Slide 1: Wakefield-Harrison GU B #1 Re-entry, deepening and subsurface evaluation
Empire Petroleum Corporation Wakefield-Harrison GU B #1 Re-entry, deepening and subsurface evaluation — technical brief Fort Trinidad Field · Madison County, Texas AUGUST 2026 www.empirepetroleumcorp.com NYSE American: EP
Slide 2: Disclaimer
Disclaimer Cautionary Note Regarding Well Data Log data, sidewall core recovery and hydrocarbon shows indicate the presence of hydrocarbons and provide information on reservoir quality. They are not a measurement of producible reserves and are not indicative of commercial flow rates. The Wakefield-H
Slide 3: Empire 21,006' vs Depth Relative to Play Offsets
Empire 21,006’ vs Depth Relative to Play Offsets 21,006’ 19,236’ 18,551’ ~16,000’ ~12,000’ Empire Petroleum Expand Energy Comstock Western Wakefield- Original Bobby Yancey #1 Resources Haynesville Play Harrison GU B#1 Haynesville Play Dec 2024 McCullough GLR #3 Play opened 2022 2026 2025 Depth bring
Slide 4: Summary of Results
Summary of Results 21,006 ft 4,000+ ft 434°F ~$4.4 MM measured depth gross logged interval maximum logging spent to date 20,949 ft true vertical Approximately 17,000 to temperature Against approximately $30.0 depth. Re-entered, 21,000 ft, spanning the Travis A complete open-hole to $45.0 million per
Slide 5: The Well and the Evaluation
THE WELL AND THE EVALUATION
Slide 6: Re-Entry Scope of Work
Re-Entry Scope of Work Re-entered and cleaned out to 21,006 ft measured depth. 7-inch casing at approximately 16,997 ft, leaving the section below in open hole. Empire's logged interval corresponds to that 2030' open-hole section. Overcoming vast amounts of mechanical complications, packers, unknown
Slide 7: Logging Program and Downhole Conditions
Logging Program and Downhole Conditions Ran a complete, modern open-hole logging suite and recovered sidewall cores over the objective section. Roughly 4,000 ft of gross interval, from approximately 17,000 to 21,000 ft, spanning the Travis Peak, Cotton Valley Sand, Bossier and Haynesville. Maximum r
Slide 8: Roughly 10-11,000 Feet of New Section
Roughly 10-11,000 Feet of New Section ≈10,000 ft → 21,006 ft Historic field development depth Logged and cored in 2026 INTERMEDIATE PRODUCTION ZONE (“IPZ”) — AT AND BELOW ≈10,000 FT Lower Glen Rose, Rodessa, James Lime, Pettet, Upper Travis Peak. Reached by deepening existing wellbores. The Glen Ros
Slide 9: Structural Setting Across the Column
Structural Setting Across the Column Fort Trinidad sits above a deep-seated salt feature. Salt movement upwards at depth has driven fracture development through the overlying carbonate section. The 1961 Upper Glen Rose discovery that named the field was found on that feature, which localized the ool
Slide 10: Development Plan and Infrastructure
DEVELOPMENT PLAN AND INFRASTRUCTURE
Slide 11: A Phased Development Plan
A Phased Development Plan PHASE ONE — UNDERWAY (IPZ) PHASE TWO — DATA COLLECTED Deepenings Deep Gas Intermediate Productive Zone (IPZ) Deep Productive Zone (DPZ) Lower Glen Rose and Rodessa, James Lime, Pettet and Upper Lower Travis Peak, Cotton Valley Sand, Bossier and Haynesville Travis Peak, reac
Slide 12: Midstream Already in Place
Midstream Already in Place 49+ 2 9.5 HP taps miles of pipeline owned and separate takeaway outlets, MMcf/d low-pressure direct access into the high- operated both to investment-grade compression at the plant pressure system counterparties Getting gas to market is a bottleneck in this part of East Te
Slide 13: Empire Cost Advantage Driving Competitive Value
Empire Cost Advantage Driving Completive Value $30.0–45.0 MM per well ~$4.4 MM to date New drill and complete Empire — re-entry, underream, cleanout and evaluation in this play Reported costs above $3,000 For a wellbore that reaches per lateral foot. deeper than any of them. Empire pursued the lowes
Slide 14: Offset Operator Results in the Play
Offset Operator Results in the Play OPERATOR WELL OR PROGRAM REPORTED RESULT Comstock Resources 11 wells turned to sales YTD 2026, 10,331 ft 31 MMcf/d average IP (33 MMcf/d for 12 NYSE: CRK average lateral; 545,000+ net acres, 40+ wells wells in 2025); 3.5 Bcf per 1,000 lateral ft EUR online Expand
Slide 15: Next Steps
Next Steps 01 Petrophysical interpretation of the log suite First well successfully obtained the data for the IPZ and DPZ. Currently tying in Logs, Sidewall Cores, VSPs, existing 3D Seismic and reprocess to pick optimal horizontal targets. 02 Laboratory analysis of the sidewall cores Cores are at th
Slide 16: Thank you
Thank you Phil Mulacek, Chairman of the Board Mike Morrisett, President, CEO & Director 539.444.8002 info@empirepetrocorp.com Disclaimer: This presentation is for information purposes only and does not constitute an offer to sell or issue, or the solicitation of an offer to buy, acquire or subscribe