Amplify Energy Corp. · NYSE:AMPY

Amplify Energy — Investor Presentation (March 2026)

28 slides from Amplify Energy's investor presentation, Mar 9, 2026

  1. Slide 1: Investor Presentation

    NYSE: AMPY www.amplifyenergy.com Investor Presentation March 9, 2026

  2. Slide 2: Forward Looking Statements

    Forward Looking Statements This presentation includes “forward-looking statements” within the meaning of 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 fact, included in th

  3. Slide 3: Non-GAAP Disclosure / Oil and Gas Reserves

    Non-GAAP Disclosure / Oil and Gas Reserves Use of Non-GAAP Financial Measures. Amplify uses the non-GAAP financial measures of Adjusted EBITDA, free cash flow, PV-10/20 and cash G&A. The accompanying schedules include the non-GAAP financial measures of Adjusted EBITDA, free cash flow, PV-10/20 and c

  4. Slide 4: Executing on Amplify's Go-Forward Strategy

    Executing on Amplify’s Go-Forward Strategy Simplify the Portfolio: – Divested assets in East Texas, Oklahoma, and the Eagle Ford for gross proceeds of approximately $250 MM – Streamlined corporate structure and reduced overhead through a right-sized organizational footprint – Reduced operational com

  5. Slide 5: Portfolio Overview

    Portfolio Overview Driving Value in Mature Oil Fields Amplify Energy operates two mature and prolific oilfields with Asset Locator Map significant upside as a 100% WI owner Bairoil Beta Bairoil Pacific Outer-Continental Shelf Greater Green River Basin, WY  Discovered in 1977 by Royal  Discovered i

  6. Slide 6: Compelling Valuation with Additional Upside

    Compelling Valuation with Additional Upside Key Points Proved Reserves Summary1  Proved reserve (1P) value at various flat pricing scenarios PD PV-10 & PUD PV-20 ($ MM)1,6 is greater than Amplify's current enterprise value Category At Various WTI Flat Oil Prices WTI Price: $60 $65 $70 $80  Premium

  7. Slide 7: Beta Overview

    Beta Overview Federal Waters Asset Locator Map Key Stats & Highlights  Net Acres: ~17,000 acres1 ‒ WI %: 100% ‒ NRI%: ~75.2%  Net Production: 3.6 MBoe/d2  Oil Mix: 100%2  1P Reserves: 24.3 MMBoe3,5  1P R/P: ~18 years3,4,5  P&A obligation supported by $172 MM of surety bonds, plus a growing sin

  8. Slide 8: Beta Geology & Reservoir Overview

    Beta Geology & Reservoir Overview  Beta is a large oil accumulation with similar reservoir characteristics as the onshore LA Basin fields  Approximately 1 billion barrels of original oil in place with approximately 10% recovered to date; analogous onshore fields have demonstrated 30 – 40% recovery

  9. Slide 9: Development Evolution & Risk Mitigation

    Development Evolution & Risk Mitigation Key Points Legacy Development Current Development  Continuous development analysis and improvement has led to the evolution from angled directional wellbores that commingle production from all six sandstones (A – F) to horizontal wellbores that contact more o

  10. Slide 10: Average Net Production (Bopd)

    Historical | Projected Production Growth Key Points Beta Production Growth  Following the re-start of the Beta field in 6,000 Mid-Point of 2026 Production early 2023, production has grown Guidance Implies significantly from the completion of 6 ~20% growth rate at Beta development wells from 6/2024

  11. Slide 11: 2024|2025 Beta Development Well Locations

    2024|2025 Beta Development Well Locations D-Sand Horizontal Development \ = Producing D sand Completion Joulters Fault Block (“FB”) Ellen  Three D-Sand horizontal wells completed in the Joulters fault Main Fault block Block  Joulters is largely undeveloped with virgin pressures and predicable oil

  12. Slide 12: Joulters Fault Block Overview

    Joulters Fault Block Overview Total Resource Potential Joulters Fault Block Ideal for Full D-Sand Development Key Points Eureka  Approximately 70 million barrels of Original Oil in Place (“OOIP”) in the D-Sand of the Joulters fault block  Estimated recovery factor of 30% to 40%, implying total rec

  13. Slide 13: Joulters Fault Block Development Results

    Joulters Fault Block Development Results D-Sand Joulters Fault Block Drilling Results (Actual Production) vs. Type Curve Key Points1,2 C59 C54 C08 Joulters D TC  Updated Joulters type curve ~25% higher than previous 10,000 Beta type curve Gross Oil Rate (Bopd)  3 wells drilled in the Joulters faul

  14. Slide 14: Main Fault Block Development Results

    Main Fault Block Development Results D-Sand Main Fault Block Drilling Results (Actual Production) vs. Type Curve Key Points1,2 A50 C61 Main FB D TC  2 wells drilled in the Main fault block to date as 10,000 horizontal wells in the D-Sand Gross Oil Rate (Bopd) − A50: 266’ completion interval; comple

  15. Slide 15: D-Sand Current Development Inventory

    D-Sand Current Development Inventory Key Points \ = Producing D sand Completion  29 total D Sand locations identified \ = Proposed D sand Completion − 22 Joulters FB location at average ~1,200’ lateral lengths Ellen − 7 Main FB locations at average ~1,000’ lateral lengths  Joulters locations at ap

  16. Slide 16: 2024|2025 Beta Development Locations + 1H26 Planned Locations

    2024|2025 Beta Development Locations + 1H26 2026 Planned Locations Ellen Key Points \ = Producing D sand Completion \ = Proposed D sand Completion  The next 4 wells currently anticipated to Main Fault be drilled in 1H26 consist of three wells Block in the Joulters fault block and one well in the Ma

  17. Slide 17: Bairoil Overview

    Bairoil Overview Asset Locator Map Key Stats & Highlights  Net Acres: ~7,000 acres1 ‒ WI %: 100% ‒ NRI%: ~88%  Net Production: 2.9 MBoe/d2  Oil Mix: 100%2  1P Reserves: 11.3 MMBoe3,5  1P R/P: ~13 years3,4,5  2026 focus on cost savings and CCUS potential  Long-life, low-decline oil-weighted pr

  18. Slide 18: Focused on Optimizing Cost with Value Upside

    Focused on Optimizing Cost with Value Upside Bairoil Cost Reductions Additional Value Potential Average Monthly LOE, $ MM  New CO2 purchase contract and CO2 compression optimization project expected to generate ~$10 MM in $16 LOE savings annually  Currently evaluating power generation and CCUS opp

  19. Slide 19: Investment Highlights

    Investment Highlights Net Cash Position, Beta Development and Operational Efficiency Initiatives Drive Shareholder Value Implied Year-End 2025 1P Equity Value Represents a ~40 – 70% Premium to Current Share Price1,2 Beta Field Development Proves Up Additional Reserves and Profitability Bairoil Cost

  20. Slide 20: Appendix

    elaa ements —_ acini ae ier : Ps, i mm 7

  21. Slide 21: Amplify Corporate ESG Profile

    Amplify Corporate ESG Profile  Streamlined the portfolio through the divestiture of higher-emission assets Environmental  Performed platform electrification and other emissions reducing projects Focus at Beta  Comprehensive employee health and safety program with dedicated EH&S personnel at each

  22. Slide 22: 2026 Guidance and Details

    2026 Guidance and Details FY 2026E Low High Net Average Daily Production Oil (MBbls/d) 6.7 - 7.9 Commodity Price Differential / Realizations (Unhedged) Oil Differential ($ / Bbl) ($6.00) - ($9.00) Gathering, Processing and Transportation Costs Oil ($ MM) $2 - $3 Average Costs Lease Operating ($ MM)

  23. Slide 23: Crude Hedge Detail

    Crude Hedge Detail Key Points  Amplify maintains a robust hedge book to support our cash flow profile and provide downside protection in weak commodity environments, with upside in higher pricing environments  Amplify will look to layer additional positions as opportunities arise 2026-2027 Crude H

  24. Slide 24: Non-GAAP Reconciliations

    Non-GAAP Reconciliations Twelve Months Twelve Months Twelve Months Three Months Three Months Three Months Three Months Ended Ended Ended Ended Ended Ended Ended December 31, 2025 December 31, 2024 December 31, 2023 December 31, 2025 September 30, 2025 June 30, 2025 March 31, 2025 (Amounts in $000s)

  25. Slide 25: Non-GAAP Reconciliations (Cont'd)

    Non-GAAP Reconciliations (Cont’d) Twelve Months Twelve Months Twelve Months Three Months Three Months Three Months Three Months Ended Ended Ended Ended Ended Ended Ended December 31, 2025 December 31, 2024 December 31, 2023 December 31, 2025 September 30, 2025 June 30, 2025 March 31, 2025 (Amounts i

  26. Slide 26: Non-GAAP Reconciliations (Cont'd)

    Non-GAAP Reconciliations (Cont’d) Reconciliation of Total G&A to Cash G&A Amplify defines cash G&A as general and administrative expense, less share-based compensation expense; acquisition and divestiture costs; bad debt expense; and severance payments. Cash G&A is an important non-GAAP financial me

  27. Slide 27: Non-GAAP Reconciliations (Cont'd)

    Non-GAAP Reconciliations (Cont’d) Reconciliation of PV-10 to Standardized Measure Amplify defines PV-10, which is a non-GAAP financial measure that represents the present value of estimated future cash inflows from proved oil and natural gas reserves that are calculated using the unweighted arithmet

  28. Slide 28: NYSE: AMPY | amplifyenergy.com

    NYSE: AMPY | amplifyenergy.com

Amplify Energy — Investor Presentation (March 2026) on 6ix