Exhibit 99.2

Western Glasscock County Acquisition September 19, 2021

Forward - Looking / Cautionary Statements 2 This presentation, including any oral statements made regarding the contents of this presentation, contains forward - looking stat ements as defined under Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, that address acti vit ies that Laredo Petroleum, Inc. (together with its subsidiaries, the “Company”, “Laredo” or “LPI”) assumes, plans, expects, believes, intends, projects, indicates, enables, transforms, estimates or anticipates (and other sim ila r expressions) will, should or may occur in the future are forward - looking statements. The forward - looking statements are based on management’s current belief, based on currently available information, as to the outcome and tim ing of future events. General risks relating to Laredo include, but are not limited to, the decline in prices of oil, natural gas liquids and natur al gas and the related impact to financial statements as a result of asset impairments and revisions to reserve estimates, the ability of the Company to execute its strategies, including its ability to successfully identify and consummat e strategic acquisitions at purchase prices that are accretive to its financial results and to successfully integrate acquired businesses, assets and properties, oil production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries and other p ro ducing countries (“OPEC+”), the outbreak of disease, such as the coronavirus (“COVID - 19”) pandemic, and any related government policies and actions, changes in domestic and global production, supply and demand for commodities, including as a result of the COVID - 19 pandemic and actions by OPEC+, long - term performance of wells, drilling and operating risks, the increase in service and supply costs, tariffs on steel, pipeline transportation and storage constraints in the Permian Basin, the possibility of production curtailment, hedging activities, the impacts of severe weather, including the freezing of wells and pi pelines in the Permian Basin due to cold weather, possible impacts of litigation and regulations, the impact of the Company’s transactions, if any, with its securities from time to time, the impact of new laws and regulations, includi ng those regarding the use of hydraulic fracturing, the impact of new environmental, health and safety requirements applicable to the Company’s business activities, the possibility of the elimination of federal income tax deduct ion s for oil and gas exploration and development and other factors, including those and other risks described in its Annual Report on Form 10 - K for the year ended December 31, 2020, Current Report on Form 8 - K, filed with the Securities and Exchange Commission ("SEC") on May 11, 2021, and those set forth from time to time in other filings with the SEC. These documents are available through Laredo’s website at www.laredopetro.com under the tab “I nve stor Relations” or through the SEC’s Electronic Data Gathering and Analysis Retrieval System at www.sec.gov. Any of these factors could cause Laredo’s actual results and plans to differ materially from those in the forwar d - l ooking statements. Therefore, Laredo can give no assurance that its future results will be as estimated. Any forward - looking statement speaks only as of the date on which such statement is made. Laredo does not intend to, and disclai ms any obligation to, correct, update or revise any forward - looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law. The SEC generally permits oil and natural gas companies, in filings made with the SEC, to disclose proved reserves, which are re serve estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, and certain probable and pos sible reserves that meet the SEC’s definitions for such terms. In this presentation, the Company may use the terms “resource potential,” “resource play,” “estimated ultimate recovery,” or “EURs,” “type curve” and “standard ize d measure,” each of which the SEC guidelines restrict from being included in filings with the SEC without strict compliance with SEC definitions. These terms refer to the Company’s internal estimates of unbooked hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques. “Resource potential” is used by the Company to refer to the estimated quantities of hydrocar bon s that may be added to proved reserves, largely from a specified resource play potentially supporting numerous drilling locations. A “resource play” is a term used by the Company to describe an accumulation of hydrocarbons know n t o exist over a large areal expanse and/or thick vertical section potentially supporting numerous drilling locations, which, when compared to a conventional play, typically has a lower geological and/or commercial developme nt risk. “EURs” are based on the Company’s previous operating experience in a given area and publicly available information relating to the operations of producers who are conducting operations in these areas. Unbooked resource potential and “EURs” do not constitute reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or SEC rules and do not include any proved reserves. Actual quantities of res erv es that may be ultimately recovered from the Company’s interests may differ substantially from those presented herein. Factors affecting ultimate recovery include the scope of the Company’s ongoing drilling program, whic h w ill be directly affected by the availability of capital, decreases in oil, natural gas liquids and natural gas prices, well spacing, drilling and production costs, availability and cost of drilling services and equipment, lease expi rat ions, transportation constraints, regulatory approvals, negative revisions to reserve estimates and other factors, as well as actual drilling results, including geological and mechanical factors affecting recovery rates. “EURs” fro m r eserves may change significantly as development of the Company’s core assets provides additional data. In addition, the Company’s production forecasts and expectations for future periods are dependent upon many assumptions, incl udi ng estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price declines or drilling cost increases. “Type cur ve” refers to a production profile of a well, or a particular category of wells, for a specific play and/or area. The “standardized measure” of discounted future new cash flows is calculated in accordance with SEC regulations and a discount ra te of 10%. Actual results may vary considerably and should not be considered to represent the fair market value of the Company’s proved reserves. This presentation includes financial measures that are not in accordance with generally accepted accounting principles (“GAAP ”), such as Adjusted EBITDA, Net Asset Value and Free Cash Flow. While management believes that such measures are useful for investors, they should not be used as a replacement for financial measures that are in accordanc e w ith GAAP. For definitions of such non - GAAP financial measures, please see the Appendix. Unless otherwise specified, references to “average sales price” refer to average sales price excluding the effects of the Com pan y’s derivative transactions. All amounts, dollars and percentages presented in this presentation are rounded and therefore approximate.

3 Acquisition Expands W. Glasscock Oil - Weighted Core Development Area Pro Forma W. Glasscock County Leasehold Increases Company’s high - margin, oil - weighted inventory by 50% ▪ Extends development runway to approximately seven years at current activity levels ▪ Adds ~135 gross operated locations with an a nticipated oil cut >50% ▪ Builds W. Glasscock core development area to >22,000 net acres Accretive to Free Cash Flow 1 and Net Asset Value 1 per share ▪ Company remains on track to achieve YE - 22 leverage target of 1.5x Net Debt/TTM Adjusted EBITDA 1 Acquisition Details Net Acres ~20,000 Gross Op Locations / Avg. WI / Avg. Royalty Rate ~135 / 90% / 20% Average Lateral Length (operated locations) 9,700’ Net Production (three stream) 2 ~4,400 BOE/d (59% oil / 82% liquids) Purchase Price Details Cash $160 million Common Shares to Pioneer Natural Resources 959,691 shares Total Purchase Price ~$230 million W. Glasscock Legacy Pending Acquisition 1 See Appendix for reconciliations and definitions of non - GAAP measures; 2 Expected average daily production for September 2021

Continuously Improve ▪ Reduced percentage of produced natural gas flared/vented to 0.25% in 1H - 21 from 0.71% for FY - 20 ▪ Reduced drilling costs by 14% in 1H - 21 versus FY - 20 average ▪ Company - owned sand mine protects against sand cost inflation, saving an estimated $200,000 per well ▪ Commitment to reduce GHG emissions by 20% and eliminate routine flaring by 2025 Manage Risk ▪ No term - debt maturities until 2025 ▪ Extended credit facility maturity to 2025 ▪ Executed $75 million “at - the - market” equity program during 1H - 21 ▪ Active hedge program in 2022 to protect forecasted Free Cash Flow 2 ▪ Expect to reduce total leverage ratio to ~1.5x by YE - 22 Transactions Drive Rapid Execution of Transformational Strategy 4 1 Pro forma for pending acquisition; 2 See Appendix for reconciliations and definitions of non - GAAP measures Expand High - Margin Inventory ▪ Added ~55,000 net acres 1 of oil - weighted leasehold in six separate transactions ▪ Divested ~94 million BOE of legacy low - margin, gas - weighted reserves ▪ Developme nt focused on recently acquired oil - weighted inventory ▪ Oil cut expected to rise from 31% in 1Q - 21 to ~50% by YE - 22

5 Actively Building Oil - Weighted Leasehold October 2019 Leasehold YE - 2019 Leasehold Pro Forma Current Leasehold Legacy Leasehold Acquired Oil - Weighted Leasehold Acquired approximately 55,000 net acres of highly productive, oil - weighted inventory in Howard and western Glasscock counties in just two years

1 Map and acreage as of 9 - 9 - 21, pro forma for pending acquisition; 2 Gross operated locations as of January 2021 (adjusted for 2020 completions), pro forma for all announced acquisitions; 3 Flat oil price needed to achieve 10% IRR assuming a $3.00 natural gas price; 4 Production data normalized to 10,000’ lateral length, downtime days excluded Acquisition Extends Runway of High - Margin Inventory To ~Seven Years 6 W. Glasscock County Howard County Total Net acres 1 ~22,200 ~33,400 ~55,600 Target formations LS/WC - A/WC - B LS/WC - A * Locations (gross) 2 ~175 ~225 ~400 Avg. breakeven oil price 3 <$40 <$35 * Laredo Leasehold Pending Acquisition Central Howard North Howard W. Glasscock Package Location

LAREDO PETROLEUM APPENDIX

Supplemental Non - GAAP Financial Measures Adjusted EBITDA Adjusted EBITDA is a non - GAAP financial measure that we define as net income or loss (GAAP) plus adjustments for share - settled e quity - based compensation, depletion, depreciation and amortization, impairment expense, mark - to - market on derivatives, premiums paid or received for commodity derivatives that mature d during the period, accretion expense, gains or losses on disposal of assets, interest expense, income taxes and other non - recurring income and expenses. Adjusted EBITDA provides no info rmation regarding a company's capital structure, borrowings, interest costs, capital expenditures, working capital movement or tax position. Adjusted EBITDA does not represent funds avai lab le for future discretionary use because it excludes funds required for debt service, capital expenditures, working capital, income taxes, franchise taxes and other commitments and obligations. Ho wever, our management believes Adjusted EBITDA is useful to an investor in evaluating our operating performance because this measure: is widely used by investors in the oil and natural gas in dustry to measure a company's operating performance without regard to items that can vary substantially from company to company depending upon accounting methods, the book value of asse ts, capital structure and the method by which assets were acquired, among other factors; helps investors to more meaningfully evaluate and compare the results of our operations from p eri od to period by removing the effect of our capital structure from our operating structure; and is used by our management for various purposes, including as a measure of operating performance, in presentations to our board of directors and as a basis for strategic planning and forecasting. There are significant limitations to the use of Adjusted EBITDA as a measure of performan ce, including the inability to analyze the effect of certain recurring and non - recurring items that materially affect our net income or loss and the lack of comparability of results of operations to diff erent companies due to the different methods of calculating Adjusted EBITDA reported by different companies. Our measurements of Adjusted EBITDA for financial reporting as compared to compliance un der our debt agreements differ. The following table presents a reconciliation of net income (loss) (GAAP) to Adjusted EBITDA (non - GAAP): 8 Three months ended, (in thousands, unaudited) 9/30/2020 12/31/2020 3/31/2021 6/30/2021 Net loss ($237,432) ($165,932) ($75,439) ($132,661) Plus: Share - settled equity - based compensation, net 2,041 2,106 2,068 1,730 Depletion, depreciation and amortization 47,015 42,210 38,109 39,976 Impairment expense 196,088 109,804 — 1,613 Organizational restructuring expenses — — — 9,800 Transaction expenses — — — 1,741 Mark - to - market on derivatives: (Gain) loss on derivatives, net 45,250 81,935 154,365 216,942 Settlements received (paid) for matured derivatives, net 51,840 41,786 (41,174) (57,607) Settlements received for early - terminated commodity derivatives, net 6,340 — — — Net premiums paid for commodity derivatives that matured during the period (1) — — (11,005) (10,183) Accretion expense 1,102 1,105 1,143 1,158 (Gain) loss on disposal of assets, net 607 (94) 72 (66) Interest expense 26,828 26,139 25,946 25,870 Gain on extinguishment of debt, net — (22,309) — — Income tax (benefit) expense (2,398) 3,208 (762) (1,322) Adjusted EBITDA $137,281 $119,958 $93,323 $96,991 (1) Reflects net premiums paid previously or upon settlement that are attributable to derivatives settled in the respective p eri ods presented

Net Debt Net Debt, a non - GAAP financial measure, is calculated as the face value of long - term debt less cash and cash equivalents. Manage ment believes Net Debt is useful to management and investors in determining the Company’s leverage position since the Company has the ability, and may decide, to use a port ion of its cash and cash equivalents to reduce debt. Net Debt as of 6 - 30 - 21 was $1.125 B. Net Debt to TTM Adjusted EBITDA Net Debt to TTM Adjusted EBITDA, a non - GAAP financial measure, is calculated as Net Debt divided by trailing twelve - month Adjust ed EBITDA. Net Debt to Adjusted EBITDA is used by our management for various purposes, including as a measure of operating performance, in presentations to our board o f d irectors and as a basis for strategic planning and forecasting. Free Cash Flow Free Cash Flow is a non - GAAP financial measure, that we define as net cash provided by operating activities (GAAP) before change s in operating assets and liabilities, net, less incurred capital expenditures, excluding non - budgeted acquisition costs. Free Cash Flow does not represent funds available for f uture discretionary use because it excludes funds required for future debt service, capital expenditures, acquisitions, working capital, income taxes, franchise taxes and othe r c ommitments and obligations. However, management believes Free Cash Flow is useful to management and investors in evaluating operating trends in our business that are affecte d b y production, commodity prices, operating costs and other related factors. There are significant limitations to the use of Free Cash Flow as a measure of performance, includ ing the lack of comparability due to the different methods of calculating Free Cash Flow reported by different companies. Net Asset Vaue Net Asset Value is a non - GAAP financial measure that the Company defines as the present value of future revenues less future exp enses, less Net Debt. Net Asset Value does not represent the standardized measure of discounted future net cash flows because it adjusts for Net Debt and excludes adjustmen ts for future income tax expense. However, management believes Net Asset Value is useful to management and investors in evaluating the value of the Company, which is af fec ted by the pace of capital expenditures and development of inventory, future commodity prices and future prices of services utilized to develop the Company’s inventory. The re are significant limitations to the use of Net Asset Value as a measure of value, including lack of comparability to calculations of Net Asset Value by other companies due to differences in assumptions utilized in the calculations. 9 Supplemental Non - GAAP Financial Measures