Ladies and gentlemen, thank you for standing by, and welcome to the W&T Offshore Q2 2023 conference call. During today's call, all parties will be in a listen-only mode. In following the company's prepared remarks, the call will be open for questions. During the question and answer session, we ask that you limit yourself to 1 question and 1 follow-up. You may always rejoin the queue if you have an additional question. To join the queue, you may press Star, then 1 on your touchtone phone, and to withdraw yourself from the queue, please press Star, then 2. This conference is being recorded and a replay will be made available on the company's website following the call. I would now like to turn the conference over to Al Petrie, Investor Relations Coordinator. Thank you, Joe. On behalf of the management team, I would like to welcome all of you to today's conference call to review W&T Offshore's Q2 2023 financial and operational results. Before we begin, I would like to remind you that our comments may include forward-looking statements. It should be noted that a variety of factors could cause W&T's actual results to differ materially from the anticipated results or expectations expressed in these forward-looking statements. Today's call may also contain certain non-GAAP financial measures. Please refer to the earnings release that we issued yesterday for disclosures on forward-looking statements and the reconciliations of non-GAAP measures. I'd like to turn the call over to Tracy Krohn, our Chairman and CEO. Thanks, Al. Good day, everyone, thanks for joining us this morning. With me today are William Williford, our Executive Vice President and Chief Operating Officer, Samir Parasnis, our new Executive Vice President and Chief Financial Officer, and Trey Hartman, our Chief Accounting Officer. They'll be available to answer questions later. Before I get into the operational and financial results, I would like to welcome Samir Parasnis, who joined us as our new CFO in early July. We've been working with Samir for years. He was a trusted advisor at Stifel and instrumental in helping W&T complete some key strategic initiatives. Some of these included our drilling joint venture and corporate debt refinancing in 2018, term loan financing in 2021, and the at-the-market equity offering in 2022. Needless to say, Samir already has a strong working relationship with our senior leadership team, his extensive capital markets and financial experience will be valuable to W&T moving forward. Let me begin by reviewing our long-standing and successful strategic rationale. Our strategy has always been simple: generate free cash flow, maintain high-quality conventional production, and opportunistically capitalize on accretive opportunities to build shareholder value. We've delivered 22 consecutive quarters of free cash flow because we prioritize cash flow, brutally invest capital, we have a valuable asset base that delivers strong production and generates meaningful Adjusted EBITDA. Let me put that into perspective for you. We have generated positive free cash flow for every quarter since the beginning of 2018, successfully navigating through the COVID-19 pandemic, highly volatile commodity prices and several economic cycles. By prioritizing cash flow, we ensure we maintain a strong balance sheet with ample cash to opportunistically acquire complementary assets. We began 2023 by redeeming all of our outstanding 2023 senior second lien notes and issuing new 2026 second lien notes. This significantly reduced our debt and interest payments while strengthening our balance sheet. This provided us with financial flexibility in the uncertain economic environment we've seen so far in 2023, 2023, that's included much lower natural gas prices and softer oil prices. Because of those factors, we decided to proactively reduce our current year capital budget and delay a significant portion of our drilling capital investments until 2024. We believe that a lower pricing scenario enhances acquisition opportunities. We have a strong cash position and balance sheet to act quickly could we see the right acquisition opportunity arise. We feel that patience is important as we're looking for strategic, strategic value and free cash flow generation potential in all acquisition opportunities that we are currently evaluating. Over the years, we've created significant value by seamlessly integrating producing property acquisitions, while maintaining strong operational excellence, and we plan to continue to do so in the future. We foresee a number of opportunities arising that will allow us to continue with that strategy. In the meantime, assuming no acquisitions for the remainder of the year, we are reducing our capital expenditure plans for 2023 from a range of $90 million-$110 million to $50 million-$70 million, and are focused on maintaining cash. This will delay some production uplift from our drilling program, but we will continue high rates of return recompletion and workover projects to help mitigate decline and maintain those production levels. One of the most attractive attributes of our asset base is our ability to adjust our drilling plans without losing drilling opportunities, since our leases are largely held by existing production. Turning to Q2 results, I would like to point out some key highlights and accomplishments. We increased production by 14% - 37,000 barrels of oil per day, which was at the midpoint of our guidance. As expected, production recovered from 32,000 barrels of oil equivalent per day in the Q1 due to planned and unplanned downtime. We generated strong Adjusted EBITDA of $38.8 million. We reported $26.2 million net cash from operating activities and generated $9.7 million of free cash flow, our 22nd consecutive quarter, despite continued softening of commodity pricing. We maintained a strong cash balance at the end of the Q2 with cash and cash equivalents of $171.6 million and an undrawn RBL with a $50 million base. Gives us significant dry powder to continue to evaluate meaningful acquisition opportunities in the Gulf of Mexico. Overall, our net debt remains low at $231.9 million at June 30, 2023, and reducing by virtue of amortization of debt at Mobile Bay, and our Net Debt to Trailing Twelve Months Adjusted EBITDA is just 0.9 times, or less than a turn. We reported mid-year SEC proved reserves using SEC pricing, of $157.7 million barrel oil equivalent. The reserves were prepared by our third-party independent engineering reserve consultants, Netherland, Sewell & Associates. The PV-10 value of those reserves is $2.1 billion. We clearly adhered to our strategy and delivered sustainable and consistent results. We believe that continued success is driven by the ability of both our operations and finance teams to execute at a high level, and our outstanding base in the Gulf of Mexico helps with that effort. Coupled with our ability to pay down debt and improve our balance sheet, we're clearly in a much stronger financial position today. We remain focused on operational execution in 2023 and beyond to continue building on those outstanding results. Last call, we discussed that in the Q1 of 2023, we had several planned periodic facility and pipeline maintenance projects underway at the Mobile Bay field that required us temporarily shutting the field. We also experienced some unplanned downtime at several non-operating fields that temporarily reduced our production volumes in the Q1. These events contributed to the lower Q1 2023 production levels. As you saw with our Q2 production of 37,000 barrels of oil equivalent per day, an increase of 14%. Production deferrals are now behind us. Our production was in line with guidance, that being 1.3 million barrels of oil, 443,000 barrels of NGLs, and 10 Bcf of natural gas for the quarter. Taking into account the reduction of capital for 2023, we expect to see modest declines in the second half of 2023, with Q3 2023 production guidance midpoint only down 4% compared to Q2. We've focused on acquisitions over the last years, last few years, rather than on drilling many new wells. Our guidance reflects the low natural decline of our asset base compared with much higher declines than unconventional onshore reservoirs. We saw the benefit of 7 workovers during the Q2, and we'll continue to focus on high-returning workover and recompletions to help mitigate production declines in the second half of 2023. Well, on the cost side, we continue to see inflationary pressures in the industry, but our Q2 results were very encouraging as we were able to maintain lease operating expense nearly flat compared to the Q1. With production increasing 14% and costs essentially flat, our per barrel LOE declined from $22.29 in Q1 2023 to $19.60 in Q2 2023. We remain focused on cost control and margin expansion despite the current inflationary environment. For the Q3, our guidance for lease operating expense is expected to be lower, so between $60 million and $67 million. We also continue to control our G&A costs. In the Q2, cash G&A costs were $15.3 million, down 14% from $18 million in Q1 2023. For the Q3, we are expecting cash G&A to increase modestly between $15.4 million and $17.3 million. We'll continue to manage controllable costs to help maximize our margins. Turning to our balance sheet, during 2023, we've reduced total debt by almost $300 million from year-end 2022. At the end of the Q2, we had net debt of $231.9 million, which was total debt of $403.6 million, net of cash and cash equivalents of $171.6 million. As I mentioned previously, the large reduction in total debt was driven by issuing new 2026 Senior Second Lien Notes in January 2023, at par, totaling $275 million in a private offering and using the proceeds, along with a portion of our considerable cash position, to retire all of our outstanding 2023 Senior Second Lien Notes. We continue to have the flexibility and dry powder to make additional acquisitions, continue to build cash, further paying down debt. Because we have no long-term rig commitments or near-term drilling obligations, we do have the flexibility to ramp up or defer capital opportunities. We will continue to defer capital expenditures in 2023 as we monitor current commodity pricing, environment, and service costs. In Q2 2023, we spent $15.6 million in CapEx and have invested $23 million for the first six months of this year. As I mentioned, we have lowered our CapEx range for 2023 by about $40 million to now be in a range of $50 million-$70 million. Included, included in this range are planned expenditures related to long lead items, capital costs for facilities, leasehold, seismic, and recompletions. We expect to continue generating meaningful free cash flow, which provides this flexibility to execute on accretive opportunities quickly. Before I close the call, I'd like to talk to you about our midyear 2023 reserve report. I'd like to point out that we continue to see positive well performance and technical revisions, which demonstrates the strength of our world-class management of GOM assets. This also directly points to our ability to enhance production in our reserve base through operational excellence. For midyear 2023, we reported SEC proved reserves of 157.7 million barrels of oil equivalent, which included 3.5 million barrels of positive performance revisions, offset by a decrease of 4.8 million barrels due to pricing revisions and production of 6.3 million barrels of oil. We're pleased with these results, since over the past 18 months, we've focused on reducing net debt while completing bolt-on acquisitions and less emphasis on drilling. The impact of lower pricing is also seen in the PV-10 value of our SEC approved reserves, which was $2.1 billion, a decrease of 35% from year-end 2022. Approximately 36% of midyear 2023 SEC proved reserves were liquids, with 24% crude oil and 12% NGLs, and we had 64% natural gas. Our large natural gas reserve position has very good upside potential from future higher prices. The market is anticipating increased demand for natural gas and a related strong price recovery when the new LNG export facilities along the Gulf Coast are online in 2024. All of our reserves are well positioned to benefit from that increase in demand. Our reserves were classified as 71% Proved Developed Producing, 16% Proved Developed Non-Producing, and 13% Proved Undeveloped. Midyear 2023 proved reserves and PV-10 were based on average SEC 12-month crude oil and natural gas prices of $83.23 per barrel and $4.76 per MMBtu. year-end 2022 prices were $94.14 per barrel of oil and $6.36 per MMBtu of natural gas. We believe we've built a sustainable group of high-performing GOM assets that will continue to provide meaningful cash flow to our shareholders for many years. With regard to our ongoing ESG initiatives, and initiatives, we've made a concerted effort in addressing shareholder concerns and improving our ESG metrics. W&T's culture of success and sustainability is built on environmental stewardship, also sound corporate governance, and contributing positively to our employees and the communities where we work and operate. Earlier this year, we added a new board member, Dr. Nancy Chang, who is the chair of our Environmental, Safety and Governance Committee that oversees our ESG efforts. We believe that Dr. Chang will help guide our, our continuous improvement and assist us in our commitment to the highest standards of ESG and corporate governance. Our ongoing commitment will be demonstrated when we issue our 2022 Sustainability Report in the next few weeks. That's going to highlight our continued progress in our ESG efforts. In closing, we're very pleased with how well we've performed thus far in 2023, both operationally and financially. I'd like to thank our strong team at W&T, which I believe we're well positioned for continued success in the future. This strong financial position provides us with optionality and flexibility moving forward. Our liquidity and cash position enables us to continue to evaluate growth opportunities, both organically and inorganically, and we are poised to execute on accretive opportunities that meet our long-standing improvement criteria. We believe the Gulf of Mexico is and will continue to be a world-class basin with strong producing assets. Quickly evaluating and executing on opportunities within our focus area is a pillar of our success. We have a premier portfolio of both shallow water and deepwater properties in the Gulf of Mexico that have low decline rates and significant upside. Our management team's efforts and interests are highly aligned with those of our shareholders, given our 34% stake in W&T's equity, which is one of the highest of any public E&P company. As a shareholder, I'm very confident that W&T's bright future in 2023 and, and beyond is, is not in question. Operator, we'll now open the lines for questions. We will now begin the question and answer session. To ask a question, you may press star, then one on your touchtone phone. If you're using a speakerphone, please pick up your handset before pressing the keys. To withdraw your question, please press star, then two. At this time, we will pause just momentarily to assemble our roster. Our first question will come from John White with ROTH MKM. Please go ahead. Good morning. Thanks for taking my question. I was wondering, does the reduction in capital expenditures for the remainder of the year, does that in some way reflect increased optimism about potential acquisitions? ...Well, in a word, yes. As usual, John, you, you, you put your, your, your, your finger on a very substantial portion of the thinking. We're, we're, we're always gonna look out for, for different opportunities. They ebb and flow a little bit, yeah, that is a substantial part of the thought process here. Okay. That's. I appreciate the straightforward answer. I'll pass the call back to the operator. Thank you. Thanks, John. Our next question will come from Nathaniel Pendleton with Stifel. Please go ahead. Good morning, all. Congrats on the strong quarter. Thanks, Nate. Could you offer some more color on the service environment that you alluded to earlier, in the GOM and its impact on your capital investment decisions? Sure. We are in the process for one, we're in the process of servicing and refurbishing a drilling rig that a platform rig that'll go out to Magnolia to drill our Holy Grail prospect. We decided to defer on that a little bit not only because of winter months coming up, but also because there's a good bit of uncertainty on pricing at the moment. It's, you know, I hear a lot of different opinions. I have opinions of my own, and we do see some inflation in pricing, particularly in transportation, which is one of our key components. Boats are more expensive. They're more difficult to get. A lot of this is seasonal, and that breaks a little bit in, in, in the wintertime, because of the weather. People often think that, that, that issues with drilling occur in the summer due to hurricanes, but they're really more obvious in the winter because of continued wave activity and wind and whatnot, that affects our, our, our vessels and helicopters out there. I, I do see upward inflation pressure with personnel and, and the costs, and, and, and, and, and in fact, in some, in some cases, with regard to quality. I, I, I think that's, that's a little bit more empirical, but it's still a factor for us. I think that, we're seeing the supply chains get a little better, but I think, as the cost of goods is concerned, that we're seeing a plateau there at this point in time. Services are a little bit of a different story. We wanna make sure that we're well ahead of the curve in getting personnel and equipment where we need to have them at the right time. That's part of the equation. Plus, the continuing softening in commodity prices makes it more difficult for everyone. Thanks for the detail. Regarding your prior comments exploring CCS, can you speak to what you see as the advantages of W&T and the potential of doing offshore CCS versus onshore? Yeah, sure. I mean, we've, we've got the infrastructure to do it. What, what people need to be aware of with regard to underground sequestration is that it takes a long time to get the permits. Until that changes, I, I don't feel the need to, to, to, to go out and, and do a great deal of effort on that. The, the, the real technology is the, the technology coming off the flue gas stack and how to separate that out and get it offshore. People think that it's just CO2, and it's not. There, there's a whole whole slew of of gases and particulates that, that come along with that. It has to be separated out over, you know, before you, you start dumping just pure CO2 into the ground. It, it, it's doubtful that it'll just be pure CO2. There will probably be some, some other components, maybe, nitrates and, and, sulfur dioxide, nitrogen. There's, of course, a compound release, flue gas emissions. I, I, I don't really see the, the value in, in going out and spending a great deal of money. We already have reservoirs that, that fit the description, of, of what you'd need to be able to encapsulate huge volumes of, of CO2, in, in the ground. The, the real problem, again, tends to be the permitting. There isn't primacy in Louisiana or Texas at this point in time, or Alabama, for that matter. I think that until that permitting process speeds up, it's a little bit of a waste of our energy. I'd rather focus on things that generate cash flow at this point in time. Got it. Thanks for taking my question. Yes, sir. Our next question will come from Jeff Robertson with Water Tower Research. Please go ahead. Thank you. Good morning, Tracy. Good morning. You, you talked a little bit about, about your pricing outlook and maybe some of the volatility that, that you see and you see other people talk about affecting your decision on capital spending. Are you seeing pricing volatility concerns play their way into valuations in the acquisition market? Yeah, we are. Clearly, it's a almost week by week, maybe even day by day, factor in everything that we do. You know, oil and gas commodity projects are always affected by price the most. We do see that. I, I can't tell you what the price is gonna be a week from now, but I can tell you that we are not hedged on oil at this point in time. We're pretty heavily hedged on gas at our Mobile Bay facility, but all the rest of the corporate company gas is not hedged, and the oil isn't hedged either. I, I don't know which way prices are gonna go, but my perception is, for the short term, they're going up. You all have, excuse me, June 30, $170 million, or a little over $170 million of cash on the balance sheet. Can you talk about funding considerations for an acquisition, maybe, if you, if you just assume do one with all cash, would you use debt? I'm sure it all depends on the size of, of the opportunity, but can you just share your thoughts around how all that plays out? Yeah. You know, we, we look at them all as individual entities for purchase, not necessarily on a corporate basis, but as properties, we think of them as all hybrids. You know, some of them have more proved producing reserves, some of them have more Proved Undeveloped reserves, some of them have high pipe in disproportionate numbers. Some of them have better cash flow than others. Some of them have more abandonment and decommissioning liabilities. They're all different. Of course, then there's the size. Size does matter here. I think it's important that you understand the liabilities around the properties very well. You know, we've done over $1 billion of decommissioning over the years. We think that's an important consideration that a lot of the private equity entities that have gotten involved in this business really have not paid that much attention to. Perhaps it's, it's more because they're, they're concerned about they're not as concerned about that because they're, they're, they're not strategic players. But I, I, I would tell you that, that, you know, the, the ideal set situation is a, is a property with good cash flow and, and, and something that we can consider upside with, with the drill bit, that we might be able to drill and, and, and bring to fruition. The, the, the rest of it is, is workovers, recompletions, facility upgrades that we, that we can do to generate cash flow short term. They're all a little bit different. We, we've seen a bunch of different properties over the years, so we, we have a pretty good appreciation of, of, of the things that, that, that have value and also take away from value. Thank you. Sure. Again, if you have a question or a follow-up, you may join the queue by pressing star, then one. Our next question is a follow-up from John White with ROTH MKM. Please go ahead. Yeah, I wanted to come back on and I had another question, but also wanted to offer my congratulations to Samir on his recent appointment, and I look forward to working with him going forward. Hey, thank you, John. I appreciate it. I look forward to working with you as well. Great. Tracy, did your previous comments on Holy Grail, did those comments indicate that well has been pushed into 2024? Yes, sir. Yeah, that's, that's, we expect to begin there around February of 2024. Okay. Thank you. I'll pass it back to the operator. Yes, sir. This will conclude our question and answer session. I would now like to turn the conference back over to Tracy Krohn for any closing remarks. Thanks, Operator. Look, we appreciate your attention. Hopefully, we'll have some other news before our next conference call. We look forward to talking with you again soon. Thank you very much. The conference has now concluded. Thank you very much for attending today's presentation. You may now disconnect your lines.