Good day, and thank you for standing by. Welcome to SilverBow Resources' first quarter 2022 earnings conference call. At this time, all participants' lines are in a listen-only mode. After the speaker's presentation, there will be a question- and- answer session. To ask a question during the session, you will need to press star one on your telephone. Please be advised that today's conference is being recorded. If you require any further assistance, please press star zero. I would now like to hand the call over to your speaker today, Mr. Jeff Magids, Director of Finance & Investor Relations. Please go ahead. Thank you, Buena, and good morning, everyone. Thank you very much for joining us for our first quarter 2022 conference call. With me on the call today are Sean Woolverton, our CEO, Steve Adam, our COO, and Chris Abundis, our CFO. Yesterday afternoon, we posted a new corporate presentation to our website, and we'll occasionally refer to it during this call. We encourage listeners to download the latest materials. Please note that we may make references to certain non-GAAP financial measures, which are reconciled to their closest GAAP measure in the earnings press release. Our discussion today may include forward-looking statements, which are subject to risks and uncertainties, many of which are beyond our control. These risks and uncertainties are described more fully in our documents on file with the SEC, which are also available on our website. With that, I will now turn the call over to Sean. Thank you, Jeff, and thank you, everyone, for joining our call this morning. SilverBow is off to a strong start to the year. Our first quarter results, borrowing base increase, and recently announced transactions exemplify the winning strategy we have consistently executed on. The Sundance and SandPoint acquisitions mark the fourth and fifth transactions we have announced since August 2021. Combined, we view these acquisitions as attractively valued at a purchase price of less than $30,000 per flowing Boe per day of current production and at a cash flow multiple of 2.1x. We are excited about adding scale to our legacy position in the Western Eagle Ford, the efficiencies we stand to gain, and the projected growth from the combined asset base. For the past several quarters, we have outlined our strategic objectives. First, we are targeting double-digit production growth while living within cash flow. Second, we are focused on expanding our inventory through accretive acquisitions and organic leasing. Third, we want to lead our peers in capital efficiency and cost structure. Last, our fourth objective is to deliver the balance sheet through debt reduction and cash flow generation. During the first quarter, we continued to progress these objectives, and in doing so, we are seeing strong performance in the equity. Year to date, our stock is up over 60%, and that is coming off a 300%+ increase in 2021. In the first quarter, we generated $28 million of free cash flow and reduced our net debt by the same amount. We further reduced our leverage ratio quarter-over-quarter and ended 1Q with $262 million of liquidity. Notably, our quarter- end liquidity position does not reflect the increase to our borrowing base, which went into effect on April 12. Operationally, we drilled three Austin Chalk wells at La Mesa in the quarter, with the first being a single well brought online earlier this year. The other two Austin Chalk wells were part of an 8-well La Mesa pad we drilled in the quarter, which is the largest pad drilled in our company's history and represents a shift towards full-scale development of our Austin Chalk assets. As shown on slide 20, the Austin Chalk formation continues to exhibit some of the highest returns across our portfolio, and we plan to drill additional locations this year. Currently, we have 50+ Austin Chalk locations in our inventory, and we are actively pursuing opportunities to add to that count. In April, we made several major announcements that enhanced SilverBow's shareholder value proposition going forward. First, we announced our spring redetermination results, which increased our borrowing base to $525 million. The $65 million increase further enhances our liquidity. Notably, we did not include any contribution or uplift from the pending acquisitions. We expect to receive consents from the bank group to substantially increase our borrowing base upon closing of the Sundance acquisition, which should further increase our RBL availability. Following the announcement of the borrowing base redetermination, we announced two accretive acquisitions for a combined transaction value of $425 million. The SandPoint acquisition adds approximately 27,000 net acres in LaSalle and McMullen counties with a PDP PV-10 value of $89 million, which is $18 million more than what we paid for the assets. With two new wells coming online, we anticipate these assets to contribute five Mboe per day, with the expected closing to occur later this month. The Sundance acquisition adds approximately 39,000 net acres, with a PDP PV10 value of $277 million, and significantly increases our oil-weighted production and inventory with approximately 200 gross locations. As of January, the Sundance assets were producing 11 Mboe per day. Combined, these deals have compelling industrial logic given the acreage overlap with our positions in LaSalle and McMullen Counties, or what we refer to as our AWP and Artesia fields. The contiguous pro forma position, shown on slides 9 and 15, will provide synergistic opportunities for both OpEx and G&A as we achieve greater scale in areas in which SilverBow has extensive experience. On a pro forma basis, SilverBow will have ample high-return drilling locations representing over 20 rig years. A PDP PV-10 value of $1.6 billion in an oil production mix of roughly 25%, which is a meaningful step change compared to the 11% oil mix in 2021. A core pillar of our strategy has focused on a balanced commodity portfolio in which we can quickly shift between oil and gas development based on prevailing commodity prices. We believe this has been, and will continue to be, a competitive advantage in generating greater returns in the long term compared to peers who do not have the same flexibility in their portfolios. The increase in our oil production and inventory is a transformational and, candidly, a much-needed shift, ensuring SilverBow can benefit from the strength in liquids pricing moving forward. While at the same time, we have a deep inventory of high- rate- of- return gas locations, especially with the emergence of the Austin Chalk in Webb County. We have not published updated guidance for 2022 at this point. We anticipate closing the Sundance acquisition in June or July, at which time we'll release updated guidance. For reference, on slide 14, we show the full year 2022 pro forma company projections, which convey the magnitude of the increase from these deals compared to standalone SilverBow. Additionally, on slide 16, we highlight the accretion across key financial metrics, particularly free cash flow per share. Upon closing the Sundance acquisition, we anticipate adding a second rig, which will primarily focus on those assets. Our near-term plan is to allocate capital 50/50 between our oil and gas inventory. We essentially will have one drilling rig for oil and one drilling rig for gas full-time, which should drive greater efficiencies and full utilization of a frack crew. The optimized development plan we can pursue with our pro forma asset base will enable continued double-digit production growth annually. In fact, we are now projecting 20%-30% growth over the next few years. We can achieve the growth with a reinvestment rate below 60% while driving free cash flow greater than $1 billion through 2024. Assuming the latest strip pricing, we have line of sight towards $700 million of Adjusted EBITDA in 2023, an incredible pace of growth compared to Adjusted EBITDA of just under $250 million in 2021. At the same time, we expect to accelerate delivering and achieve our year-end 2022 leverage ratio target of less than 1x. SilverBow's value creation proposition thus far has focused on growth through the drill bit while converting enterprise value from debt to equity through free cash flow generation. With the accretive acquisitions we have made over the last year, SilverBow has rapidly scaled its cash flows within a favorable commodity price environment and improved its balance sheet in per-share metrics. For the near term, our focus will remain on the successful closing and integration of the acquisitions. In a strong commodity price environment, it is easy to forget where prices were just a year ago. Furthermore, we are seeing continued inflationary pressures across all services. Therefore, capital discipline, operational efficiencies, and prudent risk management will remain critical towards realizing the full value of our growth strategy. We have optionality given our balance sheet and strong cash flow outlook, which will allow SilverBow to remain active in further consolidation opportunities. Right now, two things are clear to us. First, pro forma SilverBow is set up to deliver strong growth in the coming years, which will bolster our portfolio and drive stakeholder value. Second, the Eagle Ford is ripe for consolidation, and SilverBow has a track record and capabilities to lead the charge. With that, I will turn the call over to Steve to provide an operational update. Steve, please go ahead. Thank you, Sean. In the first quarter, we drilled nine net wells, completed one net well, and brought one net well online. Essentially, all of our D&C activity was in our Webb County gas area, where we drilled one La Mesa Austin Chalk well at a lateral length of approximately 9,800 feet, the longest Chalk well we have drilled to date. Additionally, we drilled and began completing an eight-well La Mesa pad, which is the largest pad in company history. The La Mesa pad targeted three locations in the Upper Eagle Ford, three in the Lower Eagle Ford, and two in the Austin Chalk. The co-development of these wells utilized a wine rack approach and extended spacing for the Austin Chalk. This is our first spacing test of the Chalk formation as compared to the single laterals we have brought online to date. As shown on slide 20, our Austin Chalk results have outperformed our expectations and are exhibiting strong commercial returns. These wells are showing payback periods of less than a year, and at current strip prices, the payback periods and NPVs per well are even better. First quarter production averaged 226 MMcfe per day, right at the midpoint of our guidance range. Our oil and NGL volumes came in at the low end of their guidance ranges as weather-related issues and non-operated well performance impacted initial expectations. The current upcycle in the industry has caused a tight labor market in the service sector. We observed this with the rig we brought in earlier this year. Those efficiency losses proved temporary, and our drilling and surface rig fleets have returned to their prior efficiency levels. We expect the gains we have made operationally over the last few years to continue going forward. Furthermore, we intend to add a rig on the Sundance assets this summer. This will provide us with greater size and scale and the efficiencies of utilizing a level-loaded frac crew. All of this is to say that SilverBow will have greater abilities to mitigate rising costs as we work to provide our service partners with higher utilization across the asset base. For the second quarter, we are guiding to production of 225 MMcfe per day at the midpoint on a standalone basis, with natural gas representing approximately 80% of our production mix. This is roughly flat to our first quarter production. Due to minimal D&C activity in the fourth quarter of last year and the size and timing of the 8-well pad we developed over the first quarter of 2022, monthly production in the second quarter should decline sequentially before hitting a strong production ramp in June as first production from our La Mesa pad is brought online. Furthermore, we have optimized SilverBow's drilling schedule to maximize returns based on well selections and also accelerate the timing of first production of subsequent wells for the remainder of the year. This should drive, on a standalone basis, daily production rates to average 15% higher in the second half of the year as compared to the first half. Given the two acquisition announcements, which meaningfully impact our production levels, we are withholding full-year 2022 guidance until closing the Sundance acquisition. It is worth noting on a standalone basis that SilverBow's CapEx budget for this year remains unchanged as our team continues to identify efficiencies from a full rig. We remain committed to a flexible and adaptable development program which provides for such changes in short time periods. This has allowed us to stay within our original budget as we are actively offsetting cost inflation, increasing our field efficiencies, and pulling forward the first production timing of our highest rate of return wells. Specific to cost inflation, proppant, horsepower, diesel fuel, tubular goods, and labor are areas where the market is experiencing the most constraints. On the drilling side, utilizing a cost-effective spudder rig on our pads has helped to maintain cycle time efficiencies and reduce the number of drilling days needed from our super-spec rig. On the completion side, we have been primarily focused on land and sand costs at the well site. As such, we have utilized a blend of regional and imported sands along with other logistical trade-offs to help offset the inflationary effects of our stimulations. We are also working with our completion providers to further reduce the time from rig release to first stage pumped. Again, as we grow the size of our program, we're able to provide greater utilization to service partners who, in turn, are able to provide greater cost efficiencies to us. Looking ahead, our drilling rig has moved to our liquids-weighted assets and will target locations we acquired with the three acquisitions last year. In total, there are 13 locations we will drill in 2022 from last year's acquisitions. Assuming a standalone SilverBow scenario, this rig would shift back to gas drilling in Webb County in the fourth quarter. From a timing standpoint, we expect to incur roughly $70 million of CapEx in the second quarter. Again, on a standalone basis, this should result in a slight cash flow deficit for the quarter. However, the pulling forward of high-return wells and production timing will set us up for significant free cash flow through the second half of the year. With that, I'll turn it over to Chris. Thanks, Steve, and good morning, everyone. In my comments this morning, I will highlight our first quarter financial results, as well as our price realizations, hedging program, operating costs, and capital structure. First quarter oil and gas sales were $130 million, excluding derivatives, with natural gas representing 77% of production and 60% of sales. During the quarter, our realized oil price was 98% of NYMEX WTI. Our realized gas price was 100% of the NYMEX Henry Hub, and our realized NGL price was 37% of the NYMEX WTI. Notably, our realized gas price was $0.01 per Mcf higher than benchmark Henry Hub prices, highlighting the attractiveness of operating in Gulf Coast markets. Our realized hedging loss on contracts for the quarter was approximately $28 million. Based on our hedge book as of April 29th, for the remainder of 2022, we have 131 MMcf per day of natural gas hedged, 3,929 bbl per day of oil hedged, and 2,780 bbl per day of NGLs hedged. In 2023, we have approximately 134 MMcf per day of natural gas hedged, 2,900 bbl per day of oil hedged, and just over 2,200 bbl per day of NGLs hedged. The hedged amounts are inclusive of both swaps and collars and do not include the pending acquisitions. A detailed summary of our derivative contracts is contained in our corporate presentation and 10-Q filing for the first quarter of 2022, which we expect to file later today. Turning to cost. Lease operating expenses were $0.48 per Mcfe. Transportation and processing costs were $0.31 per Mcfe. Production taxes were 6% of oil and gas sales. We anticipate our unit LOE cost to increase due to higher cost liquids production, much of which was acquired over the last year. Cash G&A, which excludes stock-based compensation, was $3.7 million for the first quarter, a 1% decrease year-over-year. As we continue to add the size and scale of the company, a function of both organic and acquisitive growth, we do not anticipate a meaningful increase to G&A. Rather, we expect G&A on a per unit basis to decline compared to historical ranges. We consider our lean cost structure to be a competitive advantage, allowing SilverBow to sustain profitability during periods of volatile commodity prices. Adjusted EBITDA for the first quarter was $74 million. As reconciled in our earnings materials, we generated $28 million of free cash flow during the quarter. As Steve noted, we remain on track with our original CapEx budget range on a stand-alone basis, particularly as scheduling optimizations and full rig efficiencies have helped mitigate service cost inflation. Turning to our balance sheet. We reduced total debt by $27 million quarter-over-quarter. Strong price realizations allowed us to reduce debt in a quarter in which we pulled forward nearly $10 million of accrued CapEx, which totaled approximately $40 million. As of March thirty-first, we had $200 million outstanding under our credit facility, approximately $2 million of cash on hand, and $262 million of liquidity. As Sean mentioned, our spring redetermination in April resulted in a borrowing base of $525 million. I would like to thank our admin agent as well as the rest of our bank syndicate, which included two new member banks, for their support. We look forward to constructively working together as we close our pending acquisitions and further our consolidation efforts. SilverBow, in accordance with our credit facility, includes contributions from closed acquisitions for the entirety of the LTM Adjusted EBITDA period, which is used for the leverage ratio calculation. On an LTM basis for the period ending with the first quarter of 2022, the contributions from acquired assets totaled approximately $25 million, bringing our LTM Adjusted EBITDA for covenant purposes to $281 million and quarter-end leverage ratio to 1.24x. At the end of the first quarter, we were in full compliance with our financial covenants and had sufficient headroom. With that, I will turn it over to Sean to wrap up our prepared remarks. Thanks, Chris. SilverBow has taken actions over the last 12 months that have grown the company and resulted in significant value creation. With the latest acquisitions, we are set to increase SilverBow's flow in liquidity, which, combined with greater cash flow potential going forward, should garner increased investor attention. A key milestone for SilverBow to reach was $500 million in annualized EBITDA. Next year, we have a line of sight to over $700 million of EBITDA. As we continue to find ways to scale our cash flows and pay down debt, we still see the highest return on investment through the drill bit in accretive transactions. Our plan is to integrate the new assets and identify additional synergies. Furthermore, we will accelerate growth through our expanded 2-rig program. The growth will drive significant EBITDA and free cash flow above current levels as we move into 2023. The narrative surrounding SilverBow's value proposition has meaningfully changed in a short amount of time. I want to thank our stakeholders for their continued support. We look forward to providing further updates on our next call. With that, I will turn the call back to the operator for questions. Thank you, sir. As a reminder, to ask a question, you will need to press star one on your telephone. To withdraw your question, press the pound key. Please stand by while we compile the Q&A roster. Your first question is from Charles Meade of Johnson Rice. Your line is open. Hi, good morning. This is Michael Furrow filling in for Charles Meade. Hey, good morning, Michael. All right. In regards to the eight-well La Mesa pad, you all mentioned that the wine rack configuration targets three Lower Eagle Ford, three Upper Eagle Ford, and two Austin Chalk wells. Could you provide a little more further detail on why that configuration was chosen and if there are further opportunities for other large pads similar to this one? Yes, Michael, this is Steve. The reason that that particular configuration was chosen is in the greater Fasken area, we have a history of high development and learning going forward. We've been able to work our appropriate 880 spacing in the Lower Eagle Ford as well as in the Upper Eagle Ford, which has been demonstrated time and again. Obviously, heavy density in the Lower Eagle Ford and continuing to grow density in the Upper Eagle Ford. That said, we've also been doing, as you know, that delineation testing in the Austin Chalk and using that, as well as offset data information, we've been able to get as well. We know that we typically wanna be right now at this stage in the development, somewhere in that 1,100 to 1,200 foot spacing. Therefore, it provided quite readily and handily for a wine rack development with offsetting vertical takes all the way from the Lower Eagle Ford looking up to the Chalk. Michael, I'd just add that hey, as we move forward, our probably optimized pad count is closer to four. Three to four versus eight. We do have a couple, you know, larger pads, six-eight, but the majority of our development plan moving forward will probably be in the three-four range. Great. Thank you. It sounds like that eight-well pad has been fully drilled. At this point, can you provide some more detail based on the number of wells that are completed and sort of some of the timing going forward? Yeah. From a drilling perspective, you're right, everything's been TD'd. At this point, everything has been fracked, and we're in the early stages of flow back. Expect to see a, you know, significant production ramp in the next few weeks. As you're aware, wells down in this area, both through all zones, lower, upper, and Eagle Ford, and Austin Chalk have IPs ranging from anywhere in the 12-18 million a day range. With bringing on eight wells, we're gonna see a significant ramp in our production. All right. Thank you. You know, from a timing perspective, it couldn't be any better with gas prices above $8 now. All right. No doubt about that. All right, my second question is centered around the Sundance and SandPoint acquisition. SandPoint's expected to close in the second quarter with Sundance in the third quarter. At this point, do you see any, like, major hurdles to closing these transactions or anything that could potentially mess with the timing related to the anticipated close of the deals? You know, we've been working on both transactions. We, you know, have a track record now to demonstrate the ability to get these transactions closed. Everything remains on schedule as planned. You mentioned SandPoint closing in the second quarter. That should be here in the very near future. Sundance, we're targeting late in the quarter, early third quarter. The one, you know, difference between the two is the Sundance transaction requires a shareholder vote, which is scheduled preliminarily. 21st For June 21st. That's kind of the timing pivot point around getting the Sundance transaction closed. Great. Thank you. That's very helpful. Thank you for taking my questions. Yeah. Appreciate it. Thanks. Your next question is from Neal Dingmann of Truist Securities. Your line is open. Hey, good morning, guys. In your prepared remarks, you kinda indicated you're not done pursuing acquisitions. Can you talk how the market looks? Some other operators in other basins have taken a step back with volatile oil prices. Are you guys approaching it differently? Maybe because you're using equity for some of the acquisitions, you can maybe take a little off the strip and leave some upside for sellers. Yeah. You know, let me kind of walk you through what we're seeing. We've been, you know, very active in the Eagle Ford looking for opportunities for quite a while now. The transactions that we've actually done over the last 12 months have been based upon longer- term relationships that we've built with the sellers. We believe, you know, the opportunity that we provide as a buyer offering both the combination of cash as well as stock provides the seller to participate in taking some value off the table through the cash component, and then being exposed to upside with the stock. You know, we believe, you know, folks that we've transacted with so far have recognized that value accretion. We do think that we're a logical acquirer of assets in the Eagle Ford. There's a tremendous amount of runway of opportunity sets out there with a number of private entities that are looking for opportunities to probably transact at these higher prices. Now, with all that said, we wanna continue to remain very disciplined. I think I mentioned in my opening remarks that across the five transactions, we've averaged a purchase price of about 30,000 BOE per day. We are seeing other buyers, you know, starting to push the high end of what we would consider probably overpaying for acquisitions in this volatile market. It is gonna continue to be a, you know, a challenging environment at these high prices and this volatility until we kinda get a stabilized go- forward strip. We're gonna continue to work it hard but be very diligent in making smart transactions. That all makes sense. Maybe just shifting gears. On the new acquisitions, they make total sense, you know, contiguous with your acreage. I assume part of the value was that you can run a more stable program. Is the second rig or the additional rig you're bringing in locked in already? Or is that gonna kinda be a game-time decision based on what the costs look like when the acquisitions close? We actually have that contract for the second drilling rig firmed up. It's, you know, our plan is to start drilling as soon as the acquisitions close. It's a rig that's currently active. Again, we have a good, strong relationship with our service providers, and so we work with them to work on the timing of bringing the second rig in right around the close of the Sundance transaction. We're pretty excited that we're gonna be able to hit the ground running. We're already working closely with the Sundance team to identify, you know, what they felt were the best opportunities to hit this year. We're getting those locations, you know, kind of teed up and ready to go, so that we can hit the ground running. That sounds great. Thanks, guys. Yeah. Appreciate the questions. Once again, to ask a question, please press the star, then the number one on your telephone. Your next question is from Geoff Jay of Daniel Energy Partners. Your line is open. Thank you. Hey, good morning. Just a follow-up to that. The rig is already secured. What's the term for that? In other words, I guess, is that rig, you know, do you feel confident that that rig will be kinda locked into that rate for the next, you know, six months, a year, kind of? How should we think about sort of, you know, potential for inflation down the line with that incremental rig? Yeah. Definitely, we're entering an environment, you know, that we haven't seen for many years. We're moving from, you know, over the last several years, where contracts were pad to pad. Now, looking at more, you know, longer- term type contracts from an operator's perspective. We're trying to lock in those rates where the service companies are now trying to kinda keep them short, so they can try to capture upside in future pricing. We're trying to balance that, right, and avoid mistakes that the industry's made in the past of getting too long commitments, knowing that prices can be volatile. We put in what we think is a reasonable amount of term and, you know, agreeable to the drilling provider as well, you know, kind of both sides trying to balance what makes sense for both entities. Good. Thanks. From an inflation standpoint, you know, it is, we are seeing it. You know, we over the last several years have continued our operations teams to find ways to drive costs lower. That becomes more and more challenging as you try to wring efficiencies out of the system. What we're benefiting from is the increased scale. You know, all the things that come with that, having more purchasing power, having more, you know, ability to commit to longer- term type arrangements. But more importantly, just having consistency in the schedule going forward. You know, 12, 15 months ago, we were running half a rig. Running two rigs will just allow us to be more efficient, and more importantly, commit to essentially almost a full frac utilization schedule. We're pretty optimistic that we're gonna be able to, you know, hold the line on capital, offset inflation through continued efficiencies from the scaled- up program. Okay. Appreciate the question. Operator, are there any additional calls in the queue? If not, we can wrap up the call for this morning. No more questions, sir. Please continue. Okay. Well, appreciate everyone joining us this morning. We look forward to providing additional updates as, you know, activity and news warrant it, from us. Everyone, have a good morning. This concludes today's conference call. Thank you for participating. You may now disconnect.