Greetings, welcome to the Gulfport Energy Corporation Fourth Quarter 2022 Earnings Call. At this time, all participants are in a listen-only mode. A brief question and answer session will follow the formal presentation. If anyone should require operator assistance during the conference, please press star zero on your telephone keypad. As a reminder, this conference is being recorded. It is now my pleasure to introduce your host, Jessica Antle, Director of Investor Relations. Thank you, Jessica. You may begin. Thank you. Good morning. Welcome to Gulfport Energy Corporation's fourth quarter and full year 2022 earnings conference call. Speakers on today's call include John Reinhart, President and CEO, and Bill Buese, Executive Vice President and Chief Financial Officer. I would like to remind everybody that during this conference call, the participants may make certain forward-looking statements relating to the company's financial condition, results of operations, plans, objectives, future performance, and business. We caution you that actual results could differ materially from those that are indicated in these forward-looking statements due to a variety of factors. Information concerning these factors can be found in the company's filing with the SEC. We may make reference to non-GAAP measures. Reconciliations to these comparable GAAP measures will be posted on our website. An updated Gulfport presentation was posted yesterday evening to our website in conjunction with the earnings announcement. Please review at your leisure. At this time, I would like to turn the call over to John, President and CEO. Thank you, Jessica, and thank you to everyone for listening to our call today. To open, I would like to express my gratitude to the Board of Directors for the opportunity to be a part of the continuing evolution of Gulfport Energy. The company is positioned with high-quality natural gas-weighted asset base and a balance sheet that provides optionality to enhance shareholder value. Working alongside the many talented individuals at Gulfport, we will remain focused on actions that facilitate efficient and sustainable development of the company's quality inventory, enhance margins, and optimize efficiencies within our capital programs, all while maintaining an attractive balance sheet and utilizing our free cash flow to position the company for success. Further to this point, the Board recently authorized the expansion of our common share repurchase program by an incremental $100 million. We believe allocating our free cash flow towards the continued investment in our undervalued stock, as well as utilizing it in acquiring incremental leasehold, will add value, optionality, and quality resource depth for the company moving forward. On behalf of the full board, I would like to also thank Timothy Cutt for his leadership of the company through the initial post-restructuring period. This was a critical phase of the company, and his leadership positioned us for meaningful shareholder value enhancement moving forward. We all look forward to working closely with Tim as Chairman of the Board. I will begin with a summary of our 2022 operational highlights, followed by our 2023 outlook, including the cadence of our capital and production in the upcoming year. Bill will review our fourth quarter and full year 2022 financial results and provide some additional commentary surrounding our 2023 plans. 2022 was a productive year for Gulfport, maintaining inventories of high quality acreage and delivering strong results from both the Utica and SCOOP development programs. The company generated over $240 million of adjusted free cash flow, which was utilized to return capital to shareholders and reduce our outstanding shares by over 12%, or 3 million shares since initiating the common share repurchase program in early 2022. The quality asset base contributed to an increase in both proved reserves and borrowing base, while also delivering top quartile well productivity results. The commodity markets have certainly been volatile, the company is well positioned to deliver value on our 2023 operating plans and maintain financial strength. Turning to the specifics, full year 2022 capital expenditures totaled approximately $450 million. Production for the year averaged 983 million cubic feet equivalent per day at the midpoint of guidance, which includes the impacts from Winter Storm Elliott. For the full year, the company drilled 28 gross wells, which were predominantly focused in the Utica. On the completion side, Gulfport completed and turned to sales 15 gross wells in the Utica and 13 gross wells in the SCOOP throughout 2022. Operationally, we continue to be very pleased with the recent well results in both the Utica and SCOOP. On slide 7 and 8 of the investor relations deck, we included slides that highlight Gulfport's recent single well performance compared to peers, normalizing the cumulative production on a 1,000 foot of lateral basis. In the Utica, Gulfport's development results have led to production outperformance compared to peers, with nine of the top 15 producing wells over the past two years being Gulfport-operated wells. In the SCOOP, for comparative purposes, data was included that depicts all wells drilled in both the SCOOP and Stack. Similarly, the Gulfport-operated development program over the past two years has outpaced our peers as 13 of the top 15 producing wells, which include all five wells from the company's new well development being top performers when comparing cumulative production on a per 1,000 foot of lateral normalized basis. Turning to reserves, our strong and consistent well performance is reflected in the 2022 reserve report, as our proved reserves were up 4% year-over-year, totaling 4 trillion cu ft equivalent. At the year-end 2022 SEC price deck of $6.36 per MMBtu and $94.14 per barrel of oil, the company's before-tax proved reserve value was $9.5 billion. At a flat $3 per MMBtu and $70 per barrel oil case, our after-tax proved reserve values total approximately $2.8 billion or $108 per share after subtracting our current net debt. This highlights, along with our peer-leading free cash flow yield, attractive margins, debt maturity profile, and attractive balance sheet, the compelling value opportunity that Gulfport Energy represents. As the company progresses into 2023, we are focused on further optimizing margins and capital efficiencies through reductions in our cycle times and operating costs, ultimately supporting the company's expected free cash flow generation. Given the current market, we have taken proactive steps to moderate overall development activity, with 2023 primarily focused on Utica development and Marcellus delineation activity. Total capital spend for the year is projected to be approximately $450 million, which includes roughly $50 million-$75 million of land and leasehold investment. The land spend is focused on bolstering our 2023 and 2024 drilling program, facilitating increases in our working interest and lateral footage in units we plan to drill near term. Full-year D&C spend is expected to be in the range of $375 million-$400 million, a decrease of approximately 6% from full year 2022. We expect minimal, if any, oil field service inflation year-over-year. Given the meaningful pullback in commodity prices, we believe there is potential to take advantage of a better service cost environment in the second half of the year as we lock in our 2024 program. Looking at allocation between our assets, we project roughly 90% of D&C capital spend will be allocated to our Ohio development, which includes Gulfport's first Marcellus delineation activities, developing two gross wells in Belmont County, Ohio. We currently forecast 2/3 of our capital will be allocated in the first half of 2023, trend lower in both the third and fourth quarters of the year. Turning to production, we anticipate this level of spend will deliver 1.0-1.04 billion cu ft equivalent per day in 2023, an increase of 2%-6% over full year 2022. Production growth will be back-half weighted, driven primarily by timing of capital spend and the Utica turn-in-line schedule being heavily concentrated in the summer months. In our investor deck on slide 11, we include a more detailed outlook on our expected 2023 capital and production cadence. For 2023, we expect our per-unit operating cost to decrease by approximately 7% compared to 2022, driven primarily by production tax impacts associated with lower commodity prices and midstream cost reductions year-over-year. We continue to maintain top quartile G&A spend and forecast recurring cash G&A of $0.12 per million cu ft equivalent for the full year. On slide 18 of our investor presentation, we provided a range of 2023 adjusted free cash flow outlooks at various natural gas prices. We project adjusted free cash flow will range from roughly $175 million at $2.50 gas to $320 million at $3.50 gas, implying a free cash flow yield range of 14%-25%. We plan to continue the return of capital to our shareholders through common share repurchases, while also actively pursuing incremental leasehold opportunities that increase our resource depth and provide optionality to our future development plans. These opportunities would have characteristics comparable to our existing assets and further build on our core position while improving our opportunity set and drilling economics in our future development plan. In closing, we have right-sized our drilling program for 2023 and are intently focused on reducing cycle times and operating costs to further improve margins. As we progress through the year, we plan to maintain capital discipline, prioritize free cash flow generation, return capital to shareholders through common share repurchases, enhance scale through incremental leasehold opportunities, all while protecting our balance sheet and adding value to the company. I will turn the call over to Bill to discuss our financial results. Thank you, John, and good morning, everyone. Turning now to our fourth quarter financials. The company continued to achieve strong results in almost every area of the business during the quarter, despite a challenging commodity price environment. We reported net income of $749 million and generated $155 million of adjusted EBITDA during the quarter. A key driver of the net income was a $437 million net gain associated with our commodity derivative portfolio. For the 12-month period ending December 31st, 2022, we reported net income of $495 million and generated $768 million of adjusted EBITDA. On the capital front, we incurred capital expenditures of $102 million during the fourth quarter, consisting of $89 million in drilling and completion capital and $13 million in land and related capital, both of which were in line with expectations. For the full year 2022, we incurred capital expenditures of $448 million, consisting of $411 million in the D&C capital and $37 million in land and related capital. Our total incurred capital for the year was negatively impacted by inflationary pressures on our oil field services costs as well as supply chain disruptions throughout the year. Net cash provided by operating activities totaled $188 million during the fourth quarter. We generated adjusted free cash flow of $33 million for the same period. Despite some weather-related headwinds during the quarter, we were still able to generate positive free cash flow for the seventh consecutive quarter post-emergence. For the full year 2022, we generated roughly $240 million of adjusted free cash flow. Moving on to derivatives. To further support our ability to fund our capital program and return of capital initiatives going forward, we have continued to enter into commodities derivative contracts since our last call. As of February 23rd, we had downside protection covering approximately 56% of our 2023 natural gas production at an average floor price of $3.53 per Mcf and roughly 355 million cubic feet per day of downside protection in 2024 at an average floor price just under $4 per Mcf. On the basis front, we now have nearly 40% of our 2023 natural gas basis covered, providing some pricing security at our largest points of exposure. We plan to continue to layer on additional basis hedges for 2023 as well as 2024 in the months to come. Finally, we recently restructured approximately 20% of our 2023 sold calls. The restructure increased the strike price from $2.90 per Mcf to $3.70 per Mcf on the restructured contracts and provides the ability to capture additional benefit up to a $3.70 price on those volumes. In total, the restructure increased our average 2023 strike price on the calls from $2.90 to $3.16 per Mcf. Overall, we are pleased with the progress we have made on our derivative portfolio, and you should expect us to continue to optimize and add to our portfolio in the future when opportunities present themselves. Turning quickly to the balance sheet. At the end of the fourth quarter, total assets were approximately $2.5 billion, while total gross debt was approximately $695 million, consisting of $145 million outstanding under our credit facility and $550 million of outstanding senior notes. We also had $7 million of cash on hand and $113 million of letters of credit outstanding at the end of the quarter. We exited the fourth quarter with roughly $450 million of total liquidity, consisting of $7 million of cash and $442 of borrowing capacity under the credit facility. We continued to execute our common share repurchase program in the fourth quarter, during which we repurchased approximately 293,000 common shares at an average price of $79 per share. As of February 23rd, we had repurchased approximately 3.1 million shares of common stock at an average share price of $85 per share, lowering our outstanding share count by approximately 12%. Inclusive of our recent expanded share repurchase authorization, we now have approximately $135 million of availability under the $400 million program to utilize over the next 12+ months. Let's now shift to our 2023 guidance as outlined on slide 18 in the slide deck. Our 2023 total production guidance is 1.0- 1.04 billion cu ft equivalent per day, with a midpoint up roughly 4% from the 2022 levels. Our year-over-year growth will be driven by our Ohio assets as we forecast a proactive moderation of SCOOP activity in 2023, which will lead to a production decline of 5%-10% in that basin compared to full year 2022. Our 2023 guidance for capital investment is $425 million-$475 million and includes $50 million-$75 million of capital for leasehold and land-related activities. As John mentioned earlier, we expect inflation to be limited in 2023 as we believe we incurred the bulk of the oil field service cost inflation as part of our 2022 development program. Finally, we expect our 2023 realized natural gas differential before hedges to fall in a range of $0.20-$0.35 off of NYMEX. Despite realizing wider gas differentials in the third and fourth quarters of 2022, we believe that the primary factors contributing to the weaker differentials are non-recurring in nature, and we are not seeing these impacts roll through the forward pricing used in our 2023 guidance. Please see our earnings release and slide deck for a few additional details on our 2023 guidance. In summary, despite a busy operational quarter and lower than expected realized natural gas pricing and differentials, we delivered another quarter of positive free cash flow. We are confident that our strong asset base will continue to support our ability to generate free cash flow in future quarters at a wide range of commodity prices, allowing us to continue to return capital to shareholders and to invest in incremental leasehold opportunities, all while maintaining our strong financial position. We will now open the call up for questions. Thank you. We will now be conducting a question and answer session. If you would like to ask a question, please press star one on your telephone keypad. A confirmation tone will indicate your line is in the question queue. You may press star two if you'd like to remove your question from the queue. For participants using speaker equipment, it may be necessary to pick up your handset before pressing the star keys. One moment please while we poll for questions. Thank you. Our first question is from Neal Dingmann with Truist Securities. Please proceed with your question. Morning, guys, and welcome aboard, John. My first question, just John, you sound confident, you guys have reiterated this even a couple times before you came on, just about the minimal or even no inflation this year. Just could you talk a bit about that, just what the confidence there and maybe a little bit more color on what this might lead you to do? I know you don't wanna, you know, I'm not expecting 2024 guide this early, but maybe what sort of opportunities you might have then, as you mentioned later on, to, you know, maybe lock some things in. Yeah, Neal, good morning. Thanks for the question. You know, as we look back at the company throughout 2022, post-restructuring, I would say that the contracts or the services the company was contracted for were pretty light. So we were a bit exposed to some moderate inflation in 2022, perhaps maybe slightly above the peers. As we move forward though into 2023, why we expect minimal is we have services contracted out throughout the year, at least the high spend services. So we feel very comfortable with where we sit on those. As well as we see with the fundamentals in the market somewhat changing, you know, we expect towards the second half of the year, general activity will be impacted in the service side, which will create an environment for us to perhaps take a little bit better advantage, in the second half of the year of some service pricing, in addition to potential discussions about 2024 work. Once you combine the current environment, the inflation last year, we're locked up for contracts, and we see the market being pretty volatile and a better kind of atmosphere moving into the rest of this year, there's some opportunity for us to actually make some headway, not only keeping it flat, but a possible reduction. Great. Great point. Just wondering, I don't know if it's still too early, you haven't been there terribly long. Have you been able to sort of get your hand around you guys have a lot of inventory, a lot of acreage, I'm just wondering, you know, kind of wrap that into an M&A question. When you look at things, I mean, are there things to trade? You know, I'm just wondering, when you think about sort of overall inventory and M&A, what sort of opportunities do you see? It's another good question. What I'll say is I've been very happy with the quality of resources that the company has in its portfolio. We're very fortunate to have some very solid, as you see in the IR deck, some SCOOP results, very good acreage. You can see in the Utica, very good well performance, good acreage, a lot of runway. Now we're recently talking about the Marcellus as far as the delineation, which the company has no value currently booked under. I mean, there's a lot of opportunities to actually take some advantage of actually accruing that value within the company by this delineation test. As we look at, you know, where our focus is, we see a really quality good asset base. We are gonna be putting focus on value of the company, increasing value of the company, improving margins, protecting the balance sheet, keeping the company healthy, very attractive, you know, with some attributes that are very favorable as we navigate this kind of volatile market throughout the next, you know, 12-18 months, and position the company in a really good place as we look at fundamentals changing and the gas macro changing, to be a, you know, to be a very attractive investment. That's kinda where we're focused, I think right now, relative to positioning the company for value enhancement, you know, kinda with an eye towards the future. If I could just add one last one just on that macro focus you mentioned. Bill, you mentioned the hedges a little bit. In today's market, you know, are you adding more hedges or, you know, would you wait until kind of see what prices do? I'm just wondering if the future curve still looks quite positive. Just I, I was wondering on your earlier comments, how much you're adding. Would you add in 2024? Are you adding 2024? Would you add in 2025? Just your thoughts on hedging here. Thanks. Yeah. Good question, you know, Neal. The answer is yes, we're gonna continue to layer on hedges. That's our philosophy as a company, and we'll continue to do that. We, you know, we put some hedges on in 2024 as recently as last week. We'll continue to do that, and we'll, you know, As I mentioned in my comments, we started doing 2023 basis. You can expect us to start looking at 2024 basis as well, going forward. We take a methodical approach to hedging, and we'll continue to do it, you know, as the opportunities present themselves. Glad you're doing it. Thanks, guys. Thanks, Neal. Thank you. Our next question will be from Tim Rezvan with KeyBanc Capital Markets. Please proceed with your question. Good morning, everybody. Thank you for taking my call. I'd like to start with digging into slide 11 a little bit on your 2023 development plan. Can you talk about why you chose the spot you did in Southeast Belmont for that Marcellus pad? Yeah. No, Good morning, Tim, and thanks for the question. You know, as we look at our leasehold around the area, I think what's attractive to that particular area is we have an existing pad out there with infrastructure lease roads that we wanted to take advantage of. There's also, you know, right across the river, a lot of activity in the Marcellus that's looks very attractive to us. Whenever you step back and take a look at where this delineation test is, you know, it gives us a lot of assurances that we're in a good spot here for a test. We can actually drill to the southeast and northwest to get a better handle on liquids content to see how prolific this side of the river is. That's basically the genesis of the location in Southeast Belmont for the test. Okay. I appreciate that. Then looking farther north, excuse me, in Ohio, a four-well pad is planned in western Harrison County. Without knowing where exactly the phase windows lie on this map, is that a dry gas target? Is that liquids rich? How are you thinking about, you know, liquids rich and dry gas overall, you know, in Ohio? Yeah, no, it's a great question. This is targeting, as it shows, for late in the year for a spud. This particular window here is definitely liquids rich and wet gas. You know, as we view it, the Marcellus to me is where we're gonna be drilling is liquids rich as well. The economics on these things should compete with regards to capital or, you know, or we wouldn't be prioritizing it. We feel pretty bullish about where it stands as far as, you know, ranks on the economic scale. I think, as we look at it between the mix, we have a lot of liquids rich production in the SCOOP. That's a toggle for us. We have some western type Utica acreage that we could kinda toggle for some liquids rich. We have dry gas that's solid in the, in the core of the Utica from Jefferson, Belmont down in Monroe. Now we're introducing a test in the Marcellus, which give us more optionality. The more triggers we have to pull and the more toggles we have for a variety of commodity type environments, depending on where prices go, it's nice to have a portfolio like that so you can kinda ebb and flow and reprioritize as needed. Okay. I appreciate that color. If I could ask, just sneak one last one in. I know, you know, post-restructuring you've been sort of there's been an intermittent program across your assets, and you can sort of see the, excuse me, the spud to pop schedule, you know, the variability, you know, across these pads. How do you think about it, running a more continuous program as, I guess, you get through 2023 and beyond? You've talked about, you know, reducing cycle times. You know, is your plan to kinda get rid of these extended spud to pop cycles? I guess, how do you think about that in terms of driving more efficiencies through the business? No, no, look, it's a great question, actually, Tim. I appreciate it. I think as we look at it, we look at it from purely a pad level type rate of return. Minimizing and optimizing that cycle time when you spend money and when you deliver revenue. What that means is there's gonna be some overlap, certainly in 2023, where we have, you know, a couple frack crews running, and there'll be times when we have zero frack crews running. I think as long as we keep those balances within, you know, a cadence of one to two crews, very manageable, and quite frankly, it's much more efficient and it's much more efficient from a capital efficiency standpoint and actually, you know, a return on the investment. you know, you're gonna see some rigs kind of the cadence of them will come. There'll be some overlap. you're gonna see frack crews somewhat overlap. Generally speaking, you know, it'll be that one-and-a-quarter type rig and, generally one frack crew throughout the year. There will be, though, however, some overlap as we look to optimize these cycle times and bring some value forward to the company. Okay, thanks, John. I appreciate all the color. Yeah, you bet. Thank you very much. Thank you. There are no further questions at this time. I'd like to hand the floor back over to John Reinhart for any closing comments. Yeah, I'd like to thank everybody for joining our call today. Appreciate the questions. We're very excited about 2023 and the development plan. The company's in a great position to be able to generate free cash flow at a variety of commodity prices, and we're very focused, again, to reiterate on when actually focusing and targeting those funds to increase value of the company. The toggles that we're using are the share repurchase program, which we've recently announced an extension on, as well as incremental leasehold to bolster our total footprint and grow some scale from an inventory perspective. Again, very excited about 2023 and look forward to sharing more about the results for our next quarter's call. Thank you very much. This concludes today's conference. You may disconnect your lines at this time. Thank you for your participation.