425

Contango Oil & Gas Company

(Commission File No. 001-16317)

Pursuant to Rule 425 under the Securities Act of 1933, as amended

and deemed filed under Rule 14a-12 under the

Securities Exchange Act of 1934, as amended

Subject Company: Mid-Con Energy Partners, LP

(Commission File No. 001-35374)

ADDITIONAL INFORMATION AND WHERE TO FIND IT

Contango and Mid-Con filed a consent statement/proxy statement/prospectus (the “Consent Statement/Proxy Statement/Prospectus”) with the Securities and Exchange Commission (the “SEC”) in connection with the Partnership Unitholder Approval and the Contango Shareholder Approval (each as defined in the Merger Agreement between the parties) in connection with the proposed merger of Mid-Con into a subsidiary of Contango (the “Proposed Merger”). Contango filed a registration statement on Form S-4 (the “Form S-4”) with the SEC, in which the Consent Statement/Proxy Statement/Prospectus was included as a prospectus. Contango and Mid-Con may also file other relevant documents with the SEC regarding the Proposed Merger. The definitive Consent Statement/Proxy Statement/Prospectus was mailed to Contango’s shareholders and Mid-Con’s unitholders. BEFORE MAKING ANY VOTING OR INVESTMENT DECISION WITH RESPECT TO THE PROPOSED MERGER, INVESTORS AND SHAREHOLDERS OF CONTANGO AND INVESTORS AND UNITHOLDERS OF MID-CON ARE URGED TO READ THE DEFINITIVE CONSENT STATEMENT/PROXY STATEMENT/PROSPECTUS REGARDING THE PROPOSED MERGER (INCLUDING ANY AMENDMENTS OR SUPPLEMENTS THERETO) AND OTHER RELEVANT MATERIALS CAREFULLY AND IN THEIR ENTIRETY BECAUSE THEY CONTAIN IMPORTANT INFORMATION ABOUT THE PROPOSED MERGER.

The Consent Statement/Proxy Statement/Prospectus, any amendments or supplements thereto and other relevant materials, and any other documents filed by Contango or Mid-Con with the SEC, may be obtained free of charge at the SEC’s website at www.sec.gov or free of charge from Contango at www.contango.com or by directing a request to Contango’s Investor Relations Department at investorrelations@contango.com or free of charge from Mid-Con at www.mceplp.com or by directing a request to Mid-Con’s Investor Relations Department at MSA.OwnerRelations@Contango.com.

NO OFFER OR SOLICITATION

This communication does not constitute an offer to sell or the solicitation of an offer to buy any securities, or a solicitation of any vote or approval, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the Securities Act of 1933, as amended.


January 2021 PresentationJanuary 2021 Presentation


Cautionary Statements Certain statements included in this presentation are forward-looking statements under the Private Securities Litigation Reform Act of 1995. Forward- looking statements are those statements that are not historical in nature and may be identified by words such as, but not limited to, expect, “assume”, “project”, “plan”, outlook, intend, will, “preview,” “estimate,” and could.“ Contango Oil & Gas Company (“Contango”, “MCF” or the “Company”) cautions that strategic plans, assumptions, expectations, objectives for future operations, drilling results, projections, intentions, or beliefs about future events may, and often do, vary from actual results and the differences can be material. Some of the key factors which could cause actual results to vary from those Contango expects include risks related to the COVID-19 pandemic; the risk that the pending acquisition of oil and gas properties may not close as or when expected or produce anticipated benefits; the risk that the merger with Mid-Con Energy Partners, LP (“Mid-Con” or “MCEP”) will not be completed as expected and that, upon completion of the merger (the “Proposed Transaction”) of Mid-Con with and into Contango (the “Combined Company”); the cost savings, synergies and growth from the Proposed Transaction may not be fully realized or may take longer to realize than expected; the diversion of management time on transaction-related issues; the effect of future regulatory or legislative actions on the companies or the industry in which they operate; the risk that the credit ratings of the combined company or its subsidiaries may be different from what the companies expect; the risk that Contango or Mid-Con may be unable to obtain governmental and regulatory approvals required for the Proposed Transaction, or that required governmental and regulatory approvals may delay the Proposed Transaction or result in the imposition of conditions that could reduce the anticipated benefits from the Proposed Transaction or cause the parties to abandon the Proposed Transaction; the risk that a condition to closing of the Proposed Transaction may not be satisfied; the length of time necessary to consummate the Proposed Transaction, which may be longer than anticipated for various reasons; potential liability resulting from pending or future litigation; changes in the general economic environment, or social or political conditions, that could affect the businesses; the potential impact of the announcement or consummation of the Proposed Transaction on relationships with customers, suppliers, competitors, management and other employees; and risks associated with changes in natural gas and oil prices, the timing of planned capital expenditures, availability of acquisitions, uncertainties in estimating proved reserves and resource potential and forecasting drilling and production results, operational factors affecting the commencement or maintenance of producing wells, access to liquidity and compliance with credit agreements, the condition of the capital markets generally, as well as the Company’s ability to access them, and uncertainties regarding environmental regulations or litigation and other legal or regulatory developments affecting Contango's business; and the risk that Contango cannot secure financing for, close as expected, or realize the benefits from, the acquisition of the Project Silvertip assets. Statements regarding future production are subject to all of the risks and uncertainties normally incident to the exploration for and development and production of oil and gas. Please refer to our filings with the Securities and Exchange Commission (“SEC”), including our Annual Report on Form 10-K for the fiscal year ended December 31, 2019, and subsequent filings for a further discussion of these risks. This presentation includes certain estimates of proved reserves that have not been prepared in accordance with SEC pricing guidelines. Other estimates of hydrocarbon quantities included herein may not comport with specific definitions of reserves under SEC rules and cannot be disclosed in SEC filings. These estimates have been prepared by the Company and are by their nature more speculative than estimates of proved reserves and accordingly are subject to substantially greater risk of being actually realized by the Company. Please read “Reserves Disclaimers for certain information regarding the reserves and related information presented herein. Pro Forma for the Combined Company does not necessarily represent the actual reserves, or production or other results of the Combined Company. Although such estimates and any projections shown are based on management's good faith belief and current information available to it, actual results may differ materially from pro forma information, estimates or expectations. This presentation shall not constitute an offer to sell, or a solicitation of an offer to buy, any securities. 2Cautionary Statements Certain statements included in this presentation are forward-looking statements under the Private Securities Litigation Reform Act of 1995. Forward- looking statements are those statements that are not historical in nature and may be identified by words such as, but not limited to, expect, “assume”, “project”, “plan”, outlook, intend, will, “preview,” “estimate,” and could.“ Contango Oil & Gas Company (“Contango”, “MCF” or the “Company”) cautions that strategic plans, assumptions, expectations, objectives for future operations, drilling results, projections, intentions, or beliefs about future events may, and often do, vary from actual results and the differences can be material. Some of the key factors which could cause actual results to vary from those Contango expects include risks related to the COVID-19 pandemic; the risk that the pending acquisition of oil and gas properties may not close as or when expected or produce anticipated benefits; the risk that the merger with Mid-Con Energy Partners, LP (“Mid-Con” or “MCEP”) will not be completed as expected and that, upon completion of the merger (the “Proposed Transaction”) of Mid-Con with and into Contango (the “Combined Company”); the cost savings, synergies and growth from the Proposed Transaction may not be fully realized or may take longer to realize than expected; the diversion of management time on transaction-related issues; the effect of future regulatory or legislative actions on the companies or the industry in which they operate; the risk that the credit ratings of the combined company or its subsidiaries may be different from what the companies expect; the risk that Contango or Mid-Con may be unable to obtain governmental and regulatory approvals required for the Proposed Transaction, or that required governmental and regulatory approvals may delay the Proposed Transaction or result in the imposition of conditions that could reduce the anticipated benefits from the Proposed Transaction or cause the parties to abandon the Proposed Transaction; the risk that a condition to closing of the Proposed Transaction may not be satisfied; the length of time necessary to consummate the Proposed Transaction, which may be longer than anticipated for various reasons; potential liability resulting from pending or future litigation; changes in the general economic environment, or social or political conditions, that could affect the businesses; the potential impact of the announcement or consummation of the Proposed Transaction on relationships with customers, suppliers, competitors, management and other employees; and risks associated with changes in natural gas and oil prices, the timing of planned capital expenditures, availability of acquisitions, uncertainties in estimating proved reserves and resource potential and forecasting drilling and production results, operational factors affecting the commencement or maintenance of producing wells, access to liquidity and compliance with credit agreements, the condition of the capital markets generally, as well as the Company’s ability to access them, and uncertainties regarding environmental regulations or litigation and other legal or regulatory developments affecting Contango's business; and the risk that Contango cannot secure financing for, close as expected, or realize the benefits from, the acquisition of the Project Silvertip assets. Statements regarding future production are subject to all of the risks and uncertainties normally incident to the exploration for and development and production of oil and gas. Please refer to our filings with the Securities and Exchange Commission (“SEC”), including our Annual Report on Form 10-K for the fiscal year ended December 31, 2019, and subsequent filings for a further discussion of these risks. This presentation includes certain estimates of proved reserves that have not been prepared in accordance with SEC pricing guidelines. Other estimates of hydrocarbon quantities included herein may not comport with specific definitions of reserves under SEC rules and cannot be disclosed in SEC filings. These estimates have been prepared by the Company and are by their nature more speculative than estimates of proved reserves and accordingly are subject to substantially greater risk of being actually realized by the Company. Please read “Reserves Disclaimers for certain information regarding the reserves and related information presented herein. Pro Forma for the Combined Company does not necessarily represent the actual reserves, or production or other results of the Combined Company. Although such estimates and any projections shown are based on management's good faith belief and current information available to it, actual results may differ materially from pro forma information, estimates or expectations. This presentation shall not constitute an offer to sell, or a solicitation of an offer to buy, any securities. 2


Additional Information ADDITIONAL INFORMATION AND WHERE TO FIND IT This communication may be deemed to be solicitation material in respect of the proposed merger (the “Proposed Merger”). The Proposed Merger will be submitted to Contango shareholders and Mid-Con unitholders for their consideration. Contango and Mid-Con intend to file a preliminary consent statement/proxy statement/prospectus (the “Consent Statement/Proxy Statement/Prospectus”) with the Securities and Exchange Commission (the “SEC”) in connection with the Partnership Unitholder Approval and the Contango Shareholder Approval (each as defined in the Merger Agreement) in connection with the Proposed Merger. Contango intends to file a registration statement on Form S-4 (the “Form S-4”) with the SEC, in which the Consent Statement/Proxy Statement/Prospectus will be included as a prospectus. Contango and Mid-Con also intend to file other relevant documents with the SEC regarding the Proposed Merger. After the Form S-4 is declared effective by the SEC, the definitive Consent Statement/Proxy Statement/Prospectus will be mailed to Contango’s shareholders and Mid- Con’s unitholders. BEFORE MAKING ANY VOTING OR INVESTMENT DECISION WITH RESPECT TO THE PROPOSED MERGER, INVESTORS AND SHAREHOLDERS OF CONTANGO AND INVESTORS AND UNITHOLDERS OF MID-CON ARE URGED TO READ THE DEFINITIVE CONSENT STATEMENT/PROXY STATEMENT/PROSPECTUS REGARDING THE PROPOSED MERGER (INCLUDING ANY AMENDMENTS OR SUPPLEMENTS THERETO) AND OTHER RELEVANT MATERIALS CAREFULLY AND IN THEIR ENTIRETY WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT THE PROPOSED MERGER. The Consent Statement/Proxy Statement/Prospectus, any amendments or supplements thereto and other relevant materials, and any other documents filed by Contango or Mid-Con with the SEC, may be obtained once such documents are filed with the SEC free of charge at the SEC’s website at www.sec.gov or free of charge from Contango at www.contango.com or by directing a request to Contango’s Investor Relations Department at investorrelations@contango.com or free of charge from Mid-Con at www.mceplp.com or by directing a request to Mid-Con’s Investor Relations Department at MSA.OwnerRelations@Contango.com. NO OFFER OR SOLICITATION This communication does not constitute an offer to sell or the solicitation of an offer to buy any securities, or a solicitation of any vote or approval, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the Securities Act of 1933, as amended. 3Additional Information ADDITIONAL INFORMATION AND WHERE TO FIND IT This communication may be deemed to be solicitation material in respect of the proposed merger (the “Proposed Merger”). The Proposed Merger will be submitted to Contango shareholders and Mid-Con unitholders for their consideration. Contango and Mid-Con intend to file a preliminary consent statement/proxy statement/prospectus (the “Consent Statement/Proxy Statement/Prospectus”) with the Securities and Exchange Commission (the “SEC”) in connection with the Partnership Unitholder Approval and the Contango Shareholder Approval (each as defined in the Merger Agreement) in connection with the Proposed Merger. Contango intends to file a registration statement on Form S-4 (the “Form S-4”) with the SEC, in which the Consent Statement/Proxy Statement/Prospectus will be included as a prospectus. Contango and Mid-Con also intend to file other relevant documents with the SEC regarding the Proposed Merger. After the Form S-4 is declared effective by the SEC, the definitive Consent Statement/Proxy Statement/Prospectus will be mailed to Contango’s shareholders and Mid- Con’s unitholders. BEFORE MAKING ANY VOTING OR INVESTMENT DECISION WITH RESPECT TO THE PROPOSED MERGER, INVESTORS AND SHAREHOLDERS OF CONTANGO AND INVESTORS AND UNITHOLDERS OF MID-CON ARE URGED TO READ THE DEFINITIVE CONSENT STATEMENT/PROXY STATEMENT/PROSPECTUS REGARDING THE PROPOSED MERGER (INCLUDING ANY AMENDMENTS OR SUPPLEMENTS THERETO) AND OTHER RELEVANT MATERIALS CAREFULLY AND IN THEIR ENTIRETY WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT THE PROPOSED MERGER. The Consent Statement/Proxy Statement/Prospectus, any amendments or supplements thereto and other relevant materials, and any other documents filed by Contango or Mid-Con with the SEC, may be obtained once such documents are filed with the SEC free of charge at the SEC’s website at www.sec.gov or free of charge from Contango at www.contango.com or by directing a request to Contango’s Investor Relations Department at investorrelations@contango.com or free of charge from Mid-Con at www.mceplp.com or by directing a request to Mid-Con’s Investor Relations Department at MSA.OwnerRelations@Contango.com. NO OFFER OR SOLICITATION This communication does not constitute an offer to sell or the solicitation of an offer to buy any securities, or a solicitation of any vote or approval, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the Securities Act of 1933, as amended. 3


Contango History and Highlights Company History • Closed $56.4mm public equity offering and new, JPM-led RCF • Closed $22.1mm private placement equity offering 2006 - • Closed acquisitions of Will Energy 2013 1999 2018 2020 • Acquired 5,000 net ($23.0mm) and White Star 2010 acres in Pecos County ($132.5mm) (“Bullseye”) and • Closed $53.4mm private placement • Fayetteville Shale • Fayetteville Shale sold subsequently added an • Expected Q1 closing equity offering additional 1,700 net acquired for to Petrohawk and • Entered joint development of MCEP and Silvertip ~$10mm XTO for ~$300mm acres transactions agreement with Juneau Oil & Gas, LLC • Contango • Offshore success of • Kenneth Peak medical • John Goff and affiliates • Announced management founded in Eugene Island shallow leave of absence purchased 18.8% of MCF services agreement with 1999 water discovery • Merger with Crimson • Wilkie Colyer, Jr. named CEO MCEP including 10 wells that Exploration • Completed $34.5m equity • Announces merger with remain a major offering MCEP production source • Acquired “Northeast Bullseye” • Acquisition of Project (53% of 4Q19A legacy Silvertip assets 2005 2008 2021 2019 MCF production 2016 • Closed $39.7 private excluding Will Energy placement equity offering and White Star) • Closed $22.0 private placement equity offering Contango Highlights ü Management and directors committing time and capital to Proprietary relationships with lending banks and legal advisors ü transforming business (high insider ownership) that help Contango continue to evaluate potential opportunities ü Low management salaries and G&A Low PDP decline rate ü Simple capital structure Low drilling requirements and lease expirations üü Focused on acquiring assets that are less desirable by Expect to maintain positive free cash flow for 2021 üü many at attractive returns Highly supportive, value-based equity ownership ü Insiders’ Incentives are Aligned with Shareholders ü Note: Free cash flow is a non-GAAP measure which we define as cash flow from operations less capital expenditures.. 4Contango History and Highlights Company History • Closed $56.4mm public equity offering and new, JPM-led RCF • Closed $22.1mm private placement equity offering 2006 - • Closed acquisitions of Will Energy 2013 1999 2018 2020 • Acquired 5,000 net ($23.0mm) and White Star 2010 acres in Pecos County ($132.5mm) (“Bullseye”) and • Closed $53.4mm private placement • Fayetteville Shale • Fayetteville Shale sold subsequently added an • Expected Q1 closing equity offering additional 1,700 net acquired for to Petrohawk and • Entered joint development of MCEP and Silvertip ~$10mm XTO for ~$300mm acres transactions agreement with Juneau Oil & Gas, LLC • Contango • Offshore success of • Kenneth Peak medical • John Goff and affiliates • Announced management founded in Eugene Island shallow leave of absence purchased 18.8% of MCF services agreement with 1999 water discovery • Merger with Crimson • Wilkie Colyer, Jr. named CEO MCEP including 10 wells that Exploration • Completed $34.5m equity • Announces merger with remain a major offering MCEP production source • Acquired “Northeast Bullseye” • Acquisition of Project (53% of 4Q19A legacy Silvertip assets 2005 2008 2021 2019 MCF production 2016 • Closed $39.7 private excluding Will Energy placement equity offering and White Star) • Closed $22.0 private placement equity offering Contango Highlights ü Management and directors committing time and capital to Proprietary relationships with lending banks and legal advisors ü transforming business (high insider ownership) that help Contango continue to evaluate potential opportunities ü Low management salaries and G&A Low PDP decline rate ü Simple capital structure Low drilling requirements and lease expirations üü Focused on acquiring assets that are less desirable by Expect to maintain positive free cash flow for 2021 üü many at attractive returns Highly supportive, value-based equity ownership ü Insiders’ Incentives are Aligned with Shareholders ü Note: Free cash flow is a non-GAAP measure which we define as cash flow from operations less capital expenditures.. 4


Incentive Alignment – Equity Ownership High Insider Ownership Key Contango Insiders Insider Ownership Comparison % Common 30% (2) Management Title Outstanding CEO Wilkie S. Colyer, Jr. 0.62% 25% President W. Farley Dakan 2.05% 20% Chad Roller, PhD SVP, COO 0% Started July 2020 15% SVP, CFO E. Joseph Grady 0.13% 10% SVP, General Counsel & Chad McLawhorn 0% Secretary Started July 2020 5% % Common Directors Affiliation Outstanding (3) 0% John C. Goff Founder of Crescent Real 12 3456 789 10 MCF 21.6% Estate and Goff Capital CHAIRMAN (1) MCF vs Peers CEO of Contango Wilkie S. Colyer, Jr. 0.62% Previously CEO of Patara Oil B.A. Berilgen 0.065% & Gas Fmr. VP, CFO of Westport Res; Dir. of Cheniere and Lon McCain 0.071% Continental Resources President and CEO of Olympic Joseph J. Romano 0.081% Energy Partners Key Insider Ownership % ~24.6% Source: Public Filings 1) Peer group includes AMPY, BATL, BCEI, BRY, CDEV, CPE, ESTE, LPI, PVAC and SBOW 2) Excludes any and all unvested LTIPs 3) John C. Goff and affiliates are expected to own approximately 24.4% upon closing of MCEP merger 5Incentive Alignment – Equity Ownership High Insider Ownership Key Contango Insiders Insider Ownership Comparison % Common 30% (2) Management Title Outstanding CEO Wilkie S. Colyer, Jr. 0.62% 25% President W. Farley Dakan 2.05% 20% Chad Roller, PhD SVP, COO 0% Started July 2020 15% SVP, CFO E. Joseph Grady 0.13% 10% SVP, General Counsel & Chad McLawhorn 0% Secretary Started July 2020 5% % Common Directors Affiliation Outstanding (3) 0% John C. Goff Founder of Crescent Real 12 3456 789 10 MCF 21.6% Estate and Goff Capital CHAIRMAN (1) MCF vs Peers CEO of Contango Wilkie S. Colyer, Jr. 0.62% Previously CEO of Patara Oil B.A. Berilgen 0.065% & Gas Fmr. VP, CFO of Westport Res; Dir. of Cheniere and Lon McCain 0.071% Continental Resources President and CEO of Olympic Joseph J. Romano 0.081% Energy Partners Key Insider Ownership % ~24.6% Source: Public Filings 1) Peer group includes AMPY, BATL, BCEI, BRY, CDEV, CPE, ESTE, LPI, PVAC and SBOW 2) Excludes any and all unvested LTIPs 3) John C. Goff and affiliates are expected to own approximately 24.4% upon closing of MCEP merger 5


Incentive Alignment - Management Compensation Low Management Salaries / G&A (2) Current Management Salaries Recurring Cash G&A $16,000 Peer Group Position Contango (1) Avg $14,000 $12,000 CEO $590k $300k $10,000 President $590k $250k $8,000 $6,000 CFO $390k $400k $4,000 COO $400k $250k $2,000 $- 12 MCF 3 4 5 6 789 10 General Counsel $360k $250k (1) Q3 2020 Recurring Cash G&A MCF vs Peers Compensation Philosophy Focus on Lean G&A ─ Reduced Management’s salaries compared to peer group─ Maintain a low G&A headcount with incoming acquisitions ─ Increased equity incentive ─ Reduce reliance on expensive software products and find other lower cost alternatives ─ Focused on Performance Stock Unit awards to further incentivize key employees─ Rationalize office expenses ─ Equity awards for all employees Source: Public Filings 1) Peer group includes AMPY, BATL, BCEI, BRY, CDEV, CPE, ESTE, LPI, PVAC and SBOW 2) Recurring Cash G&A means general and administrative expense less stock compensation and non-recurring expenses 6Incentive Alignment - Management Compensation Low Management Salaries / G&A (2) Current Management Salaries Recurring Cash G&A $16,000 Peer Group Position Contango (1) Avg $14,000 $12,000 CEO $590k $300k $10,000 President $590k $250k $8,000 $6,000 CFO $390k $400k $4,000 COO $400k $250k $2,000 $- 12 MCF 3 4 5 6 789 10 General Counsel $360k $250k (1) Q3 2020 Recurring Cash G&A MCF vs Peers Compensation Philosophy Focus on Lean G&A ─ Reduced Management’s salaries compared to peer group─ Maintain a low G&A headcount with incoming acquisitions ─ Increased equity incentive ─ Reduce reliance on expensive software products and find other lower cost alternatives ─ Focused on Performance Stock Unit awards to further incentivize key employees─ Rationalize office expenses ─ Equity awards for all employees Source: Public Filings 1) Peer group includes AMPY, BATL, BCEI, BRY, CDEV, CPE, ESTE, LPI, PVAC and SBOW 2) Recurring Cash G&A means general and administrative expense less stock compensation and non-recurring expenses 6


Simple Capital Structure Right-Sized Balance Sheet (1) % of Capitalization Capital Source Contango Peer Group Avg Other Info Senior Secured Revolving •Sep 2024 Maturity 13% 32% • 9 Banks in RCF group Credit Facility (“RCF”) Senior • No intention or need to raise 0% 29% unsecured notes Notes / Bonds Preferred • Converted remaining 0% 0% preferred units Summer 2020 Equity • Using stock as currency for Common acquisitions 87% 39% • Incentivizing employee base Equity with equity awards Source: Public Filings 1) Market data as of January 11, 2021. Excludes impact of MCEP merger and Project Silvertip acquisition. Peer group includes AMPY, BATL, BCEI, BRY, CDEV, CPE, ESTE, LPI, PVAC and SBOW 7Simple Capital Structure Right-Sized Balance Sheet (1) % of Capitalization Capital Source Contango Peer Group Avg Other Info Senior Secured Revolving •Sep 2024 Maturity 13% 32% • 9 Banks in RCF group Credit Facility (“RCF”) Senior • No intention or need to raise 0% 29% unsecured notes Notes / Bonds Preferred • Converted remaining 0% 0% preferred units Summer 2020 Equity • Using stock as currency for Common acquisitions 87% 39% • Incentivizing employee base Equity with equity awards Source: Public Filings 1) Market data as of January 11, 2021. Excludes impact of MCEP merger and Project Silvertip acquisition. Peer group includes AMPY, BATL, BCEI, BRY, CDEV, CPE, ESTE, LPI, PVAC and SBOW 7


Asset Profile Current & target asset base characteristics yield low capital needs and predictable cash flows through our robust hedging program Asset Profile Low Capital Intensity Low PDP Low Drilling Decline Requirement Minimal Reliance on Drill Bit Few Lease Positive Cash Flow PDP Heavy Expirations 8Asset Profile Current & target asset base characteristics yield low capital needs and predictable cash flows through our robust hedging program Asset Profile Low Capital Intensity Low PDP Low Drilling Decline Requirement Minimal Reliance on Drill Bit Few Lease Positive Cash Flow PDP Heavy Expirations 8


Focus on Growth via Acquisition More economic to buy reserves rather than develop them given the current market dislocation Use track record of underwriting, buying and managing distressed assets as a competitive advantage Leverage proprietary relationships with legal advisors, investment banks and lenders to source unique opportunities Opportunity Flexible mandate hyper-focused on value Set Underwrite and analyze PDP and upside potential, but focus on producing cash flow Optimize production post transaction with cost cutting, workovers, and targeted capital spending 9Focus on Growth via Acquisition More economic to buy reserves rather than develop them given the current market dislocation Use track record of underwriting, buying and managing distressed assets as a competitive advantage Leverage proprietary relationships with legal advisors, investment banks and lenders to source unique opportunities Opportunity Flexible mandate hyper-focused on value Set Underwrite and analyze PDP and upside potential, but focus on producing cash flow Optimize production post transaction with cost cutting, workovers, and targeted capital spending 9


Executing Our Plan: Central OK YE 2020 Preview 5.00 Central Oklahoma value gain due to LOE reductions $4.5 4.50 4.00 ► Lease operating expenses (LOE) 48% lower than previous year prior to taking over operations 3.50 $2.9 3.00 ► LOE reduction is expected to result in >50% value increase in year 48% 2.50 over year value, or $41.7mm PV-10, for the Central Oklahoma region 2.00 $1.5 1.50 ► Year-end 2020 reserves for Central Oklahoma are expected to 1.00 exceed year-end 2019 reserves when normalized to the same pricing 0.50 0.00 Mar-19 Oct-19 Current  120 $103.1  100  80 $72.7  60 $41.7 ($13.8) $2.5  40  20  ‐ Year‐end 2019 Year Roll Revisions LOE Reduction Projected Year‐end 2020 Forward Values and reserves of Central Oklahoma properties prepared by William M. Cobb & Associates, the Company’s independent third party petroleum engineering firm, using strip pricing at August 4, 2020. Actual year-end 2019 is as of December 31, 2019 and projected year-end 2020 is estimated as of December 31, 2020. See Appendix for more information. 10 PV‐10 ($mm) Gross Total Production Expenses ($mm/month)Executing Our Plan: Central OK YE 2020 Preview 5.00 Central Oklahoma value gain due to LOE reductions $4.5 4.50 4.00 ► Lease operating expenses (LOE) 48% lower than previous year prior to taking over operations 3.50 $2.9 3.00 ► LOE reduction is expected to result in >50% value increase in year 48% 2.50 over year value, or $41.7mm PV-10, for the Central Oklahoma region 2.00 $1.5 1.50 ► Year-end 2020 reserves for Central Oklahoma are expected to 1.00 exceed year-end 2019 reserves when normalized to the same pricing 0.50 0.00 Mar-19 Oct-19 Current 120 $103.1 100 80 $72.7 60 $41.7 ($13.8) $2.5 40 20 ‐ Year‐end 2019 Year Roll Revisions LOE Reduction Projected Year‐end 2020 Forward Values and reserves of Central Oklahoma properties prepared by William M. Cobb & Associates, the Company’s independent third party petroleum engineering firm, using strip pricing at August 4, 2020. Actual year-end 2019 is as of December 31, 2019 and projected year-end 2020 is estimated as of December 31, 2020. See Appendix for more information. 10 PV‐10 ($mm) Gross Total Production Expenses ($mm/month)


Summary of Assets and Reserves January 2021 11 11Summary of Assets and Reserves January 2021 11 11


MCF Current Asset Overview Map of Current Assets Gulf of Mexico ► Stable production / cash flow base supported by active hedging program Southern Delaware ► Shallow shelf position Pecos Co. • Eugene Island situated in 13’ of water NE Bullseye ► 100% PDP ► Minimal incremental capex and total net P&A liabilities of < $9mm as of June 2020 Bullseye ► Significant upside opportunity via high impact exploratory prospects Southern Delaware ► ~7,700 net operated acres within premier U.S. onshore play Gulf of Mexico • Bullseye: ~5,700 net; NE Bullseye: ~2,000 net Southern Delaware Gulf of Mexico► Acreage materially de-risked from recent development by Contango and Central Oklahoma offset operators • Eugene Island 11 Western Anadarko ► 6 gross wells (2.25 net) to drill in 2021 to fully HBP acreage • Various Prospects Other Onshore • Represents majority of PUD value and capital requirements Note: Additional assets in Kansas, Mississippi, Wyoming and Gulf Coast are not shown ► Targeting WC A, WC B; prospective for Bone Spring ► Midstream integration / optionality – 18.5 miles of water pipeline and 2 active Q2 2020 Proved Proved SWDs (2) (2) Asset Area Net Production Reserves PV-10 Central Oklahoma (MBoe/d) MMBoe $mm % PDP % Liquids ► ~265,000 net acres; long-life, low decline assets with infrastructure Gulf of Mexico 2.7 18% 5.8 $40.6 100% (1) • 93% HBP / 84% operated (1) (1) • Average WI: ~69% / Average NRI: ~56% Southern Delaware 0.9 94% 5.1 26.6 91% ► Multiple target zones focused in the STACK and Cherokee Platform formations Central Oklahoma 9.1 47% 21.1 72.7 96% Western Anadarko 2.5 40% 7.9 29.2 100% Western Anadarko Other Onshore 0.9 60% 3.1 21.6 96% ► ~122,000 net acres; long-life, low decline assets (1) • 95% HBP / ~81% operated Total 16.1 44% 43.0 $190.7 97% (1) (1) • Average WI: ~74% / Average NRI: ~64% ► Low-risk upside potential 1) Figures are for operated, held by production acreage. 2) Net proved reserves and PV-10 are as of 12/31/2019 using strip pricing as of 8/4/2020; excludes reserves associated with ~37% interest in Exaro. PV-10 is a non-GAAP measure. See Appendix for more information. 12MCF Current Asset Overview Map of Current Assets Gulf of Mexico ► Stable production / cash flow base supported by active hedging program Southern Delaware ► Shallow shelf position Pecos Co. • Eugene Island situated in 13’ of water NE Bullseye ► 100% PDP ► Minimal incremental capex and total net P&A liabilities of < $9mm as of June 2020 Bullseye ► Significant upside opportunity via high impact exploratory prospects Southern Delaware ► ~7,700 net operated acres within premier U.S. onshore play Gulf of Mexico • Bullseye: ~5,700 net; NE Bullseye: ~2,000 net Southern Delaware Gulf of Mexico► Acreage materially de-risked from recent development by Contango and Central Oklahoma offset operators • Eugene Island 11 Western Anadarko ► 6 gross wells (2.25 net) to drill in 2021 to fully HBP acreage • Various Prospects Other Onshore • Represents majority of PUD value and capital requirements Note: Additional assets in Kansas, Mississippi, Wyoming and Gulf Coast are not shown ► Targeting WC A, WC B; prospective for Bone Spring ► Midstream integration / optionality – 18.5 miles of water pipeline and 2 active Q2 2020 Proved Proved SWDs (2) (2) Asset Area Net Production Reserves PV-10 Central Oklahoma (MBoe/d) MMBoe $mm % PDP % Liquids ► ~265,000 net acres; long-life, low decline assets with infrastructure Gulf of Mexico 2.7 18% 5.8 $40.6 100% (1) • 93% HBP / 84% operated (1) (1) • Average WI: ~69% / Average NRI: ~56% Southern Delaware 0.9 94% 5.1 26.6 91% ► Multiple target zones focused in the STACK and Cherokee Platform formations Central Oklahoma 9.1 47% 21.1 72.7 96% Western Anadarko 2.5 40% 7.9 29.2 100% Western Anadarko Other Onshore 0.9 60% 3.1 21.6 96% ► ~122,000 net acres; long-life, low decline assets (1) • 95% HBP / ~81% operated Total 16.1 44% 43.0 $190.7 97% (1) (1) • Average WI: ~74% / Average NRI: ~64% ► Low-risk upside potential 1) Figures are for operated, held by production acreage. 2) Net proved reserves and PV-10 are as of 12/31/2019 using strip pricing as of 8/4/2020; excludes reserves associated with ~37% interest in Exaro. PV-10 is a non-GAAP measure. See Appendix for more information. 12


Mid-Con Energy Partners, LP (“MCEP”) Asset Overview Map of Current Assets Mid-Con Energy Partners, LP (MCEP) Merger Agreement th ► On October 26 MCF announced a strategic merger with MCEP. The closing is scheduled to occur January 21, 2021 Pine Tree Unit • 13,000 acre waterflood MCEP – Low Decline Asset Base development ► Achieved significant debt paydown since 2015 through a series of strategic transactions ► Asset base is stable and low-decline ► Low capex development projects in WY and OK with material reserves and attractive economic returns Oklahoma ► Mature production with high cash flow margins and low production decline ► Track record of successful low-cost waterflood redevelopments generating significant free cash flow and reserves (e.g. Cleveland Field Unit) Oklahoma ► Multiple Cleveland formation waterflood redevelopment Wyoming opportunities in Central Oklahoma with significant upside Wyoming Q2 2020 Proved Proved (1) (1) ► Mature production with low overall production declines in the Asset Area Net Production Reserves PV-10 Big Horn and Powder River basins (MBoe/d) % Liquids MMBoe $mm % PDP ► Large waterflood units with immense scale offering significant Oklahoma 2.5 93% 17.7 128.3 91% redevelopment opportunities Wyoming 0.3 90% 6.2 45.5 29% ► Pine Tree is large 13,000 acre waterflood development requiring low capex to establish significant PDP value in the Total 2.8 23.9 $173.9 93% 74% near term Note: Figures are for operated, held by production acerage. 1) Net proved reserves and PV-10 are as of 12/31/2019 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 13Mid-Con Energy Partners, LP (“MCEP”) Asset Overview Map of Current Assets Mid-Con Energy Partners, LP (MCEP) Merger Agreement th ► On October 26 MCF announced a strategic merger with MCEP. The closing is scheduled to occur January 21, 2021 Pine Tree Unit • 13,000 acre waterflood MCEP – Low Decline Asset Base development ► Achieved significant debt paydown since 2015 through a series of strategic transactions ► Asset base is stable and low-decline ► Low capex development projects in WY and OK with material reserves and attractive economic returns Oklahoma ► Mature production with high cash flow margins and low production decline ► Track record of successful low-cost waterflood redevelopments generating significant free cash flow and reserves (e.g. Cleveland Field Unit) Oklahoma ► Multiple Cleveland formation waterflood redevelopment Wyoming opportunities in Central Oklahoma with significant upside Wyoming Q2 2020 Proved Proved (1) (1) ► Mature production with low overall production declines in the Asset Area Net Production Reserves PV-10 Big Horn and Powder River basins (MBoe/d) % Liquids MMBoe $mm % PDP ► Large waterflood units with immense scale offering significant Oklahoma 2.5 93% 17.7 128.3 91% redevelopment opportunities Wyoming 0.3 90% 6.2 45.5 29% ► Pine Tree is large 13,000 acre waterflood development requiring low capex to establish significant PDP value in the Total 2.8 23.9 $173.9 93% 74% near term Note: Figures are for operated, held by production acerage. 1) Net proved reserves and PV-10 are as of 12/31/2019 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 13


Project Silvertip Current Asset Overview Map of Current Assets Asset Highlights ► Closing scheduled for February 1, 2021 ► ~182,000 net acres; Significant operational control and 100% HBP ► Expands on pro-forma Wyoming footprint and establishes solid position of conventional, vertical production in the Permian Basin ► Adds sizable incremental volumes of long-life, low-decline PDP to Powder River Basin existing portfolio • Current total production volumes are >55% liquids; oily Big Horn and Permian assets are >72% liquids Big Horn Basin ► The Elk Basin Field in Wyoming provides access to significant resources in place • Over 1 billion barrels of estimated original oil in place • Cumulative production to date is over 500mmbo • Production from multiple formations on a large structure ► Recent vertical development in Red Lake area of the Northwest Shelf (Permian) Permian Basin • Benefit of new wellbores for future waterflood developments • Potential behind pipe targets and operational optimizations Q2 2020 Proved Proved Asset Area Net Production Reserves PV-10 (MBoe/d) % Liquids MMBoe $mm % PDP Texas Permian 3.4 65% 7.0 100% New Mexico Wyoming 96% 100% Big Horn 1.9 9.5 Montana Powder River Basin 1.7 0% 1.8 100% Total 7.0 57% 18.3 $130.3 100% Note: Figures are for operated, held by production acreage. Source: Undisclosed Seller. 1) Net proved reserves for Project Silvertip are unaudited estimates prepared by Undisclosed Seller as of 11/1/2020 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 14Project Silvertip Current Asset Overview Map of Current Assets Asset Highlights ► Closing scheduled for February 1, 2021 ► ~182,000 net acres; Significant operational control and 100% HBP ► Expands on pro-forma Wyoming footprint and establishes solid position of conventional, vertical production in the Permian Basin ► Adds sizable incremental volumes of long-life, low-decline PDP to Powder River Basin existing portfolio • Current total production volumes are >55% liquids; oily Big Horn and Permian assets are >72% liquids Big Horn Basin ► The Elk Basin Field in Wyoming provides access to significant resources in place • Over 1 billion barrels of estimated original oil in place • Cumulative production to date is over 500mmbo • Production from multiple formations on a large structure ► Recent vertical development in Red Lake area of the Northwest Shelf (Permian) Permian Basin • Benefit of new wellbores for future waterflood developments • Potential behind pipe targets and operational optimizations Q2 2020 Proved Proved Asset Area Net Production Reserves PV-10 (MBoe/d) % Liquids MMBoe $mm % PDP Texas Permian 3.4 65% 7.0 100% New Mexico Wyoming 96% 100% Big Horn 1.9 9.5 Montana Powder River Basin 1.7 0% 1.8 100% Total 7.0 57% 18.3 $130.3 100% Note: Figures are for operated, held by production acreage. Source: Undisclosed Seller. 1) Net proved reserves for Project Silvertip are unaudited estimates prepared by Undisclosed Seller as of 11/1/2020 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 14


Estimated Pro Forma Asset Overview Asset Map Asset and Operating Comparison Project Est. Pro Summary Metrics MCF MCEP Silvertip Forma Proved Reserves 43.0 23.9 18.3 85.2 (1) (MMBoe) Proved PV-10 $190.7 $173.9 $130.3 $494.9 (1) ($mm) Total Debt / (3) 1.09x 6.89x 1.80x 1.86x (2) EBITDAX RCF 9/17/2024 5/1/2021 N/A 9/17/2024 Maturity Date Current and Pro Forma Reserve Mix Project MCF MCEP Est Pro Forma Silvertip 2.7% 48.2% 22.6% 29.9% 70.1% 51.8% 97.3% 77.4% Contango 43.0 MMBoe 23.9 MMBoe 18.3 MMBoe 85.2 MMBoe Offshore Mid-Con Prospects Liquids Gas Project Silvertip Overlapping Acreage Note: Additional Contango assets in Kansas, Mississippi, and Gulf Coast are not shown 1) Net proved reserves for MCF and MCEP are as of 12/31/2019 using strip pricing as of 8/4/2020 and exclude reserves associated with ~37% interest in Exaro. Net proved reserves for Project Silvertip are unaudited estimates prepared by Undisclosed Seller as of 11/1/2020 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 2) Total debt as of 9/30/2020 and excludes debt associated with PPP loans; MCF & MCEP EBITDAX based on Q1 2020A Adjusted EBITDAX. Silvertip EBITDAX based on Jan and Feb 2020A Adjusted EBTIDAX. EBITDAX is a non-GAAP measure. See Appendix for more information. Debt assumed in Silvertip transaction defined as $58 million purchase price less $22 million of equity capital raised in the private placement. 3) Includes ~$1.9mm in expected annual synergies from the MCF and MCEP merger. 15Estimated Pro Forma Asset Overview Asset Map Asset and Operating Comparison Project Est. Pro Summary Metrics MCF MCEP Silvertip Forma Proved Reserves 43.0 23.9 18.3 85.2 (1) (MMBoe) Proved PV-10 $190.7 $173.9 $130.3 $494.9 (1) ($mm) Total Debt / (3) 1.09x 6.89x 1.80x 1.86x (2) EBITDAX RCF 9/17/2024 5/1/2021 N/A 9/17/2024 Maturity Date Current and Pro Forma Reserve Mix Project MCF MCEP Est Pro Forma Silvertip 2.7% 48.2% 22.6% 29.9% 70.1% 51.8% 97.3% 77.4% Contango 43.0 MMBoe 23.9 MMBoe 18.3 MMBoe 85.2 MMBoe Offshore Mid-Con Prospects Liquids Gas Project Silvertip Overlapping Acreage Note: Additional Contango assets in Kansas, Mississippi, and Gulf Coast are not shown 1) Net proved reserves for MCF and MCEP are as of 12/31/2019 using strip pricing as of 8/4/2020 and exclude reserves associated with ~37% interest in Exaro. Net proved reserves for Project Silvertip are unaudited estimates prepared by Undisclosed Seller as of 11/1/2020 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 2) Total debt as of 9/30/2020 and excludes debt associated with PPP loans; MCF & MCEP EBITDAX based on Q1 2020A Adjusted EBITDAX. Silvertip EBITDAX based on Jan and Feb 2020A Adjusted EBTIDAX. EBITDAX is a non-GAAP measure. See Appendix for more information. Debt assumed in Silvertip transaction defined as $58 million purchase price less $22 million of equity capital raised in the private placement. 3) Includes ~$1.9mm in expected annual synergies from the MCF and MCEP merger. 15


Estimated Pro Forma 1P Reserves – 8/4/2020 NYMEX Strip Pricing Total 1P Reserves Oil Gas NGL Total PV-10 (MMBbl) (Bcf) (MMBbl) (MMBoe) ($mm) Proved Developed Producing (PDP) 38.5 149.1 12.7 76.1 $446.2 Proved Developed Non-Producing (PDNP) 0.1 0.7 0.0 0.2 $1.8 Proved Undeveloped (PUD) 8.0 3.2 0.4 8.9 $46.9 Total Proved Reserves (1P) 46.6 153.0 13.1 85.2 $494.9 Total 1P Mix Total 1P PV-10 by Category Total 1P PV-10 by Area 0% 10% 15% 35% 55% 30% 39% 26% 90% Project MCF MCEP GRIZZ PDP PDNP PUD Oil Gas NGL Silvertip Total MMBoe: 92.9 Total PV-10: $494.9mm Total PV-10: $494.9mm Note: Net proved reserves for MCEF and MCEP are as of 12/31/2019 using strip pricing as of 8/4/2020 and exclude reserves associated with ~37% interest in Exaro. Net proved reserves for Project Silvertip are unaudited estimates prepared by Undisclosed Seller as of 11/1/2020 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 16Estimated Pro Forma 1P Reserves – 8/4/2020 NYMEX Strip Pricing Total 1P Reserves Oil Gas NGL Total PV-10 (MMBbl) (Bcf) (MMBbl) (MMBoe) ($mm) Proved Developed Producing (PDP) 38.5 149.1 12.7 76.1 $446.2 Proved Developed Non-Producing (PDNP) 0.1 0.7 0.0 0.2 $1.8 Proved Undeveloped (PUD) 8.0 3.2 0.4 8.9 $46.9 Total Proved Reserves (1P) 46.6 153.0 13.1 85.2 $494.9 Total 1P Mix Total 1P PV-10 by Category Total 1P PV-10 by Area 0% 10% 15% 35% 55% 30% 39% 26% 90% Project MCF MCEP GRIZZ PDP PDNP PUD Oil Gas NGL Silvertip Total MMBoe: 92.9 Total PV-10: $494.9mm Total PV-10: $494.9mm Note: Net proved reserves for MCEF and MCEP are as of 12/31/2019 using strip pricing as of 8/4/2020 and exclude reserves associated with ~37% interest in Exaro. Net proved reserves for Project Silvertip are unaudited estimates prepared by Undisclosed Seller as of 11/1/2020 using strip pricing as of 8/4/2020. PV-10 is a non-GAAP measure. See Appendix for more information. 16


PV-10 Definition PV-10 is a non-GAAP financial measure and represents the present value, discounted at 10% per year, of estimated future cash inflows from proved natural gas and crude oil reserves, less future development and production costs using pricing assumptions in effect at the end of the period. PV-10 differs from Standardized Measure because it does not include the effects of income taxes on future net revenues. Neither PV-10 nor Standardized Measure represents an estimate of fair market value of our natural gas and crude oil properties. PV-10 is used by the industry and by our management as an arbitrary reserve asset value measure to compare against past reserve bases and the reserve bases of other business entities that are not dependent on the taxpaying status of the entity. For purposes of the following table, proved reserves and PV-10 as of December 31, 2019 is calculated using SEC pricing. The following table provides a reconciliation of our Standardized Measure to PV-10 (in millions): Reconciliation of SEC PV‐10 and Adjusted PV‐10 (non‐GAAP) – Proved Reserves December 31, 2019 MCF MCEP Pro Forma (in millions) (in millions) (in millions) Standardized measure of future discounted cash flows (proved reserves) $           257.8 $           241.2 $           499.0 (1) Add: Present value of future income taxes attributable to proved reserves discounted at 10%                  28.7                       ‐                 28.7 SEC PV‐10 ‐ Proved reserves $           286.6 $           241.2 $           527.8 Less: Adjustment for strip pricing as of August 4, 2020 for proved reserves               (95.9)               (71.3)             (167.1) (2) Add: Other Adjustments                        ‐                   4.0                   4.0 Adjusted PV‐10 of proved reserves $           190.7 $           173.9 $           364.6 A reconciliation of PV-10 for the Undisclosed Seller Assets or the pro forma combined company to standardized measure is unavailable to Contango without unreasonable effort. Contango is not able to provide a quantitative reconciliation because certain items required for such reconciliation are not available to and/or cannot be reasonably determined. 1) No future income taxes are computed for MCEP, because it’s a non-taxable entity 2) Timing differences and other 17PV-10 Definition PV-10 is a non-GAAP financial measure and represents the present value, discounted at 10% per year, of estimated future cash inflows from proved natural gas and crude oil reserves, less future development and production costs using pricing assumptions in effect at the end of the period. PV-10 differs from Standardized Measure because it does not include the effects of income taxes on future net revenues. Neither PV-10 nor Standardized Measure represents an estimate of fair market value of our natural gas and crude oil properties. PV-10 is used by the industry and by our management as an arbitrary reserve asset value measure to compare against past reserve bases and the reserve bases of other business entities that are not dependent on the taxpaying status of the entity. For purposes of the following table, proved reserves and PV-10 as of December 31, 2019 is calculated using SEC pricing. The following table provides a reconciliation of our Standardized Measure to PV-10 (in millions): Reconciliation of SEC PV‐10 and Adjusted PV‐10 (non‐GAAP) – Proved Reserves December 31, 2019 MCF MCEP Pro Forma (in millions) (in millions) (in millions) Standardized measure of future discounted cash flows (proved reserves) $ 257.8 $ 241.2 $ 499.0 (1) Add: Present value of future income taxes attributable to proved reserves discounted at 10% 28.7 ‐ 28.7 SEC PV‐10 ‐ Proved reserves $ 286.6 $ 241.2 $ 527.8 Less: Adjustment for strip pricing as of August 4, 2020 for proved reserves (95.9) (71.3) (167.1) (2) Add: Other Adjustments ‐ 4.0 4.0 Adjusted PV‐10 of proved reserves $ 190.7 $ 173.9 $ 364.6 A reconciliation of PV-10 for the Undisclosed Seller Assets or the pro forma combined company to standardized measure is unavailable to Contango without unreasonable effort. Contango is not able to provide a quantitative reconciliation because certain items required for such reconciliation are not available to and/or cannot be reasonably determined. 1) No future income taxes are computed for MCEP, because it’s a non-taxable entity 2) Timing differences and other 17


Reserves Disclaimer Reserves Disclaimer The SEC requires oil and gas companies, in their filings with the SEC, to disclose proved reserves, which are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions (using unweighted average 12-month first day of the month prices), operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. In this presentation, we use the terms “proved reserves,” “proved developed producing (PDP)”, “proved developed non-producing (PDNP)”, “proved undeveloped (PUD)”, “upside”, and other descriptions of volumes of hydrocarbons potentially recoverable, through additional drilling or recovery techniques. None of the estimates contained in this release conform to SEC guidelines and were estimated under different pricing assumptions than the unweighted average 12-month first day of the month prices. All Contango reserves at December 31, 2019, were prepared by William M. Cobb & Associates, the Company’s independent third party petroleum engineering firm. Information regarding MCEP and the Undisclosed Seller Assets reserves was based on information provided, and representations made, by MCEP or Undisclosed Seller, respectively, and Contango disclaims any responsibility for its accuracy. Strip Pricing at August 4, 2020 is as follows: Yearly Average : Year WTI HH 2020 $41.83 $2.30 2021 $43.85 $2.77 2022 $45.19 $2.55 2023 $46.11 $2.46 2024 $46.98 $2.50 2025 $47.95 $2.58 2026 $49.02 $2.65 2027 $50.12 $2.70 2028 $51.23 $2.78 2029 $52.33 $2.90 This presentation includes reserves information pro forma for the Combined Company. Contango did not construct a consolidated reserves report of the Combined Company and did not engage an independent reserves engineer to produce such a report. The MCEP and the Undisclosed Seller Assets reserves are based on the MCEP or Undisclosed Seller development plan, which may differ from the plan that would be adopted by the combined company. Therefore, the pro forma reserves information and results of the Combined Company shown in this presentation are not necessarily indicative of actual future results of the Combined Company and such actual results may differ materially. Estimates of proved reserves disclosed in this presentation should be read together with the estimates of proved reserves that have been prepared in accordance with applicable SEC regulations and included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2019. Non-GAAP Financial Measures This presentation includes the non-GAAP financial measures, EBITDAX and PV-10. EBITDAX represents net income (loss) before interest expense, taxes, depreciation, depletion and amortization, and oil and gas exploration expenses. We have included EBITDAX. We believe EBITDAX is an important supplemental measure of operating performance because it eliminates items that have less bearing on our operating performance and therefore highlights trends in our core business that may not otherwise be apparent when relying solely on GAAP financial measures. We also believe that securities analysts, investors and other interested parties frequently use EBITDAX in the evaluation of companies, many of which present EBITDAX when reporting their results. A reconciliation of EBITDAX, for Mid-Con, for Silvertip, or pro forma for Mid-Con, to net income (loss) is unavailable to Contango without unreasonable effort. Contango is not able to provide a quantitative reconciliation because certain items required for such reconciliation are outside of the company's control and/or cannot be reasonably determined. 18Reserves Disclaimer Reserves Disclaimer The SEC requires oil and gas companies, in their filings with the SEC, to disclose proved reserves, which are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions (using unweighted average 12-month first day of the month prices), operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. In this presentation, we use the terms “proved reserves,” “proved developed producing (PDP)”, “proved developed non-producing (PDNP)”, “proved undeveloped (PUD)”, “upside”, and other descriptions of volumes of hydrocarbons potentially recoverable, through additional drilling or recovery techniques. None of the estimates contained in this release conform to SEC guidelines and were estimated under different pricing assumptions than the unweighted average 12-month first day of the month prices. All Contango reserves at December 31, 2019, were prepared by William M. Cobb & Associates, the Company’s independent third party petroleum engineering firm. Information regarding MCEP and the Undisclosed Seller Assets reserves was based on information provided, and representations made, by MCEP or Undisclosed Seller, respectively, and Contango disclaims any responsibility for its accuracy. Strip Pricing at August 4, 2020 is as follows: Yearly Average : Year WTI HH 2020 $41.83 $2.30 2021 $43.85 $2.77 2022 $45.19 $2.55 2023 $46.11 $2.46 2024 $46.98 $2.50 2025 $47.95 $2.58 2026 $49.02 $2.65 2027 $50.12 $2.70 2028 $51.23 $2.78 2029 $52.33 $2.90 This presentation includes reserves information pro forma for the Combined Company. Contango did not construct a consolidated reserves report of the Combined Company and did not engage an independent reserves engineer to produce such a report. The MCEP and the Undisclosed Seller Assets reserves are based on the MCEP or Undisclosed Seller development plan, which may differ from the plan that would be adopted by the combined company. Therefore, the pro forma reserves information and results of the Combined Company shown in this presentation are not necessarily indicative of actual future results of the Combined Company and such actual results may differ materially. Estimates of proved reserves disclosed in this presentation should be read together with the estimates of proved reserves that have been prepared in accordance with applicable SEC regulations and included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2019. Non-GAAP Financial Measures This presentation includes the non-GAAP financial measures, EBITDAX and PV-10. EBITDAX represents net income (loss) before interest expense, taxes, depreciation, depletion and amortization, and oil and gas exploration expenses. We have included EBITDAX. We believe EBITDAX is an important supplemental measure of operating performance because it eliminates items that have less bearing on our operating performance and therefore highlights trends in our core business that may not otherwise be apparent when relying solely on GAAP financial measures. We also believe that securities analysts, investors and other interested parties frequently use EBITDAX in the evaluation of companies, many of which present EBITDAX when reporting their results. A reconciliation of EBITDAX, for Mid-Con, for Silvertip, or pro forma for Mid-Con, to net income (loss) is unavailable to Contango without unreasonable effort. Contango is not able to provide a quantitative reconciliation because certain items required for such reconciliation are outside of the company's control and/or cannot be reasonably determined. 18