Ladies and gentlemen, thank you for standing by. Welcome to the W&T Offshore Third Quarter 2022 conference call. During today's call, all parties will be in a listen-only mode. Following the company's prepared comments, the call will be open for questions and answers. To ask a question, you may press star, then one on your telephone keypad. To withdraw your question, please press star then two. During the question and answer session, we ask that you limit your questions to one and a single follow-up. You can always rejoin the queue. 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. Please go ahead. Thank you, Gary. 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 third quarter 2022 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. Additional information concerning these factors are contained in our earnings release that we issued yesterday, as well as our public filings on Form 10-K, Form 10-Q, and 8-K with the SEC. Today's call may also contain certain non-GAAP financial measures. Please refer to the earnings release that we issued yesterday for reconciliations of non-GAAP financial measures to our GAAP results. With that, I'd like to turn the call over to Tracy Krohn, our Chairman and CEO. Thanks, Al, and good day to everyone, and thank you for joining us for our third quarter 2022 conference call. With me today are Janet Yang, our Executive VP and Chief Financial Officer, and William Williford, another Executive VP and Chief Operating Officer. They're both gonna be available to answer questions later during the call. We maintained our strong financial results in the third quarter, and 2022 is on track to be one of the best years in our long and profitable history. Our strategy has always been very simple, generate free cash flow, maintain high-quality conventional production, and opportunistically capitalize on accretive opportunities to build shareholder value. Our ability to execute and maintain strong operational excellence has been a significant driver in our outstanding financial results in 2022 and have continued in the third quarter. These are the key accomplishments we delivered in the quarter. We maintained solid production at 41.5 thousand barrels of oil equivalent per day at the midpoint of guidance. We reported net income of $68.2 million or $0.47 per share and generated adjusted EBITDA of $113.9 million in the third quarter. For the nineteenth consecutive quarter, that includes throughout the COVID and supply chain disruptions and everything, we had positive free cash flow, and in the third quarter, we produced $71.1 million of free cash flow. Both adjusted EBITDA and free cash flow have grown considerably in 2022. Year to date, we've totaled $497.6 million in adjusted EBITDA and $351.5 million in free cash flow. We increased cash and cash equivalents to $447.1 million, up 74% from a year ago. Hand in hand with our growth in cash has been a reduction in net debt. Our net debt is down almost 50% year-over-year to $254.3 million as of September 30, 2022. Our net debt to trailing twelve months Adjusted EBITDA continued to improve significantly to 0.5x or half turn compared to 2.5 turns or 2.5 x a year ago, which is well below our stated goal of 1x by year-end. We've maintained positive momentum with another outstanding quarter, thanks in no small part to the ability of both our operations, of course, kudos to our folks offshore and finance team to execute at a high level. In the third quarter, we also experienced sustained higher pricing and our realized price per barrel of oil equivalent before derivative settlements was $68.39, down less than 2% from the second quarter. Our average realized price for oil was $90.23 per barrel. For NGLs, we realized $37.17 per barrel, and for natural gas, $9.89 per Mcf, in each case, before derivative settlements. Our third quarter production of 41.5 thousand barrels of oil equivalent per day was down only about 2% from the prior quarter. We had no new wells come online and only spent $4 and a half million in CapEx in the third quarter. Nonetheless, we experienced minimum sequential production decline thanks to our conventional asset base and successful workover and recompletion program. The combination of strong production and continued strong pricing resulted in our outstanding Adjusted EBITDA and Free Cash Flow numbers. We've now generated almost half a billion dollars of Adjusted EBITDA in the first nine months of 2022. To put this in perspective, for both years, 2021 and 2020 combined, we generated $383.7 million of Adjusted EBITDA. Third quarter also marked the nineteenth consecutive quarter that we've generated that positive free cash flow. Our free cash flow in the first nine months of 2022 of $351.5 million is more than double the free cash flow that we generated in all of 2020 and 2021 combined. We're clearly in a much stronger financial position today, and we remain focused on operational execution to build on these solid results. Now, moving on to operations. We did not drill any new wells during the quarter, but we did perform two recompletions and five workovers that positively impacted production in the third quarter. We plan to continue to perform additional workovers and recompletions in 2022 that can benefit production and pay out quickly. Because we have no long-term rig commitments or near-term drilling obligations, we have flexibility to ramp up or defer capital opportunities. We're anticipating timing deferrals related to capital spending and now expect drilling in early 2023 that was originally expected in late 2022. As a result, we're reducing our CapEx range for 2022 by $10 million at the midpoint to between $65 million and $75 million. Now, in regard to future drilling, we're currently in the permitting and feed processes, as well as buying long-term and long lead items in preparation to spud our Holy Grail well at Garden Bank 783 in the Magnolia field in the second quarter of 2023. This is a potentially very large production increase for us going into latter part of 2023. With low Net Debt and a meaningful amount of cash on hand, we will continue to evaluate accretive acquisition opportunities that meet our criteria while systematically paying down debt. Our Net Debt decreased by $77.1 million in the third quarter of 2022 to $254.3 million due to the increase in cash and cash equivalents resulting from strong cash flows throughout the quarter, driven by stable production and high oil and natural gas prices. As of September 30, 2022, we had available liquidity of $497.1 million, comprised of $447.1 million in cash and cash equivalents, and $50 million of borrowing availability under our revolving credit facility. As noted in our release yesterday, we recently amended the credit agreement for that facility and extended the maturity date and revolver commitment to January 3, 2024. In regard to our senior second lien notes due November 2023, we continue to evaluate refinancing options. Should capital markets remain volatile, we're confident that we're able to repay these notes prior to maturity out of future expected free cash flows, our substantial cash on hand of $447 million, and access to our unused $100 million at-the-market equity program. Additionally, we have $50 million in liquidity on our undrawn credit facility and natural gas calls that are currently worth $30-$40 million that can be monetized quickly. Looking ahead to fourth quarter of 2022, our guidance for production is between 38,000-42,000 barrels of oil equivalent per day. Fourth quarter Lease Operating Expense is expected to be between $67 million and $73 million, which includes increased workover and facilities expense activity. Cash G&A costs are expected to be between $17 million and $19 million. LOE and G&A costs estimated for the fourth quarter reflect some of the same cost inflation that the entire industry has faced. Our budget for capital expenditures in 2022 was reduced to $65 million-$75 million for the full year, which excludes acquisition opportunities. Included in this range are costs already incurred with wells drilled earlier this year and planned fourth quarter expenditures related to long lead items for our Holy Grail well, as well as capital costs for facilities, leasehold, seismic, and recompletions. The reduction in our capital expenditures budget for 2022 is primarily related to receiving the permit for a riser for the Holy Grail well later than we had previously anticipated. In regard to ARO expenditures, given the spending incurred to date, including $21 and a half million in the third quarter, we adjusted our range for P&A expenditures to between $65 million and $75 million. Continuing to actively address our abandonment requirements is an important part of our ESG focus and leads to greater long-term sustainability. As a reminder, all of our guidance can be found in yesterday's press release. In closing, 2022 has been an outstanding year for us operationally and financially. As you can see, we're poised for continued success in this strong commodity price environment with stable production that we expect to support our positive outlook on continuing to generate Free Cash Flow. We have generated record Free Cash Flow and Adjusted EBITDA thus far in 2022, and we expect continued growth in the fourth quarter. Our substantial cash position of $447.1 million, ability to generate free cash flow from operations, and access to an additional $150-$200 million in liquidity via our undrawn RBL ATM equity sales program and monetization of long calls provide clear line of sight to either eliminate or refinance our decreasing debt position. Our strong financial position will provide us with optionality and flexibility moving forward. We'll continue to evaluate growth opportunities both organically and inorganically, and we're poised to execute on accretive opportunities that meet our long-standing and proven criteria while continuing to prudently manage our balance sheet. We believe the Gulf of Mexico is and will continue to be a world-class basin with strong producing assets. Leveraging our nearly four decades of experience in the Gulf of Mexico to quickly evaluate and execute on opportunities within our focus area has always been a key 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 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 excited about the bright future for W&T and look forward to continued success in 2022 and beyond. With that, operator, we can now open the lines for questions. Operator, did you copy that? Pardon me. We will now begin the question-and-answer session. Okay. To ask a question, you may press star, then one on your telephone keypad. If you are using a speakerphone, please pick up your handset before pressing the keys. To withdraw your question, please press star then two. Please limit your questions to one and a single follow-up. At this time, we will pause momentarily to assemble our roster. Our first question is from John White with Roth Capital. Please go ahead. Good morning. Congratulations on a very fine quarter. Thanks, John. On the CapEx reduction, the minor CapEx reduction, is that related to the lack of availability of oil field service equipment? You had mentioned the riser for the Holy Grail. No, it's really more associated with permitting. We've made a pretty good effort to acquire long lead items. The riser itself is where we wanted to focus and had some concerns, and BSEE, in examining it, took a very methodical approach to it. I can't disagree with you know, the way they've worked to you know, to make this as safe as possible. Of course, we have the same goal. I think that we have a very in-depth understanding of what we need to do and we're talking about dry trees on a floating facility and single barrier, what are called single barrier risers, that were already in place before new regulations. We wanna make sure they're right and BSEE wants to make sure they're right as well. We're doing relatively well on the longer lead items. There have been some delays, but not really more delays in that would've affected being able to put a rig on location. We're in that phase now, working with BSEE to have the permits completely buttoned up and start putting the rig on location. Thanks for that detail. Back to Holy Grail. What's your working interest there? 100%. Fantastic. To the northeast, you've got another one, ST 320 SS number one. Your slides show that's scheduled for fourth quarter 2023. How's that coming? Well, we're gonna compare that with our available set of opportunities as we go through the year and see where that ends up at the end of the program with regard to the other commitments we've made for drilling. Okay. You know, I've followed the company or covered the company for a number of years. Mm-hmm. I've never seen you in a stronger financial position. Congratulations again. Thanks, John. Thank you very much. I'll pass it back. The next question is from Derrick Whitfield with Stifel. Please go ahead. Good morning, all, and thanks for taking my questions. Thank you, sir. With respect to Q4 guidance, could you offer some color on the unplanned downtime at the Neptune fields and temporary maintenance downtime at Mobile Bay fields? Yeah. to be resolved before Q1. Yeah, sure. We're down about 1,500 barrels oil per day at the midpoint. Again, this is unplanned downtime at the outside-operated Neptune field. There's a blockage in one of the risers there. They're trying to generate a work plan to overcome that. They're having some success at doing that. It's just taking longer than anybody would want to. We would want it to take. Temporary maintenance downtime at Mobile Bay was pipeline related. That's been resolved and the leak repaired and clamped off. We didn't see that as a continuing type of operation. That's really primarily the causes there. Terrific. With regard to the slight delay with the Holy Grail well, it sounds as though that's primarily attributed to the regulatory side. With that- Uh- Sorry about that. Do you guys have any concerns in advancing the permit, or is it simply just taking longer to process? No, we're not thinking that we have concerns with advancing it. The process is taking longer. We've actually got a permit approval subject to certain conditions which we need to satisfy before we start drilling the well. I'm not concerned about the efficacy of the permitting at this point. I'm really, you know, we're ready to get started. There's not, you know, too much that we need to do to prep the platform and to be putting the rig on site. That's helpful. Thanks for your time. Sure. Thank you. Again, if you have a question, please press star then one. The next question is from Jeff Robertson with Water Tower Research. Please go ahead. Thank you. Tracy, from a conceptual standpoint, can you talk about how you think about liquidity in 2023 with respect to refinancing the second lien notes? You added $70 million in cash to the balance sheet in the third quarter. W&T is positioned to generate a lot of free cash flow in 2023. As you look at those notes and the balance sheet and opportunities in the capital program and also perhaps in the acquisition market, just how do you think about positioning the company with enough dry powder to take advantage of opportunities next year? That's a great question, Jeff. Thank you. We've planned pretty hard to make sure that we were able to repay these notes. We've been fortunate in that we made some good choices with regard to how to hedge this and give us protection. We picked up another, you know, $150 million or so as a result of that. You know what was arguably a trade for protective purposes, but it just turned out to be very successful on the long gas calls. With regard to the refi, you know, we're in the enviable position of knowing that we can refi. It's not a matter of whether we can refi. We certainly can. The markets have been in flux here lately, with increases in interest rates and bondholders being somewhat hesitant and the stock market being affected by the Fed speak, if you will. We're being patient here in thinking that we know we can refi. Not our worst case, but one potential is that we just hang tight, and we repay the debt over time. Then the next one is we reload somewhat to handle any acquisitions that might come up. We're fortunately blessed with the optionality. That's the best I can say about that. That is not a simple feat. My kudos to our team for making that possible. It's good to be in a position where you can do something and you don't have to do it. I think the balance sheet appears to give you all better terms to dictate what happens as opposed to being subject to the market forces. Yes. At Magnolia or at Holy Grail, can you share an estimate of what that well will cost? Yeah. The current estimates are around 80, drill and complete. Okay. If it spuds in the second quarter, I think you said you would expect it to be on in the second half of 2023. Is that correct? Yes, sir. Thank you very much. Probably fourth quarter. Yeah, probably fourth quarter. Okay. Thank you. Yes, sir. Thank you. The next question is a follow-up from Derrick Whitfield of Stifel. Please go ahead. Yeah, guys, just one quick follow-up question and really more of a build on Jeff's question. I wanted to ask if you could speak to the A&D environment in the Gulf at present, and similar to onshore, are you guys seeing greater deal flow as a result of relatively strong commodity prices in a less certain economic backdrop? Yes. I can say that. I think what we have seen is greater volatility in pricing and markets. I think that affects everybody's thought process about how they're gonna proceed with these things. You know, I've always told everyone that we make acquisitions in high pricing environments and low pricing environments. Very often we see higher pricing environments lead to better execution on the acquisitions. Fortunately, since you know nearly 25, 30 years now, we've had the availability of being able to do hedging to help protect some of those acquisitions. Normally, when we make a larger acquisition, we have some debt, but we also attach a little piece of equity to it. With that, you know, we're very cognizant of acquisitions and making sure that they are accretive. So anything that we would do would be certainly accretive to our balance sheet in that we would also seek to protect our leverage ratios. Terrific. Thanks for your color. Yes, sir. Thank you. Showing no further questions, this concludes our question-and-answer session. I would like to turn the conference back over to Tracy Krohn for any closing remarks. I think it's been a very good quarter for us. I'm looking forward to the rest of the year and the years after that. I like the way the company looks right now with our balance sheet, and feels good to be in a position where you can pay off all the debt as well, or, you know, carry it further into the future with a modest amount of debt and leverage by making accretive acquisitions. We're very pleased to be where we are. Again, this is reflective of our operational and financial teams to make this happen. I'm just very, very delighted to be still here and making this company stronger and nobody does it by themselves. My sincere appreciation to our teams for getting that done. With that, we'll talk to you again soon. The conference is now concluded. Thank you for attending today's presentation. You may now disconnect.