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Good day, everyone. My name is Kelly and I'll be your conference operator for today. At this time, I'd like to welcome everyone to the Laredo Petroleum Inc. Q2 2022 Earnings Conference Call. Today's call is being recorded. All lines have been placed on mute to prevent any background noise. After the speakers' remarks, there will be a question-and-answer session. [Operator Instructions] It is now my pleasure to introduce Mr. Ron Hagood Vice President of Investor Relations. Please go ahead sir.

Thank you and good morning. Joining me today are Jason Pigott, President and Chief Executive Officer; Karen Chandler, Senior Vice President and Chief Operating Officer; Bryan Lemmerman, Senior Vice President and Chief Financial Officer; as well as additional members of our management team. During today's call, we will be making forward-looking statements. These statements including those describing our beliefs, goals, expectations, forecasts, and assumptions are intended to be covered by the Safe Harbor provisions of the Private Securities Litigation Reform Act of 1995. Actual results may differ from these forward-looking statements for a variety of reasons, many of which are beyond our control. In addition we'll be making reference to non-GAAP financial measures. Conciliation to GAAP financial measures are included in the press release and presentation we issued yesterday that detail our financial and operating results for second quarter 2022. Press release and presentation can be accessed on our website at www.laredopetro.com. I will now turn the call over to Jason Pigott, President and Chief Executive Officer.

Thank you, Ron. Good morning and thank you for joining us for our discussion of our second quarter results. Our financial and operational results for the quarter, we have also updated our 2022 outlook, and given capital and oil production projections and updated free cash flow sensitivities for 2023. I'll start with our quarterly results. Our second quarter results exceeded expectations delivering company record adjusted EBITDA and free cash flow. Second, we immediately began delivering on our $200 million equity repurchase program and debt reduction targets we announced on May 31st. To-date, we repurchased $16.1 million of equity and $91.4 million of face value term debt. In addition to reducing absolute debt, our leverage ratio decreased from 1.9 times in the first quarter to 1.4 times in the second quarter. Third, we continue to demonstrate capital discipline. Second quarter capital came in a little higher than expected, primarily due to acceleration of operations associated with the timing of ongoing completions, associated facilities, and a small amount of non-op activity that was expected in the second half, not changing our full year 2022 capital budget of $550 million. Moving to our updated 2022 and 2023 outlook. At the end of the second quarter, we turned into line a six-well package the leach wells consisting of six 15,000-foot wells in our most southeastern unit in Howard County. These wells are still in the flow light stage. The oil production ramp has taken much longer than the offset wells and the wells are underperforming our prior forecast. Oil production for full year 2022 is now expected to be between 38,000 and 39,000 barrels of oil per day versus prior guidance of 39,500 to 42,500 barrels of oil per day. Full year 2022 free cash flow at prices of $100 per barrel WTI for the remainder of the year is now expected to be approximately $280 million versus prior projections of $350 million. Our initial outlook for 2023, we have incorporated the impact of the leach package, our current capital expenditure projection, additional drilling and completion efficiencies, and interest savings from debt repurchases to date. Currently, a $90 per barrel WTI price for 2023, we expect free cash flow of approximately, $560 million versus prior projections of $550 million, and expect low single-digit oil growth compared to the new 2022 oil production range. Stress that, nothing has changed the trajectory of the company, or our debt reduction and equity repurchase plan. There's no impact to inventory counts, or how we execute our development plan. For all financial impact of all of our updates over the second half of 2022, and full year 2023 is approximately $60 million. We are committed to delivering on our $200 million equity repurchase program, absolute debt reduction target of $700 million, and our leverage ratio target of sub 1.0 times. I will now turn the call over to Karen.

Thank you, Jason, and good morning. In the second quarter, we completed 11 wells and killed seven wells. Production was within our guided ranges, even when including the working interest adjustments to wells that reached payout prior to the quarter that was outlined in the earnings release. Total expenditures were slightly above expectations, mainly due to a slight acceleration of operations, associated with the timing of ongoing completions and associated facilities, and acceleration into second quarter of a small amount of non-op capital that was expected in the second half. About a quarter of the increase was due to inflation, which was primarily related to diesel expenses running over 40% higher on average than our original estimates. For second half, we have incorporated these higher diesel costs into our capital numbers. We expect capital to be approximately $120 million in both the third and fourth quarters and to maintain our full year 2022 budget of $550 million. As Jason mentioned, six of the seven wells that we killed during the quarter were 15000-foot Wolfcamp A wells in the leach package, developed on the fuller southeastern edge of our central Howard acreage position. We generally feel that, rock quality in Howard County degrades to the South. Very good well control and data from previous packages in and around the leach area, and decided to take measures to de-risk the package and improve projected returns based on this information. We developed only the Wolfcamp A formation, despite traditionally co-developing with the Lower Spraberry, also widened spacing in the Wolfcamp A. These changes resulted in a six-well development in the unit versus our standard development plan of 12 wells per DSU. Despite these efforts production results have been disappointing. The leach package has been on pull back for a little more than two months and is still producing significant amounts of water and low oil production. We're currently working on options to optimize our artificial strategies and evaluating other potential remediation strategies as we continue to watch, and gain additional understanding of the well production over time. Given the abundance of offsetting well data in Central Howard, the remainder of our development being west and north of the leach wells, we do not believe this impacts, any of the 23 remaining locations in Central Howard. These locations five are expected to come online in 2023 and direct offsets to the Worthy/Buchanan and Connor packages completed in fourth quarter 2021 and first quarter 2022, respectively. 18 are expected to be developed in 2024 giving us plenty of time to find earnings from the leach package and adjust how those DSUs are developed if needed. 2012 results do not impact our long-term trajectory or door counts, the deep inventory of high-quality drill-ready locations, and flexibility in our development plan. The remainder of oil fields in 2022 are all in North Howard and more than 90% of oil fields in 2023 are in North Howard. [indiscernible] rock quality is substantially better in Howard County as you move Northwest and as you can see on slide 6 in earnings presentation, our production data bears that out. Focus on North Howard in the second half of 2022 and full year 2023 this is our oil production expectations for 2023. In the preliminary 2023 outlook, we issued within our earnings release our projection of low single-digit oil growth compared to updated guidance for full year 2022 is driven by the expected productivity of North Howard. Within our preliminary 2023 outlook, we have a capital estimate of approximately $585 million. Primary difference from the $550 million budget in 2022 is related to the spot frac crew that is currently anticipated to operate for most of the first half of the year. The continued performance improvements in drilling feet per day, we are anticipating being able to run a spot frac crew for a total of five months without adding any additional drilling activity above our current two rigs. Overall keeping our DUC count low and using the spot frac crew as early as possible in the year provides our most capital-efficient operations program. This additional completions activity is also the reason we are able to fully offset the expected negative production impact from these wells next year. I will now turn the call over to Bryan for a financial update.

Thanks, Karen. We delivered very strong financial performance in the second quarter. We generated company record free cash flow and adjusted EBITDA. We took our revolver balance to zero. We reduced leverage by 0.5 turn and we aggressively repurchased our debt and equity fulfilling our commitment to return capital to shareholders. Taking a look at the balance sheet. We ended the quarter with $146 million of cash. And as of Tuesday, we have approximately $114 million of cash with our revolving credit facility completely undrawn. Liquidity stands at $1.1 billion with quarter end leverage at 1.4 times. You reiterate our leverage goal of achieving a sub-onetimes leverage goal, which we believe we will achieve in Q2 of 2023. Also reiterate our absolute debt reduction target of $700 million putting us at approximately $700 million of net debt. The $700 million target leaves us in a position to be approximately one times levered in lower price environments. Through Tuesday, Laredo has purchased $91.4 million of our notes at an average price of $98. These purchases have been skewed toward the 2029 and 2028s, with approximately $52 million of the 2029, $29 million of the 2028s and $11 million of the 2025s purchased to date. We plan to repurchase a total of $250 million of notes through the end of the year. On the equity side of the equation, through Tuesday's trading, we have repurchased approximately $16 million of our stock at an average price of $87.62 a share. We will continue to repurchase shares somewhat methodically. But when our share price indicates that we can repurchase our shares, which are a proxy for our assets, at prices below where assets are trading on the M&A market, we will accelerate those repurchases. Free cash flow for the second quarter came in at $110 million, in line with our expectations and these cash flows were directed towards our debt and equity repurchases. Dated for current guidance, under the same pricing scenario we used in our last guidance, Laredo is expected to generate $280 million of free cash flow for 2022 and approximately $840 million of free cash flow through the end of 2023. This represents a decrease over the two-year period of approximately $60 million over our prior guidance. On the M&A front, we have been actively looking at opportunities in the market and have not found many that have the right mix of inventory to PDP. Do still believe that scale matters and that M&A will be a part of our strategy for the foreseeable future, but we will remain diligent in what we go after and how we finance it. So that it is accretive to shareholders and does not derail our deleveraging goals. With that, I will turn it over to Jason for final comments.

Thank you, Bryan, and thank you all for joining us today. Operator, please open the lines for questions.

[Operator Instructions] We'll hear first today from Derrick Whitfield with Stifel.

Thanks and good morning, all.

Good morning, Derrick.

For my first question, I wanted to start with the leach DSU. It appears that both pre and post-drill data indicated this was your highest risk DSU within Howard County. Could you speak to your degree of confidence that the DSU to the west, which you plan to develop in 2024, would be a commercial DSU and perhaps also speak to if there's a noticeable difference in well performance from east to west within the leach DSU?

Yes. Thanks, Derrick. This is Mikell Pigott. So, yes, absolutely within the leach DSU itself, the Western most wells are the highest pursing wells. As we move to the east, we see a higher water cut and lower oil production in the Eastern most wells. And so, that combined with our current offsetting production around the undeveloped DSUs that will be developed in 2024. We have strong production around those DSUs on both sides, which ultimately gives us confidence that they are unaffected by the issues that we're seeing in the leach package.

Terrific. And just as a follow-up to put some parameters around this leach DSU. Could you frame the NPV impact associated with it if your oil cut doesn't meaningfully appreciate? At most, it would just seem to be the cost of the wells, but you already trade at a discount or at your PDP depending on your discount rate. Am I thinking about that correctly?

Yes, Derrick, this is Bryan. The capital has already been spent. I think the way to think about it is the impact on cash flows going forward. And the largest portion of that would be the $70 million impact in the back half of this year. That will get almost all of your NPV impact.

Terrific. That’s all for me. Thanks for your time.

And at this time I'd like to turn things back to Mr. Hagood for any closing remarks.

Well, thank you for joining us this morning. We appreciate your interest in Laredo. This concludes this morning's call.