our 2022 capital program, with fourth quarter volumes being the highest of the year. As oil prices have continued to strengthen, we've added to our hedge positions for 2023, primarily with collars that provide floor protection around $70 or higher, while also providing exposure to significantly higher oil prices. With an enhanced cash flow outlook, our board recently authorized a $250 million share repurchase program. As we've emphasized in the past, while maintaining a strong balance sheet, our capital allocation priorities are, first, to fund our production business at a sustaining to moderate growth level. Second, to fund expected CCUS investments. Third, to return capital to our shareholders when generating sufficient free cash flow to do so. Based on our success to date and our view toward expanding our CCUS business, we anticipate meaningful capital needs in the future. However, at current commodity prices, we expect to have the ability to meet all of those needs as well as to fund the share repurchase program. Highlighting some of our recent operational accomplishments, our CCA development continues to progress extremely well. Phase one CO2 injection commenced on February 1st, and as of today, we have 55 wells on injection with a total rate of over 115 million cubic feet per day, or over two million tons of industrial source CO2 on an annual basis. The project remains on plan for first tertiary production in the second half of 2023. This extraordinary asset is the largest EOR development we have undertaken, with a total recoverable EOR potential of over 400 million barrels, more than twice our current proved reserves. Based on our exclusive use of industrial source CO2, all produced barrels will be carbon-negative Blue Oil and should be some of our highest margin production. The EOR-focused side of our business is fundamental to the execution of our CCUS vision. Financially, it drives strong cash flows that allow us to organically fund our CCUS investments and new investment opportunities in the energy transition space. Technically, the pipeline project management wells and subsurface skill sets that we have developed in our 20+ years of EOR operations are the exact same skill sets needed for highly reliable CO2 transportation and sequestration. Operationally, EOR is still the only form of CCUS available at scale in the U.S. today, providing offtake certainty for industrial customers to move forward with capture projects. As I mentioned in our 2022 outlook call, this year will be transformational for Denbury's CCUS business. Our carbon solutions team continues to make great progress, both in building out our sequestration capacity through new pore space agreements, as well as reaching agreements with industrial partners for the transportation and storage of their CO2 emissions. Multiple agreements are continuing to advance and new opportunities are coming to us virtually every day. This morning, we announced the execution of a new term sheet for another significant transportation and storage agreement in the Gulf Coast, representing an incremental two million tons of captured CO2 per year. This is a planned chemicals facility intended to be constructed in close proximity to our existing CO2 pipeline infrastructure. With this agreement, we have now reached an industry-leading seven million metric tons per year of CO2 for new transportation and storage services. Based on what I see today in terms of what we're working on, I believe we're on track this year to substantially exceed our cumulative annual target of getting to 10 million tons per year. While the agreements we have reached to date have been for CO2 transportation and storage, we're offering industrial customers a full suite of service options ranging from transportation and storage to transportation only, and even providing a full package that includes the in-plant capture process as well. Each of these solutions is being tailored to the unique needs of our industrial customers. I'm looking forward to updating you in the coming weeks and months as more of these agreements are completed and the growing scale of Denbury's CCUS business becomes more evident. Our build-out plan for Denbury's Gulf Coast CCUS system is to provide a highly reliable and efficient network of sequestration sites located at key points across our pipeline infrastructure. The team is highly focused on the development of our contracted sequestration sites and is engaging with the various EPA regions in support of our Class VI permitting process. As part of that effort, we are planning to drill multiple stratigraphic test wells later this year. In addition, we are continuing to build out storage capacity further, and I expect that we'll complete several more sequestration site agreements in the coming months. We have great momentum at Denbury. Our production business is generating strong cash flow, and we are developing an incredible EOR resource with our CCA project that will drive volume growth beginning late in 2023 and into 2024, becoming the foundation of our production for future decades. Concurrently, our CCUS business is making important progress, the details of which we plan to further lay out as we go through the year. As I close, I wanted to note that we intend to issue our 2021 corporate responsibility report in the near future. I encourage you to read through the report to learn more about Denbury's focus on sustainability. As I mentioned at the outset, I am extremely proud of what our teams are doing. Denbury has an incredible and energizing opportunity in front of us, not just to redefine the future of our company, but to also provide the energy our world needs while reducing carbon emissions in a meaningful way. Thanks for your time today, and we'll now turn the call over for your questions. Thank you. If you would like to ask a question at this point, please press star followed by number one on your telephone keypad. If you would like to withdraw your question, please press star followed by number two. When preparing to ask a question, please ensure your phone is unmuted locally. The first question comes from the line of Doug Leggate from Bank of America. Please, Doug, your line is now open. Hey, thank you everybody. This is Clay. Thanks for taking my question here. My first question just concerns slide number 12, and there's a comment, a footnote on there, and it indicates that you're considering a two-three tops expansion in the Green Pipeline. I think this opens the door to several questions, and I apologize because this is tiered, but I'm just trying to understand. Number one, are the rights-of-way already in place? Number two, have you already gotten the critical mass of CO2 offtakes to underwrite the expansion? Just kind of considering the lead time of construction, would you take FID before the Class VI permits are granted? Good questions, Clay. You know, looking at that expansion of the Green Pipeline, that's honestly something that we have been planning for some time. What it's primarily based on is just the incredible volume of demand that we see coming. It's certainly not contracted today, as you can see from just our progress towards the goals that we have right now. But as we look at the agreements that we're negotiating, as we look at what is yet to come, the potential for what we can do here is enormous. Primarily, you know, we can start with the line itself and adding pump stations at various locations to enhance the capacity and line loops within an existing right of way, as you know, per your question. We can do an awful lot of expansion just with that. Ultimately, we expect the expansion to take place over time. Remember, we have about 16 million tons of capacity in the line right now, which is only being used at about a quarter of capacity. We have quite a ways to go with the capacity that we have. What that does is it gives us room to plan and execute that expansion in line with the projects that we think are coming that will ultimately take all of the capacity we have and require that expansion. Just kind of looking at the distance of the pipeline versus the various storage options, it seems like this could be a tier development where the storage sites that are closer to the pipeline get developed first, and then New Orleans and Mobile, Alabama, are developed later. Is that the right way to think about it? In that context, how do you see the cadence of spending? When does it begin? Ultimately, when do you see it concluding if you have those agreements set by 2025, 2026? Sure. I don't quite think of it as a tiered development, Clay. I think of it as kind of an all of the above. I mean, if you were to look into Nik's team right now, you'd see that they're steadily churning on the permitting process for every single site that we have. The idea that every one of the sites is going to have a specific region that it is best suited for emissions that occur in that region that are captured. Over time, we just expect that we can work all of these sites together. Like I mentioned just a minute ago, we're going to be adding more sites as we go, building this you know over the coming years. Certainly our view is towards matching with the projects that we are aware of that are either being executed or in plans right now to have those sites available when that time comes. You asked a question about the cadence of capital, and certainly I would think that as we ramp this up, we want to do quite a bit of work next year. I expect capital to meaningfully increase in 2023 as we build these sites out, along with the pipeline laterals that connect to the sites as well as to the emitters. You know, and along the way, one thing that we're thinking about, Clay, is just we wanna make sure, going back to the efficiency of this system, that not only do we have, you know, one site that's ideal for any particular emitter, but that we have redundancy in the system, and that we can bring emissions to various locations across the system. That's part of the beauty of the system, the way that we think about it. Thanks for the added detail on there, Chris. The follow-up question just tries to understand the value creation opportunity that's in front of you. As you continue to develop, how do you think about the incremental value of the contracts that you're adding? Ultimately, as you noted, the scale of this project is significant. Are you ultimately the right operator of this project? I'll leave it there. Sure. I mean, you know, honestly, when I just look back at what Denbury does, you know, for 21-22 years now, we have been primarily focused on enhanced oil recovery using carbon dioxide. If you were to look inside the company, Clay, you'd see a suite of technical and operational professionals who have handled all things CO2 for 20+ years. You know, from that aspect, I can't imagine anybody better qualified to be transporting and injecting CO2 even outside of EOR. I take it a step further, and I just think about the infrastructure that we have in place. We have the longest operated CO2 pipeline network in the United States, split between the Gulf Coast region that you mentioned earlier, as well as in our Rockies region. A great head start on infrastructure as well that I think really sets a backbone in place that allows us to access storage sites, that allows us to be close to emissions sites as well, and really, at the end of the day, creates the most economic solution for industrial emitters to bring their emissions into the system and put them underground permanently. Thank you. Our next questions come from the lines of Charles Meade from Johnson Rice & Company. Please, Charles, your line is now open. Chris, good morning to you and Mark. Hey, Charles. the rest of the Denbury crew there. I want to ask about the buyback. You know, when I look at the announcement, I think, okay, $250 million authorization. It's a great arrow to have in the quiver, but it doesn't necessarily mean that you're gonna. It's good to have that option, but having the option is different from committing to doing it. What I wanna ask is how are you and, you know, the management and the board thinking about, you know, the relative attractiveness of spending for cash buying back your shares versus frankly, to the point you've already been making on this call, really it seems like a really rich and deep opportunity set in front of you, not just on the CCUS side, but even on the tertiary side. What are the guidelines of how you and the board are thinking about that allocation decision? You bet, Charles. I'll just share a couple of thoughts on that, and then I'll ask Mark to share some of his as well. Like you, this abundance of opportunities within our EOR business, within the CCUS business, and we're focused on executing on all of those. We honestly just have the luxury with where prices are today to have cash flow on top of all of that, of being able to do everything that we wanna do and look at this buyback. Honestly, when we look at where the share price is today compared to what we see as the value of this company, and particularly the potential ahead of us with CCUS that we are making gains on every single day, it just doesn't look like it's in the right place. Those are my thoughts. I might ask Mark to just weigh in on some of the other elements of your question there. Sure. You know, Charles, as Chris said, we're obviously not, you know, pleased with the share price performance through the first part of this year. We recognize the weakness. We think the potential here is much, much greater. As we think about this and look at the free cash flow generation that we see, you know, we wanna be thoughtful about this. We wanna consider, you know, all aspects of it. We'll think about a systematic approach and something that aligns with our free cash flow generation. And obviously, you know, our share price will be a factor and so will all the legal aspects we need to take into consideration as we execute it. But that's how we're thinking about it today. Got it. Okay. Then a follow-up question on the CCUS. You guys, with this South Louisiana new build project, you're at seven million tons per annum, you've signed up and you're, I think you said you wanna be at 10, and you have multiple ways to get there. Should we be thinking more along the same lines of the sorts of deals you guys have brought to the table so far? Or is there a chance that we're gonna see something, you know, new and different? I mean, to the extent that you could kind of guide our speculation a bit on that, I guess is what I'm looking for. Hi there. This is Nik Wood. I'll take this question. To point out that we've continued on the progress that we have and we continue to see a pathway to continue to gain more emissions on the same type of suite of services we provided previously is accurate. We continue to see new ways of servicing different emitters and different industrial partners, one of which is adding additional capture services to our suite of services. That's a new approach relative to what you may have seen in the past. I would add that to the services we could provide. Yeah. The way I think about it, Charles, is just every one of our industrial customers has different needs and preferences. What we're trying to do is just make sure that what we can provide meets that. It may be just transportation in certain cases, or it may be the whole kit in others. Got it. That is helpful detail. I'll stay tuned to see the news. Thanks a lot. Yeah. Thank you, Charles. Thank you. Our next question comes from the line of Richard Tullis from Capital One Securities. Please, Richard, your line is now open. Thanks. Good morning, everyone. Morning, Richard. Chris, if continuing with the same discussion just previously with Charles Meade, related to, you know, Denbury potentially expand or looking at expanding the suite of services. Am I hearing you correctly that maybe you would provide part of the equipment to capture the CO2 at the facility? That's right, Richard. If you think about it, there's a whole spectrum of what that looks like. A lot of the industry that is incentivized under 45Q today is pre-combustion. In many cases, the capture that you're talking about is really limited to CO2 compression and dehydration. Of course, you know, handling 70 million tons of CO2 a year in our EOR operations, and I think compressing pretty much all of that, we just have a great depth of experience in compression, dehydration as well. That's an easy step. Then as you go further and you start to become more integrated in the plants themselves, it's, you know, those are just decisions you make on a case-by-case basis. We can see cases where it just makes sense, and it's the preferred solution that the industrial customer is looking for that all of that would be taken care of, and allow them to continue to focus on the core business that they've been operating. If you could provide any more, you know, details on how you're thinking about this or the team is thinking about it. You know, what level of investment would Denbury be comfortable with in that, you know, part of the service portfolio? You know, what sort of volumes would you be looking for range of volumes from these particular emitters? Is this on the lower end of the scale? It could be a range of volumes that we're looking at. I don't think it's primarily one end or the other, Richard. You know, really what I think about on your initial question, as far as level of investment, what I'd say is, as we go further upstream, we would very likely look at partnerships with other entities that deal in some of that upstream work in a more day-to-day fashion than we do. For example, if it's beyond the compression and dehydration, I'd say. It really depends on our approach there. You know, end of the day, what we'd look at in any case here is making sure that we're driving a good return on capital for our investors, while also providing the best solution for the industrial customer. Okay. All right. That's helpful, Chris. Just a last question from me, maybe for Nick or maybe for you, Chris. Pipeline conversions, we've been hearing, you know, from some industry participants, discussions, plans to possibly convert natural gas pipelines to CO2 transporters. You know, just wanted to get your take on the expected cost involved there, you know, the timelines to complete that sort of project, and really the effectiveness of converting pipelines to CO2 for transportation. If I can get your thoughts there. Sure. You know, we talked about it a bit in the past, just the nature of the operating pressure of moving CO2 in dense phase. For us, it's typically an ANSI Class 900 service, which has a, you know, maximum pressure above 2,000 PSI. The conversions that we've seen have been with typically natural gas service that's around 1,400 or 1,500 PSI, which is harder to transport in dense phase. We believe that the higher pressure is the most efficient, economical way to move CO2 at scale over distances. I think that conversions can be done. In fact, we've even had some minor portions of our network converted. It is even within our own network, we've had a bit of that. It is just in our view, at least, Richard, it presents some operational limitations and some costs of compression and needing to be sure that you can get to a pressure you can inject underground at the other end that works better for us. It is just something really on a case-by-case basis, how it works. We strongly prefer going with the system that we talked about. Okay. Well, that's all for me. Thank you. Thanks, Richard. Thank you. As a reminder to ask any further questions, please press star followed by one on your telephone keypads now. The next question comes from the line of Michael Scialla from Stifel. Please, Michael, your line is now open. Yeah. Good morning, everybody. I had a question on the Class VI permitting process on slide 11. You've given your estimates on first injection for your four project areas. Would you expect to submit Class VI permit applications for those projects and maybe any update on Louisiana receiving primacy over the process? Hi, Michael. This is Nik again. When I think about the Class VI permitting timeline and where we're at, the permitting process is a continuous permitting process in that we have continuous interaction with the EPA. That includes downloading our information to the Geologic Sequestration Data Tool, which has been done for all of our sites already. We continue to progress the interaction on what I'll call the desktop studies of our different sites. That includes simulation, geologic modeling, working through the different seals and containment factors. As we get to a point where we are at a construction permitting process, we will get a construction permit from the EPA for Class VI construction. At that point, we will drill a Class VI well and start the injection process. I still believe this is an 18-24-month process. We are in that 18 or 24 month timeline right now, and so we look forward to getting that first injection, hopefully in mid-2025. Yeah. Mike, this is Chris. Just, on your question on primacy. You know, that's one. What we have heard, you know, following the EPA's granting of primacy to North Dakota and Wyoming is that Louisiana should be next. I will tell you it has taken longer than we expected. We have great confidence in the EPA that just along with what Nik said, that we're gonna continue to work that. I do think that over time, that we'll see primacy granted to Louisiana and other states. At least right now, it's. I wouldn't say it's moving. It should be close, but it seems to be moving a little bit slower than we expected. Is it fair to say that the timeline you've built in there assumes that there is primacy granted to Louisiana, or is it more just assuming that the EPA controls it and the control? Yeah, Michael, I think it's more the latter. We've built the plan around EPA Class VI process. You know, once you do see primacy and you have the you know, folks that are local to the state, you would expect some acceleration there. At least everything that we have out right now is based on still working through the EPA and the Class VI process. Got it. Wanted to get your thoughts on the legislative environment now. Anything in particular beyond 45Q that you could use to your benefit? I know, for example, one of your peers plans to receive grants under the Infrastructure Investment and Jobs Act. Any possibility of Denbury doing something similar? You know, that's a good question, and we've seen a few elements of the infrastructure bill that do some of that. Some of the folks that we're talking to have been working with the DOE toward grants for certain aspects of what they're doing. I do see some of that coming along. Generally, the numbers are, you know, they help, but they're not game changers. For us, the legislation that we think is interesting is just ultimately I think it's inevitable that the tax credit, the 45Q tax credit will increase. It's just that today, where the tax credit is, we already see a great business. We think it needs to increase over time, and when it does, it's just that great business just becomes that much better. Just considering the current political environment, I know that there's some forces at work to push that forward. We'll just have to see how it works out here. Great. Thanks. One last one for me. I just noticed, maybe it's not a big deal at all, but on slide five, you had listed ISO certification for Cedar Hills South and East Lookout Butte at Cedar Creek Anticline. Is that something that you've done for all your EOR projects, or is that something unique to CCA? Yeah, Michael, this is Matthew Dahan. We've actually completed ISO certification on Hastings and Oyster Bayou in the Gulf Coast. Cedar Hills is in process. Should get that back here in a month or two, and we just continue working through the portfolio. Should get the bulk of them done within the next year. Certainly well ahead of any new emissions coming in that that's gonna require it. Okay. Thank you, guys. Thanks, Michael. Thank you. We currently have no further questions on the line, so I'll hand over back to Brad Whitmarsh for any final remarks. Thank you all for joining us today. Brad and I look forward to talking with many of you over the next several days, and we've got several conferences coming up, so we hope to see you in person. Thanks again, and Happy Mother's Day to all the moms out there. This concludes today's conference call. Thank you so much for joining. You may now.