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Home My WebLink About221-048 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Mooses Tooth DATE: 12/19/2023 Transmitted: North Slope, Mooses Tooth Unit Via hard drive data drop Moose's Tooth MT6-08 50-103-20772-00 218048_MT6-08_JetCutter_22Apr2022 218048_MT6-08_Puncher_02Feb2022 MT6-09 50-103-20779-00 218134_MT6-09_Puncher_18Feb2022 218134_MT6-09_SBHP_16Feb2022 218134_MT6-09_Tubing Cut_22Feb2022 MT7-01 50-10-320832-00 221052_MT7-01_Perf_29Oct2022 221052_MT7-01_PPROF_03Feb2023 MT7-02 50-103-20840-00 222026_MT7-02_ChemCut_21Dec2022 222026_MT7-02_Plug&Perf_17Apr2023 MT7-03 50-103-20830-00 221024_MT7-03_GR_12Aug23 221024_MT7-03_MechCutter_31Oct23 221024_MT7-03_RBP_1Nov23 MT7-05 50-103-20833-00 221087_MT7-05_PPROF_20Apr2023 221087_MT7-05_SCMT_25Dec2021 MT7-06 50-103-20831-00 221048_MT7-06_IBC-DSLT_04Oct2022 1of 3 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38419 T38420 T38421 T38422 T38423 T38424 T38425 2/29/2024 MT7-06 50-103-20831-00 221048_MT7-06_IBC-DSLT_04Oct2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:56:14 -09'00' 1a. Well Status:Oil SPLUG Other Abandoned 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ______________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 69' FSL, 2406' FWL S6 T9N R2E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 100.9 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" H-40 120' 13.375" L-80 3052' 7.625" L-80 3246' 24. Open to production or injection?Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate TUBING RECORD 11" 3735' 12219'4.5" tubing tail 10143'MD/7292'TVD 16" PACKER SET (MD/TVD) Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 3074'MD/2823'TVD-3730'MD/3247'TVD 6211'MD/4829'TVD-7014'MD/5344'TVD 7014'MD/5344'TVD-7807'MD/5853'TVD 9202'MD/6730'TVD-10081'MD/7255'TVD plug: 87bbls 15.8 ppg Class G plug: 37bbls 15.8 ppg Class G Plug: 37bbls 15.8 ppg Class G Plug: 33bbls 15.8 ppg Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 10/02/2022: 7770'MD/5829'TVD-7790'MD/5842'TVD 08/10/2021: 10923'MD/7748'TVD-10925'MD/7749'TVD Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A 40' 40' Per 20 AAC 25.283 (i)(2) attach electronic information 29.7 37 94 68 120' 37' 3730' SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. TOP SETTING DEPTH MD 5915791 Greater Mooses Tooth/Rendevous Pool AA081800, AA081781, AA081736 932535000, 932516000, 300840000 N/A CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, BOTTOMCASINGWT. PER FT.GRADE 285165 290953 CEMENTING RECORD 5909744 982'MD/981'TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/7/2022 221-048/321-396/321-368/321-535 42" 40' 40' 3425' Suspended 501-103-20831-00-00 GMT/MT7-06 9/30/2022 26153'MD/8483'TVD 3074'MD/2823' TVD 140.4 P.O.Box 100360, Anchorage, AK 99510-0360 289937 968' FSL, 1859' FWL S32 T10N R2E UM 3614' FSL, 3329' FWL S20 T9N R2E 10/7/2022 SETTING DEPTH TVD 5897282 TOP HOLE SIZE AMOUNT PULLED Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Abandoned 10/7/2022 JSB RBDMS JSB 022823 By Meredith Guhl at 1:01 pm, Mar 02, 2023 xG DSR-3/3/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 982 981 C-30 1662 1649 2028 1993 3348 3004 K-2 3880 3334 Albian 97 4301 3610 Albian 96 4599 3799 HRZ 10395 7442 Kalubik 10512 7511 Kuparuk C 10716 7631 10724 7636 12396 8339 26153 8483 31. List of Attachments: Well Schematic, Cement Operations, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jenna Taylor Digital Signature with Date: Contact Phone:907-263-4522 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. LCU/Miluveach C-10 Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Contact Email: jenna.l.taylor@conocophillips.com Authorized Title: Wells Analyst K-3 If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Formation Name at TD: Alpine D Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval Alpine C Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Page 1/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/22/2022 12:00 9/22/2022 15:00 3.00 MIRU, MOVE DMOB P Move pump complex to make room for coil unit. 0.0 0.0 9/22/2022 15:00 9/23/2022 00:00 9.00 MIRU, MOVE OTHR P Clean and clear rig floor, Work on pipe skate, change out pump liners from 5.5" to 6.5". Servicing plug valves, Inspect mud pit ISO valves, C/O butterfly valves in pits. 0.0 0.0 9/23/2022 00:00 9/23/2022 15:00 15.00 MIRU, MOVE OTHR P Continue rig PM's, cleanning and maintenance. Service valves on squeeze manifold Inspect mud pump and injection valves Organize rig floor cabinets Installl discharge skirt on centrifuge PM's on mud pits Inspect Demco valves on rig floor Check Koomy bottle pressure BW Maintinance on BOP Cellar Demco valve inspection Pipe skate maintiance 0.0 0.0 9/23/2022 15:00 9/23/2022 18:00 3.00 MIRU, MOVE OTHR P Disconnect pits interconnects, Secure energy track, Mud line/cement lines in derrick. Stow and pin C-Section. Weld on pipe skate. 0.0 0.0 9/23/2022 18:00 9/23/2022 21:00 3.00 MIRU, MOVE OTHR P Send cattle shoot to pipe shed, Skid rig floor to MOB position and L/D derrick. 0.0 0.0 9/23/2022 21:00 9/24/2022 00:00 3.00 MIRU, MOVE OTHR P Prep modules to move. Unpin Pipe shed from sub. 0.0 0.0 9/24/2022 00:00 9/24/2022 03:00 3.00 MIRU, MOVE OTHR P Pick up rig matts to prep for respotting. Unpin pip shed from sub. Prep to Move casing and pipe module. 0.0 0.0 9/24/2022 03:00 9/24/2022 06:00 3.00 MIRU, MOVE MOB P Stomp casing module away from pipe module. 0.0 0.0 9/24/2022 06:00 9/24/2022 08:30 2.50 MIRU, MOVE OTHR P Prep pad/dirt work for mat lay out. Coil tubing RDMO, Rig down hard line and prep pad for crane operations. 0.0 0.0 9/24/2022 08:30 9/24/2022 12:00 3.50 MIRU, MOVE OTHR P Continue with pad work. SIMOPS: Remove well house and jungle Gym. 0.0 0.0 9/24/2022 12:00 9/24/2022 15:00 3.00 MIRU, MOVE OTHR P Continue with pad work and Lay out mats. Stump out pipe module 5'. SIMOPS: Spot LRS at 1500hrs. 0.0 0.0 9/24/2022 15:00 9/24/2022 21:00 6.00 MIRU, MOVE OTHR P Level pad (shim mats as needed), Paint in pits, install splash skirt on centrifuge. SIMOPS: remove BOP studs to make ready for shipment. 0.0 0.0 9/24/2022 21:00 9/25/2022 00:00 3.00 MIRU, MOVE DMOB P Stump out pipe shed module. Stump out pit module and place on suspension. 0.0 0.0 9/25/2022 00:00 9/25/2022 04:30 4.50 MIRU, MOVE DMOB P Stomp out pipe shed module, Stump out Sub off MT7-99 well at 0230hrs. Continue stomp sub to install jeep. 0.0 0.0 9/25/2022 04:30 9/25/2022 09:30 5.00 MIRU, MOVE MOB P Install Jeep onto sub, Start to move sub onto MT7-06 well. SIMOPS: Stage pit, pump and motor modules to sub. 0.0 0.0 9/25/2022 09:30 9/25/2022 15:00 5.50 MIRU, MOVE MOB P Move pipe shed close to sub. Stomp, sqare up with sub and pin into position. 0.0 0.0 9/25/2022 15:00 9/25/2022 18:00 3.00 MIRU, MOVE MOB P Stomp motor and pump module into position. Hook up interconnects. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 2/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/25/2022 18:00 9/25/2022 21:00 3.00 MIRU, MOVE RURD P PJSM, raise derrick, Plug in electrical to sub, Swap to Gen power, Skid rig floor to drilling position, Continue hook up all interconnection, Spool on drill line onto drawworks, 0.0 0.0 9/25/2022 21:00 9/26/2022 00:00 3.00 MIRU, MOVE RURD P Lower cellar windwalls, Unpin block, Scope up derrick and R/D bridle lines. Raise cattle shute and work on rig acceptance checklist. Installing kelly hose onto top drive. Well pressures TBG: 150psi (fluid at surface) OA: 170psi (gas at surface) IA: 170psi (gas at surface) 0.0 0.0 9/26/2022 00:00 9/26/2022 01:00 1.00 MIRU, MOVE RURD P Complete R/U interconnects on pits. Complete and accept rig at 0100hrs 9- 26-22. Install all service lines onto tree. TBG: 150psi IA: 170psi OA: 170 psi 0.0 0.0 9/26/2022 01:00 9/26/2022 04:00 3.00 COMPZ1, WELCTL OTHR P Taking on 10.3ppg bromide to pits. Build 50bbls Hi-Vis LCM pill. SIMOPS: De-Iceing Mousehole, changing saver sub on Top drive and loading and process casing shed with 4" drill pipe. 0.0 0.0 9/26/2022 04:00 9/26/2022 05:30 1.50 COMPZ1, WELCTL KLWL P PJSM, Pressure test lines to 2,000psi, Circulate 10.3ppg down tbg and up IA.Trashing fluid to flow back tank. GPM: 147 TBG: 750psi IA: 468psi BBLS pumped: 98bbls Max weight out 10.1ppg Fluid with Gas, oil/diesel returns 0.0 0.0 9/26/2022 05:30 9/26/2022 06:00 0.50 COMPZ1, WELCTL KLWL P Circulate down tubing and up IA through communication area and up OA. Trashing fluid to flow back tank. GPM 147 TBG: 760psi IA: 470psi BBLS pumped: 96.5bbls Max weight out 10.1+ppg Fluid with Gas, oil/diesel returns 0.0 0.0 9/26/2022 06:00 9/26/2022 06:30 0.50 COMPZ1, WELCTL OWFF P Monitor well TBG: 75psi IA: 125psi OA: 125psi 0.0 0.0 9/26/2022 06:30 9/26/2022 07:30 1.00 COMPZ1, WELCTL KLWL P Circulate down tubing and up IA. Take returns to two empty pits. Attempt to save fluid. GPM 168 TBG: 720psi IA: 340psi BBLS pumped: 145bbls Max weight out 10.0 to 10.2ppg Fluid with Gas, oil/diesel returns 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 3/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/26/2022 07:30 9/26/2022 08:30 1.00 COMPZ1, WELCTL OWFF P Monitor well, shut in pressures TBG: 186psi IA: 255psi Bled back 4.7bbls TBG: 112psi IA: 184psi Fluid with Gas, oil/diesel returns 0.0 0.0 9/26/2022 08:30 9/26/2022 09:30 1.00 COMPZ1, WELCTL OWFF P Monitor well, shut in pressures TBG: 117psi IA: 191psi Bled down TBG/IA TBG: 56psi IA: 137psi Fluid with Gas, oil/diesel returns 0.0 0.0 9/26/2022 09:30 9/26/2022 13:30 4.00 COMPZ1, WELCTL OWFF P Monitor well SIMOPS: Load and process 4" drill pipe, Prep BOP equipment for N/U, Repair pipe skate, adjust shot pin on top drive. 0.0 0.0 9/26/2022 13:30 9/26/2022 15:00 1.50 COMPZ1, WELCTL KLWL P PJSM, bled OA pressure from 133psi to 0psi, bull head 123bbls 10.2ppg GPM: 70 PSI: 1060 0.0 0.0 9/26/2022 15:00 9/26/2022 16:00 1.00 COMPZ1, WELCTL OWFF P Monitor well, shut in pressures IA pressure dorpped From: 735psi to 271psi. 0.0 0.0 9/26/2022 16:00 9/26/2022 17:00 1.00 COMPZ1, WELCTL KLWL P Bled OA pressure from 271psi to 84psi, 5min built uo 23psi, continue bled back OA to 107psi to 52psi. 0.0 0.0 9/26/2022 17:00 9/27/2022 00:00 7.00 COMPZ1, WELCTL OWFF P Monitor well, shut in pressures while WO 10.3ppg fluid 1700hrs TBG: 20psi IA: 95psi OA: 59psi 2100hrs TBG: 20psi IA: 95psi OA: 54psi 2400hrs TBG: 15psi IA: 95psi OA: 50psi SIMOPS: Service TD, ST80, changed ball mill cam-loc's build tubing/casing L/D area. 0.0 0.0 9/27/2022 00:00 9/27/2022 01:00 1.00 COMPZ1, WELCTL OWFF P Monitor pressures while waithing on 10.3ppg fluid. 0100hrs TBG: 15psi IA: 94psi OA: 50psi 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 4/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/27/2022 01:00 9/27/2022 04:30 3.50 COMPZ1, WELCTL KLWL P Bull head 10.3ppg down OA, monitor tubing and IA pressure. Pump at 34gpm 800psi and stage up to 119gpm 1074psi OA, 984 IA, 900 TBG, pumped total 480bbls. Shut down pumps at 0420hrs. Pressure dropping TBG: 360psi IA: 440psi OA: 400psi 0.0 0.0 9/27/2022 04:30 9/27/2022 06:30 2.00 COMPZ1, WELCTL KLWL P Ciculate pump down tubing and up IA return to tiger tank at 210gpm tbg:1208psi IA: 663psi at 30bbls pumped clean 10.3ppg fluid returns. Send fluid to pits. Continue circulate at 252gpm 1274psi IA:396psi OA: 370 psi total 450bbls. 0.0 0.0 9/27/2022 06:30 9/27/2022 13:00 6.50 COMPZ1, WELCTL OWFF P Shut in well and monitor pressures. Waiting on more 10.3# fluid. Reconfigure service lines and gauges in cellar. TBG: 12psi IA: 18psi OA: 16psi 0.0 0.0 9/27/2022 13:00 9/27/2022 15:00 2.00 COMPZ1, WELCTL KLWL P Ciculate pump down tubing and up IA at 205gpm tbg: 865psi IA: 241psi OA: 303psi Final circulate at 230gpm 1062psi IA: 285psi OA: 360psi. Total 640bbls pumped 0.0 0.0 9/27/2022 15:00 9/27/2022 17:00 2.00 COMPZ1, WELCTL KLWL P Ciculate pump down tubing and up OA at 205gpm tbg: 886psi IA: 240psi OA: 302psi Final circulate at 231gpm 1043psi IA: 283psi OA: 334psi Total 480bbls pumped 0.0 0.0 9/27/2022 17:00 9/28/2022 00:00 7.00 COMPZ1, WELCTL OWFF P Monitor well. 1800hrs TBG: 14psi IA: 12psi OA: 3psi 2000hrs TBG: 5psi IA: 1psi OA: 0psi 2100hrs (IA and OA on slight vacuum) TBG: 0psi IA: 0psi OA: 0psi 2400hrs (IA and OA on slight vacuum) TBG: 0psi IA: 0psi OA: 0psi Fill IA and OA with 10.3ppg fluid 17bbls to fill 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 5/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/28/2022 00:00 9/28/2022 07:00 7.00 COMPZ1, WELCTL OWFF P Monitor well. 0200hrs (TBG, IA, OA on vacuum) Fill TBG, OA and IA with 10.3ppg fluid 14.3bbls. 0400hrs (TBG, IA, OA on vacuum) Fill TBG, OA and IA with 10.3ppg fluid 8.8bbls. 0600hrs (TBG, IA, OA on vacuum) Fill TBG, OA and IA with 10.3ppg fluid 9bbls 0.0 0.0 9/28/2022 07:00 9/28/2022 08:30 1.50 COMPZ1, WELCTL THGR P Install BPV and rolling test in direction of flow 390psi. 0.0 0.0 9/28/2022 08:30 9/28/2022 09:00 0.50 COMPZ1, WHDBOP NUND P PJSM, N/D tree 0.0 0.0 9/28/2022 09:00 9/28/2022 13:00 4.00 COMPZ1, WHDBOP NUND P N/U BOP's, install flow line, choke and kill lines, Joe's box with dresser sleeves, MPD equipment, 0.0 0.0 9/28/2022 13:00 9/28/2022 15:30 2.50 COMPZ1, WHDBOP RURD P Blose blind rams and shell test BOP's 250/5000psi 5min/10min. 0.0 0.0 9/28/2022 15:30 9/28/2022 16:30 1.00 COMPZ1, WHDBOP RURD P Install trip nipple and 90' mouse hole. 0.0 0.0 9/28/2022 16:30 9/28/2022 19:00 2.50 COMPZ1, WHDBOP BOPE P R/U and flood lines, purge air from system, Test annular with 4" test joint 250/3500psi 5min/10min. Perform Koomey draw down test ACC=3050psi Post function test =1600psi at 200psi 16sec and 97sec build up system. Closeing time ANN: 18sec UPR: 14sec, BS: 16sec, LPR: 14 sec, HCR choke and Kill 2sec. Test PVT GL system and flow alarms. Tested LEL and H2S alarms. Witnessed by AOGCC: Guy Cook and BLM: Quinn Sawyer 0.0 0.0 9/28/2022 19:00 9/28/2022 20:00 1.00 COMPZ1, WHDBOP RGRP T Leak observed on BOP stack/ riser connection. Retorque all BOP and riser bolts. 0.0 0.0 9/28/2022 20:00 9/28/2022 21:00 1.00 COMPZ1, WHDBOP RGRP T Attempt to retest #2, Trouble shoot slow leak, Grease Kill line HCR. 0.0 0.0 9/28/2022 21:00 9/28/2022 23:30 2.50 COMPZ1, WHDBOP RGRP T Attempt to retest #2, Trouble shoot slow leak. Observed leak on choke manifold valve #5. Observed on choke manifold a bolt hand tight on flow cross. Dicision made to check all choke manifold bolts. 0.0 0.0 9/28/2022 23:30 9/29/2022 00:00 0.50 COMPZ1, WHDBOP RGRP T Attempt to retest #2, Trouble shoot slow leak, Observed leak on choke line OTECO connection. Well on losses at ~9BPH 0.0 0.0 9/29/2022 00:00 9/29/2022 04:00 4.00 COMPZ1, WHDBOP RGRP T Change seal on choke line OTECO connection. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 6/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/29/2022 04:00 9/29/2022 18:00 14.00 COMPZ1, WHDBOP BOPE P BOPE Test All tests to 250psi/5min 5000psi/10min Annular 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 4” Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR,Test choke valves 1-15. Manula operated and super choke. W/ 4.5" Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPRChoke manuals and HCR valves. 4" kill line valve. Test 2x 4" FO safety valves. 4" dart valve. Test upper and lower IBOP. Blind/Shear rams. Koomey test preformed 9-28-22 at 18:00hrs Performed Koomey draw down, ACC = 3050 psi, Manifold = 1500 psi, ACC = 1650 psi after all functions on bottles,16 sec for 200 psi. Build w/ 2 electric pumps, 97 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 18 sec. UPR = 14 sec, Blind / Shears = 16 sec, LPR = 14 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms AOGCC Guy Cook witness test. BLM Quinn Sawyer witness test. 0.0 0.0 9/29/2022 18:00 9/29/2022 18:30 0.50 COMPZ1, WHDBOP BOPE P R/D test equipment, B/D surface equipment 0.0 0.0 9/29/2022 18:30 9/29/2022 19:00 0.50 COMPZ1, WHDBOP RURD P OWFF (0psi in IA, OA and TBG) avg 5bbl/hr losses. SIMOPS: R/U bail extensions and tubing tongs. 0.0 0.0 9/29/2022 19:00 9/29/2022 20:00 1.00 COMPZ1, WHDBOP OTHR P Pull BPV . 0.0 0.0 9/29/2022 20:00 9/29/2022 20:30 0.50 COMPZ1, WHDBOP OTHR P R/U bail extensions, M/U safety valve and landing joint. BOLD and pul tubing, Free with 188k P/U 130k S/O 109k. Continue pull hanger to rig floor from 10,081' MD to 10,053' MD 10,081.0 10,053.0 9/29/2022 20:30 9/29/2022 21:30 1.00 COMPZ1, RPCOMP CIRC P M/U safety valve and head pin, Displace down OA and up IA 75bbls 10.0ppg Vis brine. 10,053.0 10,053.0 9/29/2022 21:30 9/29/2022 22:30 1.00 COMPZ1, RPCOMP CIRC P Pump down tbg and up IA displace with 10.0ppg Vis Brine at 270gpm 398psi 10,053.0 10,053.0 9/29/2022 22:30 9/29/2022 23:00 0.50 COMPZ1, RPCOMP OWFF P OWFF, slow drop in IA. 10,053.0 10,053.0 9/29/2022 23:00 9/30/2022 00:00 1.00 COMPZ1, RPCOMP PUTB P POOH and L/D 4.5" 12.6ppf H563 tubing. from 10,053' MD to 9,808' MD. PU: 130k SO: 109k 10,053.0 9,808.0 9/30/2022 00:00 9/30/2022 06:00 6.00 COMPZ1, RPCOMP PUTB P POOH and L/D 4.5" 12.6ppf H563 tubing. from 9,809' MD to 2,100' MD. 9,808.0 2,100.0 9/30/2022 06:00 9/30/2022 08:00 2.00 COMPZ1, RPCOMP PUTB P POOH and L/D 4.5" 12.6ppf H563 tubing. from 2,100' MD to surface. 2,100.0 0.0 9/30/2022 08:00 9/30/2022 09:30 1.50 COMPZ1, RPCOMP CLEN P Clean and clear rig floor and install wear bushing. 0.0 0.0 9/30/2022 09:30 9/30/2022 11:00 1.50 COMPZ1, PLUG PULD P P/U and run 948' 3.5" EUE cement stinger. 0.0 948.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 7/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/30/2022 11:00 9/30/2022 18:00 7.00 COMPZ1, PLUG PULD P Continue RIH with 3.5" stnger P/U 4" drill pipe from 948' MD to 7,012' MD 948.0 7,012.0 9/30/2022 18:00 9/30/2022 21:30 3.50 COMPZ1, PLUG PULD P Continue RIH with 3.5" stnger P/U 4" drill pipe from 7,012' MD to 10,081' MD 7,012.0 10,081.0 9/30/2022 21:30 9/30/2022 22:00 0.50 COMPZ1, PLUG RURD P P/U Baker cement swivel and change 10' pump joint and safety valve on top from 3.5" IF to 4" XT39. 10,081.0 10,081.0 9/30/2022 22:00 9/30/2022 23:00 1.00 COMPZ1, PLUG CIRC P Circulate at 10,081' MD at 8bpm 940psi with 50rpm. 2100stks 10.0ppg in/out SIMOPS: Batch up 13.0ppg spacer and PJSM for cement operatons. PU: 148K SO: 123k 10,081.0 10,081.0 9/30/2022 23:00 10/1/2022 00:00 1.00 COMPZ1, PLUG CMNT P Pressure test lines to 5k, leak on union between pump and Ball Mill, tighten union and retest to 5k (good test) SLB, Tested lines to 5000 psi high, pump 15 bbls of 13.0 ppg Mud Push II @ 3.8 bbls/min, 337 psi, Batch cement (cement wet @ 23:05) Pump 33 bbls of Class G 15.8 ppg cement @ 2.3 bbls/min, ICP = 154 psi, FCP = 142 psi. Batch and pump 5 bbls 13.0 ppg Mud Push II at 3.4 bbls/min, 144 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 2.6 bbls/min, ICP = 134 psi, FCP= 136 psi. 0 losses during the job, shut down pumps at (86 bbls). CIP 00:19 Hrs 10/1/2022. 10,081.0 10,081.0 10/1/2022 00:00 10/1/2022 00:30 0.50 COMPZ1, PLUG CMNT P Continue displace cement at 122gpm (max feeding unit)with 50rpm 2k tq 136psi total 86bbls. Full returns 10,081.0 10,081.0 10/1/2022 00:30 10/1/2022 01:00 0.50 COMPZ1, PLUG RURD P Flow check (drill string static) R/D Baker cement swivel and blow down service lines. ROT: 136k 10,081.0 10,081.0 10/1/2022 01:00 10/1/2022 02:30 1.50 COMPZ1, PLUG TRIP P POOH from 10,081' MD to 9,102' MD at 15'/min. Drill pipe pulled dry. 10,081.0 9,102.0 10/1/2022 02:30 10/1/2022 03:00 0.50 COMPZ1, PLUG CIRC P Install nerf ball and circulate at 9,102' MD at 800gpm 2950psi 50rpm pumped 5978stks(~5bbls cement returns) 9,102.0 9,102.0 10/1/2022 03:00 10/1/2022 03:30 0.50 COMPZ1, PLUG OTHR P OWFF (static) Blow down top drive, install PS21's 9,102.0 9,102.0 10/1/2022 03:30 10/1/2022 07:15 3.75 COMPZ1, PLUG TRIP P POOH from 9,100' MD to 950' MD. 9,102.0 950.0 10/1/2022 07:15 10/1/2022 07:45 0.50 COMPZ1, PLUG OTHR P Pull PS21's and Install master bushing and 3.5" air slips. Change elevators ato 3.5". 950.0 950.0 10/1/2022 07:45 10/1/2022 09:00 1.25 COMPZ1, PLUG TRIP P POOH and rack back 3.5" EUE tubing, L/D mule shoe. 950.0 0.0 10/1/2022 09:00 10/1/2022 09:30 0.50 COMPZ1, PLUG CLEN P Clean and clear rig floor, Change to 4" handling equipment, R/D tubing tongs. 0.0 0.0 10/1/2022 09:30 10/1/2022 12:00 2.50 COMPZ1, PLUG TRIP P M/U 6.5" bit and TIH with 4" drill pipe to 3,222' MD. PU: 82k SO: 80k 0.0 3,222.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 8/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/1/2022 12:00 10/1/2022 15:00 3.00 COMPZ1, PLUG TRIP P Continue TIH with 4" drill pipe to 9,105' MD. Wash in hole and tag @ 9,202' MD with 15K PU: 140k SO: 120k GPM: 42 AOGCC Sean Sullivan witness tagging cement plug. BLM Quinn Sawyer waived witness on tagging cement and all other pumping and tagging cement plugs on MT7-06 08:25hrs 9-30-22 3,222.0 9,202.0 10/1/2022 15:00 10/1/2022 16:00 1.00 COMPZ1, PLUG CIRC P Circulate at 9,190' MD 2600stks GPM: 400 PSI: 1200 9,202.0 9,190.0 10/1/2022 16:00 10/1/2022 20:00 4.00 COMPZ1, PLUG TRIP P POOH from 9,190' MD to surface. 9,190.0 0.0 10/1/2022 20:00 10/1/2022 21:00 1.00 COMPZ1, PLUG BHAH P Remove 6.5" bit and float valve, M/U 6.75" bit. Clean and clear rig floor. 0.0 0.0 10/1/2022 21:00 10/1/2022 22:00 1.00 COMPZ1, PLUG TRIP P RIH with 6.75" bit to 2489' MD. 0.0 2,489.0 10/1/2022 22:00 10/1/2022 22:30 0.50 COMPZ1, PLUG OTHR P M/U Baker retrievamatic packer. 2,489.0 2,489.0 10/1/2022 22:30 10/2/2022 00:00 1.50 COMPZ1, PLUG TRIP P Continue RIH with 6.75" bit and Baker retrievamatic packer to 4984' MD, Packer depth 2500' MD. 2,489.0 4,984.0 10/2/2022 00:00 10/2/2022 02:00 2.00 COMPZ1, PLUG PRTS P R/U service lines and equipment, Set packer at 2,500' MD with 25k. Perge lines and test cement plug to 1,865psi (45min) As per AOGCC witness Sean Sullivan PU: 98k SO: 96k 4,984.0 4,984.0 10/2/2022 02:00 10/2/2022 02:30 0.50 COMPZ1, PLUG RURD P R/D and blow down surface equipment. 4,984.0 4,984.0 10/2/2022 02:30 10/2/2022 03:45 1.25 COMPZ1, PLUG TRIP P POOH from 4,984' MD to 2,489' MD. 4,984.0 2,489.0 10/2/2022 03:45 10/2/2022 04:15 0.50 COMPZ1, PLUG RURD P L/D Baker retrievamatic packer. 2,489.0 2,489.0 10/2/2022 04:15 10/2/2022 05:30 1.25 COMPZ1, PLUG TRIP P Continue POOH from 2,489' MD to surface. 2,489.0 0.0 10/2/2022 05:30 10/2/2022 06:00 0.50 COMPZ1, PLUG BHAH P Break and L/D bit, Bit sub and X/O. M/U Baker 4AA 7-5/8" 24-39# Cement retainer (PN: ACT 050-6317-001). 0.0 0.0 10/2/2022 06:00 10/2/2022 11:00 5.00 COMPZ1, PLUG TRIP P TIH with cement retainer at 40'/min from surface to 2,500' MD and 60'/min from 2,500' MD to 7,832' MD. 0.0 7,832.0 10/2/2022 11:00 10/2/2022 11:30 0.50 COMPZ1, PLUG OTHR P Set retainer at 7,832' MD. 7,832.0 7,832.0 10/2/2022 11:30 10/2/2022 14:30 3.00 COMPZ1, PLUG TRIP P POOH from 7,832' MD to surface, L/D and inspect Baker running tools. (all ok) 7,832.0 0.0 10/2/2022 14:30 10/2/2022 15:30 1.00 COMPZ1, PLUG CLEN P Clean and clear rig floor, PJSM (P/U guns) P/U Schlumberger 4.72" 135/45 phase 21spf 20' of shots total 420. Gun ser# 4.72-21-35 0.0 0.0 10/2/2022 15:30 10/2/2022 20:00 4.50 COMPZ1, PLUG TRIP P TIH with Schlumberger guns at 90'/min, Set on depth 7,770' MD to 7,790' MD. 0.0 7,790.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 9/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/2/2022 20:00 10/2/2022 21:00 1.00 COMPZ1, PLUG PERF P Drop Schlumberger 5/8" steel ball, Pump down at 1bpm 127psi, Ball landed at 228stks, Increase pressure to 2,700psi guns fired at 2018hrs, OA pressure 64psi before Quick respond to 67psi after and back down to 63psi. EST circulation at 2bpm 1300psi up IA, RIH to 7,828' MD tag and verify Retainer still on depth. OWFF: Static PU: 122k SO: 96k 7,790.0 7,790.0 10/2/2022 21:00 10/3/2022 00:00 3.00 COMPZ1, PLUG TRIP P POOH with perf guns from 7,790' MD to 2,002' MD. 7,790.0 2,002.0 10/3/2022 00:00 10/3/2022 00:45 0.75 COMPZ1, PLUG TRIP P POOH with perf guns from 2,002' MD to 500' MD. 2,002.0 500.0 10/3/2022 00:45 10/3/2022 01:15 0.50 COMPZ1, PLUG OWFF P OWFF, gun gass breaking out at surface, Circulate at 2bpm 1141psi. (well static) 500.0 500.0 10/3/2022 01:15 10/3/2022 02:00 0.75 COMPZ1, PLUG TRIP P Continue POOH from 500' MD. L/D Schlumberger guns (All shots fired) 500.0 0.0 10/3/2022 02:00 10/3/2022 03:00 1.00 COMPZ1, PLUG PULD P M/U 4" mule shoe and P/U 4" HWT drill pipe TIH to 275' MD. 0.0 275.0 10/3/2022 03:00 10/3/2022 03:30 0.50 COMPZ1, PLUG PULD P M/U Baker retrievamatic packer. 275.0 275.0 10/3/2022 03:30 10/3/2022 05:00 1.50 COMPZ1, PLUG TRIP P TIH with Backer retrievamatic packer from 275' MD to 2791' MD, Set packer at 2,500' MD with 25k. 275.0 2,791.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 10/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/3/2022 05:00 10/3/2022 08:00 3.00 COMPZ1, PLUG CIRC P Test return line to tiger tank to 1,500psi. 1st attempt Pump at 1bpm 1190psi up OA 59psi start 58psi end pumped 3.5bbls returned 2.3bbls 1min 1072psi 2min 1039psi 3min 995psi 4min 941psi 5min 860psi 2nd attempt Pump at 1bpm 1330psi up OA 56psi start 56psi end pumped 2.8bbls, 2bbls returned 1min 1100psi 2min 1066psi 3min 1046psi 4min 1028psi 5min 1014psi 6min 1001psi 7min 985psi 8min 969psi 9min 956psi 10min 945ps 15min 691psi Mud pump pulsation dampener relaxed 20min 653psi 25min 632psi 30min 619psi 3rd attempt Pump at 1/2bpm 1180psi up OA 56psi start 56psi end pumped 2.24bbls, 2bbls returned 1min 1180psi 2min 1073psi 3min 995psi 4min 970psi 5min 955psi 6min 949psi 7min 942psi 8min 937psi 9min 933psi 10min 930ps 15min 915psi 20min 902psi 25min 890psi 30min 880psi 35min 872psi 2,791.0 2,791.0 10/3/2022 08:00 10/3/2022 09:30 1.50 COMPZ1, PLUG TRIP P POOH from 2,791' MD, L/D Baker retrievamatic packer. (no visual wear) 2,791.0 0.0 10/3/2022 09:30 10/3/2022 14:00 4.50 COMPZ1, PLUG BHAH P M/U BHA and TIH to 7,765' MD. 0.0 7,765.0 10/3/2022 14:00 10/3/2022 18:00 4.00 COMPZ1, PLUG CIRC P Circulate at 7,761' MD 250gpm 995psi (2875stks) SIMOPS: Build and rack back 5" stands 7,765.0 7,765.0 10/3/2022 18:00 10/3/2022 20:30 2.50 COMPZ1, PLUG TRIP P POOH from 7,765' To 2,553' MD 7,765.0 2,553.0 10/3/2022 20:30 10/4/2022 00:00 3.50 COMPZ1, PLUG OWFF P OWFF, Drill pipe at 2,553' MD for safty while waiting on E-Line. SIMOPS: Build and rack back 5" stands, Total 34stds. Eline unit changing out spool and re- heading line. 2,553.0 2,553.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 11/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/4/2022 00:00 10/4/2022 00:30 0.50 COMPZ1, PLUG OWFF P OWFF, Drill pipe at 2,553' MD for safty while waiting on E-Line. SIMOPS: Build and rack back 5" stands, Total 37stds. Eline unit in route to location. 2,553.0 2,552.0 10/4/2022 00:30 10/4/2022 01:30 1.00 COMPZ1, PLUG TRIP P POOH from 2,553' MD to surface, L/D Bit. Wire line unit arrived on location at 1230hrs, Spotting unit and M/U tools in pipe shed for testing. 2,552.0 0.0 10/4/2022 01:30 10/4/2022 03:30 2.00 COMPZ1, PLUG RURD P Continue M/U tools in pipe shed and testing. Spotting tools and equipment on rig floor. 0.0 0.0 10/4/2022 03:30 10/4/2022 09:30 6.00 COMPZ1, PLUG QEVL P PJSM, P/U USIT tool string. RIH at 0445hrs. 3kft/hr to 1000', then 10kft/hr to to 7,750' MD, Log up to Surface. Tool length: 54.74' Max OD 7" Rope socket: 8K (electrical release) 0.39" line: 6984# Disp. 0.1478bbl/1000' 0.0 0.0 10/4/2022 09:30 10/4/2022 10:30 1.00 COMPZ1, PLUG RURD P Rig down E-Line and equipment 0.0 0.0 10/4/2022 10:30 10/4/2022 12:00 1.50 COMPZ1, PLUG TRIP P TIH with 3.5" cement string and 4" drill pipe to 1,226' MD 0.0 1,226.0 10/4/2022 12:00 10/4/2022 20:00 8.00 COMPZ1, PLUG PULD P OWFF , Build and rack back 5" drill pipe (total 96stds) 1,226.0 1,226.0 10/4/2022 20:00 10/5/2022 00:00 4.00 COMPZ1, PLUG WAIT T Waiting on approvals from State for path forward. SIMOPS: Cleaning and organizing rig 1,226.0 1,226.0 10/5/2022 00:00 10/5/2022 13:30 13.50 COMPZ1, PLUG WAIT T Waiting on approvals from State for path forward. SIMOPS: Cleaning and organizing rig 1,226.0 1,226.0 10/5/2022 13:30 10/5/2022 16:00 2.50 COMPZ1, PLUG TRIP P M/U Baker retrievamatic packer and TIH at 90'/min, Set packer at 2,572' MD, EOT at 4,002' MD. R/U service lines and equipment. 1,226.0 4,002.0 10/5/2022 16:00 10/5/2022 17:30 1.50 COMPZ1, PLUG PRTS P Pressure test formation (Perfs 7770' MD - 7790' MD Pump at 1/2bpm 1800psi 2.8bbls, 2.5bbls returned 1min 1800psi 2min 1780psi 3min 1760psi 4min 1730psi 5min 1710psi 6min 1700psi 7min 1660psi 8min 1610psi 9min 1590psi 10min 1550ps 15min 1400psi 20min 1300psi 25min 1220psi 30min 1180psi 4,002.0 4,002.0 10/5/2022 17:30 10/5/2022 18:00 0.50 COMPZ1, PLUG WAIT T Waiting on approvals from State for path forward. 4,002.0 4,002.0 10/5/2022 18:00 10/5/2022 19:30 1.50 COMPZ1, PLUG TRIP P Release test packer, Blow down top drive, POOH from 4,002' MD to 1,441' MD 4,002.0 1,441.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 12/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/5/2022 19:30 10/5/2022 23:00 3.50 COMPZ1, PLUG TRIP P TIH with 3.5" cement stinger from 1,441' MD to 7,807' MD. Stinger: 949.60' 1,441.0 7,807.0 10/5/2022 23:00 10/5/2022 23:30 0.50 COMPZ1, PLUG CIRC P Circulate BTMs up at 730gpm 2350psi 7,807.0 7,807.0 10/5/2022 23:30 10/6/2022 00:00 0.50 COMPZ1, PLUG RURD P P/U cement swivel, R/U survice lines and equipment. Circulate at 8bpm 801psi while crew change. 7,807.0 7,807.0 10/6/2022 00:00 10/6/2022 00:30 0.50 COMPZ1, PLUG CIRC P R/U cement swivel and service lines, Continue circulate at 333gpm at 800psi 7,807.0 7,807.0 10/6/2022 00:30 10/6/2022 01:15 0.75 COMPZ1, PLUG CMNT P Batch up 48bbls 11.5ppg Mud Push II spacer (for both plugs) SIMOPS: M/U cement swivel and circulate at 333gpm 800psi. 7,807.0 7,807.0 10/6/2022 01:15 10/6/2022 02:00 0.75 COMPZ1, PLUG CMNT P SLB, Tested lines to 3500 psi high, pump 12bbls of 11.5 ppg Mud Push II @ 4.8 bbls/min, 497 psi, Batch cement (cement wet @ 0054) Pump 37 bbls of Class G 15.8 ppg cement @ 4.8 bbls/min, ICP = 290 psi, FCP = 210 psi. Batch and pump 4 bbls 11.5 ppg Mud Push II at 4.7 bbls/min, 200 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 4.8 bbls/min, ICP = 134 psi, @ 2bpm FCP= 167 psi. 0 losses during the job, shut down pumps at (62 bbls). Rotating at 50rpm 2.6k torque, CIP 01:42 Hrs 10/6/2022. 7,807.0 7,807.0 10/6/2022 02:00 10/6/2022 03:00 1.00 COMPZ1, PLUG TRIP P R/D cement swivel and POOH to 7014' MD at 20'/min. 7,807.0 7,014.0 10/6/2022 03:00 10/6/2022 03:30 0.50 COMPZ1, PLUG CIRC P Install Nerf ball and Circulate 2- BTMs up at 730gpm 2350psi 5bbls cement returns. 7,014.0 7,014.0 10/6/2022 03:30 10/6/2022 03:45 0.25 COMPZ1, PLUG CIRC P Blow down top drive, R/U cement swivel and service lines, test lines to 3500psi. 7,014.0 7,014.0 10/6/2022 03:45 10/6/2022 04:30 0.75 COMPZ1, PLUG CMNT P SLB, Tested lines to 3000 psi high, pump 12bbls of 11.5 ppg Mud Push II @ 3.5 bbls/min, 300 psi, Batch cement (cement wet @ 0345) Pump 37 bbls of Class G 15.8 ppg cement @ 3.5 bbls/min, ICP = 138 psi, FCP = 150 psi. Batch and pump 4 bbls 11.5 ppg Mud Push II at 3.4 bbls/min, 157 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 54 bbls/min, ICP = 126 psi, FCP= 125 psi. 0 losses during the job, shut down pumps at (54 bbls). Rotating at 50rpm 2.6k torque, CIP 04:33 Hrs 10/6/2022. 7,014.0 7,014.0 10/6/2022 04:30 10/6/2022 06:00 1.50 COMPZ1, PLUG RURD P R/D cement swivel and POOH from 7014' MD to 6,066' MD at 20'/min. 7,014.0 6,066.0 10/6/2022 06:00 10/6/2022 07:00 1.00 COMPZ1, PLUG CIRC P Install Nerf ball and Circulate 2- BTMs up at 735gpm 1930psi 4.5bbls cement returns. Blow down top drive. 6,066.0 6,066.0 10/6/2022 07:00 10/6/2022 09:00 2.00 COMPZ1, PLUG TRIP P POOH from 6,066' MD to 950' MD. 6,066.0 950.0 10/6/2022 09:00 10/6/2022 10:30 1.50 COMPZ1, PLUG BHAH P OWFF, (Static) Change handling equipment and R/U tubing tongs. POOH and rack back 3.5" cement string. 950.0 0.0 10/6/2022 10:30 10/6/2022 11:00 0.50 COMPZ1, PLUG CLEN P Clean and clear rig floor, Change handling equipment and R/D tubing tongs. Jet stack and BOP function test (10:30hrs 10-6-22) 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 13/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/6/2022 11:00 10/6/2022 15:00 4.00 COMPZ1, PLUG OTHR P M/U 6-3/4" Bit and TIH to 5,977' MD. 0.0 5,977.0 10/6/2022 15:00 10/6/2022 17:00 2.00 COMPZ1, PLUG WASH P Wash in hole from 5,977' MD to 6,366' MD (tagged 15k) GPM: 42 PSI: 102 5,977.0 6,366.0 10/6/2022 17:00 10/6/2022 17:30 0.50 COMPZ1, PLUG CIRC P Circulate at 6,366' MD (Observed contaminated cement returns) GPM: 400 PSI: 2110 6,366.0 6,366.0 10/6/2022 17:30 10/6/2022 21:30 4.00 COMPZ1, PLUG CIRC T Circulate at 6,366' MD. Waiting on State Lou Laubenstein to witness tag cement. GPM: 400 PSI: 2110 6,366.0 6,366.0 10/6/2022 21:30 10/6/2022 21:45 0.25 COMPZ1, PLUG TRIP P Lou Laubenstein arrived at 2130 hrs. TIH and tag at 6,366' MD with 15k(90k) PU: 108k SO: 105k 6,366.0 6,366.0 10/6/2022 21:45 10/6/2022 23:00 1.25 COMPZ1, PLUG TRIP P Blow down top drive and POOH from 6,366' MD to 3,324' MD 6,366.0 3,324.0 10/6/2022 23:00 10/6/2022 23:30 0.50 COMPZ1, PLUG OTHR P M/U Baker retrievamatic packer. 3,324.0 3,324.0 10/6/2022 23:30 10/7/2022 00:00 0.50 COMPZ1, PLUG TRIP P TIH with Backer retrievamatic packer from 3,324' MD to 4,195' MD. 3,324.0 4,195.0 10/7/2022 00:00 10/7/2022 01:00 1.00 COMPZ1, PLUG TRIP P Continue TIH with test packer to 5,900' MD 4,195.0 5,900.0 10/7/2022 01:00 10/7/2022 02:00 1.00 COMPZ1, PLUG PRTS P P/U Baker swivel, Set Baker test packer at 2,568' (5900' MD bit depth) with 25k. R/U service lines and equipment. Test cement plug to 1500psi 30min (good test) pumped 1.2bbls returned 1bbls. AOGCC Lou Laubenstein witnessed test. 5,900.0 5,900.0 10/7/2022 02:00 10/7/2022 02:15 0.25 COMPZ1, PLUG RURD P R/D service lines and cement swivel, Blow down lines. 5,900.0 5,900.0 10/7/2022 02:15 10/7/2022 05:00 2.75 COMPZ1, PLUG TRIP P POOH from 5,900' MD, L/D Baker retrievamatic packer. (no visual damage) Continue POOH L/D bit. 5,900.0 0.0 10/7/2022 05:00 10/7/2022 05:30 0.50 COMPZ1, PLUG CLEN P Clean and clear rig floor (Rig Crew change) 0.0 0.0 10/7/2022 05:30 10/7/2022 09:00 3.50 COMPZ1, PLUG TRIP P M/U Baker CICR , TIH to 3,745' MD, Set CICR at 3,745' MD Set with 50k up/36k down. Release running tool. Size: 4AA / 7-5/8" 24-39# PN: ACT 050-6317-001 0.0 3,745.0 10/7/2022 09:00 10/7/2022 12:00 3.00 COMPZ1, PLUG OTHR P POOH from 3,745' MD to Srface L/D Baker running tool. 3,745.0 0.0 10/7/2022 12:00 10/7/2022 14:30 2.50 COMPZ1, PLUG TRIP P M/U Baker casing cutter with 3" knives, TIH to 3,730' MD. 0.0 3,730.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 14/56 MT7-06 Report Printed: 2/13/2023 Operations Summary (with Timelog Depths) Job: DRILLING RE-ENTRY Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/7/2022 14:30 10/7/2022 18:00 3.50 COMPZ1, PLUG CPBO P Establish parameters, Cut 7-5/8" casing at 3,730' MD and 3,400' MD. PU: 85k SO: 87k ROT: 88 GPM: 175 PSI: 724 RPM: 60 TRQ: 3k on TRQ: 1.5 off 3,730.0 3,400.0 10/7/2022 18:00 10/7/2022 20:00 2.00 COMPZ1, PLUG TRIP P OWFF (Static) POOH from 3,400' MD to surface. 3,400.0 0.0 10/7/2022 20:00 10/7/2022 20:30 0.50 COMPZ1, PLUG OTHR P Pull and inspect casing cutter, Outer markings ~6-8" above cutters on tools. Removed 3" cutters with good markings showing full extension of knifes. Dress casing cutter with 2-1/4" knifes. 0.0 0.0 10/7/2022 20:30 10/7/2022 21:00 0.50 COMPZ1, PLUG CPBO P RIH to 75' MD to make final cut. Torque increased to 2.4k and pump pressure drop to 260psi. Indication knifes full extended. Minimum rotation after pressure drop to keep from gouging surface casing. ROT: 44k GPM 175 PSI: 560 RPM: 60 TRQ:1.7k 0.0 75.0 10/7/2022 21:00 10/7/2022 22:00 1.00 COMPZ1, PLUG TRIP P Pull and inspect casing cutter. Removed 2-1/4" cutters with good markings showing full extension of knifes. Clean and clear rig floor. 75.0 0.0 10/7/2022 22:00 10/7/2022 23:00 1.00 COMPZ1, PLUG OTHR P Pump out stack, M/U FMC retriving tool, RIH and pull wear ring. M/U retrieving tool and BO lock downs and pull pack off. 0.0 0.0 10/7/2022 23:00 10/8/2022 00:00 1.00 COMPZ1, PLUG BHAH P Remove PS21's and install master bushings, P/U and M/U Baker 6.676" Grapple/Spear assy and No Go. 0.0 0.0 10/8/2022 00:00 10/8/2022 01:00 1.00 COMPZ1, PLUG FISH P RIH to Attempt to spear 7-5/8" casing. NoGo landed onto casing slips, Pulled lockdown (visual inspect) NoGo sitting ontop of hanger slips. POOH and L/D spear. SIMOPS: R/D MPD Orbit valve and lines. 0.0 37.0 10/8/2022 01:00 10/8/2022 04:00 3.00 COMPZ1, PLUG NUND P N/D BOP's and Well head, Lift stack and head to expose slips. Casing stub ~3' below slips. BO studs on well head to make room to pull slips. Unable to unwedge slip segments (gouge segment to release slips). Note: Top of 7-5/8" casing stump has a worn slot in casing that let slips release. Casing widely expanded below slip area. Note: On upper completion, first joint of 4.5" tubing was bent just below hanger. Posible caused when slips released on 7-5/8" casing. 37.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 11/15/2022 Page 1/1 MT7-06 Report Printed: 2/13/2023 Cement Cement Details Description Cement Plug Cementing Start Date 9/30/2022 22:34 Cementing End Date 10/1/2022 00:19 Wellbore Name MT7-06 Comment SLB pump 3 bbls of fresh H2O. Tested lines to 5000 psi high, pump 15 bbls of 13.0 ppg Mud Push II @ 3.8 bbls/min, 337 psi, Batch cement (cement wet @ 23:05) Pump 33 bbls of Class G 15.8 ppg cement @ 2.3 bbls/min, ICP = 154 psi, FCP = 142 psi. Batch and pump 5 bbls 13.0 ppg Mud Push II at 3.4 bbls/min, 144 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 2.6 bbls/min, ICP = 134 psi, FCP= 136 psi. 0 losses during the job, shut down pumps at (86 bbls). CIP 00:19 Hrs 10/1/2022. Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 9,202.0 Bottom Depth (ftKB) 10,081.0 Full Return? Yes Vol Cement … 5.0 Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 3 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 3 P Pump Final (psi) 136.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? Yes Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB pump 3 bbls of fresh H2O. Tested lines to 5000 psi high, pump 15 bbls of 13.0 ppg Mud Push II @ 3.8 bbls/min, 337 psi, Batch cement (cement wet @ 23:05) Pump 33 bbls of Class G 15.8 ppg cement @ 2.3 bbls/min, ICP = 154 psi, FCP = 142 psi. Batch and pump 5 bbls 13.0 ppg Mud Push II at 3.4 bbls/min, 144 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 2.6 bbls/min, ICP = 134 psi, FCP= 136 psi. 0 losses during the job, shut down pumps at (86 bbls). CIP 00:19 Hrs 10/1/2022. Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 9,202.0 Est Btm (ftKB) 10,081.0 Amount (sacks) 217 Class G Volume Pumped (bbl) 33.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 4.90 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Cement Plug Page 1/1 MT7-06 Report Printed: 2/13/2023 Cement Cement Details Description Cement Plug Cementing Start Date 10/6/2022 01:15 Cementing End Date 10/6/2022 02:00 Wellbore Name MT7-06 Comment SLB, Tested lines to 3500 psi high, pump 12bbls of 11.5 ppg Mud Push II @ 4.8 bbls/min, 497 psi, Batch cement (cement wet @ 0053) Pump 37 bbls of Class G 15.8 ppg cement @ 4.8 bbls/min, ICP = 290 psi, FCP = 210 psi. Batch and pump 4 bbls 11.5 ppg Mud Push II at 4.7 bbls/min, 200 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 4.8 bbls/min, ICP = 134 psi, @ 2bpm FCP= 167 psi. 0 losses during the job, shut down pumps at (62 bbls). CIP 01:40 Hrs 10/6/2022. Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 7,014.0 Bottom Depth (ftKB) 7,807.0 Full Return? Yes Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 4 P Pump Final (psi) 167.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? Yes Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB, Tested lines to 3500 psi high, pump 12bbls of 11.5 ppg Mud Push II @ 4.8 bbls/min, 497 psi, Batch cement (cement wet @ 0053) Pump 37 bbls of Class G 15.8 ppg cement @ 4.8 bbls/min, ICP = 290 psi, FCP = 210 psi. Batch and pump 4 bbls 11.5 ppg Mud Push II at 4.7 bbls/min, 200 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 4.8 bbls/min, ICP = 134 psi, @ 2bpm FCP= 167 psi. 0 losses during the job, shut down pumps at (62 bbls). CIP 01:42 Hrs 10/6/2022. Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 7,014.0 Est Btm (ftKB) 7,807.0 Amount (sacks) 177 Class G Volume Pumped (bbl) 37.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 4.90 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Cement Plug Page 1/1 MT7-06 Report Printed: 2/13/2023 Cement Cement Details Description Cement Plug Cementing Start Date 10/6/2022 03:45 Cementing End Date 10/6/2022 04:30 Wellbore Name MT7-06 Comment SLB, Tested lines to 3000 psi high, pump 12bbls of 11.5 ppg Mud Push II @ 3.5 bbls/min, 300 psi, Batch cement (cement wet @ 0345) Pump 37 bbls of Class G 15.8 ppg cement @ 3.5 bbls/min, ICP = 138 psi, FCP = 150 psi. Batch and pump 4 bbls 11.5 ppg Mud Push II at 3.4 bbls/min, 157 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 5.4 bbls/min, ICP = 126 psi, FCP= 125 psi. 0 losses during the job, shut down pumps at (54 bbls). Rotating at 50rpm 2.6k torque, CIP 04:33 Hrs 10/6/2022. Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 6,211.0 Bottom Depth (ftKB) 7,014.0 Full Return? Yes Vol Cement … 4.5 Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 5 P Pump Final (psi) 125.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? Yes Pipe RPM (rpm) Tagged Depth (ftKB) 6,366.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB, Tested lines to 3000 psi high, pump 12bbls of 11.5 ppg Mud Push II @ 3.5 bbls/min, 300 psi, Batch cement (cement wet @ 0345) Pump 37 bbls of Class G 15.8 ppg cement @ 3.5 bbls/min, ICP = 138 psi, FCP = 150 psi. Batch and pump 4 bbls 11.5 ppg Mud Push II at 3.4 bbls/min, 157 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 54 bbls/min, ICP = 126 psi, FCP= 125 psi. 0 losses during the job, shut down pumps at (54 bbls). Rotating at 50rpm 2.6k torque, CIP 04:33 Hrs 10/6/2022. Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 6,211.0 Est Btm (ftKB) 7,014.0 Amount (sacks) 177 Class G Volume Pumped (bbl) 37.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 4.90 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Cement Plug Page 1/1 MT7-06 Report Printed: 2/13/2023 Cement Cement Details Description Cement Plug Cementing Start Date 10/11/2022 00:56 Cementing End Date 10/11/2022 01:58 Wellbore Name MT7-06 Comment SLB, Tested lines to 2500 psi high, pump 45bbls of 13.5 ppg Mud Push II @ 3 bbls/min, 118 psi, Batch cement (cement wet @ 23:15hrs) Pump 87 bbls of Class G 16.8 ppg cement @ 4.2 bbls/min, ICP = 207 psi, FCP = 180 psi. Batch and pump 3.5 bbls 13.5 ppg Mud Push II at 1.8 bbls/min, 138 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 4.2 bbls/min, ICP = 166 psi, FCP= 235 psi. 0 losses during the job, shut down pumps at (22 bbls). Rotating at 30rpm 1.5k torque, CIP 02:35 Hrs 10/11/2022. Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 3,074.0 Bottom Depth (ftKB) 3,730.0 Full Return? Yes Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 3 P Pump Final (psi) 150.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? Yes Pipe RPM (rpm) Tagged Depth (ftKB) 3,074.0 Tag Method Pipe/String Depth Plug Drilled Out To (ftKB) 3,485.0 Drill Out Diameter (in) 12 1/4 Comment SLB, Tested lines to 2500 psi high, pump 45bbls of 13.5 ppg Mud Push II @ 3 bbls/min, 118 psi, Batch cement (cement wet @ 23:15hrs) Pump 87 bbls of Class G 16.8 ppg cement @ 4.2 bbls/min, ICP = 207 psi, FCP = 180 psi. Batch and pump 3.5 bbls 13.5 ppg Mud Push II at 1.8 bbls/min, 138 psi, pump. Displace w/ 10.0 ppg Vis Brine @ 4.2 bbls/min, ICP = 166 psi, FCP= 235 psi. 0 losses during the job, shut down pumps at (22 bbls). Rotating at 30rpm 1.5k torque, CIP 02:35 Hrs 10/11/2022. Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,959.0 Est Btm (ftKB) 3,730.0 Amount (sacks) 177 Class G Volume Pumped (bbl) 87.0 Yield (ft³/sack) 1.03 Mix H20 Ratio (gal/sack) 3.88 Free Water (%) Density (lb/gal) 16.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Cement Plug 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Wednesday, October 19, 2022 11:15 AM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; WSC Rig Advisor; Greg.S.Hobbs@conocophillips.com; Ben Wedin; Bill Walter Subject:Doyon 25 9 5/8 and annular test Attachments:Doyon 25 10-19-22.xlsx; Test Chart 10-19-22.jpg Everett Potter Rig 25 Toolpusher rig25@doyondrilling.com 907-670-4971 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greater Mooses Tooth Unit MT7-06A PTD 2210480 Casing Rams and Annular test before running 9 5/8 " casing -- jbr Doyon 25 Csg Ram Test GMTU MT7-06A PTD 2210480 10/19/2022 J. Regg; 118/25/2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-06 JBR 12/13/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Use 4.5" and 5" Test joint for testing, Test 2 each 4.5" and 5" TIW and 1 each IBOP 4.5: and 5". Test went without any issues Test Results TEST DATA Rig Rep:R. Fritz / Z ColemanOperator:ConocoPhillips Alaska, Inc.Operator Rep:R. Reinhardt/P. Angelle Rig Owner/Rig No.:Doyon 25 PTD#:2210480 DATE:10/11/2022 Type Operation:WRKOV Annular: 250/3500Type Test:BIWKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS221013165233 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7.5 MASP: 3110 Sundry No: 322-565 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 4 P Inside BOP 2 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8 5K P #1 Rams 1 2-7/8x5-1/2 V P #2 Rams 1 Blind/Shears P #3 Rams 1 2-7/8x5-1/2 V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8 5K P HCR Valves 2 3-1/8 5K P Kill Line Valves 2 3-1/8 5K P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1600 200 PSI Attained P15 Full Pressure Attained P97 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6 @ 2066 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P14 #2 Rams P22 #3 Rams P15 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2      Test charts attached BOPE Test - Doyon 25 10/11/2022 GMTU MT7-06 (PTD 2210480) J. Regg; 12/13/2022 MT7-06 10/11/2022 Tested to 250 psi / 5 min, 35OO psi / 10min 5” Test Jt 1.Annular Preventer, Valves: 1, 13, 14, 15, 4” Kill Line Valve, UIBOP 2.Upper Pipe Rams (2.87” x 5.5” ), Valves: 2, 10, 12, HCR Kill & LIBOP 3.Valves: 6, 9 ,11, Manual Kill, 5” Dart Valve 4.Valves 5, 7, 8 & 5” FOSV # 1 5.Valves 3 & 5” FOSV # 2 6.Lower Pipe Rams (2.87” x 5.5” VBR’S) 7.Blind Shear Rams, Valves: 4 & 5” Dart Valve 8.Manually Operated & Super Choke ( 8A = Manual Choke – 8B = Super Choke) 4” Test Jt 9.Annular Preventer, HCR Choke , 5” FOSV # 1 10.Upper Pipe Rams (2.87” x 5.5” VBR’S) & Manual Choke, 5” FOSV # 2 11.Lower Pipe Rams (2.87” x 5.5” VBR’S) GMTU MT7-06 PTD 2210480 J. Regg; 12/13/2022 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Sunday, October 9, 2022 4:35 PM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; WSC Rig Advisor; Greg.S.Hobbs@conocophillips.com Subject:Doyon 25 10-9-22 Attachments:Doyon 25 10-9-22 Test chart.pdf; Doyon 25 10-9-22.xlsx Categories:Blue Category CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 10/9/22 Test report attached for 5" Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907‐670‐4971 Greater Mooses Tooth Unit MT7-06 PTD 2210480 Tested LPR (2 7/8" x 5 1/2" VBR), Annular, Dart valve, and FOSV with 5-inch test joint -- jbr Doyon 25 - BOPE Test LPR, Annular, Dart, FOSV 5-inch Test jt GMTU MT7-06 PTD 2210480 10/9/2022 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Sunday, October 9, 2022 4:39 PM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; Greg.S.Hobbs@conocophillips.com; WSC Rig Advisor Subject:RE: Doyon 25 10-8-22 Attachments:Doyon 25 10-8-22 test chart.pdf; Doyon 25 10-8-22.xlsx CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Revision made to reflect the correct ram size for ram #1 ‐ 7‐5/8" Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907‐670‐4971 ‐‐‐‐‐Original Message‐‐‐‐‐ From: Rig 25 Sent: Saturday, October 08, 2022 9:57 AM To: AOGCC <AOGCC.Inspectors@alaska.gov>; jim.regg@alaska.gov; Brooks, Poebe L)CED <phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Greg.S.Hobbs@conocophillips.com; WSC Rig Advisor <wscrigadvisor@conocophillips.com> Subject: Doyon 25 10‐8‐22 Test report attached for the 7‐5/8" ram change Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907‐670‐4971 Greater Mooses Tooth Unit MT7-06 PTD 2210480 Changed #1 Rams from 2 7/8" x 5 1/2" VBR to 7 5/8"casing rams -- jbr Doyon 25 Ram Change 10/8/2022 GMTU MT7-07 PTD 2210480 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 32 Township: 10N Range: 2E Meridian: Umiat Drilling Rig: Doyon 25 Rig Elevation: 39.5 ft Total Depth: 26153 ft MD Lease No.: Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 13.375" O.D. Shoe@ 3425 Feet Csg Cut@ Feet Intermediate: 7.625" O.D. Shoe@ 12241 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 4.5" O.D. Tail@ 12219 Feet Tbg Cut@ 10091 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 7807 ft 6366 ft 10 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1620 1590 1580 IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Percy Angelle Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Cement plug in place/curred before arrival to witness a tag and MIT on the second plug in the plug back program. Top of cement was found to be @ 6366 ft using drill pipe; 15K lbs set down on top of plug and re-tagged showing the same depth. The MIT on the plug passed without issue. October 6, 2022 Lou Laubenstein Well Bore Plug & Abandonment MT7-06 ConocoPhillips Alaska Inc PTD 221048; Sundry 322-565 none Test Data: P Casing Removal: rev. 11-28-18 2022-1007_Plug_Verification_GMTU_MT7-06_ll Top of cement Cement plug in place/curred before arrival to witness a tag and MIT on the second plug in the plug back program. was found to be @ 6366 ft using drill pipe; 15K lbs set down on top of plug and re-tagged showing the same depth. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 32 Township: 10N Range: 2E Meridian: Umiat Drilling Rig: Doyon 25 Rig Elevation: 39.5 ft Total Depth: 26153 ft MD Lease No.: AA081800 Operator Rep: Suspend: P&A: X Conductor: 20 O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 13 3/8 O.D. Shoe@ 3425 Feet Csg Cut@ Feet Intermediate: 7 5/8 O.D. Shoe@ 12241 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 4 1/2 O.D. Tail@ 12219 Feet Tbg Cut@ 10091 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 10081 ft 9202 ft Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1875 1802 1749 IA OA Initial 15 min 30 min 45 min Result Tubing 1863 1841 1796 1772 IA OA Remarks: Attachments: John Benedict P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Casing Removal (depths are MD): Plug back for redrill. Tag top of cement plug at 9202 ft MD and set 15,000 lb drill string wt on cement plug. Pull out of hole to pick up a test packer and pressure test to 1865 psi. Work procedure said 10 min test but they could not produce an AOGCC variance so required 30 minute test. Initial deemed inconclusive because of 2 quick 20-40 psi drops. Bumped back up and ran a 45 min test with passing result. October 1, 2022 Sully Sullivan Well Bore Plug & Abandonment Greater Mooses Tooth Unit MT7-06 ConocoPhillips Alaska Inc PTD 2210480; Sundry 322-565 none Test Data: I rev. 3-24-2022 2022-1001_Plug_Verification_GMTU_MT7-06_ss STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-06 JBR 11/04/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:11 4" and 4.5" test joints used for testing. H2S detector at the shakers needed calibrated and retested good. Test #2 leak on the BOP riser flange. Tightened. This is captured under BOP Misc. Leaking flange on the choke manifold at CMV #5. Also found a nut on another CMV that was handy so all flanges on the choke manifold were retightened before testing continued. This fail is captured under CH Misc. HCR Kill failed and was serviced. The Oteco flange on the choke side of the BOP and was tightened. Continued to leak so the Oteco was replaced. This is captured under BOP Misc. The upper IBOP failed and was serviced. The blinds failed and were cycled. A test valve on the test pump was found to be leaking and was replaced. CMV #4 was leaking and serviced. It continued to leak and was replaced. The well sign had the incorrect API number on it and was corrected. The flow indicator was calibrated as it was not working correctly. The HCR choke was leaking and was serviced. Horrible test. BLM Quinn Sawyer also witnessed the BOP test. Test Results TEST DATA Rig Rep:E. Potter/C. BaliOperator:ConocoPhillips Alaska, Inc.Operator Rep:J. Benedict/P. Angelle Rig Owner/Rig No.:Doyon 25 PTD#:2210480 DATE:9/29/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC220927142134 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 25 MASP: 3110 Sundry No: 322-565 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign FP Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 FP Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 FPCH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5.5" V P #2 Rams 1 Blind/Shear FP #3 Rams 1 2 7/8"x5.5" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 FP Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 2 Flange/Oteco FP System Pressure P3050 Pressure After Closure P1650 200 PSI Attained P18 Full Pressure Attained P97 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2033 ACC Misc NA0 P PTrip Tank P PPit Level Indicators FP PFlow Indicator P PMeth Gas Detector P FPH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P16 #1 Rams P14 #2 Rams P16 #3 Rams P14 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 FP FP FP FP FPFP FP FP FP H2S detector at the shakers BOP riser flange.Leaking flange on the choke manifold HCR Kill failed Oteco flange on the choke side of the BOP blinds failed CMV #4 well sign e flow indicator HCR choke %23(7HVW'R\RQ*0780737' %23(7HVW'R\RQ*0780737' %23(7HVW'R\RQ*0780737' %23(7HVW'R\RQ*0780737' Doyon rig 25 BOPE test 9-28-22 MT7-06 4” Test joint. 1. Annular 2. Upper 2 7/8” x 5 ½” VBR’s, Upper IBOP, 4” Demco kill, CMV’s # 1, 13, 14, 15. 3. Lower IBOP, HCR Kill, CMV’s # 2, 10, 12. 4. CMV’s, 6, 9, 11, 4” Dart, Manual Kill. 5. CMV’s # 5, 7, 8, 4” FOSV # 1. 6. CMV # 3, 4” FOSV #2. 7. Lower 2 7/8” x 5 ½” VBR’s. 8. Blind rams. 9. Hydraulic choke drawdown. 9A. Manual choke drawdown. 4.5” Test joint. 10. Annular. 11. Upper 2 7/8” x 5 ½” VBR’s, CMV #4. 12. HCR Choke. 13. Manual Choke. 14. Lower 2 7/8” x 5 ½” VBR’s. 9-28-22 ! " # $! % " &&&&&&&&&&&&&&&&&&& '$ ("" )*$ +, *# - # ./$ 0/ 1$$ " ## ! 2 30%4. ,2 5 $ 6* 78 $9 4:7 9 * 3*7 9 * ;*7 9 + #* 3* + #* ;* 37 9 73*9 <=73*9 '.)->$ " ''.4 /.164 8 = ; = ;3*7 9;*7 9 ' -" != * ?= +, *# # (+ * ) != " /8 /$< *8 .;# * @ @ @ 8A@ @"" #@/$< ! "$ "+ " B " #$ @"" #! $ / ? 3 / 8" //C3/ >25 $ +, 25 $ ;+*?5 # "33//$+ D+@"" * " " + @ + 1(1-> '.)-> 1(1-> $ "06- @ 3*7 9 =E4(->3*:0'6'>;* * ;*7 9 B () ?== +8F 8F/8$*@"$+ ;/$"33//$ ! 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ϭϲ͘^ƉŽƚŬŝĐŬͲŽĨĨƉůƵŐŽŶƚŽƉŽĨƉůƵŐ͘dĂƌŐĞƚdKŝŶƐŝĚĞƐƵƌĨĂĐĞĐĂ ƐŝŶŐƐŚŽĞ͘ ϭϳ͘>ĂǇĚŽǁŶϰ͟ĚƌŝůůƉŝƉĞ ϭϴ͘DŽǀĞƚŽŶĞǁWdĨŽƌƐŝĚĞͲƚƌĂĐŬŽƉĞƌĂƚŝŽŶƐ͘ WΘĞŵĞŶƚĞƚĂŝůƐ ZĞƐĞƌǀŽŝƌWΘ KƉƚŝŽŶϭ ĂůĂŶĐĞĚWůƵŐƵƐŝŶŐƐĂĐƌŝĨŝĐŝĂůƐƚƌŝŶŐĂŶĚ,<ĨƌŽŵϭϬ͕ϰϮϱʹϭϲ͕ϱϬϬ͛Dǁͬϭϯ͘ϱƉƉŐůĂƐƐ'н ĂĚĚŝƚŝǀĞƐ ϰ͟W;ϭϲϱϬϬʹϭϬϱϬϬͿΎ͘ϬϭϬϮďďůͬĨƚсϲϭ͘Ϯďďů ϲͲϭͬϮ͟K,ǆϰ͟W;ϭϲϱϬϬʹϭϮϮϰϭͿΎϬ͘ϬϮϱϱďďůͬĨƚсϭϬϴ͘ϲďďů ϳͲϱͬϴ͟ƐŐǆϰ͟W;ϭϮϮϰϭʹϭϬϱϬϬͿΎϬ͘ϬϰϬϵϰďďůͬĨƚсϳϭ͘ϯďďů ϳͲϱͬϴ͟ƐŐ;ϭϬϱϬϬʹϭϬϰϮϱͿΎϬ͘ϬϰϰϯďďůͬĨƚсϯ͘ϯďďů dŽƚĂůsŽůƵŵĞ;ŝŶĐůƵĚŝŶŐϭϱϬйĞǆĐĞƐƐͿсϰϯϳďďůƐсхϭ͕ϰϬϬƐŬƐůĂƐƐ'͕ϭйϬϳϵĞǆƚĞŶĚĞƌ͕Ϭ͘ϲйϮϱϱ ĨůƵŝĚůŽƐƐ͕Ϭ͘ϰйϬϲϱĚŝƐƉĞƌƐĂŶƚ͕Ϭ͘ϲйϬϭϯƌĞƚĂƌĚĞƌΛϭ͘ϳϱĨƚΔϯͬƐŬ KƉƚŝŽŶϮ ĞŵĞŶƚ^ƋƵĞĞǌĞǁŝƚŚƌĞƚĂŝŶĞƌĨƌŽŵϭϬ͕ϰϮϱʹϭϮ͕Ϯϰϭ͛Dǁͬϭϯ͘ϱƉƉŐůĂƐƐ'нĂĚĚŝƚŝǀĞƐ ϲͲϭͬϮ͟K,;ϭϲϬϬϬʹϭϮϮϰϭͿΎϬ͘ϬϰϭϬϰďďůͬĨƚсϭϱϰ͘ϯďďůƐ ϳͲϱͬϴ͟ƐŐ;ϭϮϮϰϭʹϭϬϰϮϱͿΎϬ͘ϬϰϰϯďďůͬĨƚсϴϬ͘ϱďďůƐ dŽƚĂůsŽůƵŵĞ;ŝŶĐůƵĚŝŶŐϭϬϬйĞǆĐĞƐƐͿсϯϴϵ͘ϭďďůƐсхϭ͕ϮϱϬƐŬƐůĂƐƐ'͕ϰйϬϮϬ͕ϭйϬϳϵ͕Ϭ͘ϲй Ϯϱϱ͕Ϭ͘ϰйϬϲϱĚŝƐƉĞƌƐĂŶƚ͕Ϭ͘ϲйϬϭϯΛϭ͘ϳϱĨƚΔϯͬƐŬ WůƵŐηϮʹůďŝĂŶϵϯWΘ ĂůĂŶĐĞĚWůƵŐƵƐŝŶŐďƌŝĚŐĞƉůƵŐďĂƐĞ͕ĐŝƌĐƵůĂƚŝŶŐƚŚƌŽƵŐŚƉĞƌĨƐƵƐŝŶŐĐĞŵĞŶƚƌĞƚĂŝŶĞƌĨƌŽŵϱ͕ϲϱϬ͛ʹ ϲ͕ϯϱϬ͛Dǁͬϭϱ͘ϴƉƉŐůĂƐƐ'нĂĚĚŝƚŝǀĞƐ ϵͲϳͬϴ͟K,ǆϳͲϱͬϴ͟ƐŐ;ϲϯϱϬʹϱϲϱϬͿΎϬ͘ϬϯϴϮϱďďůͬĨƚсϮϲ͘ϴďďůƐ ϳͲϱͬϴ͟ƐŐ;ϲϯϱϬʹϱϲϱϬͿΎϬ͘ϬϰϱϳϲďďůͬĨƚсϯϮďďůƐ dŽƚĂůsŽůƵŵĞ;ŝŶĐůƵĚŝŶŐϯϬйĞǆĐĞƐƐͿсϲϱ͘ϰďďůƐсхϯϮϬƐŬƐŽĨϭϲ͘ϴƉƉŐůĂƐƐ'нϬ͘ϯйϬϲϱ ĚŝƐƉĞƌƐĂŶƚΛϭ͘ϭϲĨƚϯͬƐŬ <ŝĐŬͲŽĨĨWůƵŐ ĂůĂŶĐĞĚWůƵŐĨƌŽŵϯ͕Ϯϯϱʹϯ͕ϳϯϱ͛Dǁͬϭϲ͘ϴƉƉŐůĂƐƐ' ϵͲϳͬϴ͟K,;ϯ͕ϳϯϱʹϯ͕ϰϯϱͿΎϬ͘ϬϵϰϳϯďďůͬĨƚсϮϴ͘ϰďďů ϭϯͲϯͬϴ͟ƐŐ;ϯ͕ϰϯϱʹϯ͕ϮϯϱͿΎϬ͘ϭϰϵϳϯďďůͬĨƚсϮϵ͘ϵďďů dŽƚĂůsŽůƵŵĞ;ŝŶĐůƵĚŝŶŐϭϬϬйĞǆĐĞƐƐͿсϭϬϮďďůƐсхϱϲϬƐŬƐŽĨϭϲ͘ϴƉƉŐůĂƐƐ'Λϭ͘ϬϯĨƚϯͬƐŬ ƵƌƌĞŶƚtĞůů^ĐŚĞŵĂƚŝĐ WƌŽƉŽƐĞĚ&ŝŶĂů^ĐŚĞŵĂƚŝĐ WΘ^ĐŚĞŵĂƚŝĐƐ KƉƚŝŽŶϭ KƉƚŝŽŶϮ DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20831-00-00Well Name/No. GMTU MT7-06Completion Status1-OILCompletion Date10/10/2021Permit to Drill2210480Operator ConocoPhillips Alaska, Inc.MD26153TVD8483Current Status1-OIL1/31/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR, RES, DIR, AZI, DEN, NEU, CALIPER, POROSITY, StarTrak, LithoTrak, AziTrack, mudlog PB1 onlyNoNoYesMud Log Samples Directional SurveyREQUIRED 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CPAI_MT7-06PB1_MEM_AP-LOG TIME.pdf36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD 27_Compass Surveys_Canvas_11182021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD 27_Compass Surveys_Macro_11182021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD 27_Compass Surveys_Petrel_11182021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD 27_Compass Surveys_Surveys_11182021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD 27_Definitive Survey Report_11182021.pdf36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD83_Compass Surveys_Canvas_09282021.txt.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD83_Compass Surveys_Macro_09282021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD83_Compass Surveys_Petrel_09282021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD83_Compass Surveys_Surveys_09282021.txt36089EDDigital DataDF12/16/2021 Electronic File: MT7-06PB1_NAD83_Definitive Survey Report_09282021.pdf36089EDDigital Data0 0 2210480 GMTU MT7-06 PB1 LOG HEADERS36089LogLog Header ScansDF12/23/2021118 26241 Electronic Data Set, Filename: MT7-06PB1_Cuttings Percentages.las36104EDDigital DataDF12/23/20213435 26241 Electronic Data Set, Filename: MT7-06PB1_G5_GeoIsotopes_Corrected data_3435-26241 ft.las36104EDDigital DataMonday, January 31, 2022AOGCCPage 4 of 10MT7-,06PB1_Cuttings Percentages.lasMT7-,06PB1_G5_GeoIsotopes_Corrected data_3435-__26241 ft.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20831-00-00Well Name/No. GMTU MT7-06Completion Status1-OILCompletion Date10/10/2021Permit to Drill2210480Operator ConocoPhillips Alaska, Inc.MD26153TVD8483Current Status1-OIL1/31/2022UICNoDF12/23/2021 Electronic File: 50-103-20831-70-00_MT7_06PB1_MUDLOG_26241ft TD FINAL.pdf36104EDDigital DataDF12/23/2021 Electronic File: MT7-06PB1-End of well Mudlogging Report.pdf36104EDDigital Data0 0 2210480 GMTU MT7-06 PB1 LOG HEADERS36104LogLog Header 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2021_Processed Log_Main Pass.pdf36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_Processed Log_OffDepth.pdf36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_Report with Logs.pdf36117EDDigital DataMonday, January 31, 2022AOGCCPage 6 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20831-00-00Well Name/No. GMTU MT7-06Completion Status1-OILCompletion Date10/10/2021Permit to Drill2210480Operator ConocoPhillips Alaska, Inc.MD26153TVD8483Current Status1-OIL1/31/2022UICNoDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_Report.pdf36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_Thickness and Radius Values_Main Pass.xlsx36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_Thickness and Radius Values_Repeat Pass_OffDepth.xlsx36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_DLIS_Main Pass.dlis36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_DLIS_Repeat Pass_10476ft - 11080ft.dlis36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_DLIS_Repeat Pass_1366ft - 2032ft.dlis36117EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_Corrosion_02-October 2021_DLIS_Repeat Pass_466ft - 2065ft.dlis36117EDDigital Data0 0 2210480 GMTU MT7-06 LOG HEADERS36117LogLog Header ScansDF12/21/202112096 12248 Electronic Data Set, Filename: CPAI_MT7-06_MechCutter_02SEP21_Correlation_ConCu_R01_L011Up_CUTTER_CCL.las36123EDDigital DataDF12/21/202112120 12248 Electronic Data Set, Filename: CPAI_MT7-06_MechCutter_02SEP21_Cutting_ConCu_R01_L012Up_CUTTER_CCL.las36123EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_MechCutter_02SEP21_Correlation_ConCu_R01_L011Up_CUTTER_CCL.dlis36123EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_MechCutter_02SEP21_Cutting_ConCu_R01_L012Up_CUTTER_CCL.dlis36123EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_MechCutter_02SEP21_Print.Pdf36123EDDigital DataMonday, January 31, 2022AOGCCPage 7 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20831-00-00Well Name/No. GMTU MT7-06Completion Status1-OILCompletion Date10/10/2021Permit to Drill2210480Operator ConocoPhillips Alaska, Inc.MD26153TVD8483Current Status1-OIL1/31/2022UICNoDF12/21/2021 Electronic File: CPAI_MT7-06_MechCutter_02SEP21_Correlation_ConPr_R01_L011Up_CUTTER_CCL.dlis36123EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_MechCutter_02SEP21_Cutting_ConPr_R01_L012Up_CUTTER_CCL.dlis36123EDDigital Data0 0 2210480 GMTU MT7-06 LOG HEADERS36123LogLog Header Scans0 0 2210480 GMTU MT7-06 LOG HEADERS36124LogLog Header ScansDF12/21/20217883 10460 Electronic Data Set, Filename: CPAI_MT7-06_USIT_12AUG21_MainPass_60FPM_ConCu_R04_L005Up_USIT_CAL.las36124EDDigital DataDF12/21/202110076 10460 Electronic Data Set, Filename: CPAI_MT7-06_USIT_12AUG21_RepeatPass_60FPM_ConCu_R04_L004Up_USIT_CAL.las36124EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_12AUG21_MainPass_60FPM_ConCu_R04_L005Up_USIT_CAL.dlis36124EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_12AUG21_RepeatPass_60FPM_ConCu_R04_L004Up_USIT_CAL.dlis36124EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_12AUG21_FIELDPRINT.Pdf36124EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_12AUG21_MainPass_60FPM_ConPr_R04_L005Up_USIT_CAL.dlis36124EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_12AUG21_RepeatPass_60FPM_ConPr_R04_L004Up_USIT_CAL.dlis36124EDDigital DataDF12/21/20217862 12008 Electronic Data Set, Filename: CPAI_MT7-06_USIT_16AUG21_MainPass_60FPM_ConCu_R05_L006Up_USIT_CAL.las36125EDDigital DataDF12/21/202111228 11877 Electronic Data Set, Filename: CPAI_MT7-06_USIT_16AUG21_RepeatPass_60FPM_ConCu_R05_L004Up_USIT_CAL.las36125EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_16AUG21_MainPass_60FPM_ConCu_R05_L006Up_USIT_CAL.dlis36125EDDigital DataMonday, January 31, 2022AOGCCPage 8 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20831-00-00Well Name/No. GMTU MT7-06Completion Status1-OILCompletion Date10/10/2021Permit to Drill2210480Operator ConocoPhillips Alaska, Inc.MD26153TVD8483Current Status1-OIL1/31/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:10/10/2021Release Date:7/6/2021DF12/21/2021 Electronic File: CPAI_MT7-06_USIT_16AUG21_RepeatPass_60FPM_ConCu_R05_L004Up_USIT_CAL.dlis36125EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_16AUG21_FIELDPRINT.Pdf36125EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_16AUG21_MainPass_60FPM_ConPr_R05_L006Up_USIT_CAL.dlis36125EDDigital DataDF12/21/2021 Electronic File: CPAI_MT7-06_USIT_16AUG21_RepeatPass_60FPM_ConPr_R05_L004Up_USIT_CAL.dlis36125EDDigital Data0 0 2210480 GMTU MT7-06 LOG HEADERS36125LogLog Header Scans9/24/2021100 26241 PB1 Samples71783CuttingsMonday, January 31, 2022AOGCCPage 9 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20831-00-00Well Name/No. GMTU MT7-06Completion Status1-OILCompletion Date10/10/2021Permit to Drill2210480Operator ConocoPhillips Alaska, Inc.MD26153TVD8483Current Status1-OIL1/31/2022UICNoCompliance Reviewed By:Date:Monday, January 31, 2022AOGCCPage 10 of 10M. 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A7 .' 7=1 2 2?2! + ? 2 9 7 * 2 9 2 0 * 5* B /(=7)7);< 0()) 7'' 77' " $ " &' '(*+ C $ 2 C# $ 2 % +7) 89 D 2 92 E ? 2 +7) 2 2 2 0 * 5* B /(=7)7);< " $ WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϮϭϬϰϴϬͲ^Ğƚ͗ϯϲϭϮϱJRBy Abby Bell at 1:43 pm, Dec 21, 2021 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϮϭϬϰϴϬͲ^Ğƚ͗ϯϲϭϮϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϮϭϬϰϴϬͲ^Ğƚ͗ϯϲϭϮϯJRBy Abby Bell at 1:43 pm, Dec 21, 2021 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϮϭϬϰϴϬͲ^Ğƚ͗ϯϲϭϭϳJRBy Abby Bell at 1:43 pm, Dec 21, 2021 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϮϭϬϰϴϬͲ^Ğƚ͗ϯϲϭϭϲJRBy Abby Bell at 1:43 pm, Dec 21, 2021 TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: MT7-06/06PB1 DATE: 12/21/2021 Transmitted: NPRA, Greater Moose’s Tooth Via SFTP ____ Geolog Mud log data package Mud gas was not acquired on MT7-06 MT7-06 is in a federal oil and gas unit. Only with respect to the MT7-03 Well Data, CPAI hereby waives its rights to indefinitely confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for the wells not on state land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: MT7-06 e-transmittal well folder Receipt: Date: Alaska Data Support|ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 37' (6HW 12/23/2021 By Abby Bell at 10:08 am, Dec 23, 2021 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA December 14, 2021 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-06PB1 Greater Mooses Tooth API #: 50-103-20831-70 Permit No: 221-048 Rig: Doyon 25 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-06 is located in a federal oil and gas unit. Only with respect to the MT7-06 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: Please return transmittal letter to: 12/16/2021 By Abby Bell at 1:07 pm, Dec 16, 2021 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA December 14, 2021 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-06 Greater Mooses Tooth API #: 50-103-20831-00 Permit No: 221-048 Rig: Doyon 25 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-06 is located in a federal oil and gas unit. Only with respect to the MT7-06 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: 12/16/2021 15% &4FU By Abby Bell at 12:49 pm, Dec 16, 2021 From:Glessner, Dana To:Loepp, Victoria T (OGC); Roby, David S (OGC) Subject:FW: MT7-06 production test update/question Date:Friday, December 3, 2021 5:06:07 PM Attachments:Sundry_321-590_111821.pdf Victoria, thank you for taking my phone call this afternoon. We are currently production testing our unfrac’d producer MT7-06 (PTD 221-048) to determine if we will be able to start the MT7 drillsite up with it alone. We have been cleaned up and in production test mode since 11/26/21. As of today we have produced 29,000 bbls fluid total at an average 5% water cut. On Wednesday 12/1 we were producing 3300 bfpd at 1000 psi tubing pressure and 100% open choke. In an attempt to reduce the backpressure on the well, yesterday, we bypassed the line heater on the portable test separator setup and dropped the tubing pressure by 200 psi, liquid rates increased to 5000-5200 bfpd at 50% choke. We are currently working to open the choke back up to 100%. We believe that with current rates we may be able to go for a drillsite startup late next week but would like to request an additional 5-7 days in order to establish and confirm the decline rate. Since the drillsite startup would only be with this one well we want to ensure adequate flow to keep the crosscountry line from freezing until our next producer comes online ~mid-late December. The current approved sundry (321-590) for the production test is for 21 days or 50,000 bbls total fluid produced. At current rates and as we continue to open the choke over the weekend I think we may exceed the 50,000 bbls fluid limit of the approved sundry by early Monday. I would like to request a revision to the sundry and an additional 25,000 bbls of fluid for a total of 75,000 to get us through another 5-7 days of testing. Please let me know if you have any questions and if you approve to continue testing beyond the 50,000 bbls limit. Thank you, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Cell: 661-331-7-30 Dana.Glessner@conocophillips.com From: Glessner, Dana Sent: Friday, December 3, 2021 3:05 PM To: 'dave.roby@alaska.gov' <dave.roby@alaska.gov> Subject: MT7-06 production test update/question Hello Dave, are you working today and available for a quick phone call? I wanted to talk to you about our MT7-06 production test progress and ask for an increase in our approved fluid limit to get us through 1 more week of testing. thanks, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): Casing Collapse Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Length Size TVD BurstMD Perforation Depth MD (ft): Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc 700 G Street, Anchorage, AK 99507 221-048 50-103-20831-00-00 NA MT7-06 AA081800, AA081781, AA081736 Greater Mooses Tooth/Rendezvous 26153 8483 26153 8483 none liner cut Conductor 81' 20" 120' 120' Surface 3386' 13.375" 3425' 3052' Intermediate 12202'7.625"12241'8302' 12241'26154'4.5"L80 12219 Baker Premier Packer 10143' / 7292' 11/21/2021 Staff Production Engineer Dana Glessner glessd@conocophillips.com 907-265-6478 Prod test w/flaring By Samantha Carlisle at 12:21 pm, Nov 16, 2021 Dana Glessner Digitally signed by Dana Glessner Date: 2021.11.16 11:50:00 -09'00' 321-590 DSR-11/17/21DLB 11/16/2021 10-404 & 10-422 NA DLB Flaring for the purpose of testing the well prior to regular production is authorized in accordance with 20.AAC 25.235(d)(6). Flared volumes must be reported on monthly gas disposition report. If test production is sufficient to sustain production through drillsite production facilities test shall be terminated and production routed to permanent facilities instead of testing facilities. Unless otherwise approved by the AOGCC testing is limited to 21 days and 50,000 bbls of liquids. X VTL 11/18/21 dts 11/18/2021 JLC 11/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.18 10:46:39 -09'00' RBDMS HEW 11/19/2021 November 16, 2021 Jeremy Price, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 Dear Commissioner Price, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. (CPAI) to conduct a production test with gas flaring from well Greater Mooses Tooth Unit (GMTU) MT7-06 (PTD 221- 048) pursuant to 20 AAC 25.235(d)(6). Development well MT7-06 was not completed as originally proposed due to drilling and completion complications and was left as an open hole horizontal production lateral without fracture stimulation. Production tubing was run with gas lift valves. CPAI intends to return to the well in the future for either recompletion or redrill. Following the initial cleanup flowback, CPAI would like to complete a production test in order to collect unstimulated flow data from the well. The current completion of the well allows for an opportunity to collect unstimulated reservoir productivity data and further understanding of reservoir potential. Also, an analysis of the productivity is needed to determine if the well meets minimum drillsite startup flowrate requirements. Estimated total volumes during the test are ~50,000 barrels of liquid produced and 50 to 100 MMSCF gas flared. Production from the test will be handled as follows: x Produced liquids will flow through a portable test separator and the gas will be flared. x Liquids will flow to a temporary tank farm on MT7. x Total oil production volumes to be used for allocation purposes will be measured by performing tank straps prior to offloading from the tank farm at the MT7 drill site. The volumes are measured and verified using tank straps calibrated to the primary upright flowback tanks. x Little Red Services will manifest the volumes, and liquids will be trucked to a temporary tank farm at MT6 or CD4. x CPAI will pay royalty based on the manifested volumes. x Fluid manifests and volumes will be verified upon delivery to the tank farm at MT6 or CD4. x From the temporary tank farms at MT6 or CD4, the liquids will be pumped into the production pad flowline. x In the flowline, the liquids will be commingled with other GMTU or CRU production. The production will then be processed into sales quality at Alpine Central Facility, delivered to a common carrier line, and ultimately sold into commerce. Dana Glessner Staff Production Engineer North Slope Development ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 phone 907.265.6478 Also, an analysis,y of the productivity is needed to determine if the well meets minimum drillsite startup flowrate requirements.py p q Estimated total volumes during the test are ~50,000 barrels of liquid produced and 50 to 100 MMSCF gas flared. CPAI would like to complete a production test in order to collectgp, pp unstimulated flow data from the well. The current completion of the well allows for an opportunity to collectpypp unstimulated reservoir productivity data and further understanding of reservoir potential.py g p Please contact me (265-6478, glessd@conocophillips.com) if you have questions or require additional information. Regards, Dana Glessner Staff Production Engineer North Slope Development From:Roby, David S (CED) To:Glessner, Dana; AOGCC Permitting (CED sponsored) Cc:Loepp, Victoria T (CED); Boyer, David L (CED) Subject:RE: [EXTERNAL]RE: MT7-06 (PTD 221-048) Production test w/flaring 10-403 Date:Wednesday, November 17, 2021 3:43:17 PM Thank you. Dave Roby (907)793-1232 From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Wednesday, November 17, 2021 3:42 PM To: Roby, David S (CED) <dave.roby@alaska.gov>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]RE: MT7-06 (PTD 221-048) Production test w/flaring 10-403 Hello Dave, please see the answers to your questions below. Let me know if you have any others. thanks, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com From: Roby, David S (CED) <dave.roby@alaska.gov> Sent: Tuesday, November 16, 2021 5:29 PM To: Glessner, Dana <Dana.Glessner@conocophillips.com>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: [EXTERNAL]RE: MT7-06 (PTD 221-048) Production test w/flaring 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Dana, I have a few quick questions on this application. 1. You state the estimated total volume during the test would be ~50,000 bbls of liquid. Would this be all oil, and if not what kind of split between oil and water do you expect? We would expect 90 – 100% oil production split. 2. How long do you expect the test to last? We estimate a test period of 14 – 21 days. 3. One of the purposes of the test is to determine if the well meets the minimum drillsite startup flowrate requirements. If you find it does will you terminate the test an associated flaring and run production through the drillsite facilities? Yes we will terminate the test and associated flaring and startup the drillsite. Thanks in advance. Dave Roby (907)793-1232 From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Tuesday, November 16, 2021 12:21 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Roby, David S (CED) <dave.roby@alaska.gov> Subject: MT7-06 (PTD 221-048) Production test w/flaring 10-403 Please accept the attached 10-403 including a separate proposal summary from ConocoPhillips. Thank you, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ____________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 9. Ref Elevations: KB: 17. Field / Pool(s): GL:100.9 BF: Total Depth: 3614' FSL, 3329' FWL S20 T9N R2E UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: GR, RES, DIR, AZI, DEN, NEU, CALIPER, POROSITY, StarTrak, LithoTrak, AziTrack 23. BOTTOM 20" H-40 120 10 yrds 13.375" L-80 3,052 7.625" L-80 8,303 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press. 24-Hour Rate 69' FSL, 2406' FWL, S6 T9N R2E UM Sr Res EngSr Pet GeoSr Pet Eng Greater Mooses Tooth/Rendezvous N/A Oil-Bbl:Water-Bbl: Perforations@ 10,923'-10,925'MD Gas-Oil Ratio:Choke Size: 10,923'-10,925' MD 107.5bbls of 15.8ppg Class G Water-Bbl: Flow Tubing Not Pre-produced Date of Test: Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information PACKER SET (MD/TVD) 12376'4.5' SIZE TUBING RECORD GRADE PRODUCTION TEST HOLE SIZE ACID, FRACTURE, CEMENT SQUEEZE, ETC. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Lead: 477 bbls of 11ppg DeepCRETE Tail: 69bbls of 15.8ppg Class G CEMENTING RECORD 140.4 290953 TOP SETTING DEPTH MD 40 40 5909744 5897282 94 CASING, LINER AND CEMENTING RECORD 982'MD/981TVD' SETTING DEPTH TVD TOP 12,586MD/8,373 TVD 68 120 P.O. Box 100360, Anchorage, AK 99510-0360 5915791 CASING WT. PER FT. 289937 Top of Productive Interval: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 9/16/2021 50-103-20831-00-00 285165 GMTU MT7-06 AA081800, AA081781, AA081736 968' FSL, 1859' FWL, S32 T10N R2E UM 932535000, 932516000, 300840000 7/19/2021 26,153'MD/8,483'TVD 26,241'MD/8484'TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/10/2021 221-048/321-396/321-368/321-535 DEPTH SET (MD) 10,144'MD/7,292'TVD 40 3,425 AMOUNT PULLED 16" 42" BOTTOM 40 29.7 37 11"12,241 37 110bbls of 15.8ppg Class G WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RBDMS HEW 11/8/2021 Completion Date 10/10/2021 HEW By Meredith Guhl at 7:50 am, Nov 08, 2021 mudlog: PB1 only. MDG VTL 01/31/2022 GDSR-11/8/21 DLB 11/08/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ____________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 9. Ref Elevations: KB: 17. Field / Pool(s): GL:100.9 BF: Total Depth: 3614' FSL, 3329' FWL, S20 T9N R2E UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: GR, RES, DIR, AZI, DEN, NEU, CALIPER, POROSITY, StarTrak, LithoTrak, AziTrack 23. BOTTOM 20" H-40 120 10 yrds 13.375" L-80 3,052 7.625" L-80 8,303 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press. 24-Hour Rate 69' FSL, 2406' FWL, S6 T9N R2E UM Sr Res EngSr Pet GeoSr Pet Eng Greater Mooses Tooth/Rendezvous N/A Oil-Bbl:Water-Bbl: Perforations@ 10,923'-10,925'MD Gas-Oil Ratio:Choke Size: 10,923'-10,925' MD 107.5bbls of 15.8ppg Class G Water-Bbl: Flow Tubing Not Pre-produced Date of Test: Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information PACKER SET (MD/TVD) TUBING RECORD GRADE PRODUCTION TEST HOLE SIZE ACID, FRACTURE, CEMENT SQUEEZE, ETC. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Lead: 477 bbls of 11ppg DeepCRETE Tail: 69bbls of 15.8ppg Class G CEMENTING RECORD 39.5 290953 TOP SETTING DEPTH MD 40 40 5909744 5897282 94 CASING, LINER AND CEMENTING RECORD 982'MD/981TVD' SETTING DEPTH TVD TOP 12,586MD/8,373 TVD 68 120 P.O. Box 100360, Anchorage, AK 99510-0360 5915791 CASING WT. PER FT. 289937 Top of Productive Interval: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 9/16/2021 50-103-20831-00-00 285165 GMTU MT7-06 AA081800, AA081781, AA081736 968' FSL, 1859' FWL, S32 T10N R2E UM 932535000, 932516000, 300840000 7/19/2021 26,153'MD/8,483'TVD 26,241'MD/8484'TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/10/2021 221-048/321-396/321-368/321-535 12,376'MD4.5' SIZE DEPTH SET (MD) 10,144'MD/7,292'TVD 40 3,425 AMOUNT PULLED 16" 42" BOTTOM 40 29.7 37 11"12,241 37 110bbls of 15.8ppg Class G WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 2:58 pm, Nov 04, 2021 RBDMS HEW 11/5/2021 Completion Date 10/10/2021 HEW SUPERSEDED Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 982 981 C30 1662 1649 2028 1993 3348 3004 3880 3343 4301 3610 4599 3799 HRZ 10395 7442 N/A 10512 7511 Kuparuk C 10716 7631 LCU/Miluveach 10724 7636 Top of Productive Interval (Alpine C):12396 8339 Formation at total depth (TD):26153 8483 31. List of Attachments: Directional Survey, Cement Report, Well Schematic, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Nina Anderson Contact Email:nina.anderson@conocophillips.com Authorized Contact Phone:907-265-6403 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. C10 Albian 97 Kalubik K-3 K-2 INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: Jenna Taylor Wells Engineering Technician Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Albian 96 The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All lab oratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Jenna Taylor DN: C=US, CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.11.04 14:42:35-08'00' Foxit PDF Editor Version: 11.0.0 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:MT7-06 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Post Rig Wellwork 11/3/2021 MT7-06 claytg Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 40.5 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 Wt/Len (l… 94.00 Grade Top Thread Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.42 Top (ftKB) 40.3 Set Depth (ftKB) 3,425.0 Set Depth (TVD) … 3,052.5 Wt/Len (l… 68.00 Grade L-80 Top Thread H563 Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.91 Top (ftKB) 37.0 Set Depth (ftKB) 12,241.0 Set Depth (TVD) … 8,302.9 Wt/Len (l… 29.70 Grade L80 Top Thread Hyd563 Tubing Strings Tubing Description Tubing - Production String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 0.0 Set Depth (ft… 12,219.0 Set Depth (TVD) (… 8,297.4 Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 33.1 33.1 0.00 HANGER 3.958 11.000 FMC TC-EMS FMC 4-1/2" Tubing Hanger Hydril HYD 563 Min ID 3.92" 10,122.6 7,280.0 53.74 NIPPLE 3.813 5.030 HES X Nipple NIPPLE,LANDING,4 1/2","X",3.813", H563 10,143.5 7,292.4 53.73 PACKER 3.880 4.500 Baker Premier Baker Premier Production Packer, 4 1/2" X 7 5/8" 33.7# 10,212.7 7,333.3 53.71 NIPPLE 3.750 5.210 SLB DB NIPPLE,LANDING,4 1/2","DB",3.75", H563 12,218.5 8,297.3 75.40 MULE SHOE 3.958 4.500 Northern Sol Dissolvin g shoe NS DISSOLVING SHOE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 37.2 37.2 0.00 EMERGENCY SLIPS Intermediate casing landed on emergency slips with 200 k on slips. 8/13/2021 10,122. 6 7,280.0 53.74 GAUGES 3.813" X-Lock w/ Flow-Thru Sub and dual Spartek Gauges 11/3/2021 79612 / 79366 Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 3,673.8 50.71 GAS LIFT 6.393 3.865 VanOil KBMG 3,210.9 2 7,672.1 50.01 GAS LIFT 6.437 3.860 Camco KBMG 5,766.4 3 10,053.4 53.72 GAS LIFT 6.393 3.865 VanOil KBMG 7,239.1 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,673.8 3,210.9 50.71 Camco BK 1 GAS LIFT GLV BK 0.188 1,784.0 10/23/2021 2 7,672.1 5,766.4 50.01 Camco BK 1 GAS LIFT GLV BK 0.188 1,771.0 10/23/2021 3 10,053.4 7,239.1 53.72 Camco BKO-3 1 GAS LIFT OV BK 0.313 10/22/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,923.0 10,925.0 7,748.3 7,749.4 LCU, MT7-06 8/10/2021 6.0 IPERF Perforated Intermediate casing 10923' - 10,925' MD. Pumped 87 bbls of cement through the perforations followed by 1.5 bbls hesitation squeeze (925 psi final squeeze pressure). Drilled and scraped cement across the perfs. FIT perfs to 11.75 ppg EMW (solid test). Notes: General & Safety End Date Annotation NOTE: HORIZONTAL, MT7-06, 11/4/2021 12:37:27 PM Vertical schematic (actual) INTERMEDIATE; 37.0-12,241.0 IPERF; 10,923.0-10,925.0 NIPPLE; 10,212.7 PACKER; 10,143.5 GAUGES; 10,122.6 NIPPLE; 10,122.6 GAS LIFT; 10,053.4 GAS LIFT; 7,672.1 GAS LIFT; 3,673.8 SURFACE; 40.3-3,425.0 CONDUCTOR; 40.5-120.0 HANGER; 33.1 WNS PROD KB-Grd (ft) 39.50 Rig Release Date 10/10/2021 MT7-06 ... TD Act Btm (ftKB) 26,153.0 Well Attributes Field Name RENDE Wellbore API/UWI 501032083100 Wellbore Status PROD Max Angle & MD Incl (°) 91.96 MD (ftKB) 26,028.30 WELLNAME WELLBOREMT7-06 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NONE Page 1/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/17/2021 08:00 7/17/2021 08:30 0.50 MIRU, MOVE MOB P PJSM. Skidded floor. SIMOPS: Moved ball mill and staged by MT7-06 0.0 0.0 7/17/2021 08:30 7/17/2021 09:00 0.50 MIRU, MOVE MOB P Lowered the derrick. SIMOPS: Set power on suspension and staged by MT7-06 0.0 0.0 7/17/2021 09:00 7/17/2021 10:30 1.50 MIRU, MOVE MOB P Stomped out casing complex. Set pump complex on suspension and staged by MT7-06 0.0 0.0 7/17/2021 10:30 7/17/2021 12:00 1.50 MIRU, MOVE MOB P Stomped out pipe shed from under sub. SIMOPS: Continued to condition location. 0.0 0.0 7/17/2021 12:00 7/17/2021 14:00 2.00 MIRU, MOVE MOB P Off loaded rig mats. SIMOPS: Stomped motor complex into position for truck. 0.0 0.0 7/17/2021 14:00 7/17/2021 16:00 2.00 MIRU, MOVE MOB P Removed mats from courtyard. Shimmed sub complex. Put motor complex on suspension and move with SOW. Stomped pump complex and staged to make room for pit complex. 0.0 0.0 7/17/2021 16:00 7/17/2021 18:00 2.00 MIRU, MOVE MOB P Continued to move rig mats. Stomped pit complex into position. Put on suspension and move w/ SOW to staging area. 0.0 0.0 7/17/2021 18:00 7/17/2021 19:00 1.00 MIRU, MOVE MOB P Continued to set rig mats. Get casing complex on suspension and move w/ SOW to staging area. 0.0 0.0 7/17/2021 19:00 7/17/2021 21:30 2.50 MIRU, MOVE MOB P Removed rig mats in courtyard for dirt work. Continued to stomp pipeshed out from under sub to edge of pad. 0.0 0.0 7/17/2021 21:30 7/18/2021 00:00 2.50 MIRU, MOVE MOB P Continued moving rig mats. Continued dirt work to prep pad. 0.0 0.0 7/18/2021 00:00 7/18/2021 06:00 6.00 MIRU, MOVE MOB P Continued to prep pad. SIMOPS: Complete MP-2 WO, Housekeeping, C/O Sub Hydraulic filters, Clean and prepped BOP Bolts. 0.0 0.0 7/18/2021 06:00 7/18/2021 07:00 1.00 MIRU, MOVE MOB P Stomp pipe shed into spotting position 0.0 0.0 7/18/2021 07:00 7/18/2021 10:00 3.00 MIRU, MOVE MOB P Lay rig mats in place t/ walk sub & pipe shed 0.0 0.0 7/18/2021 10:00 7/18/2021 12:00 2.00 MIRU, MOVE MOB P Spotted sub over well and straightened pipe shed for spotting. 0.0 0.0 7/18/2021 12:00 7/18/2021 15:00 3.00 MIRU, MOVE MOB P Spotted pipeshed and pin to sub. SIMOPS: moved mud pits w/ truck and took off suspension. 0.0 0.0 7/18/2021 15:00 7/18/2021 16:00 1.00 MIRU, MOVE MOB P Spotted mud pits w/ stompers. Moved pump room w/ SOW and took off suspension. 0.0 0.0 7/18/2021 16:00 7/18/2021 17:00 1.00 MIRU, MOVE MOB P Spotted pump complex w/ stomper and made up interconnects. 0.0 0.0 7/18/2021 17:00 7/18/2021 19:00 2.00 MIRU, MOVE MOB P Raised derrick. Spotted motor complex and moved casing complex w/ SOW. Plugged in interconnects. 0.0 0.0 7/18/2021 19:00 7/18/2021 21:00 2.00 MIRU, MOVE MOB P Continued to plug in electric connections. Skidded rig floor. Got casing complex off suspension and spot w/ stompers. 0.0 0.0 7/18/2021 21:00 7/18/2021 23:30 2.50 MIRU, MOVE MOB P Lowered C-Section. Raised cattle chute. Prepped to scope derrick. Continued to connect interconnects in mud pits. 0.0 0.0 7/18/2021 23:30 7/19/2021 00:00 0.50 MIRU, MOVE MOB P Scoped derrick up. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 2/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/19/2021 00:00 7/19/2021 03:00 3.00 MIRU, MOVE RURD P Rig on scopping derrick equipment. Finished acceptance checklist. Rig accepted on 07/19/2021 at 0300 hr. 0.0 0.0 7/19/2021 03:00 7/19/2021 07:30 4.50 MIRU, MOVE RURD P N/U surface riser, annular, flow box, and flow line. SIMOPS: Installed mouse hole. 0.0 0.0 7/19/2021 07:30 7/19/2021 08:00 0.50 MIRU, MOVE PULD P P/U 5'' HWDP & jars & rack same back in derrick 0.0 0.0 7/19/2021 08:00 7/19/2021 09:00 1.00 MIRU, MOVE RURD P Stage subs & stabilizers t/ floor f/ BHA pick up SIMOPS: Take spud mud ti pits & stage BHA in pepe shed 0.0 0.0 7/19/2021 09:00 7/19/2021 10:15 1.25 MIRU, MOVE BHAH P PJSM, P/U mud motor, M/U bit, stab, NMPC, XO, & stand HWDP, Fill mud lines & test same t/ 3,500 PSI, Test OK 0.0 0.0 7/19/2021 10:15 7/19/2021 10:45 0.50 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 120' t/ 150' WOB- 4-8K RPM-40 Torq.-3-5K GPM-450 On Btm PSI- 1095 Off Btm PSI- 875 Flow out- 50% ECD- PPG P/U- 50K S/O- 50K Rot- 50K AST- 0 ART- .2 ADT- .2 Total Bit Hrs- .2 Total Jars- 0 0.0 150.0 7/19/2021 10:45 7/19/2021 11:00 0.25 SURFAC, DRILL TRIP P TOH f/ 150' t/ 68' to pick up mwd, UBHO, & filter sub 150.0 68.0 7/19/2021 11:00 7/19/2021 12:15 1.25 SURFAC, DRILL BHAH P PJSM, P/U MWD & UBHO, scribe same t/ high side of motor, P/U filter sub & XO 68.0 138.0 7/19/2021 12:15 7/19/2021 12:30 0.25 SURFAC, DRILL TRIP P TIH f/ 138' t/ 150' 138.0 150.0 7/19/2021 12:30 7/19/2021 14:30 2.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 150' t/ 319' WOB- 4-8K RPM-40-50 Torq.-3-5K GPM-550 On Btm PSI- 1090 Flow out- 47% ECD- 10.6 PPG P/U- 74K S/O- 73K Rot- 65K AST- 0 ART- 0.6 Total Bit Hrs- 0.8 Total Jars- 0 150.0 319.0 7/19/2021 14:30 7/19/2021 14:45 0.25 SURFAC, DRILL SLKL P PJSM, Rig up wire equipment 319.0 319.0 7/19/2021 14:45 7/19/2021 15:30 0.75 SURFAC, DRILL SLKL P RIH w/ Gyro & take gyro survey due t/ magnectic interference 319.0 319.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 3/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/19/2021 15:30 7/19/2021 18:00 2.50 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 319' t/ 493' WOB- 7K RPM- 50 Torq.-3-4K GPM-550 On Btm PSI- 1200 Flow out- 47% ECD- 10.6 PPG P/U- 74K S/O- 71K Rot- 65K AST- 0.7 ART- 1.8 ADT- 2.5 Total Bit Hrs- 3.3 Total Jars- 0 319.0 493.0 7/19/2021 18:00 7/20/2021 00:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 493' t/ 868' WOB- 22K RPM- 50 Torq.-3 K GPM-550 On Btm PSI- 1533 Flow out- 60% ECD- 10.6 PPG P/U- 79K S/O- 83K Rot- 80K AST- 1.5 ART- 2.9 ADT- 4.4 Total Bit Hrs- 7.7 Total Jars- 4.4 493.0 868.0 7/20/2021 00:00 7/20/2021 06:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 868' t/ 1,201' WOB- 22-30K RPM- 50-60 Torq.- 5-8 K GPM-700 On Btm PSI- 1990 Flow out- 60% ECD- 11.28 PPG P/U- 95K S/O- 92K Rot- 95K AST- 1.5 ART- 2.2 ADT- 3.7 Total Bit Hrs- 11.4 Total Jars- 8.1 868.0 1,055.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 4/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/20/2021 06:00 7/20/2021 12:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 1,201' t/ 1,588' WOB- 25-35K RPM- 50-60 Torq.-4-8 K GPM-800 On Btm PSI- 2480 Flow out- 60% ECD- 11.4 PPG P/U- 104K S/O- 103K Rot- 102K AST- 1.6 ART- 2.9 ADT- 4.5 Total Bit Hrs- 15.9 Total Jars- 12.6 1,055.0 1,588.0 7/20/2021 12:00 7/20/2021 18:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 1,588' t/ 2,040' WOB- 12-31K RPM- 60 Torq.-4-6 K GPM-890 On Btm PSI- 3100 Flow out- 69% ECD- 11.52 PPG P/U- 115K S/O- 109K Rot- 108K AST- 2.5 ART- 2 ADT- 4.5 Total Bit Hrs- 20.4 Total Jars- 17.1 1,588.0 2,040.0 7/20/2021 18:00 7/21/2021 00:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 2,040' t/ 2,548' WOB- 31-32K RPM- 60 Torq.-4-6 K GPM-890 On Btm PSI- 3091 Flow out- 69% ECD- 11.68 PPG P/U- 134K S/O- 116K Rot- 122K AST- 2.4 ART- 2.3 ADT- 4.7 Total Bit Hrs- 25.1 Total Jars- 21.8 2,040.0 2,548.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 5/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/21/2021 00:00 7/21/2021 06:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 2,548' t/ 3,017' WOB- 30-35K RPM- 60 Torq.-4-8 K GPM-890 On Btm PSI- 3450 Flow out- 68% ECD- 12 PPG P/U- 146K S/O- 1119K Rot- 124K AST- 2 ART- 2.3 ADT- 4.3 Total Bit Hrs- 29.4 Total Jars- 26.1 2,548.0 3,017.0 7/21/2021 06:00 7/21/2021 12:00 6.00 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 3,017' t/ 3,393' WOB- 30-35K RPM- 60 Torq.-4-8 K GPM-890 On Btm PSI- 3600 Flow out- 68% ECD- 11.59 PPG P/U- 146K S/O- 119K Rot- 124K AST- 0 ART- 3.8 ADT- 3.8 Total Bit Hrs- 33.2 Total Jars- 29.9 Had increase of cuttings @ 3,310' & 3,390' and had t/ pick up to clear flow line of pack off 3,017.0 3,393.0 7/21/2021 12:00 7/21/2021 13:45 1.75 SURFAC, DRILL DDRL P Drill 16'' Surface f/ 3,393' t/ 3,435' WOB- 28-35K RPM- 60 Torq.- 4-8 K GPM-890 On Btm PSI- 3430 Flow out- 68% ECD- 11. PPG P/U- 149K S/O- 124K Rot- 132K AST- 0 ART- .7 ADT- .7 Total Bit Hrs- 33.9 Total Jars- 30.6 3,393.0 3,435.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 6/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/21/2021 13:45 7/21/2021 15:00 1.25 SURFAC, CASING CIRC P Pump up final survey @ 3,435' Pump 2 40 bbls nut plug sweeps around @ 3,435' while rotating & reciprocating pipe GPM-890 PSI- 3233 RPM-60 Torq-5K Total pump strokes = 8,126 3,435.0 3,435.0 7/21/2021 15:00 7/21/2021 16:00 1.00 SURFAC, CASING CIRC P Pumped 50 bbl nut plug sweep. Rot and reciprocated f/ 3,421' to 3,335' MD. GPM-890 PSI- 3350 FO 64% RPM-60 Torq-3-4K ECD = 11.3 ppg Total pump strokes = 8,550 3,435.0 3,335.0 7/21/2021 16:00 7/21/2021 17:30 1.50 SURFAC, CASING CIRC P CBU 2X. Rot and reciprocated f/ 3,421' to 3,145' MD. GPM-890 PSI- 3150 FO 64% RPM-60 Torq-3-4K ECD = 11.2 ppg PU Wt 142 k SO Wt 125 k Total pump strokes = 14,330 3,335.0 3,145.0 7/21/2021 17:30 7/21/2021 18:00 0.50 SURFAC, CASING OWFF P OWFF - Slight drop in fluid level.in stack. 3,145.0 3,145.0 7/21/2021 18:00 7/21/2021 21:30 3.50 SURFAC, CASING BKRM P Attempted to POOH f/ 3,145' to 3,103' MD. Encountered 45 k OP. BROOH f/ 3,145' MD -2,480' MD. GPM-500-890 PSI- 1200-3100 FO 64% RPM-15-40 Torq-4-10 ECD = 11.4-11.6 ppg RT Wt 117 k 3,145.0 2,480.0 7/21/2021 21:30 7/22/2021 00:00 2.50 SURFAC, CASING PMPO P Pumped out of the hole f/ 2,480' - 1830' MD. GPM-890 PSI- 2950 FO 65% ECD = 11.59 ppg PU Wt 116-124 k Attempted to pull wq/o pumps at 2,040' MD and observed 40 k OP. 2,480.0 1,830.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 7/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/22/2021 00:00 7/22/2021 00:30 0.50 SURFAC, CASING PMPO P Pumped out of the hole f/ 1,830' - 1530' MD. GPM-890 PSI- 2950 FO 63% ECD = 11.79 ppg PU Wt 117 k SO Wt 106 k Attempted to pull wq/o pumps at 1,737' MD and observed 40 k OP. 1,830.0 1,530.0 7/22/2021 00:30 7/22/2021 01:30 1.00 SURFAC, CASING PMPO P Pumped out of the hole f/ 1,530' - 1,439' MD. GPM-800 PSI- 2450 FO 60% ECD = 11.69 ppg PU Wt 112 k SO Wt 100 k Attempted to pull wq/o pumps at 1,439' MD and observed 40 k OP. 1,530.0 1,439.0 7/22/2021 01:30 7/22/2021 02:00 0.50 SURFAC, CASING PMPO P Pumped out of the hole f/ 1,439 MD - 1,370' MD. GPM- 550 PSI- 1400 FO 52% RPM 40 PU Wt 109 k SO Wt 97 k 1,439.0 1,370.0 7/22/2021 02:00 7/22/2021 03:00 1.00 SURFAC, CASING BKRM P BROOH f/ 1,370' to 1,170' GPM- 800 PSI- 2351 FO 60% ECD 11.8 RPM 40 TQ 4-5 k PU Wt 109 k SO Wt 97 k Pumped 40 bbl nut plug sweep at 1,260' MD. Not much load observed coming out of hole. 1,370.0 1,170.0 7/22/2021 03:00 7/22/2021 04:00 1.00 SURFAC, CASING TRIP P POOH on elevators f/ 1,170' - 500' MD. PU Wt 115 k SO Wt 90 k Monitored displacement via pit #2. 1,170.0 500.0 7/22/2021 04:00 7/22/2021 05:00 1.00 SURFAC, CASING TRIP P POOH on elevators f/ 500' - 135' MD. PU Wt 80 k SO Wt 80 k Monitored displacement via pit #2. 500.0 135.0 7/22/2021 05:00 7/22/2021 06:30 1.50 SURFAC, CASING BHAH P OWFF. PJSM, L/D MWD, filter sub, UBHO, & stab, drain motor & break bit, L/D same 135.0 0.0 7/22/2021 06:30 7/22/2021 08:30 2.00 SURFAC, CASING RURD P Clean rig floor f/ tripping & laying down BHA & prep f/ casing run PJSM, R/U casing equipment w/ monitoring hole via hole fill.. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 8/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/22/2021 08:30 7/22/2021 09:30 1.00 SURFAC, CASING PUTB P PJSM, RIH w/ 13 3/8'' L80 68# casing f/ shoe t/ 123'. Check floats, floats ok Monitor fill ups on pit #2 0.0 123.0 7/22/2021 09:30 7/22/2021 12:00 2.50 SURFAC, CASING PUTB P RIH w/ 13 3/8'' L80 68# casing f/ 123' t/ 717' Casing started taking wait @ 600' 123.0 717.0 7/22/2021 12:00 7/22/2021 16:45 4.75 SURFAC, CASING WASH T Wash in hole w/ 13 3/8'' L80 68# casing f/ 717' t/ 1,290' GPM: 250 GPM PSI: 150 M/U XO f/ TXP t/ Hy563 @ 1,220 600.0 1,290.0 7/22/2021 16:45 7/22/2021 18:00 1.25 SURFAC, CASING PUTB P RIH w/ 13 3/8'' L80 68# casing f/ 1,290' t/ 1,450' MD. TQ Connections to 30 k ftlbs. PU Wt 125 k SO Wt 104 k Monitor fill ups on pit #2 & 3. 1,290.0 1,450.0 7/22/2021 18:00 7/22/2021 22:45 4.75 SURFAC, CASING PUTB P RIH f/ 1,450' - 2,615' MD. TQ Connections to 25 k ftlbs. PU Wt 234 k SO Wt 205 k Filled pipe on the fly and topped off every 10 joints RIH. Monitor fill ups on pit #2 & 3. 1,450.0 2,615.0 7/22/2021 22:45 7/23/2021 00:00 1.25 SURFAC, CASING WASH T While RIH w/ 205 k DW encountered tight spot at 2,615' MD. DW to 107 k. Worked past obstruction to 2,640' MD by staging up pumps to 253 gpm . FO 36% PU Wt 234 k Pump pressure 160-430 psi. 2,615.0 2,640.0 7/23/2021 00:00 7/23/2021 00:15 0.25 SURFAC, CASING PUTB T Worked past obstruction f/ 2,640' -2,648' MD by staging up pumps to 253 gpm . PSI 347 FO 38% PU Wt 240 k SO Wt 180 k 2,640.0 2,648.0 7/23/2021 00:15 7/23/2021 01:00 0.75 SURFAC, CASING PUTB P RIH w/ 13 3/8'' L80 68# casing f/ 2,648' t/ 2,782' MD. TQ Connections to 25 k ftlbs. Filling on the fly w/ the Volant and toping off every 5 jts. Monitor fill ups on pit #2 & 3. 2,648.0 2,782.0 7/23/2021 01:00 7/23/2021 05:30 4.50 SURFAC, CASING WASH P Encountered tight hole at 2,870' MD. Observed 80 k loss in hookload. P/U and staged up pumps to 6 bpm. PSI 230 FO 22% PU Wt 260 k SO Wt 190 k Washed and worked down casing. 2,782.0 2,870.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 9/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/23/2021 05:30 7/23/2021 07:00 1.50 SURFAC, CASING PUTB P RIH w/ 13 3/8'' L80 68# casing f/ 2,870' t/ 3,367' 2,870.0 3,367.0 7/23/2021 07:00 7/23/2021 07:15 0.25 SURFAC, CASING OTHR P PJSM, M/U FMC casing hanger & landing joint 3,367.0 3,367.0 7/23/2021 07:15 7/23/2021 07:30 0.25 SURFAC, CASING WASH P Wash 13 3/8'' L80 68# casing f/ 3,367' t/ 3,425' 3,367.0 3,425.0 7/23/2021 07:30 7/23/2021 10:15 2.75 SURFAC, CEMENT CIRC P Circ & condtion mud for cement job reiporcating casing 15' up & down Pumped 746 bbls total BPM- 8 PSI- 186 3,425.0 3,425.0 7/23/2021 10:15 7/23/2021 10:30 0.25 SURFAC, CEMENT OTHR P M/U cementing hose t/ CRT 3,425.0 3,425.0 7/23/2021 10:30 7/23/2021 11:45 1.25 SURFAC, CEMENT CIRC P Circ & condition mud for cement job w/ reciprocating pipe 15' up & down Pumped 394 bbls BPM- 6 PSI- 259 SIMOPS- Transfer mud t/ vac trucks to make room for cement job 3,425.0 3,425.0 7/23/2021 11:45 7/23/2021 16:30 4.75 SURFAC, CEMENT CMNT P SLB pump 5 bbls of fresh H2O. Tested lines to 500 psi low/ 3500 psi high, pump 100 bbls of 11.0 ppg Mud Push II @ 5 bbls/min, 340 psi, 12.5% F/O, Dropped bottom plug. Start batching lead. Pump 477 bbls of 11.0 ppg DeepCRETE cement at 5.5 bbls/min, 700 psi ICP, F/O 15%. Batch and pump 69 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 600 psi, F/O 14.7%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg Ksi mud @ 7 bbls/min, 685 psi, F/O 28%. Bump plug with 1050 psi (481 bbls + 20 bbls). 4071 strokes, final circ. PSI 451 @ 3 bpm, Pressure up to 1000 psi & hold for 5 minutes. Bleed off pressure, Check floats, Floats holding, 190 bbls 11.0 ppg cement to surface. 3,425.0 3,425.0 7/23/2021 16:30 7/23/2021 18:30 2.00 SURFAC, WHDBOP CLEN P Cleaned and cleared rig floor. RIgged down volant. L/D landing joint. Flushed stack and functioned annular. Cleaned flow box and flow line. Cleaned mud manifold. 3,425.0 3,425.0 7/23/2021 18:30 7/23/2021 20:30 2.00 SURFAC, WHDBOP NUND P N/D flow box, surface riser, and annular. 3,425.0 3,425.0 7/23/2021 20:30 7/23/2021 21:30 1.00 SURFAC, WHDBOP NUND P NU and oriented wellhead per FMC. Tested hanger neck seal to 100 psi for 10 minutes. 3,425.0 3,425.0 7/23/2021 21:30 7/24/2021 00:00 2.50 SURFAC, WHDBOP NUND P N/I Riser, BOP stack, and flow box. M/U choke and kill lines, flow line, and MPD equipment. 3,425.0 3,425.0 7/24/2021 00:00 7/24/2021 03:00 3.00 SURFAC, WHDBOP NUND P Continued nippling up BOPE and MPD. SIMOPS: Bring BHA to rig floor and prepare for BOP and MPD testing. 3,425.0 3,425.0 7/24/2021 03:00 7/24/2021 04:00 1.00 SURFAC, WHDBOP MPDA P Tested MPD equipment 250psi/1200psi (low/high) 3,425.0 3,425.0 7/24/2021 04:00 7/24/2021 05:30 1.50 SURFAC, WHDBOP MPDA P R/D MPD, and R/U testing equipment. 3,425.0 3,425.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 10/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/24/2021 05:30 7/24/2021 10:45 5.25 SURFAC, WHDBOP BOPE P Test BOPE all tests 250 psi low for 5 min, 3,500 psi high for 10 minutes each with 5" - test annular and 2 7/8" x 5 1/2" UPR and LPR, test choke valves 1-15, manual and super choke, choke and kill manual's and HCR's, 4" valve on kill line, 2 x 4" FOSV, upper and lower IBOP, blind/shear rams. Perform Koomey drawdown, ACC=3000 psi, manifold=1500 psi initial. After all functions, accumulator=1450 psi, 15 secs to 200 psi with two electric pumps, 109 secs to build to full system pressure with two electric and two air pumps. Closing times, annular=23 secs, UPR=18 secs, blind/shears=16 secs, LPR=16 secs, choke HCR=2 secs, kill HCR=2 secs. 6 Nitrogen bottles back-up avg=1908 psi, CPAI witnessed. Tested PVT, gain/loss, flow out, LEL and H2S alarms. AOGCC Rep Austin Mcleod waived witness via email on 7/22/21 @ 10:14, BLM Rep Quinn Sawyer waived witness of test via email on 7/21/21 @ 07:02 3,425.0 3,425.0 7/24/2021 10:45 7/24/2021 12:00 1.25 SURFAC, WHDBOP OTHR P Pull test plug & install wear bushing, FMC rep witnessed & ran in lock downs, SIMOPS: Blow down choke & testing lines 3,425.0 3,425.0 7/24/2021 12:00 7/24/2021 13:00 1.00 SURFAC, DRILLOUT BHAH P M/U Clean out BHA f/ surface to 413' MD. PU Wt 55 k SO Wt 55 k Monitored displacement on pit #2. 0.0 413.0 7/24/2021 13:00 7/24/2021 14:30 1.50 SURFAC, DRILLOUT TRIP P TIH f/ 413' - 2,000' MD w/ 5" DP from the derrick. PU Wt 98 k SO Wt 88 k Monitored displacement on pit #2. 413.0 2,000.0 7/24/2021 14:30 7/24/2021 15:00 0.50 SURFAC, DRILLOUT SVRG P Serviced top drive and blocks. 2,000.0 2,000.0 7/24/2021 15:00 7/24/2021 22:30 7.50 SURFAC, DRILLOUT EQRP T Troubleshooting Amphion, HMI lost communication t/ the drillers control screens due t/ faulty switches, Electrician was able t/ by pass switches as per NOV to get communication back to the HMI screens for driller to control TDS & drawworks 2,000.0 2,000.0 7/24/2021 22:30 7/24/2021 23:30 1.00 SURFAC, DRILLOUT TRIP P TIH f/ 2,000' - 3,238' MD w/ 5" DP from the derrick. PU Wt 128 k SO Wt 124 k Monitored displacement on pit #2. 2,000.0 3,238.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 11/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/24/2021 23:30 7/25/2021 00:00 0.50 SURFAC, DRILLOUT CIRC P Circulate and condition mud while reciprocating f/ 3238' - 3,143' MD. GPM 500 PSI 925 FO 32% RPM 20 TQ 5 k PU Wt 128 k SO Wt 124 k 3,238.0 3,238.0 7/25/2021 00:00 7/25/2021 00:30 0.50 SURFAC, DRILLOUT RURD P R/U for casing test. 3,238.0 3,229.0 7/25/2021 00:30 7/25/2021 01:15 0.75 SURFAC, DRILLOUT PRTS P Performed casing test at 3,229' MD. Pressured up casing to 3,500 psi for 30 minutes. Required 6.5 bbls to achieve ~3500 psi. Bled back 6.5 bbls to mud pits. Good test. 3,229.0 3,229.0 7/25/2021 01:15 7/25/2021 01:45 0.50 SURFAC, DRILLOUT RURD P R/D testing equipment. B/D kill line. 3,229.0 3,229.0 7/25/2021 01:45 7/25/2021 02:30 0.75 SURFAC, DRILLOUT WASH P Washed down f/ 3,229' - 3340' MD. At 3,325' MD observed 7 k decrease in hookload. Continued to wash down through cement stringer to top plug at 3,340' MD. GPM 500 PSI 898 FO 32% RPM 80 TQ 4 k SO Wt 127 k. 3,229.0 3,340.0 7/25/2021 02:30 7/25/2021 07:30 5.00 SURFAC, DRILLOUT DRLG P Drill out FC at 3,340' to 3,345' MD. Drilled cement f/ 3,345' t/ 3,423' Drill shoe f/ 3,423' t/ 3,425' Clean out rat hole f/ 3,425' t/ 3,435' GPM-800 PSI-2,035 RPM-80-110 Torq- 4-9K WOB-10-25 3,340.0 3,435.0 7/25/2021 07:30 7/25/2021 08:00 0.50 SURFAC, DRILLOUT DRLG P Drill 12 1/4' rat hole f/ 3,435' t/ 3,455' GPM-800 PSI-1,519 WOB-20-25 RPM-100-120 Torq-3-10K SIMOPS- Displace hole t/ 9,6# LSND mud 3,435.0 3,455.0 7/25/2021 08:00 7/25/2021 08:30 0.50 SURFAC, DRILLOUT CIRC P Circ btms up @ 3,455' t/ prep mud f/ FIT Working pipe f/ 3,455' t/ 3,392' GPM-800 PSI-1,381 RPM-80 Torq-4K 3,455.0 3,392.0 7/25/2021 08:30 7/25/2021 08:45 0.25 SURFAC, DRILLOUT RURD P PJSM, R/U equipment f/ FIT 3,392.0 3,392.0 7/25/2021 08:45 7/25/2021 09:15 0.50 SURFAC, DRILLOUT FIT P Perform FIT t/ 18.5 ppg equilivalent, 1,421 PSI, 29 stks, (3.3 bbls), PSI bled back t/ 1,176 after 10 min. Bled 3.3 bbls back t/ pits 3,392.0 3,392.0 7/25/2021 09:15 7/25/2021 09:45 0.50 INTRM1, DRILL OWFF P Flow check well, well static, Drop gyro. Pumped slug. 3,392.0 3,392.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 12/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/25/2021 09:45 7/25/2021 12:00 2.25 INTRM1, DRILL TRIP P TOH w/ 12 1/4'' clean out assembly f/ 3,392' t/ 507' 3,392.0 507.0 7/25/2021 12:00 7/25/2021 13:30 1.50 INTRM1, DRILL BHAH P PJSM, L/D 12 1/4'' clean out assembly Break bit, bit sub, stab, UBHO, & NMDC, lay down same 507.0 0.0 7/25/2021 13:30 7/25/2021 14:00 0.50 INTRM1, DRILL CLEN P Clean rig floor after handling BHA 0.0 0.0 7/25/2021 14:00 7/25/2021 15:30 1.50 INTRM1, DRILL SLPC P PJSM, Slip & cut drill line 0.0 0.0 7/25/2021 15:30 7/25/2021 19:00 3.50 INTRM1, DRILL BHAH P M/U BHA #3 f/ surface - 607' MD. Monitored displacement on pit #4. Wt Up 90 k SO Wt 70 k 0.0 607.0 7/25/2021 19:00 7/25/2021 21:00 2.00 INTRM1, DRILL TRIP P TIH w/ BHA f/ 607' - 3,149' MD w/ 5" DP in derrick. Monitored displacement on trip tank. Shallow hole test per BHI. Wt Up 135 k SO Wt 124 k 607.0 3,149.0 7/25/2021 21:00 7/25/2021 21:30 0.50 INTRM1, DRILL DHEQ P Function tested under reamer as per SLB. Cycle range 380 gpm. Confirmed opinging of reamer w/ 200 psi pressure drop (4605RPM -4406RPM). 3,149.0 3,149.0 7/25/2021 21:30 7/25/2021 22:00 0.50 INTRM1, DRILL SVRG P Serviced ttop drive IBOP, wash pipe. 3,149.0 3,149.0 7/25/2021 22:00 7/25/2021 22:30 0.50 INTRM1, DRILL TRIP P TIH w/ BHA #3 f/ 3,149' - 3,455' MD w/ 5" DP f/ derrick. Monitored displacement on trip tank. Wt Up 147 k SO Wt 130 k 3,149.0 3,455.0 7/25/2021 22:30 7/26/2021 00:00 1.50 INTRM1, DRILL DDRL P Drilled 9 7/8" intermediate hole f/ 3,455' - 3,590' MD (3,157' TVD). WOB 10 GPM 735 PSI 1370 RPM 80 TQ 10 k FO 36% ECD 9.9 Wt Up 147 k SO Wt 130 k RT Wt 137 k ADT 1.1 Total Bit Hours 1.1 Total Jar Hours 31.7 3,455.0 3,590.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 13/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/26/2021 00:00 7/26/2021 00:30 0.50 INTRM1, DRILL DHEQ P At 3,565' MD obtained parameters and performed ledge test w/ under reamer. Before reamer was opened: GPM 780 PSI 1,750 FO 40% RPM 20 TQ 4 k Rot Wt 141 DELCRPM 4560 Reduced rate to 377 gpm at 470 psi, FO 23%. Increased rate back to 780 gpm. Parameters when open: GPM 780 PSI 1,497 FO 38% RPM 60 TQ 5 k DELCRPM 4449 Slacked off to 3,370' MD and observed 10 k loss in hookload confirming the reamer was opened. Reamed down w/ reamer opened f/ 3,570' - 3,574' MD: GPM 780 PSI 1,580 FO 39% RPM 60 TQ 8-12 k DELCRPM 4455 P/U to 3,563' MD and closed reamer. Washed down to 3,590' and continued to drill ahead. 3,590.0 3,590.0 7/26/2021 00:30 7/26/2021 06:00 5.50 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 3,590' t/ 4,657'' WOB- 25-30K RPM- 180 Torq.- 10-15K GPM-780 On Btm PSI- 2077 Flow out- 46% ECD- 10.87 PPG P/U- 175K S/O- 139K Rot- 157K ADT- 3.2 Total Bit Hrs- 4.3 Total Jars- 34.9 3,590.0 4,660.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 14/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/26/2021 06:00 7/26/2021 12:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 4,657' t/ 5,793' WOB- 22-27K RPM- 180 Torq.- 10-15K GPM-800 On Btm PSI- 2444 Flow out- 49% ECD- 11.04 PPG P/U- 197K S/O- 154K Rot- 176K ADT- 4.0 Total Bit Hrs- 8.3 Total Jars- 38.9 4,660.0 5,793.0 7/26/2021 12:00 7/26/2021 18:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 5,793' t/ 6,922' WOB- 25K RPM- 180 Torq.- 10-16K GPM-800 On Btm PSI- 2687 Flow out- 48% ECD- 11.04 PPG P/U- 220K S/O- 169K Rot- 194K ADT- 4.3 Total Bit Hrs- 12.6 Total Jars- 43.2 5,793.0 6,922.0 7/26/2021 18:00 7/27/2021 00:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 6,922' t/ 7,984' WOB- 15K RPM- 190 Torq.- 10-16K GPM-800 On Btm PSI- 2425 Flow out- 48% ECD- 10.85 PPG P/U- 247K S/O- 177K Rot- 202K ADT- 4.0 Total Bit Hrs- 16.6 Total Jars- 47.2 6,922.0 7,984.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 15/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/27/2021 00:00 7/27/2021 06:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 7,984' t/ 8,904' WOB- 20-30K RPM- 180 Torq.- 15-18K GPM-800 On Btm PSI- 2725 Flow out- 44% ECD- 10.88 PPG P/U- 266K S/O- 190K Rot- 227K ADT- 4.0 Total Bit Hrs- 20.6 Total Jars- 51.2 7,984.0 8,900.0 7/27/2021 06:00 7/27/2021 12:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 8,904' t/ 9,730' WOB- 10K RPM- 180 Torq.- 15 K GPM-800 On Btm PSI- 2852 Flow out- 44% ECD- 10.66 PPG P/U- 301K S/O- 195K Rot- 238K ADT- 4.6 Total Bit Hrs- 25.2 Total Jars- 55.8 8,900.0 9,730.0 7/27/2021 12:00 7/27/2021 15:00 3.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 9,730' t/ 9,848' WOB- 27K RPM- 180 Torq.- 18 K GPM-800 On Btm PSI- 2871 Flow out- 44% ECD- 10.74 PPG P/U- 300K S/O- 190K Rot- 230K ADT- 2.0 Total Bit Hrs- 27.2 Total Jars- 57.8 Pumped a total of 4 BU on last two stands while drilling them down. 9,730.0 9,848.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 16/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/27/2021 15:00 7/27/2021 16:00 1.00 INTRM1, DRILL CIRC P Pumped and circualted 40 bbls HI Vis sweep while rotating and reciprocating f/ 9848' - 9750' MD. RPM- 180 Torq.- 18 K GPM-800 Off Btm PSI- 2725 Flow out- 44% ECD- 10.66 PPG P/U- 300K S/O- 198K Rot- 230K Total pumped strokes = 9,319 9,848.0 9,848.0 7/27/2021 16:00 7/27/2021 17:15 1.25 INTRM1, DRILL TRIP P Performed 5 stands wiper trip f/ 9,848' - 9,379' MD w/ 5" DP racked back in the derrick and back. P/U- 300K S/O- 190K Monitored dsiplacement on trip tank.. 9,848.0 9,848.0 7/27/2021 17:15 7/27/2021 19:15 2.00 INTRM1, DRILL DHEQ P Opened Rhino Reamer. Bit depth at 9,825' MD (Reamer cutters opened to 11" at 9,710' MD.). Drilled 15' w/ reamer open and performed ledge test. Had trouble to get reamer to index, work flow f/ 200 gpm t/ 450 gpm with no luck of reamer indexing, Decision made to go back t/ 380 gpm to compare to baseline index that was got in the surface casing and reamer opened SPP dropped f/ 2,770 psi t/ 2,560 Turbine RPM dropped f/ 4,670 t/ 4,360 Performed ledge test @ 9,830' MD, set 15K down 9,848.0 9,840.0 7/27/2021 19:15 7/27/2021 20:15 1.00 INTRM1, DRILL MPDA P Pulled trip nipple and installed MPD bearing. 9,840.0 9,848.0 7/27/2021 20:15 7/28/2021 00:00 3.75 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 9,848' t/ 10,225' WOB- 29K RPM- 170 Torq.- 26 K GPM-800 On Btm PSI- 3075 Flow out- 52% ECD- 11.75 PPG P/U- 310K S/O- 190K Rot- 239K ADT- 2.9 Total Bit Hrs- 30.1 Total Jars- 60.7 9,848.0 10,225.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 17/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/28/2021 00:00 7/28/2021 06:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 10,225' t/ 10,657' WOB- 20-30K RPM- 150 Torq.- 26-30 K GPM-780 On Btm PSI- 2560 Flow out- 43% ECD- 11.67PPG ADT- 4.7 Total Bit Hrs- 34.8 Total Jars- 65.4 MPD PSI Connection-550 10,225.0 10,657.0 7/28/2021 06:00 7/28/2021 12:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 10,657' t/ 11,046' WOB- 20-30K RPM- 150-160 Torq.- 26-30 K GPM-780 On Btm PSI- 3100 Flow out- 47% ECD- 12.0PPG ADT- 5.1 Total Bit Hrs- 39.9 Total Jars- 70.5 MPD PSI Connection- 550 10,657.0 11,046.0 7/28/2021 12:00 7/28/2021 18:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 11,046' t/ 11,448' WOB- 20-30K RPM- 180 Torq.- 23 K GPM-780 On Btm PSI- 3230 Flow out- 48% ECD- 11.89PG ADT- 3.7 Total Bit Hrs- 43.6 Total Jars- 74.2 MPD PSI Connection- 550 11,046.0 11,448.0 7/28/2021 18:00 7/29/2021 00:00 6.00 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 11,448' t/ 12,092' WOB- 20-32 K RPM- 180 Torq.- 23 K GPM-780 On Btm PSI- 3334 Flow out- 48% ECD- 11.81PG ADT- 4.7 Total Bit Hrs- 48.3 Total Jars- 78.9 MPD PSI Connection- 550 11,448.0 12,092.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 18/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/29/2021 00:00 7/29/2021 00:30 0.50 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 12,092' t/ 12,106'. Stopped drilling due to failed MPD. WOB- 20-32 K RPM- 180 Torq.- 23 K GPM-780 On Btm PSI- 3334 Flow out- 48% ECD- 11.81PG ADT- 4.7 Total Bit Hrs- 48.3 Total Jars- 78.9 MPD PSI Connection- 550 12,092.0 12,106.0 7/29/2021 00:30 7/29/2021 01:30 1.00 INTRM1, DRILL CIRC T Rotated and reciprocated pipe f/ 12,106' -12,043' MD.while CBU. SPP 3363 FO 46% RPM 70 TQ 20 k ECD 11.88 MPD 286 psi. RT Wt 243 k Total strokes pumped: 9300 12,106.0 12,043.0 7/29/2021 01:30 7/29/2021 02:15 0.75 INTRM1, DRILL MPDA T Changed out bad RCD bearing as per Beyond rep while maintaining 600 psi on the wellbore. 12,043.0 12,043.0 7/29/2021 02:15 7/29/2021 02:30 0.25 INTRM1, DRILL WASH P Washed down f/ 12,043' - 12,106' MD. GPM 780 PSI 3414 FO 46% RPM 75 TQ 20 k RT Wt 235 k 12,043.0 12,106.0 7/29/2021 02:30 7/29/2021 06:00 3.50 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 12,106' t/ 12,260'. WOB- 20-35 K RPM- 160-180 Torq.- 20-23 K GPM-780 On Btm PSI- 3430 Flow out- 46% ECD- 12.0PG ADT- 2.8 Total Bit Hrs- 51.4 Total Jars- 82 MPD PSI Connection- 650 12,106.0 12,260.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 19/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/29/2021 06:00 7/29/2021 07:30 1.50 INTRM1, DRILL DDRL P Drill 9 7/8'' Intermediate f/ 12,260' t/ 12,318'. WOB- 20-35 K RPM- 160-180 Torq.- 20-23 K GPM-780 On Btm PSI- 3465 Flow out- 46% ECD- 12.0PG ADT- 1.1 Total Bit Hrs- 52.5 Total Jars- 83.1 MPD PSI Connection- 650 P/U- 380K S/O- 145K Rot- 241K 12,260.0 12,318.0 7/29/2021 07:30 7/29/2021 10:00 2.50 INTRM1, CASING CIRC P Circ 2 btms up w/ rotating & reciprocating pipe f/ 12,318' t/ 12,204' Racking a stand back after each bottoms up GPM-780 PSI-3385 RPM-130 Torq-20K ECD-12.0 12,318.0 12,204.0 7/29/2021 10:00 7/29/2021 10:45 0.75 INTRM1, CASING CIRC P Close SLB reamer @ 12,204' Drop flow f/ 780 gpm t/ 380 gpm t/ index tool, seen no change in psi & rpm when pump was brought back up t/ 780 gpm 3,257 psi, 4,119 turbine RPM, On the 3rd sequence seen pump psi increase t/ 3,555' & turbine RPM increased t/ 4,515, SLB rep confirmed under reamer tool was closed. 12,204.0 12,204.0 7/29/2021 10:45 7/29/2021 12:00 1.25 INTRM1, CASING CIRC P Circ btms up w/ rotating & reciprocating pipe f/ 12,204' t/ 12,109' GPM-780 PSI-3385 RPM-130 Torq-20K ECD-12.0 12,204.0 12,109.0 7/29/2021 12:00 7/29/2021 12:30 0.50 INTRM1, CASING OWFF P OWFF. 12,109.0 12,109.0 7/29/2021 12:30 7/29/2021 17:00 4.50 INTRM1, CASING STRP P SOOH f/ 12,109' - 9,941' MD. PU Wt 318 k SO 145 k MPD Back Pressure 620 psi out of slips MPD Back Pressure 660 psi in slips Monitored displacement on pits 3-5. Worked pipe as hole dictates. 12,109.0 9,941.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 20/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/29/2021 17:00 7/29/2021 22:00 5.00 INTRM1, CASING CIRC P Circulated while rotating and reciprocating f/ 9,941' - 9,851' MD. GPM 750 PSI 3,071 FO 41% RPM 125 TQ 16 k ECD 12.04 PU Wt 318 k SO Wt 145 k RT Wt 223 k Total pumped strokes = 54,563 9,941.0 9,851.0 7/29/2021 22:00 7/30/2021 00:00 2.00 INTRM1, CASING CIRC P Circulated and pumped 10.8 ppg mud in and out while rotating and reciprocating f/ 9,851' - 9,941' MD. GPM 800 PSI 3,112 FO 48% RPM 125-160 TQ 14-16 k ECD 12.00 PU Wt 318 k SO Wt 145 k RT Wt 220 k Total pumped strokes = 17,871 9,851.0 9,851.0 7/30/2021 00:00 7/30/2021 00:15 0.25 INTRM1, CASING STRP P SOOH f/ 9,851' - 9,662' MD racking back DP in derrick. Monitored hole fill via pits 4 & 5. PU Wt 310 k MPD Back Pressure 550 psi out of slips MPD Back Pressure 650 psi in slips Pulled into 9 7/8" hole to try and mitigate shocks on MWD. 9,851.0 9,662.0 7/30/2021 00:15 7/30/2021 09:45 9.50 INTRM1, CASING CIRC P Rotating and reciprocating f/ 9,662' - 9,569' MD while circulating and bringing up mud weight from 10.8 ppg to 11.3 ppg. GPM 800 PSI 3,215 FO 48% RPM 150 TQ 15 k PU Wt 220 k RT Wt 210 k @10.8 ppg MPD Back Pressure 400 psi @10.8 ppg MPD Back Pressure 240 psi 9,662.0 9,662.0 7/30/2021 09:45 7/30/2021 10:15 0.50 INTRM1, CASING OWFF P OWFF (Satic) 9,662.0 9,662.0 7/30/2021 10:15 7/30/2021 10:45 0.50 INTRM1, CASING SVRG P Serviced Upper IBOP, Top drive, and IR. 9,662.0 9,662.0 7/30/2021 10:45 7/30/2021 12:00 1.25 INTRM1, CASING STRP P SOOH f/ 9,662' - 8,454' MD racking back DP in derrick. Monitored hole fill via pits 4 & 5. PU Wt 280 k SO Wt 140 k MPD Back Pressure 370 psi out of slips MPD Back Pressure 200 psi in slips 9,662.0 8,454.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 21/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/30/2021 12:00 7/30/2021 17:00 5.00 INTRM1, CASING STRP P SOOH f/ 8,454' - 4,283' MD racking back DP in derrick. Monitored hole fill via pits 4 & 5. PU Wt 280 k SO Wt 140 k MPD Back Pressure 370 psi out of slips MPD Back Pressure 200 psi in slips 8,454.0 4,283.0 7/30/2021 17:00 7/30/2021 18:30 1.50 INTRM1, CASING CIRC P CBU 2X while racking back 1 stand per BU f/ 4,283' - 4,093' MD w/ 5" DP racked back in the derrick. Monitored displacement in the pits. GPM 724 PSI 2152 FO 30% RPM 125 TQ 7 k ECD 12.35 ppg PU Wt 180 k SO Wt 120 k RT Wt 145 k 4,283.0 4,093.0 7/30/2021 18:30 7/30/2021 19:00 0.50 INTRM1, CASING STRP P SOOH f/ 4,093' - 3,950' MD racking back DP in derrick. Monitored hole fill via pits 4 & 5. PU Wt 175 k SO Wt 120 k MPD Back Pressure 370 psi out of slips MPD Back Pressure 200 psi in slips 4,093.0 3,950.0 7/30/2021 19:00 7/30/2021 21:30 2.50 INTRM1, CASING BKRM P Circulated and condition mud under shoe while racking back stands per circulation f/ 3,950' - 3,620' MD. GPM 800 PSI 2454 FO 38% RPM 125 TQ 6 k ECD 12.25 ppg PU Wt 141 k SO Wt 120 k RT Wt 145 k 3,950.0 3,620.0 7/30/2021 21:30 7/30/2021 22:00 0.50 INTRM1, CASING STRP P SOOH f/ 3,620' - 3,411' MD racking back DP in derrick. PU Wt 138 k SO Wt 120 k MPD Back Pressure 280 psi out of slips MPD Back Pressure 200 psi in slips Monitored displacements via pits 4 & 5. Entered shoe with no observed overpull at 3,425' MD. 3,620.0 3,411.0 7/30/2021 22:00 7/30/2021 22:30 0.50 INTRM1, CASING OWFF P OWFF (Static) 3,411.0 3,411.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 22/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/30/2021 22:30 7/31/2021 00:00 1.50 INTRM1, CASING STRP P SOOH f/ 3,411' - 1,298' MD racking back DP in derrick. PU Wt 140 k, SO Wt 118 k @ 3,400' MD. FO 12% at 250 gpm. MPD Back Pressure 280 psi out of slips MPD Back Pressure 200 psi in slips Monitored displacements via pits 4 & 5. 3,411.0 1,298.0 7/31/2021 00:00 7/31/2021 01:00 1.00 INTRM1, CASING STRP P SOOH f/ 1,298' - 697' MD racking back DP in derrick. Monitored displacement on pits 4 & 5. MPD Back Pressure 280 psi out of slips MPD Back Pressure 200 psi in slips FO 12% at 250 gpm. 1,298.0 697.0 7/31/2021 01:00 7/31/2021 01:45 0.75 INTRM1, CASING OWFF P OWFF through MPD port on BOP stack (Static). SIMOPS: PJSM on pulling RCD bearing and installing trip nipple. 697.0 697.0 7/31/2021 01:45 7/31/2021 02:15 0.50 INTRM1, CASING MPDA P Pulled RCD bearing and installed trip nipple. Aired up boots. Hooked up hole fill lines and function tested system. 697.0 697.0 7/31/2021 02:15 7/31/2021 05:00 2.75 INTRM1, CASING BHAH P L/D HWDP and Jars. Continued L/D BHA #3 to the pipe shed. L/D BHI subs. 697.0 0.0 7/31/2021 05:00 7/31/2021 05:30 0.50 INTRM1, CASING CLEN P Clear and cleaned rig floor of BHA. 0.0 0.0 7/31/2021 05:30 7/31/2021 05:45 0.25 INTRM1, CASING OTHR P P/U double of 5" DP FMC wear ring puller. Pull wear ring as per FMC. 0.0 0.0 7/31/2021 05:45 7/31/2021 06:00 0.25 INTRM1, CASING WWWH P M/U BOP stack washer and washed BOP stack at 500 gpm w/ 92 psi and 15 rpms. 0.0 0.0 7/31/2021 06:00 7/31/2021 07:00 1.00 INTRM1, CASING RURD P Installed FMC upper test plug. Closed blind rams and changed out upper rams to 7.625" straight rams. 0.0 0.0 7/31/2021 07:00 7/31/2021 08:00 1.00 INTRM1, CASING RURD P Built 7.625" test joint. Filled choke manifold w/ water and worked air out of the testing system. 0.0 0.0 7/31/2021 08:00 7/31/2021 10:00 2.00 INTRM1, CASING BOPE P Tested 7.625" test joint on UPR and annular preventer. Tested choke manifold valve #9 and #11. Tested manual kill line. All BOPE tests to 250 psi low (5 minutes)/ 3,500 psi high (10 minutes). 0.0 0.0 7/31/2021 10:00 7/31/2021 10:15 0.25 INTRM1, CASING RURD P R/D testing equipment and realigned choke manifold for drilling. 0.0 0.0 7/31/2021 10:15 7/31/2021 12:00 1.75 INTRM1, CASING RURD P P/U Doyon casing running equipment. R/U to run 7.625" casing. Bucked off collar on shoe joint track. 0.0 0.0 7/31/2021 12:00 7/31/2021 13:00 1.00 INTRM1, CASING RURD P Finished rigging up casing running equipment. BakerLok'd and M/U Sharknado reaming shoe. 0.0 0.0 7/31/2021 13:00 7/31/2021 18:00 5.00 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf/33.7ppf TXP/H563 Intermediate casing string while installing centralizers as per casing detail f/ 0' - 1,378' MD. Filled casing on the fly and topped off every 10 joints. PU Wt 98 k SO Wt 93 k Monitored displacement on pits 3 & 5. 0.0 1,378.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 23/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/31/2021 18:00 7/31/2021 23:15 5.25 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf/33.7ppf TXP/H563 Intermediate casing string while installing centralizers as per casing detail f/ 1,378' - 3,417' MD. Filled casing on the fly and topped off every 10 joints. PU Wt 147 k SO Wt 140 k Monitored displacement on pits 3 & 5. 1,378.0 3,417.0 7/31/2021 23:15 8/1/2021 00:00 0.75 INTRM1, CASING CIRC P Circulate and condition mud while reciprocating f/ 3,417' - 3,380' MD. Established circualtion and staged up pumps to 3 bpm. 1 bpm = 126 psi 2 bpm = 175 psi/ FO 2.9% 3 bpm = 165 psi / FO 10% MW in 11.3 ppg MW out 11.6 ppg No losses observed and no significant change in returns cuttings load obseerved on the shakers. 3,417.0 3,417.0 8/1/2021 00:00 8/1/2021 01:45 1.75 INTRM1, CASING CIRC P Circulate and condition mud while reciprocating f/ 3,417' - 3,380' MD. Established circualtion and staged up pumps to 3 bpm. 1 bpm = 126 psi 2 bpm = 175 psi/ FO 2.9% 3 bpm = 165 psi / FO 10% Circulated until MW was 11.3 ppg in/out. Gradually staged up the pump rate to 6 bpm. 4 bpm = 129 psi / FO 11.1% 5 bpm = 146 psi /FO 9.8 % 6 bpm = 147 psi / FO 9.5 % Circulate and condition mud while reciprocating f/ 3,417' - 3,380' MD. Also obtained torque and drag readings: @ 3413' MD PU 154 SO 145/ RT Wt 150 RPM 20 TQ 4 k 3,417.0 3,417.0 8/1/2021 01:45 8/1/2021 06:30 4.75 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf/33.7ppf TXP/H563 Intermediate casing string while installing centralizers as per casing detail f/ 3,417' - 6,270' MD. Filled casing on the fly and topped off every 10 joints. MU TQ TXP = 23.5 k MU TQ H563 = 10.3 k PU Wt 214 k SO Wt 163 k Monitored displacement on pits 3 & 5. 3,417.0 6,270.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 24/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/1/2021 06:30 8/1/2021 09:45 3.25 INTRM1, CASING CIRC P Circulate and condition mud while reciprocating f/ 6,270' - 6,227' MD. Established circualtion and staged up pumps to 3 bpm. 1 bpm = 350 psi 2 bpm = 360 psi 3 bpm = 330 psi / FCP 180 psi. MW in 11.3 ppg MW out 11.5 ppg Total strokes pumped = 8000 6,270.0 6,270.0 8/1/2021 09:45 8/1/2021 12:00 2.25 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf H563 Intermediate casing string while installing centralizers as per casing detail f/ 6,270' - 7,690' MD. Filled casing on the fly and topped off every 10 joints. MU TQ H563 = 10.3 k PU Wt 275 k SO Wt 180 k Monitored displacement on pits 3 & 5. 6,270.0 7,690.0 8/1/2021 12:00 8/1/2021 15:30 3.50 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf H563 Intermediate casing string while installing centralizers as per casing detail f/ 7,690' - 9,079' MD. Filled casing on the fly and topped off every 10 joints. MU TQ H563 = 10.3 k PU Wt 275 k SO Wt 180 k Monitored displacement on pits 3 & 5. 7,690.0 9,079.0 8/1/2021 15:30 8/1/2021 19:30 4.00 INTRM1, CASING CIRC P Circulate and condition mud while reciprocating f/ 9,079' - 9,039' MD. Established circualtion and staged up pumps to 3 bpm. 1 bpm = 406 psi 2 bpm = 405 psi 3 bpm = 358 psi 6 bpm = 370 psi FO 18% PU Wt 310 k SO Wt 186 k MW out 11.6 ppg Total strokes pumped = 9,497 9,079.0 9,079.0 8/1/2021 19:30 8/1/2021 22:00 2.50 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf H563 Intermediate casing string while installing centralizers as per casing detail f/ 9,079' - 10,319' MD. Filled casing on the fly and topped off every 10 joints. MU TQ H563 = 10.3 k PU Wt 378 k SO Wt 187 k Monitored displacement on pits 3 & 5. 9,079.0 10,319.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 25/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/1/2021 22:00 8/2/2021 00:00 2.00 INTRM1, CASING CIRC P Circulate and condition mud while reciprocating f/ 10,319' - 10,273' MD. Established circualtion and staged up pumps to 3 bpm. 1 bpm = 345 psi 2 bpm = 383 psi 3 bpm = 416 psi 6 bpm = 370 psi FO 18% PU Wt 310 k SO Wt 186 k MW out 11.6 ppg Total strokes pumped = 9,497 10,319.0 10,319.0 8/2/2021 00:00 8/2/2021 02:00 2.00 INTRM1, CASING CIRC P Circulate and condition mud while reciprocating f/ 10,319' - 10,273' MD. Established circualtion and staged up pumps to 3 bpm. FO 18% PU Wt 362 k SO Wt 192 k Initial MW out 11.7 ppg Initial MW out 11.3 ppg FCP @ 6bpm = 354 psi Total strokes pumped = 11,700 Obtained base line rotating wweight at 20 rpm = 20 k (25 k to break over) 10,319.0 10,319.0 8/2/2021 02:00 8/2/2021 06:00 4.00 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf H563 Intermediate casing string while installing centralizers as per casing detail f/ 10,319' - 10,526' MD. Tagged up w/ 30 k WOB. PU Wt 390 k SO Wt 198 k Monitored displacement on pits 3 & 5. Worked pipe slowly pumping 1 bpm on upstroke and slowly staging worked torque into the string. f/ 50 -200 fph. Slacking up to 30 k on obstruction while pumping at 100 gpm w/ 237 psi. Worked torque into the sting and rotated casing at 20 rpm w/ 24-26 k TQ. 10,319.0 10,526.0 8/2/2021 06:00 8/2/2021 08:45 2.75 INTRM1, CASING PUTB T Continued to work through obstruction at 10,526' MD. Slacked off to 80 k. PU Wt 365 k SO Wt 210 k Slowly worked pipe at 200 fph pumping ibpm on upstroke. Worked pipe: P/U 30' RIH at 50 fph at no flow P/U 30' RIH at 60 fph.at no flow P/U 30' RIH at 5 fpm.w/ 100 gpm, WOB 30 P/U 30' RIH at 5 fpm.w/ 100 gpm, WOB 10 P/U 30' RIH at 20 fpm.w/ 100 gpm / 20 rpm, WOB 2-5 SPP 222-450 psi MW 11.3 ppg in/out 10,526.0 10,526.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 26/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/2/2021 08:45 8/2/2021 12:00 3.25 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf H563 Intermediate casing string while installing centralizers as per casing detail f/ 10,526' - 10,828' MD. PU Wt 432 k SO Wt 211 k Monitored displacement on pits 3 & 5. 10,526.0 10,828.0 8/2/2021 12:00 8/2/2021 18:00 6.00 INTRM1, CASING PUTB P Ran 7.625" 29.7ppf H563 Intermediate casing string while installing centralizers as per casing detail f/ 10,828' - 11,071' MD. Filling on the fly every 10 joints. MU TQ 10,300 ftlbs. WOrked pipe as hole conditions dictated. PU Wt 395 k SO Wt 205 k Monitored displacement on pits 3 & 5. 10,828.0 11,071.0 8/2/2021 18:00 8/2/2021 22:00 4.00 INTRM1, CASING PUTB P Circulated and worked pipe down f/ 11,071' - 11,117' MD. stopped RIH due to obstruction at 11,117' MD. PU Wt 395 k SO Wt 205 k Monitored displacement on pits 3 & 5. 11,071.0 11,117.0 8/2/2021 22:00 8/3/2021 00:00 2.00 INTRM1, CASING PUTB T Worked pipe at 11,117' MD. Attempted to PU and B/O w/ pumps on. Unsuccessful due to pack off. Re- established circualtion. Circulated at 3 bpm and obtained rotating parameters. 10 rppm, 24 k TQ. ROT Wt 288 k. 11,117.0 11,117.0 8/3/2021 00:00 8/3/2021 05:00 5.00 INTRM1, CASING PUTB T Attempted to work pack off free. Worked pipe f/ 11,071' - 11,117' MD. Eventually observed slow returns while pumping 1 bpm on the back stroke up. Staged up pumps while monitoring stand pipe pressure from 4 spm to 15 spm. Eventually observed full returns while pumping 1 bpm. PU 395 k SO 205 k SPP 283 11,117.0 11,117.0 8/3/2021 05:00 8/3/2021 06:00 1.00 INTRM1, CASING PUTB T Continued to try and work pipe past the obstruction at 11,117' MD. Staged WOB f/ 30-180 k WOB. 11,117.0 11,117.0 8/3/2021 06:00 8/3/2021 12:00 6.00 INTRM1, CASING PUTB P Attempted to work pipe through tight hole f/ 11,117' - 11,134' MD. Worked torque into the string up to 30 k B/O Wt 425 k PU 395 k SO 210 k ROT TQ 25 k. 11,117.0 11,134.0 8/3/2021 12:00 8/3/2021 18:00 6.00 INTRM1, CASING PUTB P Continued to work pipe through tight hole f/ 11,134 - 11,204'' MD. Worked torque into the string up to 32 k w/ 10 rpm. B/O Wt 435 k PU 397 k SO 215 k ROT TQ 25 k. 11,134.0 11,204.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 27/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/3/2021 18:00 8/4/2021 00:00 6.00 INTRM1, CASING PUTB P Continued to work pipe through tight hole f/ 11,204 - 11,427'' MD. B/O Wt 435 k PU 397 k SO 215 k ROT TQ 25 k. 11,204.0 11,427.0 8/4/2021 00:00 8/4/2021 06:00 6.00 INTRM1, CASING PUTB P Continued to work pipe and RIH through tight hole f/ 11,427' - 11,620'' MD. Filled pipe on the fly and topping off every 10 jts. Monitored displacements on pits 3 & 5. SO 210-180 k 11,427.0 11,625.0 8/4/2021 06:00 8/4/2021 12:00 6.00 INTRM1, CASING PUTB P Continued to work pipe and RIH through tight hole f/ 11,620' - 11,784'' MD. Filled pipe on the fly and topping off every 10 jts. Monitored displacements on pits 3 & 5. SO 180-106 k 11,625.0 11,784.0 8/4/2021 12:00 8/4/2021 18:00 6.00 INTRM1, CASING PUTB P Continued to work pipe and RIH through tight hole f/ 11,784' - 11,942'' MD. Filled pipe on the fly and topping off every 10 jts. Monitored displacements on pits 3 & 5. SO 130-98 k 11,784.0 11,942.0 8/4/2021 18:00 8/5/2021 00:00 6.00 INTRM1, CASING PUTB P Continued to work pipe and RIH through tight hole f/ 11,942' - 12,040'' MD. Filled pipe on the fly and topping off every 10 jts. Monitored displacements on pits 3 & 5. SO 115-65 k 11,942.0 12,040.0 8/5/2021 00:00 8/5/2021 06:00 6.00 INTRM1, CASING PUTB P Continued to work pipe and RIH through tight hole f/ 12,040' - 12,180'' MD. Filled pipe on the fly and topping off every 10 jts. Monitored displacements on pits 3 & 5. SO 115-65 k 12,040.0 12,180.0 8/5/2021 06:00 8/5/2021 09:30 3.50 INTRM1, CASING PUTB P Continued to work pipe and RIH through tight hole f/ 12,180' - 12,258'' MD. Filled pipe on the fly and topping off every 10 jts. Monitored displacements on pits 3 & 5. SO 115-65 k 12,180.0 12,258.0 8/5/2021 09:30 8/5/2021 12:00 2.50 INTRM1, CASING CIRC P Worked pipe and established circulation. Slowly staged up pump 1 spm every 5 minutes up to 2.5 bpm w/ 510 psi. Monitored displacements on pits 3 & 5. PU Wt 462' k SO Wt 190 k 12,258.0 12,258.0 8/5/2021 12:00 8/5/2021 18:00 6.00 INTRM1, CASING CIRC T Worked pipe and to try and establish circulation. Slowly staged up pump Monitored displacements on pits 3 & 5. PU Wt 462' k Initial BO Wt 472 k SO Wt 190 k 12,258.0 12,258.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 28/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/5/2021 18:00 8/6/2021 00:00 6.00 INTRM1, CASING CIRC T Worked pipe and established circulation f/ 12,258' - 12,261' MD. Worked 35 k TQ. Slowly staging up pumps w/o packing off. 1 spm = 329 psi. Initially no B/O. Monitored displacements on pits 3 & 5. PU Wt 560 k SO Wt 80 k 12,258.0 12,261.0 8/6/2021 00:00 8/6/2021 06:00 6.00 INTRM1, CASING CIRC T Worked pipe and circulated f/ 12,261' - 12,241' MD. Worked 35 k TQ. Circulating thick mud out of hole. Intermittent pack offs encountered. Worked pipe to free up pack offs and resumed attempting to circulate. Monitored displacements on pits 3 & 5. PU Wt 560 k SO Wt 80 k MW in 11.3 ppg MW out 11.7-11.5 ppg (Observed FV 169-173) 12,261.0 12,241.0 8/6/2021 06:00 8/6/2021 12:00 6.00 INTRM1, CASING CIRC T Worked pipe and circulated at 12,241' MD. Staged pumps up to 3/4 bbl/min, 350 psi. Work pipe and attempt to regain circulation, work 30 k tq into the string and attempt to regain movement. Begin staging up pumps while working pipe to establish circulation. 12,241.0 12,241.0 8/6/2021 12:00 8/6/2021 18:00 6.00 INTRM1, CASING CIRC T Worked pipe and attempted to circulate at 12,241' MD. 1-4 stks/min 950 psi. 12,241.0 12,241.0 8/6/2021 18:00 8/6/2021 19:00 1.00 INTRM1, CEMENT LOT T Performed injectivity test. Pumped at 1/2 bbl min, achieved 13.9 ppg LOT, stage up rate to 4 bbls/min, FCP = 993 psi 1 bbls/min - 1200 psi 2 bbls/min - 1086 psi 3 bbls/min - 1040 psi Pumped total of 62 bbls. Shut off pumps and observed pressure fall to 165 psi. 12,241.0 12,241.0 8/6/2021 19:00 8/6/2021 20:00 1.00 INTRM1, CEMENT RURD P Rig up cementing equipment. 12,241.0 12,241.0 8/6/2021 20:00 8/7/2021 00:00 4.00 INTRM1, CEMENT OTHR P Lay down 5" drillpipe. Simops - cut mud weight in the pits to 10.8 ppg. 12,241.0 12,241.0 8/7/2021 00:00 8/7/2021 01:00 1.00 INTRM1, CEMENT CMNT P Pre job safety meeting with all parties, walk lines and double check rig up. 12,241.0 12,241.0 8/7/2021 01:00 8/7/2021 06:30 5.50 INTRM1, CEMENT CMNT P SLB pump 4 bbls of fresh H2O. Tested lines to 711 psi low/ 3530 psi high, pump 60 bbls of 12.5 ppg Mud Push II @ 4 bbls/min, 865 psi, Dropped bottom plug. (cement wet @ 02:25) Pump 110 bbls of Class G 15.8 ppg cement @ 4 bbls/min, ICP = 1035 psi, FCP = 398 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 10.8 ppg LSND mud @ 4 bbls/min, ICP = 365 psi, FCP= 520 psi. Total losses during the job, Plug bumped at 6373 strokes (539 bbls). Increased pressure to 1070 psi, Bleed off pressure and check floats, continued to see slow stream. Pressured back up on casing and monitored. CIP 06:34 Hrs 08/07/2021. 12,241.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 29/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/7/2021 06:30 8/7/2021 15:45 9.25 INTRM1, CEMENT WOC T Monitored casing pressure, oberserved climbing from 940 psi to 1975 psi, rate of pressure increase diminishing, bleed to 550 psi and observed continued diminishing pressure build. Bleed pressure to 100 psi and observed dimishing pressure build. Deemed pressure build to be due to thermal expansion. 0.0 0.0 8/7/2021 15:45 8/7/2021 21:00 5.25 INTRM1, CEMENT OWFF T Line up on the trip tank and observed diminishing return flow. 3/4 bbl returned during entire interval. Annulus static. 0.0 0.0 8/7/2021 21:00 8/7/2021 22:00 1.00 INTRM1, CEMENT OWFF T Line up to monitor on the rig floor and observed continued diminishing trickle from the casing. Annulus static. 0.0 0.0 8/7/2021 22:00 8/7/2021 23:00 1.00 INTRM1, CEMENT RURD P Rig down cementing equipment, release Volant from the casing. 0.0 0.0 8/7/2021 23:00 8/8/2021 00:00 1.00 INTRM1, CEMENT NUND T Prejob saftey meeting with all parties, begin nipple down BOP stack. 0.0 0.0 8/8/2021 00:00 8/8/2021 04:45 4.75 INTRM1, CEMENT NUND T Split the stack and set emergency slips. 73 k on slips. rig up WACH's cutter, cut 7-5/8" casing. Remove and LD cut joint, rig down casing running equipment. Clean and inspect seal area, observed significant scarring on seal area of casing and tubing spool. 0.0 0.0 8/8/2021 04:45 8/8/2021 06:00 1.25 INTRM1, CEMENT NUND T Nipple down BOP's and riser. 0.0 0.0 8/8/2021 06:00 8/8/2021 07:00 1.00 INTRM1, CEMENT NUND T Nipple down tubing spool and remove from rig, pick up new tubing spool to the rig floor. 0.0 0.0 8/8/2021 07:00 8/8/2021 08:30 1.50 INTRM1, CEMENT WWSP T FMC repair casing spool and clean. Fill void with test fluid, set 7-5/8" packoff and RILDS. Prep new tubing spool for installation. 0.0 0.0 8/8/2021 08:30 8/8/2021 12:00 3.50 INTRM1, CEMENT NUND T Nipple up new tubing spool, attempt to test packoff, nipple down the tubing spool, pull the pack off. Inspect and dress casing spool, replace seals on pack off. 0.0 0.0 8/8/2021 12:00 8/8/2021 14:00 2.00 INTRM1, CEMENT WWSP T Reinstall packoff and RILDS, nipple up tubing spool. test packoff to 3800 psi for 10 minutes (tested good). Simops- change upper rams to 2-7/8" x 5-1/2" VBR's 0.0 0.0 8/8/2021 14:00 8/8/2021 18:30 4.50 INTRM1, CEMENT NUND T Nipple up BOPE, install MPD orbit valve. 0.0 0.0 8/8/2021 18:30 8/8/2021 21:00 2.50 INTRM1, CEMENT MPDA P Install test plug, fill stack with fresh water, install MPD test cap and test per MPD rep to 1300 psi. (tested good) 0.0 0.0 8/8/2021 21:00 8/8/2021 22:00 1.00 INTRM1, CEMENT RURD P Rig up to test BOPE, purge air from lines and equipment. Shell test BOP's 0.0 0.0 8/8/2021 22:00 8/9/2021 00:00 2.00 INTRM1, WHDBOP BOPE P Begin testing BOPE with 4 inch test joint, 250 psi low for 5 min, 3500 psi high for 10 min. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 30/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/9/2021 00:00 8/9/2021 04:00 4.00 INTRM1, WHDBOP BOPE P Test BOPE: All tests to 250 psi low for 5 minutes, 3500 psi high for 10 minutes charted minimum w/ exception of manual operated Super Choke 2000 psi show bleed and hold pressure, 4" test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, Test choke valves 1- 15, choke & kill manuals & HCR's, 4" valve on kill line. Two 4" FOSV, one 4" dart valve, performed Koomey drawdown, ACC = 3000 psi. Manifold = 1500 psi. ACC - 1500 psi after all functions on the bottles, 16 secs for 200 psi. Build w/ 2 electric pumps, 99 secs to build full system pressure w/ 2 electric & 2 air pumps. Closing times annular = 23 secs, UPR 18 secs, Blind/Shears = 16 secs, LPR 16 secs, Choke HCR = 2 secs, Kill HCR = 2 secs, Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Rep waived witness at 17:18hrs 8/07/2021. BLM Rep Quinn Sawyer witnessed all tests. 0.0 0.0 8/9/2021 04:00 8/9/2021 04:30 0.50 INTRM1, WHDBOP RURD P Blow down and rig down testing equipment, pull test plug. 0.0 0.0 8/9/2021 04:30 8/9/2021 06:00 1.50 INTRM1, CEMENT OTHR P Change saver sub on topdrive to XT39. 0.0 0.0 8/9/2021 06:00 8/9/2021 07:00 1.00 INTRM1, CEMENT SLPC P Slip and cut 109 ft of drilling line. Calibrate Amphion, Pason, and Baker sensors. 0.0 0.0 8/9/2021 07:00 8/9/2021 07:30 0.50 INTRM1, CEMENT OTHR P Install wear bushing in the tubing spool per FMC rep. 0.0 0.0 8/9/2021 07:30 8/9/2021 10:00 2.50 INTRM1, CEMENT ELOG T Pick up SLB E-Line tools to the rig floor and rig up per SLB rep. 0.0 0.0 8/9/2021 10:00 8/9/2021 14:00 4.00 INTRM1, CEMENT ELOG T Run in hole with E-Line junk basket and 6.07" gauge ring to 12,130' WLM. Pull out of the hole to surface. 0.0 0.0 8/9/2021 14:00 8/9/2021 16:00 2.00 INTRM1, CEMENT ELOG T Lay down junk basket assembly, pick up USIT assembly. 0.0 0.0 8/9/2021 16:00 8/9/2021 20:30 4.50 INTRM1, CEMENT ELOG T RIH with E-Line USIT assembly to 11,802' WLM. Log from 11,802' - 9,965' WLM. Pull out of the hole to surface. 0.0 0.0 8/9/2021 20:30 8/9/2021 21:30 1.00 INTRM1, CEMENT ELOG T Lay down USIT assembly, rig down E- Line equipment. 0.0 0.0 8/9/2021 21:30 8/9/2021 22:30 1.00 INTRM1, CEMENT PRTS P Rig up testing equipment, purge air from surface system, close bind rams and test 7-5/8" casing to 4,200 psi for 30 min (tested good). Blow down and rig down testing equipment. 7 bbls bled back. 0.0 0.0 8/9/2021 22:30 8/10/2021 00:00 1.50 INTRM1, CEMENT BHAH T Load floor with HAL perf guns, pick up and make up perf gun assembly. 0.0 0.0 8/10/2021 00:00 8/10/2021 06:00 6.00 INTRM1, CEMENT TRIP T Trip in the hole with HES MaxForce 3 1/8" - 6 shot per foot, 60° phasing, 2' loaded perf assembly to 5,016' MD. 112 k Up Wt, 100 k Dn Wt. RIH at 90 ft/min, monitoring displacement on trip pit #3 0.0 5,016.0 8/10/2021 06:00 8/10/2021 11:00 5.00 INTRM1, CEMENT TRIP T Continue tripping in the hole with perf assembly from 5,016' - 8,501' MD. 172 k Up Wt, 122 k Dn Wt. RIH at 90 ft/min, monitoring displacement on trip pit #3 5,016.0 8,501.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 31/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/10/2021 11:00 8/10/2021 11:30 0.50 INTRM1, CEMENT SVRG T Grease pipe shed equipment. 8,501.0 8,501.0 8/10/2021 11:30 8/10/2021 14:00 2.50 INTRM1, CEMENT TRIP T Continue tripping in the hole with perf assembly from 8,501' - 10,925' MD. 212 k Up Wt, 134 k Dn Wt. RIH at 90 ft/min, monitoring displacement on trip pit #3 8,501.0 10,925.0 8/10/2021 14:00 8/10/2021 16:00 2.00 INTRM1, CEMENT CIRC T Circulate at 10,925' MD, 250 gpm, 1950 psi, 21% flow out. Total strokes pumped - 6,822 Simops - lay down 5" DP in with the mouse hole 10,925.0 10,925.0 8/10/2021 16:00 8/10/2021 16:30 0.50 INTRM1, CEMENT PERF T Drop perf ball and circulate down at 250 gpm, observed pressure fall at 1392 strokes. Closed upper pipe rams and monitored well for pressure increase. 10,925.0 10,925.0 8/10/2021 16:30 8/11/2021 00:00 7.50 INTRM1, CEMENT CIRC T Circulate through the perforations taking returns through the OA. 1 bbl/min - 538 psi, 1.5 bbl/ min - 492 psi, 2 bbl/min - 465 psi, 3 bbl/min - 690 psi. MW in 10.8 ppg, MW out 11+. 10,925.0 10,925.0 8/11/2021 00:00 8/11/2021 03:15 3.25 INTRM1, CEMENT TRIP T Continued staging up pumps to 4.5 bbls/min, 887 psi, 14 % flow out. 10.8 ppg MW in/out 10,925.0 10,925.0 8/11/2021 03:15 8/11/2021 03:45 0.50 INTRM1, CEMENT OWFF T OWFF for 30 min - Static 10,925.0 10,925.0 8/11/2021 03:45 8/11/2021 05:00 1.25 INTRM1, CEMENT TRIP T Trip in the hole from 10,925' - 12,142' MD. 242 k Up Wt, 142 k Dn Wt. 10,925.0 12,142.0 8/11/2021 05:00 8/11/2021 06:00 1.00 INTRM1, CEMENT CIRC T Pump and spot 50 bbls 16 ppg gel pill on top of the float collar, 178 gpm, 934 psi. 12,142.0 12,142.0 8/11/2021 06:00 8/11/2021 14:45 8.75 INTRM1, CEMENT TRIP T TOH from 12,142' MD to surface. 12,142.0 0.0 8/11/2021 14:45 8/11/2021 15:00 0.25 INTRM1, CEMENT OWFF T Observed well for flow - static 0.0 0.0 8/11/2021 15:00 8/11/2021 15:30 0.50 INTRM1, CEMENT BHAH T LD perf assembly per HES rep, confirm all guns spent. 0.0 0.0 8/11/2021 15:30 8/11/2021 16:15 0.75 INTRM1, CEMENT BHAH T Make up K1 cement retainer per Baker Rep. 0.0 14.0 8/11/2021 16:15 8/11/2021 22:00 5.75 INTRM1, CEMENT TRIP T Trip in the hole with K1 cement retainer to 10,463' MD, 205 k Up Wt, 135 k Dn Wt. 14.0 10,463.0 8/11/2021 22:00 8/11/2021 22:30 0.50 INTRM1, CEMENT CIRC T Circulate string volume at 205 gpm, 750 psi, 11% flow out. 10,463.0 10,463.0 8/11/2021 22:30 8/12/2021 00:00 1.50 INTRM1, CEMENT PACK T Set packer per Baker Rep - apply 20 right hand turns to the drill string, slack off to set depth at 10,463' MD, pick up and confirm set with 45 k over pull, 45 k excess of dn weight. Close annular preventor and test top of retainer to 2000 psi, (tested good). Pull out of retainer and begin space out for cement job. 10,463.0 10,463.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 32/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/12/2021 00:00 8/12/2021 01:30 1.50 INTRM1, CEMENT CIRC T Pick up 14.38' and 5.01' pup joints and install 1 joint below the rotary table (full joint across the BOP's). Rig up cementing equipment, sting into the cement retainer, close annular preventer and pressure up to 250 psi on the 7-5/8" by 4" DP annulus. Establish circulation through the perfs taking returns through the OA, 1 bbls/min - 310 psi, 2 bbls/min - 410 psi, 3 bbls/min - 520 psi, 4 bbls/min - 760 psi. Simops - Prejob safety meeting with all parties for cement job. 10,463.0 10,463.0 8/12/2021 01:30 8/12/2021 04:00 2.50 INTRM1, CEMENT CMNT T SLB pump 4 bbls of fresh H2O. Tested lines to 700 psi low/ 3500 psi high, pump 30 bbls of 12.5 ppg Mud Push II @ 4 bbls/min, 490 psi, Batch cement (cement wet @ 02:57) Pump 107.5 bbls of Class G 15.8 ppg cement @ 4 bbls/min, ICP = 520 psi, FCP = 120 psi. Batch and pump 10.1 bbls 12.5 ppg Mud Push II at 4 bbls/min, 92 psi, pump 5.1 bbls fresh water. Swap to rig & displace w/ 10.8 ppg LSND mud @ 4 bbls/min, ICP = 80 psi, FCP= 965 psi. Slow pumps to 0.5 bbls/min, 430 psi. 0 losses, shut down pumps at 1093 strokes (92.5 bbls). 10,463.0 10,463.0 8/12/2021 04:00 8/12/2021 05:15 1.25 INTRM1, CEMENT CIRC T Bled off pressure on the 7-5/8" by 4" DP annulus and opened the annular preventer. Pulled 6 ft out of the cement retainer, pumped 20 bbls fresh water and circulated to surface at 12 bbls/min, 2800 psi. Stung back into the retainer, closed the annular preventer, pressured up the 7- 5/8" by 4" DP annulus to 250 psi. 10,463.0 10,463.0 8/12/2021 05:15 8/12/2021 06:15 1.00 INTRM1, CEMENT CMNT T Perform hesitation sqeeze on cement. pump at in 1/2 bbl increments and hold for 15 min each. 0.5 bbls - 718 psi 1 bbl - 843 psi, 1.5 bbls - 925 psi. 10,463.0 10,463.0 8/12/2021 06:15 8/12/2021 07:45 1.50 INTRM1, CEMENT CIRC T Bled off pressure on the 7-5/8" by 4" DP annulus and opened the annular preventer, bled off pressure on the drill string and pulled 6 ft out of the cement retainer. Pumped 20 bbls fresh water and circulated out of the hole at 12 bbls/min, 2675 psi. 10,463.0 10,457.0 8/12/2021 07:45 8/12/2021 08:15 0.50 INTRM1, CEMENT OWFF T Observed well for flow (static). Simops - blew down lines and rigged down cementing equipment. Laid down space out pup joints. 10,457.0 10,412.0 8/12/2021 08:15 8/12/2021 12:30 4.25 INTRM1, CEMENT TRIP T Trip out of the hole with retainer running tool from 10,412' to 3,680' MD. 92 k Up Wt, 89 k Dn Wt. 10,412.0 3,680.0 8/12/2021 12:30 8/12/2021 13:00 0.50 INTRM1, CEMENT SVRG T Service top dirve, blocks, crown sheave, and PS-21's 3,680.0 3,680.0 8/12/2021 13:00 8/12/2021 14:30 1.50 INTRM1, CEMENT RGRP T Trouble shoot Amphion system choppers. Simops - service the ST-80, spot the E- Line truck, pick wireline tools to the rig floor. 3,680.0 3,680.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 33/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/12/2021 14:30 8/12/2021 18:00 3.50 INTRM1, CEMENT TRIP T Continue tripping out of the hole with retainer running tool from 3,680' MD to surface. 3,680.0 3,680.0 8/12/2021 18:00 8/12/2021 18:30 0.50 INTRM1, CEMENT BHAH T Lay down cement retainer running tool, clear and clean the rig floor. 3,680.0 0.0 8/12/2021 18:30 8/12/2021 19:30 1.00 INTRM1, CEMENT ELOG T Rig up E-Line, make up USIT assembly and surface test tools. 0.0 0.0 8/12/2021 19:30 8/13/2021 00:00 4.50 INTRM1, CEMENT ELOG T SLB E-Line run in hole with USIT assembly to 10,448' WLM. Log from 10,448' to 7,928' WLM. 0.0 0.0 8/13/2021 00:00 8/13/2021 02:00 2.00 INTRM1, CEMENT ELOG T Pull USIT out of the hole, lay down assembly and rig down E-line. 0.0 0.0 8/13/2021 02:00 8/13/2021 03:15 1.25 INTRM1, CEMENT NUND T Blow down choke, kill, and hole fill lines, rig down hole fill line and MPD, pull PS- 21's, and remove trip nipple. 0.0 0.0 8/13/2021 03:15 8/13/2021 04:00 0.75 INTRM1, CEMENT WWSP T Pull wear bushing per FMC rep. BOLDS, pull 7-5/8" pack off. Note: Zero overpull observed while pulling the packoff out of the wellhead. Zero damage to seals, or any substance (other than mud), visible or present on the packoff at surface. 0.0 0.0 8/13/2021 04:00 8/13/2021 06:30 2.50 INTRM1, CEMENT NUND T Nipple down BOPE, high pressure drilling riser, and tubing spool, remove and lay down the mouse hole. 0.0 0.0 8/13/2021 06:30 8/13/2021 08:00 1.50 INTRM1, CEMENT FISH T Make up spear assembly, engage spear into 7-5/8" casing stump. Pick up to 214 k and remove emegency slips (slips picked off seat at 116 k). Slack off to block weight and rotate 1 turn to the right. Pull spear out of the casing stump and stand back. 0.0 0.0 8/13/2021 08:00 8/13/2021 09:00 1.00 INTRM1, CEMENT NUND T Remove and replace casing spool per FMC procedure and rep. 0.0 0.0 8/13/2021 09:00 8/13/2021 10:00 1.00 INTRM1, CEMENT FISH T Spear 7-5/8" casing stump, pull through the casing spool and set new emergency slips (200 k on slips). Release spear from casing stump and lay down. Test casing spool seal to 1000 psi for 10 minutes (tested good). 0.0 0.0 8/13/2021 10:00 8/13/2021 11:30 1.50 INTRM1, CEMENT OTHR T Install WACHS cutter on casing stump and cut 1.71' off the casing stump and dress. Set new 7-5/8" pack off, RILDS. 0.0 0.0 8/13/2021 11:30 8/13/2021 13:30 2.00 INTRM1, CEMENT NUND T Nipple up the tubing spool, test pack off to 3,800 psi for 10 min (tested good). 0.0 0.0 8/13/2021 13:30 8/13/2021 17:00 3.50 INTRM1, CEMENT NUND T Nipple up high pressure drilling riser, BOP's, choke line and kill line, install the flow box, flow line, floor drain lines, and mouse hole. 0.0 0.0 8/13/2021 17:00 8/13/2021 18:00 1.00 INTRM1, CEMENT MPDA T Set the upper test plug per FMC, fill the stack with water, installed the MPD test cap and tested MPD equipment to 250 psi low and 1200 psi high (tested good). Pulled the MPD test cap and installed the trip nipple. 0.0 0.0 8/13/2021 18:00 8/13/2021 20:30 2.50 INTRM1, CEMENT PRTS T Pick up and install 4" test joint, flood lines with water, shell test BOPE to 250 psi low for 5 min, 3500 psi high for 10 min. Rig down testing equipment. Pull the test plug per FMC and lay down the 4" test joint. 0.0 0.0 8/13/2021 20:30 8/13/2021 22:00 1.50 INTRM1, CEMENT SLPC P Hang blocks, spool off 55 ft of drilling line and cut, feed drilling line into drawworks and install dogknot. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 34/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/13/2021 22:00 8/13/2021 23:30 1.50 INTRM1, CEMENT SLPC P Crew change first day back, handover with relief, inspect equipment and rig up prior to finishing slip and cut operations. Pre-job safety meeting on slip and cut, fill out work permits. Slip on 55 ft of drilling line, torque deadman. Unhang blocks. 0.0 0.0 8/13/2021 23:30 8/14/2021 00:00 0.50 INTRM1, CEMENT SVRG P Service top drive, drawworks, and deadman. 0.0 0.0 8/14/2021 00:00 8/14/2021 06:00 6.00 INTRM1, CEMENT RGRP T Wait on replacement choppers. Load and process 4" DP, drain gear oil and remove clam shells on mud pumps for annual maintenance, rig house keeping, work on MP2's. 0.0 0.0 8/14/2021 06:00 8/14/2021 12:00 6.00 INTRM1, CEMENT RGRP T Continue waiting on replacement choppers, Clean and inspect cuttings auger, continue working on MP2's, continue annual maintenance on mud pumps, perform annual mainteance on drilling line spooler, test high pressure mud sytem and 2" 1502 hoses to 5,000 psi for 10 mins. 0.0 0.0 8/14/2021 12:00 8/14/2021 16:30 4.50 INTRM1, CEMENT RGRP T Continue waiting on replacement choppers, prepare choppers for removal. Continue working on MP2's - clean and inspect shakers, inspect accumulator system. House keeping around the rig. 0.0 0.0 8/14/2021 16:30 8/15/2021 00:00 7.50 INTRM1, CEMENT RGRP T Install replacement choppers in the VFD. Continue working on MP2's - drawworks, EZ - torques, BOP carrier, charge pumps, pipe skate HPU, complete annual PM on mud pumps #1 and #2. 0.0 0.0 8/15/2021 00:00 8/15/2021 04:00 4.00 INTRM1, CEMENT RGRP T Continue installing choppers, troubleshoot sytem and complete repair to choppers. Continue working on MP2's - Drillers cabin annual, gas buster annual, product lift annual, weekly derrick inspection. 0.0 0.0 8/15/2021 04:00 8/15/2021 05:00 1.00 INTRM1, CEMENT OTHR T Pick up BHA compontents to the rig floor, install PS-21's. 0.0 0.0 8/15/2021 05:00 8/15/2021 07:00 2.00 INTRM1, CEMENT BHAH T Make up clean out BHA per Baker rep to 245' MD 0.0 245.0 8/15/2021 07:00 8/15/2021 13:30 6.50 INTRM1, CEMENT TRIP T Trip in the hole with clean out assembly from 245' to 10,298' MD. 200 k Up Wt, 136 k Dn Wt. Filling pipe ever 20 stands. 245.0 10,298.0 8/15/2021 13:30 8/15/2021 14:00 0.50 INTRM1, CEMENT WASH T Wash in the hole from 10,298' MD, 210 gpm, 1020 psi, 12 % flow out, 80 rpm, 7 k tq. Tag top of cement retainer at 10,461' MD. Begin cutting mud weight from 10.8 ppg to 10.2 ppg. 10,298.0 10,461.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 35/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/15/2021 14:00 8/15/2021 17:00 3.00 INTRM1, CEMENT DRLG T Drill cement retainer per BHI recommendations from 10,461' to 10,463' MD, 6-16 k wob, 210 gpm, 890 psi, 12 % flow out, 60-80 rpm, 8-12 k tq, 200 k Up Wt, 136 k Dn Wt. 170 k Rot Wt. Continue cutting mud from 10.8 ppg to 10.2 ppg. 10,461.0 10,463.0 8/15/2021 17:00 8/16/2021 00:00 7.00 INTRM1, CEMENT DRLG T Drill cement from 10,463' to 10,900' MD, 9-11 k wob, 292 gpm, 1600 psi, 16% flow out, 80 rpm, 8-11 k tq, 215 k Up Wt, 137 k Dn wt, 171 k Rot Wt. 10,463.0 10,900.0 8/16/2021 00:00 8/16/2021 01:00 1.00 INTRM1, CEMENT DRLG T Continue drilling cement from 10,900' to 11,000' MD, 9-11 k wob, 292 gpm, 1600 psi, 16% flow out, 80 rpm, 8-11 k tq, 215 k Up Wt, 137 k Dn wt, 171 k Rot Wt. 10,900.0 11,000.0 8/16/2021 01:00 8/16/2021 04:00 3.00 INTRM1, CEMENT WASH T Wash in the hole from 11,000' to 12,133' MD to circulate out the 16 ppg gel pill, 290 gpm,1740 psi, 17% flow out, 240 k Up Wt, 128 k Dn Wt. 11,000.0 12,133.0 8/16/2021 04:00 8/16/2021 05:30 1.50 INTRM1, CEMENT CIRC T Pump 50 bbls hi vis sweep and circulate out of the hole while rotating and reciprocating from 12,133' to 12,104' MD, 290 gpm, 1570 psi, 17% flow out, 40 rpm, 14 k tq, 240 k Up Wt, 128 k Dn Wt. Observed significant increase in cement cutting over the shakers. 12,133.0 12,104.0 8/16/2021 05:30 8/16/2021 06:30 1.00 INTRM1, CEMENT OWFF T Observe well for flow (static). Pump 30 bbls 12.2 ppg dry job, blow down top drive. 12,104.0 12,104.0 8/16/2021 06:30 8/16/2021 13:45 7.25 INTRM1, CEMENT TRIP T Trip out of the hole from 12,104' MD to 245' MD. Monitor hole fill on trip tank. 12,104.0 245.0 8/16/2021 13:45 8/16/2021 15:00 1.25 INTRM1, CEMENT BHAH T Observe well for flow (static), lay down clean out assembly per Baker Rep. (Collected 32 lbs of swarf from magnets and junk baskets.) 245.0 0.0 8/16/2021 15:00 8/16/2021 16:30 1.50 INTRM1, CEMENT ELOG T Rig up SLB E-Line, pick up USIT assembly and surface test tools. 0.0 0.0 8/16/2021 16:30 8/16/2021 21:30 5.00 INTRM1, CEMENT ELOG T Run USIT assembly in the hole to 11,873' WLM. Log for cement from 11,873' to 7,905' WLM. Pull USIT assembly out of the hole to surface. 0.0 0.0 8/16/2021 21:30 8/16/2021 22:30 1.00 INTRM1, CEMENT ELOG T Lay down assembly and rig down E- Line. 0.0 0.0 8/16/2021 22:30 8/16/2021 23:30 1.00 INTRM1, CEMENT OTHR T Download E-Line tools and process logs, service and inspect hand slips, rig tongs, and tuggers, prep for BHA. Perform weekly BOP function test. Simops - clean tank room and cellar. 0.0 0.0 8/16/2021 23:30 8/17/2021 00:00 0.50 INTRM1, CEMENT BHAH T Pick up clean out BHA #5 per Baker Rep with 7-5/8" casing scraper to 64' MD 0.0 64.0 8/17/2021 00:00 8/17/2021 05:30 5.50 INTRM1, CEMENT TRIP T Trip in the hole with BHA #5 to 8,501' MD, filling pipe ever 20 stands, monitoring displacement on the trip tank. 200 k Up Wt, 121 k Dn Wt. 64.0 8,501.0 8/17/2021 05:30 8/17/2021 07:30 2.00 INTRM1, CEMENT RGRP T Investigate drive fault issues, found braking resistor banks to be in an inadequate condition. 8,501.0 8,501.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 36/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/17/2021 07:30 8/17/2021 12:00 4.50 INTRM1, CEMENT OTHR T Pick up 4" drill pipe singles out of the pipe shed, build 4" drill pipe stands and rack back in the derrick using the mousehole and tugger. 8,501.0 8,501.0 8/17/2021 12:00 8/17/2021 18:00 6.00 INTRM1, CEMENT RGRP T Continue picking up 4" drill pipe singles out of the pipe shed, build 4" drill pipe stands and rack back in the derrick using the mousehole and tugger. Simops - remove dynamic brake resistors and prep for new resistor bank installment. 8,501.0 8,501.0 8/17/2021 18:00 8/17/2021 23:30 5.50 INTRM1, CEMENT RGRP T Continue picking up 4" drill pipe singles out of the pipe shed, build 4" drill pipe stands and rack back in the derrick using the mousehole and tugger. Simops - Install and form dynamic brake resistor banks. 8,501.0 8,501.0 8/17/2021 23:30 8/18/2021 00:00 0.50 INTRM1, CEMENT TRIP T Trip in the hole with BHA #5 from 8,501' MD to 9,069' MD, 215 k Up Wt, 121 k Dn Wt. Monitor displacement on the trip tank. 8,501.0 9,069.0 8/18/2021 00:00 8/18/2021 00:45 0.75 INTRM1, CEMENT TRIP T Continue trip in the hole with BHA #5 from 9,069' MD to 10,401' MD, 247 k Up Wt, 132 k Dn Wt. Monitor displacement on the trip tank. 9,069.0 10,401.0 8/18/2021 00:45 8/18/2021 02:30 1.75 INTRM1, CEMENT WASH T Wash in the hole from 10,401' to 10,970' MD working casing scaper across packer setting interval per Baker rep. 164 gpm, 600 psi, 7% flow out, 247 k Up Wt, 132 k Dn Wt. 10,401.0 10,970.0 8/18/2021 02:30 8/18/2021 03:30 1.00 INTRM1, CEMENT TRIP T Continue trip in the hole with BHA #5 from 10,401' MD to 12,113' MD, 278 k Up Wt, 127 k Dn Wt. Monitor displacement on the trip tank. Wash in the hole from 12,113' - 12,133' MD, 164 gpm, 780 psi, 10% flow out. Rack back stand to 12,113 10,970.0 12,113.0 8/18/2021 03:30 8/18/2021 06:30 3.00 INTRM1, CEMENT CIRC T Circulate and condition mud for testing the perforations, 292 gpm, 1500 psi, 13% flow out. Mud wt in and out 10.1 ppg. 12,113.0 12,113.0 8/18/2021 06:30 8/18/2021 07:00 0.50 INTRM1, CEMENT FIT T Rig up to perform FIT on the casing perfs at 10,925' MD, 7,740' TVD. FIT perfs to 11.75 ppg (670 surface psi with 10.1 ppg MW), pumped 1.3 bbls, bled back 1.3 bbls. Rig down testing equipment. 12,113.0 12,113.0 8/18/2021 07:00 8/18/2021 07:45 0.75 INTRM1, CEMENT OWFF T Observe well for flow for 30 minutes (static), Pump 30 bbls of 12.2 ppg dry job, blow down topdrive. 12,113.0 12,113.0 8/18/2021 07:45 8/18/2021 14:00 6.25 INTRM1, CEMENT TRIP T Trip out of the hole with BHA #5 from 12,113' to 275' MD, Monitor hole fill on the trip tank. 12,113.0 275.0 8/18/2021 14:00 8/18/2021 14:15 0.25 INTRM1, CEMENT OWFF T Observe well for flow for 15 minutes (static). 275.0 275.0 8/18/2021 14:15 8/18/2021 16:45 2.50 INTRM1, CEMENT BHAH T Lay down BHA #5 per Baker rep, clean debris from magnets and junk baskets, clear and clean rig floor of BHA components. 275.0 0.0 8/18/2021 16:45 8/18/2021 17:45 1.00 INTRM1, CEMENT OTHR T Pull the wear bushing and install the test plug per FMC rep, rig up to test BOPE, flood lines and purge air from the system. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 37/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/18/2021 17:45 8/19/2021 00:00 6.25 INTRM1, WHDBOP BOPE T Test BOPE: All tests to 250 psi low for 5 minutes, 3500 psi high for 10 minutes charted minimum w/ exception of manual operated Super Choke 2000 psi show bleed and hold pressure, with 4" test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, with 4 ½” test joint test annular. Test choke valves 1- 15, choke & kill manuals & HCR's, 4" valve on kill line. Two 4" FOSV, two 4" dart valve, performed Koomey drawdown, ACC = 3000 psi. Manifold = 1500 psi. ACC - 1700 psi after all functions on the bottles, 15 secs for 200 psi. Build w/ 2 electric pumps, 80 secs to build full system pressure w/ 2 electric & 2 air pumps. Closing times annular = 21 secs, UPR 18 secs, Blind/Shears = 15 secs, LPR 17 secs, Choke HCR = 2 secs, Kill HCR = 2 secs, Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Rep Matthew Herrera waived witness at 10:34hrs 8/15/2021. 0.0 0.0 8/19/2021 00:00 8/19/2021 00:30 0.50 INTRM1, WHDBOP BOPE T With 4 ½” test joint, test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR to 250 psi low pressure for 5 min and 3500 psi high pressure for 10 minutes. 0.0 0.0 8/19/2021 00:30 8/19/2021 01:15 0.75 INTRM1, WHDBOP OTHR T Pull the test plug and install the wear bushing per FMC rep. 0.0 0.0 8/19/2021 01:15 8/19/2021 02:00 0.75 INTRM1, DRILLOUT BHAH P Load the rig floor of BHA components. Simops - ball mill pressure test injection line to 2,500 psi (tested good). Perform annular LOT. 18.1 ppg EMW. 0.0 0.0 8/19/2021 02:00 8/19/2021 05:15 3.25 INTRM1, DRILLOUT BHAH P Pick up BHA #6 per Baker DD and MWD to 316 ' MD. Plug into tools on the rig floor and program/check tool electronics per Baker MWD. Simops - begin annular fresh water flush. 0.0 316.0 8/19/2021 05:15 8/19/2021 06:30 1.25 INTRM1, DRILLOUT TRIP P Trip in the hole with 6.5" production BHA from 316' to 2,214' MD, monitor displacement on trip tank. Simops - continued annular fresh water flush. 440 bbls total pumped. 316.0 2,214.0 8/19/2021 06:30 8/19/2021 07:00 0.50 INTRM1, DRILLOUT CIRC P Shallow hole test MWD tools, 242 gpm, 830 psi, 9% flow out, 30 rpm, 1 k tq. 2,214.0 2,214.0 8/19/2021 07:00 8/19/2021 09:30 2.50 INTRM1, DRILLOUT TRIP P Continue tripping in the hole with 6.5" production BHA from 2,214' to 6,863' MD, filling pipe every 20 stands, monitoring displacement on the trip tank. 2,214.0 6,863.0 8/19/2021 09:30 8/19/2021 10:00 0.50 INTRM1, DRILLOUT SVRG P Service the ST-80, PS-21 and the drawworks. 6,863.0 6,863.0 8/19/2021 10:00 8/19/2021 11:00 1.00 INTRM1, DRILLOUT RGRP T Trouble shoot choppers, replace faulted circuit board. 6,863.0 6,863.0 8/19/2021 11:00 8/19/2021 14:30 3.50 INTRM1, DRILLOUT TRIP P Continue tripping in the hole with 6.5" production BHA from 6,863' to 12,080' MD, 265 k Up Wt, 137 k Dn Wt. Monitoring displacement on the trip tank. 6,863.0 12,080.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 38/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/19/2021 14:30 8/19/2021 17:30 3.00 INTRM1, DRILLOUT SLPC P Slip and cut drilling line. During slip and cut, damage was observed on the drilling line, continued to slip until damaged line was cleared. 330 ft of line replaced. 12,080.0 12,080.0 8/19/2021 17:30 8/19/2021 18:30 1.00 INTRM1, DRILLOUT OTHR P Service the top drive, blocks and crown cluster, callibrate Amphion, Pason and Baker sensors. 12,080.0 12,080.0 8/19/2021 18:30 8/20/2021 00:00 5.50 INTRM1, DRILLOUT DRLG P Wash from 12,080' to 12,133' MD, drill shoe track and rat hole to 12,252' MD, 6 -12 k wob, 200 gpm, 1150 psi, 7% flow out, 50 rpm, 14-15 k tq, 270 k Up Wt, 140 k Dn Wt, 176 k Rot Wt. Tagged plugs at 12,152' MD, tagged shoe at 12,240' MD. Simops, perform second annular LOT (1000 psi with water - 14.6 ppg EMW). Pumped 32 bbls of water to finish annular flush (478 bbls total) freeze protected the annulus with 110 bbls of diesel. 12,080.0 12,252.0 8/20/2021 00:00 8/20/2021 00:45 0.75 INTRM1, DRILLOUT DRLG P Continue to drill rat hole from 12,152' to 12,158' MD, 3 k wob, 260 gpm, 1780 psi, 10% flow out, 10.84 ecd, 85 rpm, 15k tq. Observe packoff and top drive stalling out. 12,252.0 12,258.0 8/20/2021 00:45 8/20/2021 01:30 0.75 INTRM1, DRILLOUT CIRC P Worked the BHA back into the shoe, reciprocated from 12,258' to 12,120' MD, 260 gpm 1730 psi, 10% flow out,100 rpm, 16k tq. 12,258.0 12,241.0 8/20/2021 01:30 8/20/2021 03:00 1.50 INTRM1, DRILLOUT CIRC P Pump 40 bbls hi vis wt sweep and circulate out of the hole, 260 gpm, 1880 psi, 11% flow out, 10.98 ppg ecd, 100 rpm 15 k tq. Observed large chunks of plug rubber, cement, and shoe material over the shakers. 12,241.0 12,241.0 8/20/2021 03:00 8/20/2021 07:00 4.00 INTRM1, DRILLOUT DRLG P Continue drilling rat hole from 12,258' to 12,318' MD, mitigating packoffs and stall outs, 3-7 k wob, 260 gpm, 1790 psi, 10.81 ppg ecd, 100 rpm, 15 k tq. 12,241.0 12,318.0 8/20/2021 07:00 8/20/2021 07:15 0.25 INTRM1, DRILLOUT DDRL P Drill 6'' Production Hole f/ 12,318' ' t/ 12,338' WOB- 5-10K RPM- 100 Torq.- 12-16K GPM- 250 On Btm PSI- 1680 Flow out- 10% ECD- 10.75 PPG P/U- 270K S/O- 140K Rot- 176K ADT- .3 Total Bit Hrs- .3 12,318.0 12,338.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 39/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/20/2021 07:15 8/20/2021 08:45 1.50 INTRM1, DRILLOUT CIRC P Circ & cond. mud @ 12,338' w/ rotating and reciprocating pipe f/ 12,338' t/ 12,080' GPM-250 PSI-1710 RPM-40 Torq-14K ECD-10.77 Total strokes pumped: 4788 12,338.0 12,080.0 8/20/2021 08:45 8/20/2021 09:30 0.75 INTRM1, DRILLOUT FIT P PJSM, FIT t/ 627 psi, 11.5 ppg equilivalent PSI bled off t/ 470 psi in 10 minutes, 11.2 equilivalent 12,080.0 12,080.0 8/20/2021 09:30 8/20/2021 10:15 0.75 PROD1, DRILL OTHR P PJSM, pull trip nipple & install rotating head assembly 12,080.0 12,080.0 8/20/2021 10:15 8/20/2021 11:15 1.00 PROD1, DRILL CIRC P Ream down f/ 12,080' t/ 12,338' w/ displacing hole t/ 9.0 ppg Flo Pro 12,080.0 12,338.0 8/20/2021 11:15 8/20/2021 12:00 0.75 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 12,338' ' t/ 12,370' WOB- 17K RPM- 120 Torq.- 10K GPM- 250 On Btm PSI- 1770 Flow out- 8% ECD- 10.75 PPG P/U- 292K S/O- 183K Rot- 174K MPD Connection Back Pressure 0 psi ADT-0.4 Total Bit Hrs- 0.7 12,338.0 12,370.0 8/20/2021 12:00 8/20/2021 18:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 12,370' ' t/ 12,925' WOB- 19K RPM- 120 Torq.- 10K GPM- 250 On Btm PSI- 1665 Flow out- 10% ECD- 9.86 PPG P/U- 240K S/O- 146K Rot- 184K MPD Connection Back Pressure 20 psi ADT-4.6 Total Bit Hrs- 5.3 12,370.0 12,925.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 40/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/20/2021 18:00 8/21/2021 00:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 12,925' ' t/ 13,601' WOB- 19K RPM- 120 Torq.- 10K GPM- 250 On Btm PSI- 1665 Flow out- 10% ECD- 9.86 PPG P/U- 240K S/O- 146K Rot- 184K MPD Connection Back Pressure 20 psi ADT- 4.5 Total Bit Hrs- 9.8 12,925.0 13,601.0 8/21/2021 00:00 8/21/2021 06:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 13,601' t/ 14,302'. WOB- 15-20K RPM- 120 Torq.- 12-16K GPM- 250 On Btm PSI- 1925 Flow out- 10% ECD- 10.13 PPG P/U- 234K S/O- 150K Rot- 182K MPD Connection Back Pressure 0 psi ADT- 4.5 Total Bit Hrs- 14.3 13,601.0 14,302.0 8/21/2021 06:00 8/21/2021 12:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 14,302' t/ 15,013'. WOB- 15-20K RPM- 120 Torq.- 12-16K GPM- 250 On Btm PSI- 2095 Flow out- 10% ECD- 10.35 PPG P/U- 240K S/O- 146K Rot- 187K MPD Connection Back Pressure 0 psi ADT- 4.6 Total Bit Hrs- 18.9 14,302.0 15,013.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 41/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/21/2021 12:00 8/21/2021 18:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 15,013' t/ 15,653'. WOB- 15-21K RPM- 120 Torq.- 10K GPM- 250 On Btm PSI- 1858 Flow out- 11% ECD- 10.11 PPG P/U- 240K S/O- 146K Rot- 187K MPD Connection Back Pressure 0 psi ADT- 4.6 Total Bit Hrs- 23.5 Encountered partial losses of 35-44 bph at ~15,640' MD. 15,013.0 15,653.0 8/21/2021 18:00 8/22/2021 00:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 15,653' t/ 16,318'. WOB- 15-24K RPM- 120 Torq.- 12K GPM- 250 On Btm PSI- 2090 Flow out- 9.5% ECD- 10.26 PPG P/U- 241K S/O- 135K Rot- 179K MPD Connection Back Pressure 20-60 psi ADT- 4.7 Total Bit Hrs- 28.2 Commenced adding background LCM mixture of Medium Nut Plug (7 sacks/hr) and Safe-Carb 250 (8 sacks/hr). Partial losses of 20 bph at 16,318' MD. 15,653.0 16,318.0 8/22/2021 00:00 8/22/2021 06:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 16,318' t/ 16,884'. WOB- 15-24K RPM- 120 Torq.- 12K GPM- 250 On Btm PSI- 2215 Flow out- 9.5% ECD- 10.32 PPG P/U- 241K S/O- 138K Rot- 180K MPD Connection Back Pressure 0 psi, Floats not holding ADT- 4.4 Total Bit Hrs- 32.6 Commenced adding background LCM mixture of Medium Nut Plug (4 sacks/hr) and Safe-Carb 250 (4 sacks/hr). Partial losses of 20 bph at 17,190' MD. 16,318.0 16,884.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 42/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/22/2021 06:00 8/22/2021 12:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 16,884' t/ 17,490'. WOB- 15-24K RPM- 120 Torq.- 12K GPM- 250 On Btm PSI- 2215 Flow out- 9.5% ECD- 10.27 PPG P/U- 241K S/O- 138K Rot- 180K MPD Connection Back Pressure 0 psi, Floats not holding ADT- 4.3 Total Bit Hrs- 36.9 Added background LCM mixture of Medium Nut Plug (4 sacks/hr) and Safe- Carb 250 (4 sacks/hr). Partial losses of 20 bph at 17,190' MD. Stopped adding background LCM @ 17,500' 16,884.0 17,490.0 8/22/2021 12:00 8/22/2021 18:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 17,490' t/ 18,157'. WOB- 15-20K RPM- 120 Torq.- 10K GPM- 250 On Btm PSI- 2312 Flow out- 10.0% ECD- 10.36 PPG P/U- 234K S/O- 138K Rot- 183K MPD Connection Back Pressure 0 psi, Floats not holding ADT- 4.7 Total Bit Hrs- 41.6 17,490.0 18,157.0 8/22/2021 18:00 8/23/2021 00:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 18,157' t/ 18,767'. WOB- 15-17K RPM- 120 Torq.- 12K GPM- 250 On Btm PSI- 2365 Flow out- 10.0% ECD- 10.26 PPG P/U- 236K S/O- 138K Rot- 178K MPD Connection Back Pressure 0 psi, Floats not holding ADT- 4.5 Total Bit Hrs- 46.1 18,157.0 18,767.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 43/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/23/2021 00:00 8/23/2021 06:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 18,157' t/ 19,395' WOB- 15-17K RPM- 120 Torq.- 12K GPM- 250 On Btm PSI- 2360 Flow out- 10.0% ECD- 10.23 PPG P/U- 244K S/O- 128K Rot- 184K MPD Connection Back Pressure 85 psi ADT- 4.4 Total Bit Hrs- 50.5 Pumped lo-vis sweep and was able to get floats to shut and hold psi on connections 18,767.0 19,395.0 8/23/2021 06:00 8/23/2021 12:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 19,395' t/ 20,060' WOB- 15-17K RPM- 120 Torq.- 12K GPM- 250 On Btm PSI- 2430 Flow out- 10.0% ECD- 10.23 PPG P/U- 250K S/O- 125K Rot- 171K MPD Connection Back Pressure 85 psi ADT- 4.6 Total Bit Hrs- 55.1 Pumped lo-vis sweeps every stands to clean floats. 19,395.0 20,060.0 8/23/2021 12:00 8/23/2021 18:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 20,060' t/ 20,822'. WOB- 15-20K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 2531 Flow out- 11.0% ECD- 10.54 PPG P/U- 255K S/O- 155K Rot- 184K MPD Connection Back Pressure 48 psi ADT- 4.8 Total Bit Hrs- 59.9 LWD Speed tests within interval: 20,440' - 20,626' @ 175 fph 20,627' - 20,822' @ 200 fph Pumped lo-vis sweeps every stands to clean floats. 20,060.0 20,822.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 44/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/23/2021 18:00 8/24/2021 00:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 20,822' t/ 21,583' WOB- 15-23K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 2653 Flow out- 12.0% ECD- 10.47 PPG P/U- 260K S/O- 116K Rot- 184K MPD Connection Back Pressure 20-40 psi ADT- 4.5 Total Bit Hrs- 64.4 LWD Speed tests within interval: 20,822' - 20,910' @ 200 fph 20,921' - 21,195' @ 225 fph Pumped lo-vis sweeps every stands to clean floats. 20,822.0 21,583.0 8/24/2021 00:00 8/24/2021 06:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 21,583' t/ 22,250' WOB- 20-25K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 2600 Flow out- 12.0% ECD- 10.48 PPG P/U- 256K S/O- 118K Rot- 189K MPD Connection Back Pressure 35-95 psi ADT- 4.7 Total Bit Hrs- 69.1 21,583.0 22,250.0 8/24/2021 06:00 8/24/2021 12:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 22,250' t/ 22,917' WOB- 15-20K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 2680 Flow out- 12.0% ECD- 10.40 PPG P/U- 262K S/O- 112K Rot- 177K MPD Connection Back Pressure 44-133 psi ADT- 4.6 Total Bit Hrs- 73.7 22,250.0 22,917.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 45/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/24/2021 12:00 8/24/2021 18:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 22,917' t/ 23,584' WOB- 15-19K RPM- 120 Torq.- 15K GPM- 250 On Btm PSI- 2730 Flow out- 12.0% ECD- 10.40 PPG P/U- 262K S/O- 108K Rot- 188K MPD Connection Back Pressure 25-79 psi ADT- 4.7 Total Bit Hrs- 78.4 22,917.0 23,584.0 8/24/2021 18:00 8/25/2021 00:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 23,584' t/ 24,240' WOB- 15-17K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 2857 Flow out- 12.0% ECD- 10.52 PPG P/U- 268K S/O- 104K Rot- 186K MPD Connection Back Pressure 40-65 psi ADT- 4.8 Total Bit Hrs- 83.2 23,584.0 24,240.0 8/25/2021 00:00 8/25/2021 06:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 24,240' t/ 24,867' WOB- 15-17K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 3020 Flow out- 12.0% ECD- 10.67 PPG P/U- 283K S/O- 0K Rot- 186K MPD Connection Back Pressure 35-95 psi ADT- 4.3 Total Bit Hrs- 87.5 Loss slack off weight @ 24,802' MD 24,240.0 24,867.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 46/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/25/2021 06:00 8/25/2021 12:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 24,867' t/ 25,475' WOB- 15-17K RPM- 120 Torq.- 17K GPM- 250 On Btm PSI- 3175 Flow out- 12.0% ECD- 10.73 PPG P/U- 290K S/O- 0K Rot- 186K MPD Connection Back Pressure 100- 195 psi ADT- 4.3 Total Bit Hrs- 91.8 24,867.0 25,475.0 8/25/2021 12:00 8/25/2021 18:00 6.00 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 25,475' t/ 26,125' WOB- 15-18K RPM- 120 Torq.- 19K GPM- 250 On Btm PSI- 3227 Flow out- 11.0% ECD- 10.72 PPG P/U- 288K S/O- 0K Rot- 204K MPD Connection Back Pressure 75-121 psi ADT- 4.4 Total Bit Hrs- 96.2 25,475.0 26,125.0 8/25/2021 18:00 8/25/2021 19:30 1.50 PROD1, DRILL DDRL P Drill 6.5'' Production Hole f/ 26,125' t/ 26,241' WOB- 15-18K RPM- 120 Torq.- 18K GPM- 250 On Btm PSI- 3132 Flow out- 10.0% ECD- 10.74 PPG P/U- 288K S/O- 0K Rot- 202K MPD Connection Back Pressure 64 psi ADT- 0.8 Total Bit Hrs- 97.0 26,125.0 26,241.0 8/25/2021 19:30 8/25/2021 22:15 2.75 PROD1, CASING CIRC P Dropped 1.96 steel hollow drift w/ 135' tail. CBU while racking back one stand in the derrick f/ 26,241' - 26,122'. RPM- 120 Torq.- 15K GPM- 250 Off Btm PSI- 2825 Flow out- 9.0% ECD- 10.45 PPG P/U- 196K Total pumped strokes = 10,181 26,241.0 26,122.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 47/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/25/2021 22:15 8/25/2021 23:00 0.75 PROD1, CASING MPDA P Fingerprinted well as per MPD. Trapped and released back pressure 6 times. Initial PSI = 47 and Final PSI = 21. 1.13 bbls bled back. Rotate at 10 rpm w/ 13k TQ. Well was observed static. 26,122.0 26,122.0 8/25/2021 23:00 8/26/2021 00:00 1.00 PROD1, CASING CIRC P CBU while racking back one stand in the derrick f/ 26,122' - 26,072'. RPM- 100 Torq.- 15K GPM- 250 Off Btm PSI- 3,023 Flow out- 12.0% ECD- 10.28 PPG P/U- 196K Total pumped strokes = 5287 26,122.0 26,072.0 8/26/2021 00:00 8/26/2021 01:00 1.00 PROD1, CASING CIRC P CBU while racking back one stand in the derrick f/ 26,072' - 26,030'. RPM- 100 Torq.- 14K GPM- 250 Off Btm PSI- 3,023 Flow out- 12.0% ECD- 10.28 PPG P/U- 196K Total pumped strokes = 9,650 26,072.0 26,030.0 8/26/2021 01:00 8/26/2021 09:30 8.50 PROD1, CASING BKRM P BROOH f/ 26,030' - 23,485' MD. RPM- 100-130 Torq.- 15K GPM- 250 Off Btm PSI- 2700 Flow out- 7.6% ECD- 10.28 PPG P/U- 193K ICP-2780 - ECD-10.31 FCP-2600 - ECD- 10.16 26,030.0 23,485.0 8/26/2021 09:30 8/26/2021 10:30 1.00 PROD1, CASING OTHR P Work through high dog leg @ 23,485' and verify ability to slack off through dog leg 23,485.0 23,485.0 8/26/2021 10:30 8/26/2021 13:30 3.00 PROD1, CASING CIRC P Circ hi-vis sweep around w/ rotating & reciprocating pipe f/ 23,485' t/ 23,393' RPM-125 GPM-250 Torq- 14 k SPP 2550 FO 8.0 % ECD 10.06 P/U 174 k S/O 185 k Total pumped strokes = 11,842 23,485.0 23,485.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 48/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/26/2021 13:30 8/26/2021 17:30 4.00 PROD1, CASING STRP P SOOH f/ 23,485' - 20,444' w/ 4" DP racking back into the derrick. Monitored displacement on pits # 4 & 5. P/U 288k S/O 114k Pump #2 SPM 39 (Pump down back side) MPD back pressure while pulling = 125 psi MPD back pressure in slips = 40 psi Worked pipe througj high DLS and excursions. Worked BHA through the following interval of concern: 21,733’ – 21,478’ (Out of Zone depths) No signficant tight spots encountered while SOOH. . 23,485.0 20,400.0 8/26/2021 17:30 8/26/2021 23:30 6.00 PROD1, CASING STRP P SOOH f/ 20,444' - 15,114' w/ 4" DP racking back into the derrick. Monitored displacement on pits # 4 & 5. P/U 240k S/O 134k Pump #2 GPM 159 (Pump down back side) MPD back pressure while pulling = 108 psi MPD back pressure in slips = 30 psi Worked BHA through the following intervals of concern: 20,025’ – 19,865’ (Out of Zone depths) 18,900’ - 18,600’ (High 4.4 - 4.6 DLS) 16,893’ – 16,415’ (Out of Zone depths) 15,605’ – 15,467’ (Out of Zone depths) No signficant tight spots encountered while SOOH. . 20,400.0 15,114.0 8/26/2021 23:30 8/27/2021 00:00 0.50 PROD1, CASING OWFF P OWFF. Static. RPM 5 Flow back 4.5 bbls 23,485.0 23,485.0 8/27/2021 00:00 8/27/2021 03:45 3.75 PROD1, CASING STRP P SOOH f/ 15,114' - 12,174' w/ 4" DP racking back into the derrick. Monitored displacement on pits # 4 & 5. P/U 240k S/O 134k Pump #2 GPM 159 (Pump down back side) MPD back pressure while pulling = 100 psi MPD back pressure in slips = 30 psi Worked BHA through the following interval of concern: 14,510’ – 14,990’ (Out of Zone depths) No signficant tight spots encountered while SOOH. . 15,114.0 12,174.0 8/27/2021 03:45 8/27/2021 05:45 2.00 PROD1, CASING SLPC P Slipped and cut 80' of drill line. 12,174.0 12,174.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 49/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/27/2021 05:45 8/27/2021 10:30 4.75 PROD1, CASING STRP P SOOH f/ 12,174 t/ 6,642' w/ 4'' DP racking back in derrick, Monitoring displacement on pits 4 & 5 Pump #2 GPM 159 (Pump down back side) MPD back pressure while pulling = 100 psi MPD back pressure in slips = 30 psi 12,174.0 6,642.0 8/27/2021 10:30 8/27/2021 19:00 8.50 PROD1, CASING STRP P SOOH f/ 6,642' t/ BHA laying down singles t/ pipe shed. Monitored displacement on pits 4 & 5. P/U 64k S/O 67k Pump #2 GPM 159 (Pump down back side) MPD back pressure = 60 psi 6,642.0 316.0 8/27/2021 19:00 8/27/2021 20:45 1.75 PROD1, CASING OWFF P OWFF (Static). SIMOPS: clean and cleared rig floor. Moved centralizers and liner running equipment to the rig floor. Cleaned the pits. 316.0 316.0 8/27/2021 20:45 8/27/2021 22:30 1.75 PROD1, CASING MPDA P Removewd MPD bearing and installed trip nipple. 316.0 316.0 8/27/2021 22:30 8/28/2021 00:00 1.50 PROD1, CASING BHAH P Racked back 2 stands of 4" HWDP. f/ 316' - 131' MD. PJSM w/ BHA directional on handling sources.. L/D BHA #6 f/ 131' to surface. maintained constant hole fill over the top of the hole and monitored on trip pit #4. 316.0 0.0 8/28/2021 00:00 8/28/2021 01:30 1.50 PROD1, CASING CLEN P Cleaned and cleared rig floor. Removed BHI equipment. Removed beyond MPD equipment. SIMOPS: Washed the BOP stack and wellhead at 400 gpm w/ 84 psi SIMOPS- Rig up casing equip. 0.0 0.0 8/28/2021 01:30 8/28/2021 03:00 1.50 PROD1, CASING RURD P Rigged up to run liner w/ Doyon casing running equipment. Function tested equipment. 0.0 0.0 8/28/2021 03:00 8/28/2021 03:30 0.50 PROD1, CASING PUTB P PJSM, M/U silver bullet & 10' liner pup, & frac sleeve 0.0 14.0 8/28/2021 03:30 8/28/2021 06:00 2.50 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 14' t/ 2,016' top filling every joint & topping liner off every 15 joints Installing Arsenal polymer floating centralizers on every joint P/U 67k & S/O 70k @ 2,000'. Monitoring returns on pits 4&5 14.0 2,016.0 8/28/2021 06:00 8/28/2021 12:00 6.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 2,016' t/ 6,507' top filling every joint & topping liner off every 15 joints Installing Arsenal polymer floating centralizers on every joint P/U 114k & S/O 98k @ 6,300'. Monitoring returns on pits 4&5 2,016.0 6,507.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 50/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/28/2021 12:00 8/28/2021 18:00 6.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 6,507' t/ 11,422' top filling every joint & topping liner off every 15 joints. Installing Arsenal polymer floating centralizers on every joint P/U 127k & S/O 105k @ 11,422'. Monitoring returns on pits 4&5 6,507.0 11,422.0 8/28/2021 18:00 8/28/2021 19:00 1.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 11,422' t/ 12,004' top filling every joint & topping liner off every 15 joints. Installing Arsenal polymer floating centralizers on every joint P/U 185k & S/O 130k @ 12,004'. Monitoring returns on pits 4&5 11,422.0 12,004.0 8/28/2021 19:00 8/28/2021 19:30 0.50 PROD1, CASING SVRG P Rig service: Grease top drive, traveling blocks, service PS-21 slips, service and greased pipe skate prior to entering open hole. 12,004.0 12,004.0 8/28/2021 19:30 8/28/2021 20:30 1.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 12,004' t/ 12,209' top filling every joint & topping liner off every 15 joints. Installing Arsenal polymer floating centralizers on every joint P/U 185k & S/O 130k @ 12,209'. Monitoring returns on pits 4&5 12,004.0 12,209.0 8/28/2021 20:30 8/28/2021 21:30 1.00 PROD1, CASING CIRC P Circulated liner volume of 182 bbls. GPM 200 PSI 429 FO 5% Total pumped strokes = 2,166 12,209.0 12,209.0 8/28/2021 21:30 8/29/2021 00:00 2.50 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 12,209' t/ 14,255' top filling every joint & topping liner off every 15 joints. Installing Arsenal polymer floating centralizers on every joint Monitoring returns on pits 4&5 12,209.0 14,255.0 8/29/2021 00:00 8/29/2021 03:00 3.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per talley f/ 14,255' t/ 15,494'. P/U liner hanger assembly. Mixed and installed Zan plex gel. Installed Arsenal polymer floating centralizers on every joint Monitoring returns on pit #4. P/U 200k and S/O 112k @ 15,490'. 14,255.0 15,494.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 51/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/29/2021 03:00 8/29/2021 04:00 1.00 PROD1, CASING CIRC P P/U one stand of 14 ppf 4" DP f/ pipe rack and circualted one liner volume at 200 gpm. Staged up the pumps as follows: 100 gpm = 390 psi 125 gpm = 450 psi 150 gpm = 520 psi 175 gpm = 620 psi 200 gpm = 750 psi Pumped strokes pumped = 3000 FCP = 730 psi FO 9 % 15,494.0 15,494.0 8/29/2021 04:00 8/29/2021 06:00 2.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per detail f/ 15,494' t/ 17,865 w/ 4" DP f/ the derrick. Monitored displacement on pit #4. P/U 210k S/O 112k Filling on the fly and topping off every 5 stands. 15,494.0 17,865.0 8/29/2021 06:00 8/29/2021 12:00 6.00 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per detail f/ 17,865' t/ 23,689' w/ 4" DP f/ the derrick. Monitored displacement on pit #4. P/U 245k S/O 115k Filling on the fly and topping off every 5 stands. 17,865.0 23,689.0 8/29/2021 12:00 8/29/2021 14:15 2.25 PROD1, CASING PUTB P RIH w/ 4.5'' Liner, frac sleeves, & swell packers as per detail f/ 23,689' t/ 25,242' w/ 4" DP f/ the derrick. Monitored displacement on pit #4. P/U 275k S/O 88k Filling on the fly and topping off every 5 stands. Observed tight spot at 25,242'. Attempted to work pipe. P/U Wt 275k & Down Wt 42k. 23,689.0 25,242.0 8/29/2021 14:15 8/29/2021 18:00 3.75 PROD1, CASING CIRC T Circulated to clean up hole and attempted to work through ttight spot f/ 25,242' - 25,222'. Max Pull 300k GPM 121 / PSI 700/ FO 1.7% GPM 139 / PSI 886/ FO 4.3% GPM 174 / PSI 1145/ FO 7% Total pumped strokes = 9,478 Applied 8k torque as per Baker Hughes Rep. 25,242.0 25,242.0 8/29/2021 18:00 8/29/2021 18:45 0.75 PROD1, CASING PUTB T Attempted to slack off slowly through tight spot f/ 25,242' - 25,246' . Down weight f/ 122k to 66k. Attempted to pick up to 300k. Observed abrupt hookload loss f/ 291k to 194k at 25,277'. 25,242.0 25,242.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 52/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/29/2021 18:45 8/29/2021 21:15 2.50 PROD1, CASING WAIT T Waited on orders. Monitored well on pit #4. SIMOPS: MP2's, Cleaned pits, serviced ST-80, and PS-21 slips. Prepped for POOH. 25,242.0 25,242.0 8/29/2021 21:15 8/29/2021 22:00 0.75 PROD1, CASING CIRC T Staged up pumps to 139 gpm to compare to previously recorded pressures. (Ovserved) 139 gpm = 443 psi (Previous) 139 gpm = 806 psi Confirmed that the liner was detached from drill pipe string.. 25,242.0 25,242.0 8/29/2021 22:00 8/30/2021 00:00 2.00 PROD1, CASING TRIP T POOH f/ 9,743' - 5,940' w/ 4" DP racking back into the derrick. P/U Wt 218k - 159k S/O Wt 173k - 135k 9,743.0 5,940.0 8/30/2021 00:00 8/30/2021 00:30 0.50 PROD1, CASING TRIP T POOH to ~5,940' t/ 5,520' due t/ frac sleeve parting Monitor returns on pit #3 5,940.0 5,520.0 8/30/2021 00:30 8/30/2021 02:00 1.50 PROD1, CASING TRIP T TIH f/ 5,520' t/ 9,135' to rack 4'' HWDP where it could be pick up ahead of the 4'' drill pipe Monitor returns on pit #3 5,520.0 9,135.0 8/30/2021 02:00 8/30/2021 02:30 0.50 PROD1, CASING OTHR T Move 4'' HWDP t/ off driller side of racking board 9,135.0 9,135.0 8/30/2021 02:30 8/30/2021 07:00 4.50 PROD1, CASING TRIP T POOH f/ 9,135' t/ liner running tool due t/ frac sleeve parting Monitor returns on pit #3 9,135.0 1,694.0 8/30/2021 07:00 8/30/2021 07:30 0.50 PROD1, CASING OTHR T PJSM, R/U casing equipment 1,694.0 1,694.0 8/30/2021 07:30 8/30/2021 09:30 2.00 PROD1, CASING PULL T PJSM, L/D 4.5'' f/ 1,694' t/ Surface, Found #20 frac sleeve had parted at the bottom sub break on the frac sleeve 1,694.0 0.0 8/30/2021 09:30 8/30/2021 10:00 0.50 PROD1, CASING OTHR T PJSM, L/D casing equipment & clean rig floor after trip 0.0 0.0 8/30/2021 10:00 8/30/2021 10:30 0.50 PROD1, CASING TRIP T PJSM, M/U 6.5'' bit, bit sub, & cross over 0.0 0.0 8/30/2021 10:30 8/30/2021 11:30 1.00 PROD1, CASING TRIP T TIH w/ 4'' drill pipe f/ surface t/ 953' Monitoring returns on pit #3 0.0 953.0 8/30/2021 11:30 8/30/2021 12:00 0.50 PROD1, CASING SVRG T Rig service, grease TDS & drawworks & check oil in same 953.0 953.0 8/30/2021 12:00 8/30/2021 12:45 0.75 PROD1, CASING TRIP T TIH w/ 4'' drill pipe f/ 953' t/ 2,851' Monitoring returns on pit #3 953.0 2,851.0 8/30/2021 12:45 8/30/2021 17:00 4.25 PROD1, CASING SLPC T PJSM, Hung blocks. Slipped and cut 1,275' of drilling line. Unhung and calibrated blocks. Monitoring returns on pit #3 2,851.0 2,851.0 8/30/2021 17:00 8/30/2021 18:00 1.00 PROD1, CASING SVRG T Equipment service and maintenance. Monitoring returns on pit #3 2,851.0 2,851.0 8/30/2021 18:00 8/30/2021 20:30 2.50 PROD1, CASING WAIT T Waited on Baker fishing tools. SIMOPS: Replaced top drive rail wear pads. Blowed down injector lines. Cleaned lower tank room, BOP deck, and cellar. 2,851.0 2,851.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 53/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/30/2021 20:30 8/30/2021 22:00 1.50 PROD1, CASING TRIP T POOH f/ 2,851' to surface.w/ 4" DP racking back in the derrick. P/U 77k S/O 80k Monitoring displacement on pit #3 2,851.0 0.0 8/30/2021 22:00 8/30/2021 22:30 0.50 PROD1, CASING CLEN T Cleaned and cleared rig floor. Mobilized Baker fishing tools to the rig floor via beaver slide. 0.0 0.0 8/30/2021 22:30 8/31/2021 00:00 1.50 PROD1, CASING BHAH T M/U Fishing BHA as per Baker Fishing rep. 0.0 200.0 8/31/2021 00:00 8/31/2021 01:00 1.00 PROD1, CASING BHAH T Continued to build fishing BHA. Maintained constant hole fill over the top. Monitored displacement on pit #3. 200.0 418.0 8/31/2021 01:00 8/31/2021 06:00 5.00 PROD1, CASING TRIP T TIH to 9,675' w/ 4" DP racked back in the derrick. Moved HWDP out of the way. Resumed TIH to 10,358'. P/U 86k, S/O 90k @ 3,000'. Monitored displacement on trip tank. Filled pipe every 20 stands. 418.0 10,358.0 8/31/2021 06:00 8/31/2021 06:30 0.50 PROD1, CASING TRIP T TIH f/ 10,358' - 11,263' w/ 4" DP racked back in the derrick. Established baseline parameters. P/U 220k S/O 170k ROT 187k RPM 30 TQ 5k Monitored displacement on pit #3. 10,350.0 11,263.0 8/31/2021 06:30 8/31/2021 08:00 1.50 PROD1, CASING CIRC T Reciprocated f/ 11,263' - 11,358'. Circulated bottoms up at 280 gpm w/ 1015 psi. Total strokes = 4100 at 11,358'. 11,263.0 11,358.0 8/31/2021 08:00 8/31/2021 12:00 4.00 PROD1, CASING FISH T Tagged fish at 11,459'. Set 20k to engage spear. P/U 25k over to confirm that the fishing BHA was engaged. Slowly staged up mud pumps while keeping 60k overpull. 200 gpm w/ 2000 psi. Circulated through fish at 145 gpm w/ 1,525 psi. Staged up the pull limits at 10 k increments up to 360k while pumping at 105 gpm w/ 1,275 psi. Total strokes = 7,800. 11,358.0 11,459.0 8/31/2021 12:00 8/31/2021 16:00 4.00 PROD1, CASING FISH T Attempted to pull fish. Max pull = 390k. Minimum slack off = 250k. 11,459.0 11,459.0 8/31/2021 16:00 8/31/2021 19:30 3.50 PROD1, CASING CIRC T Unstung from the fish and pulled to 11,417'. CBU. GPM 196 PSI 1089 FO 6% P/U 220k S/O 168k Total strokes = 7517 SIMOPS: Swapped rig from generator power to Hi-Line Power at 1630hr. 11,459.0 11,417.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 54/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/31/2021 19:30 8/31/2021 20:30 1.00 PROD1, CASING TRIP T POOH f/ 11,417' - 9,714' w/ 4" racked back in the derrick. P/U 200k S/O 160k Monitored displacement on pit #3. 11,417.0 9,714.0 8/31/2021 20:30 8/31/2021 21:00 0.50 PROD1, CASING CIRC T Pumped 25 bbl dry job. B/D top drive. 9,714.0 9,714.0 8/31/2021 21:00 9/1/2021 00:00 3.00 PROD1, CASING TRIP T POOH f/ 9,714' - 3,994' w/ 4" racked back in the derrick. Monitored displacement on pit #3. 9,714.0 3,994.0 9/1/2021 00:00 9/1/2021 02:30 2.50 PROD1, CASING TRIP T POOH f/ 3,994' - surface' w/ 4" racked back in the derrick. Monitored dsiplacement on pit #3. 3,994.0 0.0 9/1/2021 02:30 9/1/2021 03:30 1.00 PROD1, CASING BHAH T L/D Fishing BHA. 0.0 0.0 9/1/2021 03:30 9/1/2021 04:00 0.50 PROD1, CASING CLEN P Cleaned and cleared rig floor. Pulled wear bushing. 0.0 0.0 9/1/2021 04:00 9/1/2021 07:00 3.00 PROD1, CASING RURD P Washed the stack. Filled stack and choke manifold w/ H2O. Stack would not fill up so pulled test plug and found seal had rolled out of groove 0.0 0.0 9/1/2021 07:00 9/1/2021 12:00 5.00 PROD1, WHDBOP BOPE P Test BOPE: All tests to 250 psi low for 5 minutes, 3500 psi high for 10 minutes charted minimum w/ exception of manual operated Super Choke 2000 psi show bleed and hold pressure, with 4" test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, with 4 ½” test joint test annular. Test choke valves 1- 15, choke & kill manuals & HCR's, 4" valve on kill line. Two 4" FOSV, two 4" dart valve, performed Koomey drawdown, ACC = 3050 psi. Manifold = 1500 psi. ACC - 1500 psi after all functions on the bottles, 9 secs for 200 psi. Build w/ 2 electric pumps, 104 secs to build full system pressure w/ 2 electric & 2 air pumps. Closing times annular = 23 secs, UPR 18 secs, Blind/Shears = 16 secs, LPR 16 secs, Choke HCR = 2 secs, Kill HCR = 2 secs, Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Rep Jeff Jones waived witness at 20:31 hrs 8/31/2021. 0.0 0.0 9/1/2021 12:00 9/1/2021 13:00 1.00 PROD1, CASING RURD P PJSM, R/D BOP testing equipment 0.0 0.0 9/1/2021 13:00 9/1/2021 14:00 1.00 PROD1, CASING OTHR P Pull master bushings & reseal the joe's box 0.0 0.0 9/1/2021 14:00 9/1/2021 18:00 4.00 PROD1, CASING RURD T PJSM. Mobilized SLB wireline running equipment to rig floor and rig up same. Waited on WellTec Tools. 0.0 0.0 9/1/2021 18:00 9/1/2021 20:45 2.75 PROD1, CASING RURD T Welltec assembled and tested tools. SIMOPS: Rig maintenance. Clean up PS-21's. 0.0 0.0 9/1/2021 20:45 9/2/2021 00:00 3.25 PROD1, CASING ELNE T P/U and M/U WellTec cutter wireline tools. RIH w/ wireline. Monitored well and displacement w/ hole fill on pit #3. Tools below rotary table at 21:30 hr. RIH on wireline to 12,201'. Tractored through frac sleeve t/ 12,257'. Performed multiple attempts to get past obstruction to no avail. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 55/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/2/2021 00:00 9/2/2021 02:30 2.50 PROD1, CASING ELNE T Performed multiple attempts to get past obstruction w/ Welltec Cutter on e-line at 12,257' to no avail. Discussed options w/ WSC and management. Attempted to drift pass frac sleeve at 300 fpm (unsuccessful). Both SLB and Welltec stated that the obstruction seems to have characteristics of fill/debris and not a solid obstruction. 0.0 0.0 9/2/2021 02:30 9/2/2021 04:15 1.75 PROD1, CASING ELNE T Strategized with WSC and management regarding options for retrieving liner. 0.0 0.0 9/2/2021 04:15 9/2/2021 06:00 1.75 PROD1, CASING ELNE T Situated Welltec Cutter.at ~12,212'. and performed a cut with Welltec Cutter below the frac sleeve. 0.0 0.0 9/2/2021 06:00 9/2/2021 07:30 1.50 PROD1, CASING ELNE T Completed cut. POOH w/ wireline and L/D Welltec cutter tools. Monitored well on pit #3 w/ constant hole fill on top. Observed that the Welltec cutter had significant residual Safe Carb packed in the tool indicating that the the weighting agent in the mud might have fall off suspension and packed up in the liner. 0.0 0.0 9/2/2021 07:30 9/2/2021 08:30 1.00 PROD1, CASING RURD T R/D wireline and Welltec cutting tool. Cleared wireline tools f/ rig floor. 0.0 0.0 9/2/2021 08:30 9/2/2021 09:15 0.75 PROD1, CASING BHAH T P/U spear fishing BHA. Monitored well on pit #3 w/ constant hole fill on top. BHA Weight = 60k. 0.0 0.0 9/2/2021 09:15 9/2/2021 12:00 2.75 PROD1, CASING TRIP T RIH w/ 4" DP stands from the derrick f/ surface - 6,595' MD. Filled pipe every 20 stands. Monitored displacement on pit #3. P/U 140k & S/O 126k @ 6,500' MD. 0.0 6,595.0 9/2/2021 12:00 9/2/2021 14:00 2.00 PROD1, CASING TRIP T RIH w/ 4" DP stands from the derrick f/ 6,595' - 11,357' MD. Filled pipe every 20 stands. Monitored displacement on pit #3. P/U 218k S/O 172k RTW 194k TQ 4.5k GPM 103 SPP 400 6,595.0 11,357.0 9/2/2021 14:00 9/2/2021 14:30 0.50 PROD1, CASING FISH T RIH to top of fish at 11,459' MD. Latched onto fish. Observed 42k overpull. P/U 260k w/ fish. 11,357.0 11,459.0 9/2/2021 14:30 9/2/2021 18:00 3.50 PROD1, CASING TRIP T OWFF. Blowed down top drive. POOH w/ fish f/ 11,459' - 8,117' MD w/ 4" DP racked back in the derrick. Monitored displacement on pit #3. Filled pipe w/ fill up hose. P/U 180k 11,459.0 8,117.0 9/2/2021 18:00 9/3/2021 00:00 6.00 PROD1, CASING TRIP T OWFF. Blowed down top drive. POOH w/ fish f/ 8,117' - surface w/ 4" DP racked back in the derrick. Monitored displacement on pit #3. Filled pipe w/ fill up hose. P/U 180k 8,117.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 56/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/3/2021 00:00 9/3/2021 00:45 0.75 PROD1, CASING BHAH T Continued to break down fishing BHA. Released spear from top of the 4 1/2" liner fish. 0.0 0.0 9/3/2021 00:45 9/3/2021 01:00 0.25 PROD1, CASING RURD T R/U 4.5" liner running equipment: Tongs, elevators, slips. 0.0 0.0 9/3/2021 01:00 9/3/2021 02:30 1.50 PROD1, CASING PULD T Laid down the following fished liner components: #20 Frac Sleeve Pup joint 17 joints of 4 1/2" Liner H563 1 Swell packer (Rubber deteriorated) #19 Frac Sleeve w/ 4.40' cut on pup joint Total Length of Fish (TLOF) = 753.99' Monitored hole fill on trip pit #3. Discussed the path forward with management. Concerns surfaced regarding the fact that a large amount of rubber came off the Swell Packer. The damaged swell packer introduce an additional risk for wireline operations as the liner would be plugged up with a significant amount of rubber. 0.0 0.0 9/3/2021 02:30 9/3/2021 03:00 0.50 PROD1, CASING RURD T Rigged down liner running equipment, L/D spear fishing equipment from rig floor. Picked up Baker fishing equipment. 0.0 0.0 9/3/2021 03:00 9/3/2021 04:00 1.00 PROD1, CASING BHAH T Made up fishing BHA w/ overshot. 0.0 0.0 9/3/2021 04:00 9/3/2021 10:00 6.00 PROD1, CASING TRIP T RIH w/ fishing BHA w/ overshot at a projected depth of 12,175'. Monitor returns on pit #3 & fill pipe every 20 stands 0.0 12,175.0 9/3/2021 10:00 9/3/2021 10:30 0.50 PROD1, CASING CIRC T Establish base line parameters before latching onto fish P/U-221K S/O-176K Rot-196K GPM-500 PSI-3080 GPM-140 PSI-415 12,175.0 12,175.0 9/3/2021 10:30 9/3/2021 11:30 1.00 PROD1, CASING CIRC T Circ & cond. w/ working pipe f/ 12,175' t/ 12,145' GPM-500 PSI-3080 On bottoms up observed pieces of suspected swell packer @ shakers 12,175.0 12,175.0 9/3/2021 11:30 9/3/2021 13:30 2.00 PROD1, CASING FISH T Wash & ream down dressing off top of fish at 12,212'. RPM-5-10 Torq-3-5 GPM-140 PSI-400 When fished was engaged pump pressure increased t/ 800 psi and returns was lost @ shakers 12,175.0 12,212.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 57/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/3/2021 13:30 9/3/2021 14:30 1.00 PROD1, CASING FISH T Attempt to work fish free at 12,212' by working string down t/ 200K and back up t/ 450K Weight was brought up in 10K increments each time string was worked 12,212.0 12,212.0 9/3/2021 14:30 9/3/2021 18:00 3.50 PROD1, CASING OTHR T Monitor well on pit#2 w/ waiting on orders 12,212.0 12,212.0 9/3/2021 18:00 9/4/2021 00:00 6.00 PROD1, CASING FISH T Continued to attempt to separate liner at frac sleeve w/ fishing assembly at 12,212' by working string hookload down t/ 45K and back up t/ 480K Weight was brought up in 10K increments each time string was worked. 12,212.0 12,212.0 9/4/2021 00:00 9/4/2021 01:30 1.50 PROD1, CASING FISH T Continued to attempt to separate liner at frac sleeve w/ fishing assembly at 12,212' by working string hookload down t/ 45K and back up t/ 480K 12,212.0 12,212.0 9/4/2021 01:30 9/4/2021 02:00 0.50 PROD1, CASING CIRC T Established bullheading parameters at 12,212'. 60 gpm = 1150 psi 100 gpm = 1250 psi 125 gpm = 1325 psi 150 gpm = 1475 psi 200 gpm = 1740 psi Bullheaded 20 bbls. 12,212.0 12,212.0 9/4/2021 02:00 9/4/2021 02:45 0.75 PROD1, CASING CIRC T Spotted Citric Acid Pill as follows: Pumped 10 bbls Visc Brine, 25 bbls of 30% Citric Acid Pill, and 10 bbls Visc Brine. Displaced pill out of the drillstring and into the liner w/ 114.5 bbls ICP 1740 psi FCP 1796 psi 12,212.0 12,212.0 9/4/2021 02:45 9/4/2021 03:15 0.50 PROD1, CASING FISH T Disengaged overshot from 4 1/2" Liner Fish. 12,212.0 12,212.0 9/4/2021 03:15 9/4/2021 03:45 0.50 PROD1, CASING OWFF T OWFF (Static). Blowed down top drive. 12,212.0 12,212.0 9/4/2021 03:45 9/4/2021 09:00 5.25 PROD1, CASING TRIP T POOH w/ fishing BHA f/ 12,212' t/ BHA w/ monitoring fill ups on pit #3 12,212.0 412.0 9/4/2021 09:00 9/4/2021 10:00 1.00 PROD1, CASING BHAH T PJSM, break down Baker fishing BHA, inspect grapple & overshot 412.0 0.0 9/4/2021 10:00 9/4/2021 11:15 1.25 PROD1, CASING SLPC P PJSM, slip & cut drill line, 97' cut, recalibrate amphion & crown saver 0.0 0.0 9/4/2021 11:15 9/4/2021 12:00 0.75 PROD1, CASING BHAH T PJSM, move 4'' HWDP around in derrick, M/U over shot & grapple and TIH w/ DP f/ surface to 291' w/ 4" DP racked back in derrick. P/U 58k, S/O 50k @ 250', Monitored displacement on trip pit #3. 0.0 291.0 9/4/2021 12:00 9/4/2021 12:45 0.75 PROD1, CASING TRIP T TIH f/ BHA t/ 1,613', Monitoring returns on pit #3. P/U 78k S/O 82k 291.0 1,613.0 9/4/2021 12:45 9/4/2021 13:15 0.50 PROD1, CASING SVRG P Inspect drill line, Serviced top drive, blocks, and crown. 1,613.0 1,613.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 58/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/4/2021 13:15 9/4/2021 13:45 0.50 PROD1, CASING TRIP T TIH f/ 1,613' t/ 2,002', Monitoring returns on pit #3. P/U 84k S/O 86k 1,613.0 2,002.0 9/4/2021 13:45 9/4/2021 15:00 1.25 PROD1, CASING SLPC T Hung blocks and performed slip and cut. Line cut 32'. Unhung blocks and calibrated Amphion and Pason. 2,002.0 2,002.0 9/4/2021 15:00 9/4/2021 20:30 5.50 PROD1, CASING TRIP T TIH f/ 2,002' t/ 12,120', Monitoring returns on pit #3. P/U 176k S/O 218k 2,002.0 12,120.0 9/4/2021 20:30 9/4/2021 21:30 1.00 PROD1, CASING FISH T Attempted to engage w/ fish. Rotated at 10 rpm. Dressed top of fish at 12,200'. GPM 140 PSI 390 FO 4-5% TQ 3-4kftls Total pump strokes = 2,068 12,120.0 12,119.0 9/4/2021 21:30 9/4/2021 22:30 1.00 PROD1, CASING TRIP T Pipe Management: R/B stand. P/U 10' + 15' pup for e-line space out and RIH to 12,198'.. Began circulating Observed gas reading increased to 2,500 units.MAX. 12,119.0 12,198.0 9/4/2021 22:30 9/4/2021 23:30 1.00 PROD1, CASING CIRC T CBU @ 12,198'. GPM 490 PSI 2600 FO 21% Total Pumped strokes = 4,550 12,198.0 12,198.0 9/4/2021 23:30 9/5/2021 00:00 0.50 PROD1, CASING FISH T Continued to dress liner top at 12,,200' GPM 140-235 PSI 520-795 FO 4-9% RPM 10 TQ 311kftls 12,198.0 12,200.0 9/5/2021 00:00 9/5/2021 02:30 2.50 PROD1, CASING FISH T Dressed the top of fish at 12,200'. Eventually latched on and pulled to 300k confirmed that the fishing BHA was engaged with the liner. Overshot seal was compromised. RPM 40 GPM 142 PSI 400 P/U 218k S/O 176k 12,200.0 12,200.0 9/5/2021 02:30 9/5/2021 03:45 1.25 PROD1, CASING CIRC T Closed the bag and bullheaded 10 bbls of Vis Brine and 175 bbls of 9.0 ppg clear brine into the string. PSI 1700-1885 GPM 221 FO: 0% - Trace 12,200.0 12,200.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 59/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/5/2021 03:45 9/5/2021 06:00 2.25 PROD1, CASING SIPB T After bullheading observed 1,014 psi on the DP. 1014 psi 979 psi 758 psi. Total 86 bbls bled back. Float never closed. Formation possibly ballooning back. 12,200.0 12,200.0 9/5/2021 06:00 9/5/2021 07:00 1.00 PROD1, CASING SIPB T Found bad transducer on casing psi sensor, changed out sensor & observed 694 psi on casing matching SPP on drill pipe. Decision made to do bleed cycles to confirm well was ballooning from bullheading fluid into formation 12,200.0 12,200.0 9/5/2021 07:00 9/5/2021 09:30 2.50 PROD1, CASING SIPB T Started bleed down cycles bleeding back 1bbl increments and monitoring psi f/ 5 minutes f/ stabilization of psi Casing psi @ start of bleed procedure was 694 psi after the last 5 minute wait peroid casing psi stabilized @ 361psi Discussion was had with supervision and decision was made to bleed well down off pressure and wait for 10 minutes for pressure to stabilize to determine well was ballooning and not gas migration 12,200.0 12,200.0 9/5/2021 09:30 9/5/2021 10:30 1.00 PROD1, CASING SIPB T Started bleed down cycles bringing casing psi down t/ 150 psi and monitoring pressure f/ 10 min for pressure t/ stabilize Casing psi started @ 361 psi after the last 10 minute wait peroid casing psi stabilized @ 263 Discussion was had with supervision and everyone was in agreement formation was ballooning so decision was made to line well up on trip tanks and open well up and monitor flow. 12,200.0 12,200.0 9/5/2021 10:30 9/5/2021 11:00 0.50 PROD1, CASING OWFF T Monitored well on trip tank after opening up annular Flowed backed 2 bbls and returns slacked off to a no flow and well was static 12,200.0 12,200.0 9/5/2021 11:00 9/5/2021 12:30 1.50 PROD1, CASING RURD T PJSM, rig up SLB wireline & pick up Well Tech tractor & mechanical cutter 12,200.0 12,200.0 9/5/2021 12:30 9/5/2021 15:30 3.00 PROD1, CASING ELNE T RIH w/ Well Tech tractor & tractor on SLB e-line f/ 39' t/ 12,985' Stopping every 3,000' and getting pick up tension on wireline Monitoring returns on pit #3. 12,200.0 12,200.0 9/5/2021 15:30 9/5/2021 17:00 1.50 PROD1, CASING ELNE T Space out e-line and comfirm depths with collar locator on Well tech tractor, Confirmed depth of 12,985' & made cut of line w/ Well tech cutter 12,200.0 12,200.0 9/5/2021 17:00 9/5/2021 18:30 1.50 PROD1, CASING ELNE T POOH w/ Welltec Cutter on e-line. Maintained hole fill over the top monitoring displacement on pit #3. 12,200.0 12,200.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 60/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/5/2021 18:30 9/5/2021 19:00 0.50 PROD1, CASING RURD T PJSM. R/D e-liner and Welltec Tractor and Cutter. Maintained hole fill over the top monitoring displacement on pit #3. 12,200.0 12,200.0 9/5/2021 19:00 9/5/2021 20:00 1.00 PROD1, CASING FISH T Fishing: Initial max P/U 340k w/o break over. Worked string to deteriorate swell packer. Confirmed cut w/ initial breakover pick up of 320k. Continued to work string. R/B and L/D space out joints. 12,985.0 12,985.0 9/5/2021 20:00 9/5/2021 22:00 2.00 PROD1, CASING CIRC T Circulated clear brine out of the hole and mixed w/ FloPro until 9.0 ppg even in/out at 12,771'. GPM 210 PSI 645 FO 8% P/U 224k S/O 167k Total Pumped Strokes = 6,857 12,985.0 12,771.0 9/5/2021 22:00 9/5/2021 22:30 0.50 PROD1, CASING OWFF T OWFF (Static). 12,771.0 12,771.0 9/5/2021 22:30 9/6/2021 00:00 1.50 PROD1, CASING TRIP T POOH f/12,771' - 11,850' w/4" DP racked back in the derrick. P/U 224k Monitored displacement on Trip Pit. 12,771.0 11,850.0 9/6/2021 00:00 9/6/2021 07:00 7.00 PROD1, CASING TRIP T POOH w/ 4.5'' fish f/ 11,850' t/ grapple Monitored displacement on Trip Pit. 11,850.0 750.0 9/6/2021 07:00 9/6/2021 07:30 0.50 PROD1, CASING PULD T PJSM, L/D over shot, grapple, & 4.5'' cut pup joint Could not get grapple to release f/ 4.5'' liner pup Pup will be sent t/ Baker's shop to cut overshot & grapple off cut piece 750.0 750.0 9/6/2021 07:30 9/6/2021 07:45 0.25 PROD1, CASING PULD T R/U casing equipment t/ lay down 4.5'' liner 750.0 750.0 9/6/2021 07:45 9/6/2021 08:15 0.50 PROD1, CASING PULD T L/D 4.5'' liner f/ 750' t/ surface Keeping constant hole fill and monitoring returns on pit #3 750.0 0.0 9/6/2021 08:15 9/6/2021 09:00 0.75 PROD1, CASING PULD T PJSM, R/D casing equipment, Break apart fishing jars & clean rig floor 0.0 0.0 9/6/2021 09:00 9/6/2021 09:15 0.25 PROD1, CASING BHAH T M/U mule shoe & float sub 0.0 6.0 9/6/2021 09:15 9/6/2021 13:00 3.75 PROD1, CASING TRIP T TIH f/ 6' t/ 5,989' w/ 4'' drill pipe t/ lay down joints of drill pipe with worn down hard band Monitor hole displacement on pit#3 6.0 5,989.0 9/6/2021 13:00 9/6/2021 13:30 0.50 PROD1, CASING TRIP T POOH f/ 5,989' t/ 5,324' w/ 4'' drill pipe racking back stands of pipe with gauged hard band Monitor hole fill on pit #4 5,989.0 5,324.0 9/6/2021 13:30 9/6/2021 21:30 8.00 PROD1, CASING TRIP T Pump 10.1 ppg dry job. L/D single 4" DP f/ 5,324' - surface. Monitor displacement w/ constant hole fill via pit #4. 5,324.0 0.0 9/6/2021 21:30 9/6/2021 22:15 0.75 PROD1, CASING OWFF T OWFF (Static). L/D mule shoe, crossover, and float. Cleaned and cleared rig floor. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 61/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/6/2021 22:15 9/7/2021 00:00 1.75 PROD1, CASING BHAH T PJSM. M/U Drilling BHA #12. 0.0 100.0 9/7/2021 00:00 9/7/2021 01:00 1.00 PROD1, CASING BHAH T PJSM. M/U Drilling BHA #12. Loaded sources and RIH w/ 2 stands of HWDP. Monitored displacement at pit #3. 100.0 286.0 9/7/2021 01:00 9/7/2021 06:00 5.00 PROD1, CASING TRIP T TIH w/ Directional RSS BHA while P/U 4" DP to a depth of 3,800' P/U 107k S/O 103k Monitored displacement at pit #3. 286.0 3,800.0 9/7/2021 06:00 9/7/2021 12:00 6.00 PROD1, CASING TRIP T TIH w/ Directional RSS BHA while P/U 4" DP to a depth of 9,870' P/U 176k S/O 141k DEPTH 8,300' Monitored displacement at pit #3. 3,800.0 9,870.0 9/7/2021 12:00 9/7/2021 13:45 1.75 PROD1, CASING TRIP T TIH w/ Directional RSS BHA while P/U 4" DP f/ derrick to a depth of 12,200' P/U 224k S/O 154k DEPTH 12,150' Monitored displacement at pit #3. 9,870.0 12,200.0 9/7/2021 13:45 9/7/2021 14:00 0.25 PROD1, CASING CIRC T Obtained SPM's and baseline parameters inside casing. 12,200.0 12,200.0 9/7/2021 14:00 9/7/2021 14:30 0.50 PROD1, CASING TRIP T Observed excess drag outside shoe. Increased to 27k at 12,273'. Observed up to 50k overpull at 12,262' and 12,248'. Also observed a 600 psi increase. 12,200.0 12,240.0 9/7/2021 14:30 9/7/2021 18:30 4.00 PROD1, CASING REAM T Reamed in hole f/ 12,240'- 12,560'. WOB 2-3k GPM 253 PSI 1480 RPM 80 TQ 5-8k FO 11% ECD 9.6 Observed rubber (Swell Packer material) after bottoms up. Tight area w/ excessive torque cleared at 12,338'. 12,240.0 12,560.0 9/7/2021 18:30 9/7/2021 21:30 3.00 PROD1, DRILL REAM T Troughed t/ kick off lateral redrill 6 1/2" production hole f/ 12,518 - 12,540'. WOB 0k GPM 256 PSI 1530 RPM 40-100 TQ On 5k FO 12% ECD 9.46 RTW 190k DEPTH 12,540' 12,518.0 12,540.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 62/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/7/2021 21:30 9/8/2021 00:00 2.50 PROD1, DRILL DDRL T Time driled (sidetracking) f/ 12,540' - 12,541'. WOB 0k GPM 220 PSI 1240 RPM 100 TQ On 5k FO 8% ECD 9.46 RTW 191k ADT 2hrs Total Bit Hours 2hrs 12,540.0 12,541.0 9/8/2021 00:00 9/8/2021 06:00 6.00 PROD1, DRILL DDRL T Time drill 6.5'' Lateral f/ 12,541' t/ 12,547' - Open hole side track WOB 0 RPM-100 Torq-5.8K GPM-220 PSI-1242 FO 11% ECD 9.46 RTW 191k ADT 6 hrs Total Bit Hours 8 hrs 12,541.0 12,547.0 9/8/2021 06:00 9/8/2021 12:00 6.00 PROD1, DRILL DDRL T Time drill 6.5'' Lateral f/ 12,547' t/ 12,560' - Open hole side track WOB 0 RPM-100 Torq-6K GPM-220 PSI-1251 FO 11% ECD 9.49 RTW 190k ADT 6 hrs Total Bit Hours 14 hrs 12,547.0 12,560.0 9/8/2021 12:00 9/8/2021 18:00 6.00 PROD1, DRILL DDRL T Time drill 6.5'' Lateral f/ 12,560' t/ 12,586' - Open hole side track WOB 3 RPM-130 Torq-7K GPM-220 PSI-1251 FO 11% ECD 9.49 RTW 185k ADT 5.9 hrs Total Bit Hours 19.9 hrs 12,560.0 12,586.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 63/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/8/2021 18:00 9/9/2021 00:00 6.00 PROD1, DRILL DDRL T Control drill 6.5'' Lateral f/ 12,586' t/ 12,714' - Open hole side track WOB 13 RPM-150 Torq-6K GPM-220 PSI-1530 FO 11% ECD 9.63 RTW 190k ADT 5.5 hrs Total Bit Hours 25.4 hrs 12,586.0 12,714.0 9/9/2021 00:00 9/9/2021 02:30 2.50 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 12,714' t/ 12,907' - Open hole side track. WOB 18 RPM-150 Torq-6K GPM-275 PSI-1845 FO- 15% ECD- 9.82 P/U- 225k S/O- 161k RT- 181k 12,714.0 12,907.0 9/9/2021 02:30 9/9/2021 03:30 1.00 PROD1, DRILL MPDA T OWFF. B/D hole fill line and drain pipe. Removed the trip nipple and installed MPD bearing. Established circulation through MPD equipment. Flow rate = 250 gpm w/ 1560 psi. 12,907.0 12,907.0 9/9/2021 03:30 9/9/2021 06:00 2.50 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 12,907' t/ 13,188' WOB- 17-20 RPM-150 Torq-11K GPM-275 PSI-1900 FO 15% ECD 9.80 P/U- 225k S/O- 161k RT- 181k MPD connection back pressure 0 psi ADT-4.1 TBH-29.5 12,907.0 13,188.0 9/9/2021 06:00 9/9/2021 12:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 13,188' t/ 13,853' WOB- 20-25 RPM-150 Torq-11K Off-6K GPM-275 PSI-1990 FO 15% ECD- 10.02 P/U- 225k S/O- 160k RT- 183k MPD connection back pressure 20 psi ADT-5.0 TBH-34.5 13,188.0 13,853.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 64/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/9/2021 12:00 9/9/2021 18:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 13,853' t/ 14,612' WOB- 20-24 RPM-150 Torq-12K Off-9K GPM-275 PSI-2146 FO 14% ECD- 10.23 P/U- 227k S/O- 155k RT- 186k MPD connection back pressure 20 psi ADT-4.4 TBH-38.9 13,853.0 14,612.0 9/9/2021 18:00 9/10/2021 00:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 14,612' t/ 15,450 WOB- 20-24 RPM-150 Torq-13K Off-9K GPM-275 PSI-2160 FO 15% ECD- 10.33 P/U- 230k S/O- 148k RT- 178k MPD connection back pressure 25 psi ADT-4.6 TBH-43.5 Observed 20 bbls losses at ~15,343'. 14,612.0 15,450.0 9/10/2021 00:00 9/10/2021 06:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 15,450' t/ 16,259' WOB- 20-24 RPM-150 Torq-13K Off-9K GPM-250 PSI-2080 FO 15% ECD- 10.37 P/U- 230K S/O- 147K RT- 180K MPD connection back pressure 165 psi ADT-4.3 TBH-47.8 Observed 20 bbls losses at ~15,343'. After possibly crossing a fault at ~15,510', started to observe varying degrees of partial losses up to 100 bph. Started to increase system background LCM w/ 7 sxs/hr Medium Nut Plug + 8 sxs/hr Safe Carb 250. 15,450.0 16,260.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 65/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/10/2021 06:00 9/10/2021 12:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 16,259' t/ 16,960' WOB- 20-25 RPM-150 Torq-12K Off-6K GPM-275 PSI-2400 FO 15% ECD- 10.55 P/U- 229K S/O- 143K RT- 178K MPD connection back pressure 200 psi ADT-4.6 TBH-52.4 Observed 20 bbls losses at ~15,343'. After possibly crossing a fault at ~15,510', started to observe varying degrees of partial losses up to 100 bph. Started to increase system background LCM w/ 7 sxs/hr Medium Nut Plug + 8 sxs/hr Safe Carb 250. 16,260.0 16,960.0 9/10/2021 12:00 9/10/2021 18:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 16,960' t/ 17,747' WOB- 20-25 RPM-150 Torq-13K Off-9K GPM-275 PSI-2530 FO 15% ECD- 10.69 P/U- 238K S/O- 144K RT- 189K MPD connection back pressure 260 psi ADT-4.3 TBH-56.7 After possibly crossing a fault at ~15,510', started to observe varying degrees of partial losses up to 100 bph. System background LCM w/ 2 sxs/hr Fine Nut Plug +2 sxs/hr Mix II Medium + 10 sxs/hr Safe Carb 250. 16,960.0 17,474.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 66/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/10/2021 18:00 9/11/2021 00:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 17,474' t/ 18,390' WOB- 20-25 RPM-150 Torq-13K Off-9K GPM-275 PSI-2640 FO 15% ECD- 10.63 P/U- 236K S/O- 141K RT- 189K MPD connection back pressure 260 psi ADT-4.4 TBH-61.1 After possibly crossing a fault at ~15,510', started to observe varying degrees of partial losses up to 100 bph. System background LCM w/ 2 sxs/hr Fine Nut Plug +2 sxs/hr Mix II Medium + 10 sxs/hr Safe Carb 250. 17,474.0 18,390.0 9/11/2021 00:00 9/11/2021 06:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 18,390' t/ 19,174' WOB- 20-25 RPM-150 Torq-15K Off-10K GPM-275 PSI-2835 FO 15% ECD- 10.78 P/U- 245K S/O- 126K RT- 175K MPD connection back pressure 230-300 psi ADT-4.3 TBH-65.4 Losses averaging 15 bbls per/hr 18,390.0 19,174.0 9/11/2021 06:00 9/11/2021 12:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 19,174' t/ 19,789' WOB- 20-25 RPM-150 Torq-15K Off-9K GPM-275 PSI-2850 FO 17% ECD- 10.89 P/U- 255K S/O- 112K RT- 176K MPD connection back pressure 260-285 psi ADT-3.4 TBH-68.8 Losses averaging 15 bbls per/hr 19,174.0 19,789.0 9/11/2021 12:00 9/11/2021 12:30 0.50 PROD1, DRILL CIRC T Trouble shoot RSS steering rib failure, down link t/ tool multiple times with no response f/ tool, Decision made to TOH 19,789.0 19,789.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 67/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/11/2021 12:30 9/11/2021 14:30 2.00 PROD1, DRILL CIRC T Circ wellbore clean w/ rotating & reciprocating pipe f/ 19,775' t/ 19,720' RPM-150 Torq-10K GPM-270 PSI-2680 ECD-10.46 19,789.0 19,720.0 9/11/2021 14:30 9/11/2021 15:00 0.50 PROD1, DRILL OWFF T Finger print well f/ ballooning @ 19,720' w/ rotating pipe @ 5 rpm's, torq-9K Initial PSI-210 Final PSI-170 Bled back 1/2 bbl per bleed sequence 19,720.0 19,720.0 9/11/2021 15:00 9/11/2021 15:30 0.50 PROD1, DRILL OWFF T Flow check well on shaker f/ 30 min. Well bled back 8.5 bbls & had a no flow 19,720.0 19,720.0 9/11/2021 15:30 9/11/2021 18:30 3.00 PROD1, DRILL SMPD T SOOH f/ 19,720' t/ 16,800' MD. 235 k Up Wt. MPD holding 300 psi w/ pulling & 50 psi w/ in slips 19,720.0 16,800.0 9/11/2021 18:30 9/11/2021 20:00 1.50 PROD1, DRILL SMPD T SOOH laying down singles f/ 16,800' t/ 15,848' MD. 224 k Up Wt. MPD holding 300 psi w/ pulling & 50 psi w/ in slips 16,800.0 15,848.0 9/11/2021 20:00 9/11/2021 22:30 2.50 PROD1, DRILL SMPD T SOOH f/ 15,848' t/ 12,433' MD. 224 k Up Wt. MPD holding 300 psi w/ pulling & 50 psi w/ in slips 15,848.0 12,433.0 9/11/2021 22:30 9/11/2021 23:00 0.50 PROD1, DRILL TRIP T Trip in the hole f/ 12,433' t/ 13,027' MD to verify BHA would freely enter side track. 220 k Up Wt, 145 k Dn Wt. MPD open w/ running in at 50 psi w/ in slips 12,433.0 13,027.0 9/11/2021 23:00 9/12/2021 00:00 1.00 PROD1, DRILL SMPD T SOOH f/ 13,027' t/ 12,208' MD. 220 k Up Wt. MPD holding 300 psi w/ pulling & 50 psi w/ in slips 13,027.0 12,208.0 9/12/2021 00:00 9/12/2021 01:00 1.00 PROD1, DRILL OWFF T Observe well for flow, (static) 12,208.0 12,208.0 9/12/2021 01:00 9/12/2021 11:00 10.00 PROD1, DRILL SMPD T SOOH f/ 12,208' t/ 286' MD. 220 k Up Wt. MPD holding 300 psi w/ pulling & 50 psi w/ in slips 12,208.0 286.0 9/12/2021 11:00 9/12/2021 11:45 0.75 PROD1, DRILL OWFF T Observed well for flow before racking back last stand of drill pipe, Well static 286.0 286.0 9/12/2021 11:45 9/12/2021 14:15 2.50 PROD1, DRILL BHAH T PJSM, Rack back HWDP, L/D XO, float sub, & filter sub, Pull radio active sources, Break bit, L/D MWD & RSS Found 4- 1/4'' bolts missing on steering ribs of RSS Monitor returns on pit #2 while handling BHA 286.0 0.0 9/12/2021 14:15 9/12/2021 14:45 0.50 PROD1, DRILL OTHR T Pull wear bushing & wash out stack 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 68/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/12/2021 14:45 9/12/2021 15:15 0.50 PROD1, DRILL OTHR T Install BOP test plug as per FMC rep 0.0 0.0 9/12/2021 15:15 9/12/2021 16:15 1.00 PROD1, DRILL RURD T Rig up BOP testing eqipment, fill stack and purge air from system. 0.0 0.0 9/12/2021 16:15 9/12/2021 22:15 6.00 PROD1, WHDBOP BOPE T Test BOPE: All tests to 250 psi low for 5 minutes, 3500 psi high for 10 minutes charted minimum w/ exception of manual operated Super Choke 2000 psi show bleed and hold pressure, with 4" test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, with 4 ½” test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR. Test choke valves 1- 15, choke & kill manuals & HCR's, 4" valve on kill line. Two 4" FOSV, 4" dart valve, performed Koomey drawdown, ACC = 3000 psi. Manifold = 1525 psi. ACC - 1625psi after all functions on the bottles, 16 secs for 200 psi. Build w/ 2 electric pumps, 95 secs to build full system pressure w/ 2 electric & 2 air pumps. Closing times annular = 21 secs, UPR 18 secs, Blind/Shears = 15 secs, LPR 17 secs, Choke HCR = 2 secs, Kill HCR = 2 secs, Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Rep Jim Regg waived witness at 08:45hrs 9/12/2021 0.0 0.0 9/12/2021 22:15 9/12/2021 23:30 1.25 PROD1, DRILL OTHR T B/D choke manifield, Choke lines pump out stack pull test plug and install wear ring as Per FMC rep 0.0 0.0 9/12/2021 23:30 9/13/2021 00:00 0.50 PROD1, DRILL SLPC T Slip and cut 134' drill line 0.0 0.0 9/13/2021 00:00 9/13/2021 01:00 1.00 PROD1, DRILL SLPC T Cont. to slip and cut drill line, calibrate recalibrate Pason hook load & Amphion 0.0 0.0 9/13/2021 01:00 9/13/2021 03:30 2.50 PROD1, DRILL BHAH T P/U 6.5" Production BHA as per Baker Reps to 288' 0.0 288.0 9/13/2021 03:30 9/13/2021 10:30 7.00 PROD1, DRILL TRIP T Cont. TIH w/ 6.5'' lateral BHA f/ 288' t/ 12,145' MD. Shallow test MWD tools at 2185' good test Monitoring returns on pit #2 Fill pipe every 20 stands 288.0 12,145.0 9/13/2021 10:30 9/13/2021 12:30 2.00 PROD1, DRILL OTHR T PJSM, Change out swivel packing on top drive 12,145.0 12,145.0 9/13/2021 12:30 9/13/2021 13:00 0.50 PROD1, DRILL TRIP T Cont. TIH w/ 6.5'' lateral BHA f/ 12,145' t/ 12,276' Started taking weight, set 30K down and would not break loose, Pulled 5K over pull to get pipe moving back up, Pulled back up t/ 12,235' Monitor displacement on pit #2 12,145.0 12,235.0 9/13/2021 13:00 9/13/2021 13:30 0.50 PROD1, DRILL WASH T Wash & ream f/ 12,235' t/ 12,335' GPM-275 PSI-1730 RPM-80 Torq-5-6K P/U-210K S/O-160K ROT-187K 12,235.0 12,335.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 69/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/13/2021 13:30 9/13/2021 14:00 0.50 PROD1, DRILL TRIP T Cont TIH w/ 6.5'' lateral BHA f/ 12,335' t/ 12,501' MD Set 30K down weight @ 12,501' MD & could not get weight to fall off Monitor displacement on pit #2 12,335.0 12,501.0 9/13/2021 14:00 9/13/2021 14:30 0.50 PROD1, DRILL WASH T Wash & ream f/ 12,501' t/ 12,714' MD GPM-275 PSI-1730 RPM-80 Torq-5-6K P/U-210K S/O-160K ROT-187K 12,501.0 12,714.0 9/13/2021 14:30 9/13/2021 17:00 2.50 PROD1, DRILL TRIP T Cont. TIH w/ 6.5'' lateral BHA f/ 12,714' t/ 14,577' Set 30K down weight @ 14,548' MD & could not get weight to fall off Monitor displacement on pit #2 Filling pipe every 20 stands 12,714.0 14,577.0 9/13/2021 17:00 9/13/2021 17:30 0.50 PROD1, DRILL WASH T Wash & ream f/ 14,577' t/ 14,612' MD GPM-275 PSI-1730 RPM-80 Torq-5-9K P/U-210K S/O-160K ROT-187K 14,577.0 14,612.0 9/13/2021 17:30 9/13/2021 18:30 1.00 PROD1, DRILL TRIP T Cont. TIH w/ 6.5'' lateral BHA f/ 14,612' t/ 15,737 ' MD Set 30k down weight @ 15,737' MD Monitor displacement on pit #2 Filling pipe every 20 stands 14,612.0 15,737.0 9/13/2021 18:30 9/13/2021 20:00 1.50 PROD1, DRILL WASH T Wash & ream f/ 15,737' t/ 15,845' MD GPM-275 PSI-1730 RPM-80 Torq-5-9K P/U-225K S/O-140K ROT-180K 15,737.0 15,845.0 9/13/2021 20:00 9/13/2021 23:30 3.50 PROD1, DRILL TRIP T Cont. RIH w/ 6.5" BHA 15,750' t/ 18,799' MD ' MD Filling pipe every 10 stands 15,750.0 18,799.0 9/13/2021 23:30 9/14/2021 00:00 0.50 PROD1, DRILL MPDA T Rack stand back, remove trip nipple install RCD bearing as per MPD rep @ 15,750' MD 15,845.0 15,750.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 70/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/14/2021 00:00 9/14/2021 03:45 3.75 PROD1, DRILL WASH T Wash and ream in hole f/ 18799' t/ 19798' Set 40k down @ 18799' MD While washing and reaming tourque was steady 8/9k, hole cleaned up torque dropped off to 3/4k WOB was 4/5 k GPM-275 PSI-1730 RPM-80 Torq-5-9K P/U-225K S/O-140K ROT-180K 18,799.0 19,798.0 9/14/2021 03:45 9/14/2021 06:00 2.25 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 18798' to 20,035' MD WOB- 20-25 RPM-150 Torq-10K Off-7K GPM-275 PSI-2640 FO 15% ECD- 10.21 P/U- 234K S/O-137 K RT-181 K MPD connection back pressure 150 psi ADT- 2 TBH- 2 . 19,798.0 20,035.0 9/14/2021 06:00 9/14/2021 12:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 20,035' to 20,669' MD WOB- 20-25 RPM-150 Torq-18K Off-10K GPM-275 PSI-2700 FO 15% ECD- 10.63 P/U- 245K S/O-130 K RT-180 K MPD connection back pressure 260 psi ADT- 4.5 TBH- 6.5 . 20,035.0 20,669.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 71/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/14/2021 12:00 9/14/2021 18:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 20,669' to 21275' MD WOB- 20-25 RPM-150 Torq-18K Off-10K GPM-275 PSI-2700 FO 15% ECD- 10.63 P/U- 245K S/O-130 K RT-180 K MPD connection back pressure 260 psi ADT- 4.2 TBH- 12.5 . 20,669.0 21,275.0 9/14/2021 18:00 9/15/2021 00:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 21275' to 21950' MD WOB- 20-25 RPM-150 Torq-18K Off-12K GPM-275 PSI-2846 FO 17% ECD- 10.63 P/U- 245K S/O-130 K RT-180 K MPD connection back pressure 260 psi ADT- 4.7 TBH- 15.4 . 21,275.0 21,950.0 9/15/2021 00:00 9/15/2021 06:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 21950' t/ 22588' MD WOB- 20-25 RPM-150 Torq-18K Off-12K GPM-275 PSI-2962 FO 17% ECD- 10.63 P/U- 256K S/O-120 K RT-181 K MPD connection back pressure 280 psi ADT- 4.9 TBH- 20.3 . 21,950.0 22,588.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 72/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/15/2021 06:00 9/15/2021 12:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 22588'' to 23188' MD WOB- 20-25 RPM-150 Torq-18K Off-12K GPM-275 PSI-3000 FO 17% ECD- 10.63 P/U- 280K S/O-0 K RT-172 K MPD connection back pressure 120 psi ADT- 4.7 TBH- 25.1 . 22,588.0 23,188.0 9/15/2021 12:00 9/15/2021 18:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 23188' to 23760' MD WOB- 20-25 RPM-150 Torq-21K Off-12K GPM-275 PSI-3000 FO 17% ECD- 10.63 P/U- 279K S/O-105 K RT-189 K MPD connection back pressure 115 psi ADT- 4.7 TBH- 29.4 . 23,188.0 23,760.0 9/15/2021 18:00 9/16/2021 00:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 23760' to 24396 ' MD WOB- 18 RPM-150 Torq-18K Off-12K GPM-275 PSI-3099 FO 17% ECD- 10.63 P/U- 289K S/O- K RT-202 K MPD connection back pressure 215 psi ADT- 4.8 TBH- 34.2 . 23,760.0 24,396.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 73/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/16/2021 00:00 9/16/2021 06:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 24396 ' to 25006' MD WOB -18 RPM-150 Torq-18K Off-12K GPM-275 PSI-3099 FO 17% ECD- 10.63 P/U- 289K S/O- K RT-202 K MPD connection back pressure 215 ps i ADT- 4.8 TBH- 38.2 . 24,396.0 25,006.0 9/16/2021 06:00 9/16/2021 12:00 6.00 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 25006 ' to 25653' MD WOB -18 RPM-150 Torq-18K Off-12K GPM-275 PSI-3056 FO 17% ECD- 10.63 P/U- 292K S/O- K RT-192 K MPD connection back pressure 215 ps i ADT- 4.8 TBH- 43.4 25,006.0 25,653.0 9/16/2021 12:00 9/16/2021 15:45 3.75 PROD1, DRILL DDRL T Drilled 6.5'' Lateral f/ 25653 ' to 26153' MD TD WOB -18 RPM-150 Torq-18K Off-12K GPM-275 PSI-3063 FO 17% ECD- 10.63 P/U- 310K S/O- K RT-206K MPD connection back pressure 215 ps i ADT- 2.8 TBH- 45.9. 25,653.0 26,153.0 9/16/2021 15:45 9/16/2021 18:30 2.75 COMPZN, CASING CIRC T Circulate Rot and Recip. 26150' to 26060' GPM 292 PSI 2989 FO 11% Total Pumped strokes = 10595 26,150.0 26,060.0 9/16/2021 18:30 9/16/2021 20:15 1.75 COMPZN, CASING CIRC T Circulate Rot and Recip. 26060' to 25970' MD GPM 292 PSI 3800 FO 11% Total Pumped strokes = 8500 26,060.0 25,970.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 74/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/16/2021 20:15 9/16/2021 22:00 1.75 COMPZN, CASING CIRC T Circulate Rot and Recip. 25970' to 25880' MD GPM 292 PSI 3800 FO 11% Total Pumped strokes = 8450 25,970.0 25,880.0 9/16/2021 22:00 9/17/2021 00:00 2.00 COMPZN, CASING CIRC T Circulate Rot and Recip. 25880' to 25790' MD GPM 292 PSI 3930 FO 13% Total Pumped strokes = 8450 25,880.0 25,790.0 9/17/2021 00:00 9/17/2021 00:45 0.75 COMPZN, CASING OWFF T Finger Print Well f/ balloning @ 25790' w/ rotating ppe @ 5 rpm Bled back .50 bbls per bleed sequence max bled back 8.17 bbls ISIP 172psi FSIP 21psi 25,790.0 25,790.0 9/17/2021 00:45 9/17/2021 06:00 5.25 COMPZN, CASING BKRM T BROOH f/ 25790' t/ 24765' MD RPM-120 Torq 13K GPM-300 PSI-3581 FO 12% ECD- 10.24 P/U- 206 S/O- 0 RT-206K MPD connection back pressure 161 psi 25,790.0 24,765.0 9/17/2021 06:00 9/17/2021 12:00 6.00 COMPZN, CASING BKRM T BROOH f/ 24,765' t / 22,918' MD RPM-120 Torq 14K GPM-300 PSI-3070 FO 12% ECD- 10.04 P/U- 188 S/O- 0 RT-188K MPD connection back pressure 150 psi 24,765.0 22,918.0 9/17/2021 12:00 9/17/2021 18:00 6.00 COMPZN, CASING BKRM T BROOH f/ 22,918' t / 20,515' MD RPM-120 Torq 11K GPM-300 PSI-32771 FO 12% ECD- 9.7 P/U- 188 S/O- 0 RT-187K MPD connection back pressure 150 psi 22,918.0 20,515.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 75/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/17/2021 18:00 9/18/2021 00:00 6.00 COMPZN, CASING BKRM T BROOH f/ 20,515' to 17,945' MD RPM-120 Torq 11k GPM-300 PSI-2443 FO 10% ECD- 9.7 P/U- 188 S/O- 0 RT-184K MPD connection back pressure 150 psi 20,515.0 17,945.0 9/18/2021 00:00 9/18/2021 00:45 0.75 COMPZN, CASING BKRM T BROOH f/ 17945' t/ 17563' MD RPM-120 Torq 11k GPM-300 PSI-2443 FO 10% ECD- 9.7 P/U- 188 S/O- 0 RT-184K MPD connection back pressure 150 psi 17,945.0 17,563.0 9/18/2021 00:45 9/18/2021 06:00 5.25 COMPZN, CASING BKRM T BROOH f/ 17563' t/ 15849' MD W/ Laying down 18 Stds of 15.7# drill pipe to pipe shed to make room for high tensil HWDP. RPM-120 Torq 11k GPM-300 PSI-2443 FO 10% ECD- 9.7 P/U- 188 S/O- 0 RT-184K MPD connection back pressure 150 psi 17,563.0 15,849.0 9/18/2021 06:00 9/18/2021 12:00 6.00 COMPZN, CASING BKRM T BROOH f/ 15849' t/ 13192' MD RPM-120 Torq 11k GPM-300 PSI-2062 FO 10% ECD- 9.5 P/U- 180 S/O- 0 RT-180K MPD connection back pressure 150 psi 15,849.0 13,192.0 9/18/2021 12:00 9/18/2021 13:30 1.50 COMPZN, CASING BKRM T BROOH f/ 13192' t/ 12260' MD RPM-120 Torq 11k GPM-300 PSI-1969 FO 10% ECD- 9.5 P/U- 181 S/O- 0 RT-181K MPD connection back pressure 150 psi 13,192.0 12,260.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 76/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/18/2021 13:30 9/18/2021 15:00 1.50 COMPZN, CASING BKRM T BROOH f/ 12260' t/ 12148' MD W/ Laying down 4 Stds of drill pipe via mouse hole RPM-120 Torq 11k GPM-300 PSI-2443 FO 10% ECD- 9.7 P/U- 188 S/O- 0 RT-184K MPD connection back pressure 150 psi 12,260.0 12,148.0 9/18/2021 15:00 9/18/2021 17:00 2.00 COMPZN, CASING CIRC T CBU and pump Hi Vis sweep, circulate out hole RPM-120 Torq 8k GPM-300 PSI-1954 FO 10% ECD- 9.5 P/U- 180 S/O- 0 RT-18K Pumped 8597 strokes 12,148.0 12,148.0 9/18/2021 17:00 9/18/2021 17:30 0.50 COMPZN, CASING OWFF T OWFF CAPI/ MPD REP witness 40 min well static 12,148.0 12,148.0 9/18/2021 17:30 9/18/2021 18:30 1.00 COMPZN, CASING SLPC T Slip and Cut (15 Wraps 117') calibrate blocks 12,148.0 12,148.0 9/18/2021 18:30 9/18/2021 19:00 0.50 COMPZN, CASING SVRG T Service Top drive 12,148.0 12,148.0 9/18/2021 19:00 9/19/2021 00:00 5.00 COMPZN, CASING TRIP T TIH f/ 12148' to 17564' MD Recording torque and drag valves every 1000' . Over Pull @ shoe 30k Washed thru tight spots at shoe, 12241' bit, 12247' auto trac stab, 12279' String Stab 12317', BHA thru shoe S/O weight was normal, Tripped thru side track with no issues RPM-20 Torq 6k GPM-280 PSI-1824 FO 10% ECD- 9.5 P/U- 184K RT-184K MPD connection back pressure 90 psi 12,148.0 17,564.0 9/19/2021 00:00 9/19/2021 03:30 3.50 COMPZN, CASING TRIP T TIH f/ 17564' to 21564' MD Recording torque and Drag valves every 1000' Loss S/O weight @ 21654' MD before losing string weight it was 113k 17,564.0 21,654.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 77/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/19/2021 03:30 9/19/2021 10:30 7.00 COMPZN, CASING REAM T Wash And Ream F/ 21654' to 24155' MD Recording Torque And Drag valves every 1000' MD RPM-120 Torq 9-11K GPM-275 PSI-3111 FO 9% ECD- 10.5 RT/W 231K 21,654.0 24,155.0 9/19/2021 10:30 9/19/2021 12:00 1.50 COMPZN, CASING REAM T Wash And Ream F/ 24155' to 24708 ' MD Recording Torque And Drag valves every 1000' MD RPM-120 Torq 9-11K GPM-275 PSI-3111 FO 9% ECD- 10.5 RT/W 231K 24,155.0 24,708.0 9/19/2021 12:00 9/19/2021 15:30 3.50 COMPZN, CASING REAM T Wash And Ream F/ 24708' to 26153' MD Recording Torque And Drag valves every 1000' MD RPM-120 Torq 9-11K GPM-275 PSI-3053 FO 12% ECD- 10.1 RT/W 231K 24,708.0 26,153.0 9/19/2021 15:30 9/19/2021 21:30 6.00 COMPZN, CASING CIRC T Circulate While Recip F/ 26153 to 26093' MD Circulate 3 BU RPM-120 Torq 9-11K GPM-275 PSI-3440 FO 9% ECD- 10.5 P/U 308K RT/W 232K Total Strokes Pumped 26867 26,153.0 26,093.0 9/19/2021 21:30 9/20/2021 00:00 2.50 COMPZN, CASING CIRC T Pump 70 bbl high vis sweep Displace well with 9.1 Vis Brine Rotating and Recip pipe f/ 26153' to 26093' 26,153.0 26,093.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 78/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/20/2021 00:00 9/20/2021 04:00 4.00 COMPZN, CASING CIRC T Cont. displace well w/ 9.1ppg vis brine fluid Note 70bbls sweep at surface 1400 strokes later than cal strokes. Circulate BU to ensure well bore was clean. Pump and spot 357 bblsVis brine 3% 776, 1% safe lube , 1LB/BBL bead pill. Displace out BHA RPM 120 TQ 11/14K ECD 9.7 RT PU 240 RT SO 231 26,153.0 26,153.0 9/20/2021 04:00 9/20/2021 04:45 0.75 COMPZN, CASING OWFF T Finger print well @ 26153' MD ROT 5 RPM TQ 11/ 13 K 26,153.0 26,153.0 9/20/2021 04:45 9/20/2021 06:00 1.25 COMPZN, CASING STRP T SOOH as per stripping schedule F/ 26153' to 25150' MD Racking pipe as per pipe mangement plan Monitoring Disp at pit 2 Taking UP/DN/RT WT'S every 1000' PU 352k SO N/A 26,153.0 25,150.0 9/20/2021 06:00 9/20/2021 12:00 6.00 COMPZN, CASING STRP T SOOH as per stripping schedule F/ 25150' to 19960' Racking pipe as per pipe mangement plan Monitoring Disp at pit 2 Achieved S/O weight at 23900' MD Taking UP/DN/RT WT'S every 1000' PU 352k SO 120k @ 23900' MD 25,150.0 19,960.0 9/20/2021 12:00 9/20/2021 18:00 6.00 COMPZN, CASING STRP T SOOH as per stripping schedule F/ 19960' to 14178' MD ' Racking pipe as per pipe mangement plan Monitoring Disp at pit 2 Achieved S/O weight at 23900' MD Taking UP/DN/RT WT'S every 1000' PU 237k SO 137k RT/WT 192 19,960.0 14,178.0 9/20/2021 18:00 9/20/2021 21:00 3.00 COMPZN, CASING STRP T SOOH as per stripping schedule F/ 14178' to 12148' MD Racking pipe as per pipe mangement plan Monitoring Disp at pit 2 Achieved S/O weight at 23900' MD Taking UP/DN/RT WT'S every 1000' PU 237k SO 137k RT/WT 192 14,178.0 12,148.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 79/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/20/2021 21:00 9/20/2021 23:00 2.00 COMPZN, CASING CIRC T Pump 40 BBLS Hi Vis and Circ out to surface While Rot and Recip pipe. 12241' to 12148' MD GPM 275 PSI 1325 F/O 10 % RPM 80 ECD 9.64 P/U 230 S/O 152 RT/WT 184 TOTAL STKS 7036 12,241.0 12,148.0 9/20/2021 23:00 9/21/2021 00:00 1.00 COMPZN, CASING OWFF T Finger print well as per/ MPD/ CAPI and OWFF @ 12148' MD while moving HWDP around in derrick for Liner run. 12,148.0 12,148.0 9/21/2021 00:00 9/21/2021 02:00 2.00 COMPZN, CASING OWFF T Cont. Finger print well as per/ MPD/ CAPI and OWFF @ 12148' MD while moving HWDP around in derrick for Liner run. Well is Static. 12,148.0 12,148.0 9/21/2021 02:00 9/21/2021 09:30 7.50 COMPZN, CASING STRP T SOOH as per stripping schedule F/ 12148' to 2185' MD Monitoring Disp at pit 2 PU 218k 12,148.0 2,185.0 9/21/2021 09:30 9/21/2021 12:00 2.50 COMPZN, CASING STRP T SOOH as per stripping schedule F/ 2185' to 382' MD Monitoring Disp at pit 2 L/D 14# DP 1x1 PU 60k 2,185.0 382.0 9/21/2021 12:00 9/21/2021 12:30 0.50 COMPZN, CASING OWFF T OWFF as per MPD/ CPIA well static 382.0 382.0 9/21/2021 12:30 9/21/2021 13:30 1.00 COMPZN, CASING MPDA T Pull RCD Bearing and Install Trip Nipple 382.0 382.0 9/21/2021 13:30 9/21/2021 16:00 2.50 COMPZN, CASING BHAH T L/D BHA as per Baker MWD and DD f/ 382' surface 382.0 0.0 9/21/2021 16:00 9/21/2021 17:00 1.00 COMPZN, CASING OTHR T Clean and clear rig floor. 0.0 0.0 9/21/2021 17:00 9/21/2021 18:00 1.00 COMPZN, CASING RURD T Rig up to run lower completion/ Plan changed R/D Equip as per CPAI Note, Bit was missing part cuttter blade down nozzle area. At the end of discusions we are making a clean out run to bottom. 0.0 0.0 9/21/2021 18:00 9/21/2021 19:00 1.00 COMPZN, CASING SLPC T Slip and Cut 97' 12 wraps drill line Calibriate blocks. 0.0 0.0 9/21/2021 19:00 9/21/2021 19:30 0.50 COMPZN, CASING SVRG T Service top drive/Blocks and Iron Roughneck 0.0 0.0 9/21/2021 19:30 9/21/2021 22:45 3.25 COMPZN, CASING BHAH T P/U Clean out run BHA as per Baker 0.0 287.0 9/21/2021 22:45 9/22/2021 00:00 1.25 COMPZN, CASING TRIP T TIH pickup single 21 jt 14# drill pipe f/ 287' to MD 908' MD 287.0 908.0 9/22/2021 00:00 9/22/2021 01:30 1.50 COMPZN, CASING TRIP T TIH f/ 876' to 2184' picking up singles f/ pipe shed P/U 90K S/O 87K Monitoing Displcement Via Trip Tank 876.0 2,184.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 80/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/22/2021 01:30 9/22/2021 07:30 6.00 COMPZN, CASING TRIP T RIH out Derrick f/ 2184' to 12148'' MD P/U 212K S/O 163K Monitoring Displacement Via Trip Tank Filling pipe every 2000' 2,184.0 12,148.0 9/22/2021 07:30 9/22/2021 08:15 0.75 COMPZN, CASING MPDA T Install RCD Bearing as Beyond MPD REP 12,148.0 12,148.0 9/22/2021 08:15 9/22/2021 09:30 1.25 COMPZN, CASING RGRP T Change out Saver Sub on top Drive. 12,148.0 12,148.0 9/22/2021 09:30 9/22/2021 12:00 2.50 COMPZN, CASING WASH T Wash in hole from 12148' to 13281' MD GPM 250 PSI 1243 F/O 10% P/U 190 S/O 142 Monitoring Displacement Via Active Pits 12,148.0 13,281.0 9/22/2021 12:00 9/22/2021 18:00 6.00 COMPZN, CASING WASH T Wash in hole from 13281' to15922' MD GPM 250 PSI 1243 F/O 10% P/U 190 S/O 142 Monitoring Displacement Via Active Pits 13,281.0 15,992.0 9/22/2021 18:00 9/23/2021 00:00 6.00 COMPZN, CASING WASH T Wash in hole from 15922' to18754' MD GPM 250 PSI 1243 F/O 10% P/U 192 S/O 142 Monitoring Displacement Via Active Pits 15,922.0 18,754.0 9/23/2021 00:00 9/23/2021 06:00 6.00 COMPZN, CASING WASH T Wash in hole from 18754' to 21290' MD GPM 250 PSI 1900 F/O 10% P/U 195 S/O 166 Monitoring Displacement Via Active Pits Note: No signs of abnormal drag while wash in hole. 18,754.0 21,290.0 9/23/2021 06:00 9/23/2021 12:00 6.00 COMPZN, CASING WASH T Wash in hole from 21290' to 24055' MD GPM 250 PSI 2316 F/O 8% P/U 195 S/O 166 Monitoring Displacement Via Active Pits Note: No signs of abnormal drag while wash in hole. 21,290.0 24,055.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 81/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/23/2021 12:00 9/23/2021 17:00 5.00 COMPZN, CASING WASH T Wash in hole from 24055' to 26153' MD GPM 250 PSI 2630 F/O 10% P/U 195 S/O 166 Monitoring Displacement Via Active Pits Note: No signs of abnormal drag while wash in hole. 24,055.0 26,153.0 9/23/2021 17:00 9/23/2021 21:00 4.00 COMPZN, CASING CIRC T Circulate Bottoms up and spot1lb/bbl in lateral Rot and Recip f/ 26153' to 26077'MD GPM 250 PSI 2940 F/O 10% RPM 80 TQ 14K ECD 9.7PPG P/U 331 S/O 118 RT/WT 234 26,153.0 26,077.0 9/23/2021 21:00 9/23/2021 21:45 0.75 COMPZN, CASING OWFF T Finger Print well and OWFF as per MPD/CPAI @ 26150' MD 26,150.0 26,150.0 9/23/2021 21:45 9/24/2021 00:00 2.25 COMPZN, CASING STRP T SOOH as per MPD F/ 26150' to 24155' MD P/U 344 S/O 149 Monitoring hole fills at pits 2/3 MPD pulling 279 psi MPD in slips 196 psi 26,150.0 24,155.0 9/24/2021 00:00 9/24/2021 06:00 6.00 COMPZN, CASING STRP T SOOH as per MPD F/ 24155' to17,247' MD P/U 346 S/O 149 Monitoring hole fills at pits 2/3 MPD pulling 280 psi MPD in slips 200 psi 24,155.0 17,247.0 9/24/2021 06:00 9/24/2021 11:30 5.50 COMPZN, CASING STRP T SOOH as per MPD F/17,247' to 12143' MD P/U 276 Monitoring hole fills at pits 2/3 MPD pulling 230 psi MPD in slips 176 psi 17,247.0 12,143.0 9/24/2021 11:30 9/24/2021 13:00 1.50 COMPZN, CASING OWFF T OWFF as per MPD/CPAI well static 12,143.0 12,143.0 9/24/2021 13:00 9/24/2021 15:30 2.50 COMPZN, CASING STRP T SOOH / L/D 20 stands of 4" 14#DP f/ 12143' to 10251' MD P/U 206 Monitoring hole fills at pits 2/3 MPD pulling 230 psi MPD in slips 176 psi 12,143.0 10,251.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 82/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/24/2021 15:30 9/25/2021 00:00 8.50 COMPZN, CASING STRP T SOOH while racking 4" pipe back in derrick f/ 10251' to 1481' MD P/U 78k Monitoring hole fills at pits 2/3 MPD pulling 230 psi MPD in slips 176 psi 10,251.0 1,481.0 9/25/2021 00:00 9/25/2021 01:00 1.00 COMPZN, CASING STRP T SOOH while racking 4" pipe back in derrick f/ 1481' to 382'MD P/U 55k Monitoring hole fills at pits 2/3 MPD pulling 230 psi MPD in slips 176 psi 1,481.0 382.0 9/25/2021 01:00 9/25/2021 02:15 1.25 OWFF T OWFF as per MPD and CPAI well static 382.0 382.0 9/25/2021 02:15 9/25/2021 03:00 0.75 COMPZN, CASING MPDA T Pull Bearing Install Trip Nipple. While montior well Via Hole Fill 382.0 382.0 9/25/2021 03:00 9/25/2021 04:15 1.25 COMPZN, CASING BHAH T TOOH with Bha L/D Tools as per Baker MWD and DD While montior well Via Hole Fill 382.0 0.0 9/25/2021 04:15 9/25/2021 05:30 1.25 COMPZN, CASING OTHR T M/U stack flushing tool, drain stack, P/U 4" test jt pull wear bushing as per FMC Simops clean and clear rig floor 0.0 0.0 9/25/2021 05:30 9/25/2021 06:15 0.75 COMPZN, CASING WWWH T Flush the stack, blow down the top drive, lay down wash tool. 0.0 0.0 9/25/2021 06:15 9/25/2021 07:00 0.75 COMPZN, CASING OTHR T Install test plug per FMC rep. Flood lines with water and purge air from the system. Shell test BOP's to 3,500 psi. 0.0 0.0 9/25/2021 07:00 9/25/2021 12:00 5.00 COMPZN, WHDBOP BOPE T Test BOPE: All tests to 250 psi low for 5 minutes, 3500 psi high for 5 minutes charted minimum w/ exception of manual operated Super Choke 2000 psi show bleed and hold pressure, with 4" test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, with 4 ½” test joint test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR. Test choke valves 1- 15, choke & kill manuals & HCR's, 4" valve on kill line. Two 4" FOSV, 4" dart valve, performed Koomey drawdown, ACC = 3000 psi. Manifold = 1450 psi. ACC – 1750 psi after all functions, 1983 psi avg on the nitrogen bottles, 14 secs for 200 psi. Build w/ 2 electric pumps, 76 secs to build full system pressure w/ 2 electric & 2 air pumps. Closing times annular = 23 secs, UPR 18 secs, Blind/Shears = 16 secs, LPR 16 secs, Choke HCR = 2 secs, Kill HCR = 2 secs, Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Rep Austin McLeod witnessed test. 0.0 0.0 9/25/2021 12:00 9/25/2021 13:30 1.50 COMPZ1, CASING OTHR T Pull the test plug and install the wear bushing per FMC rep. rig down and blow down BOP testing equipment. 0.0 0.0 9/25/2021 13:30 9/25/2021 15:00 1.50 COMPZ1, CASING RURD T Rig up to run liner. 0.0 0.0 9/25/2021 15:00 9/26/2021 00:00 9.00 COMPZ1, CASING PUTB T Pick up and run 4.5" 12.6# L-80 H563 liner to 7,300' MD. 135 k Up Wt 115 k Dn Wt. 0.0 7,300.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 83/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/26/2021 00:00 9/26/2021 05:45 5.75 COMPZ1, CASING PUTB T Continue running 4.5" 12.6# L-80 H563 liner from 7,300' to 12,231' MD. 178 k Up Wt 139 k Dn Wt. 7,300.0 12,231.0 9/26/2021 05:45 9/26/2021 07:00 1.25 COMPZ1, CASING CIRC T Circulate liner at 12,231' MD. Stage pumps up to 4 bpm 2 bbls/min = 123 psi 2.5 bbls/min = 135 psi 3 bbls/min = 180 psi 4 bbls/min = 225 psi 12,231.0 12,231.0 9/26/2021 07:00 9/26/2021 13:00 6.00 COMPZ1, CASING PUTB T Continue running 4.5" 12.6# L-80 H563 liner from 12,231' to 15,531' MD. 189 k Up Wt 123 k Dn Wt. Observed 40k drag while working liner through the shoe and rat hole. 12,231.0 15,531.0 9/26/2021 13:00 9/26/2021 13:30 0.50 COMPZ1, CASING CIRC T Pick up liner hanger per Baker rep, run in hole with 1 stand of 4" HWDP, pick up Innovex swivel, establish circulation through hanger. 2 bbls/min = 155 psi 4 bbls/min = 325 psi 6 bbls/min = 560 psi 15,531.0 15,619.0 9/26/2021 13:30 9/26/2021 22:00 8.50 COMPZ1, CASING TRIP T Run in hole with 4.5" lower completion on 4" HWDP and 4" DP from 15,619' to 20,370' MD 265 k Up Wt 150 k Dn Wt. 15,619.0 20,370.0 9/26/2021 22:00 9/27/2021 00:00 2.00 COMPZ1, CASING TRIP T Work 4.5" lower completion in the hole from 20,370' to 20,380' MD. slacking off to 80 k hookload, picking up free at 260k Up Wt. Began washing down at 5 bbl/min 1050 psi, little progress made. Observed ~ 40 ft of free travel at 260k Up wt and 150k Dn wt. Beyond the 40' of free travel either up or down observed 50 - 60 k drag. Picked up to 310k hookload and pulled 9ft. Slacked off and lost 9 ft of downward progress. 20,370.0 20,380.0 9/27/2021 00:00 9/27/2021 02:45 2.75 COMPZ1, CASING TRIP T Continue working 4.5" liner. Pulled 3 stands from 20,380' to 20,119' MD with 50-60 k over pull, run back in the hole to 20,224' MD. Work pipe. 20,380.0 20,224.0 9/27/2021 02:45 9/27/2021 06:00 3.25 COMPZ1, CASING PMPO T Pump 4.5" lower completion out of the hole from 20,224' to 18,407' MD. 4 bbl/min, 585 psi, 290 k Up Wt 20,224.0 18,407.0 9/27/2021 06:00 9/27/2021 11:00 5.00 COMPZ1, CASING PMPO T Continue pumping 4.5" lower completion out of the hole from 18,407' to 15,384' MD Lay down swivel and liner hanger per Baker rep. 243 k Up Wt 18,407.0 15,384.0 9/27/2021 11:00 9/27/2021 17:15 6.25 COMPZ1, CASING PULL T Pull and lay down 4.5" 12.6# L80 H563 liner from 15,384' to 12,200' MD. 195 k Up Wt. 15,384.0 12,200.0 9/27/2021 17:15 9/27/2021 18:30 1.25 COMPZ1, CASING SLPC T Slip and cut 165 ft of drilling line. calibrate Amphion and Pason sensors. 12,200.0 12,200.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 84/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/27/2021 18:30 9/28/2021 00:00 5.50 COMPZ1, CASING PULL T Pull and lay down 4.5" 12.6# L80 H563 liner from 12,200' to 8,462' MD. 146 k Up Wt. 12,200.0 8,462.0 9/28/2021 00:00 9/28/2021 06:00 6.00 COMPZ1, CASING PULL T Pull and lay down 4.5" 12.6# L80 H563 liner from 8,462' to 4,945' MD. 104 k Up Wt. Culled bent joints 189 - 184 and frac sleeve #13 (2.895") Scarring observed on Swell Packer #6 & #5 Deformed centralizer on joint # 162 8,462.0 5,213.0 9/28/2021 06:00 9/28/2021 12:00 6.00 COMPZ1, CASING PULL T Pull and lay down 4.5" 12.6# L80 H563 liner from 4,952' MD to surface. 104 k Up Wt. Grooving and scaring on the 6 1/8" centralizer on Frac sleeve #5 and #6 5,213.0 0.0 9/28/2021 12:00 9/28/2021 13:00 1.00 COMPZ1, CASING CLEN T Clean and clear the rig floor of casing running equipment. 0.0 0.0 9/28/2021 13:00 9/28/2021 13:30 0.50 COMPZ1, CASING SVRG T Service the top drive and blocks. 0.0 0.0 9/28/2021 13:30 9/28/2021 18:00 4.50 COMPZ1, CASING TRIP T Make up mule shoe and trip in the hole with 4" DP to 10,247' MD. monitoring displacement on the trip tank. 201 k Up Wt 145 k Dn Wt 0.0 10,247.0 9/28/2021 18:00 9/29/2021 00:00 6.00 COMPZ1, CASING TRIP T Trip out of the hole laying down 4" drill pipe from 10,247' to 5,823' MD. monitoring hole fill on the trip tank. 135 k Up Wt 10,247.0 5,823.0 9/29/2021 00:00 9/29/2021 03:45 3.75 COMPZ1, CASING TRIP T Continue trip out of the hole laying down 4" drill pipe from 5,823' MD to 2,466, monitoring hole fill on the trip tank. 86 k Up Wt 5,823.0 2,466.0 9/29/2021 03:45 9/29/2021 05:00 1.25 COMPZ1, CASING TRIP T Continue trip out of the hole racking back 4" drill pipe from 2,466' MD to surface, monitoring hole fill on the trip tank. 2,466.0 0.0 9/29/2021 05:00 9/29/2021 07:15 2.25 COMPZ1, CASING OTHR T Lay down the mule shoe, clear and clean the rig floor, prepare pipeshed and begin loading an processing 4" drillpipe. Prepare for BHA #10. 0.0 0.0 9/29/2021 07:15 9/29/2021 08:30 1.25 COMPZ1, CASING BHAH T Make up clean out BHA #10 per Baker rep to 295' MD 0.0 295.0 9/29/2021 08:30 9/29/2021 22:30 14.00 COMPZ1, CASING TRIP T Trip in the hole picking up 4" drill pipe singles from 295' to 10,629' MD. Filling pipe every 60 singles, monitoring displacement on the trip tank. 189 k Up Wt 149 k Dn Wt 295.0 10,629.0 9/29/2021 22:30 9/29/2021 23:00 0.50 COMPZ1, CASING TRIP T Trip in the hole from the derrick with 4" DP from 10,629' to 12,115' MD. monitoring displacement on the trip tank. 205 k Up Wt 154 k Dn Wt 10,629.0 12,115.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 85/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/29/2021 23:00 9/30/2021 00:00 1.00 COMPZ1, CASING MPDA T Pull the trip nipple and install the RCD bearing. 12,115.0 12,115.0 9/30/2021 00:00 9/30/2021 07:30 7.50 COMPZ1, CASING REAM T Observed 25 k drag through the rat hole at 12,280' - 12,295' MD. Reciprocate with and without pumps the drag section to clean up area, begin rotating and reciprocate through interval, pumped hi vis sweep while rotating and working mill through rat hole. continued pumping and reciprocating through the interval to clean up the drag section. Observed random pressure spikes up to 400 psi. (no indication of losses from pressure spikes) 250-325 gpm 910 - 1470 psi 40-60 rpm 7-13 k tq 220 k Up Wt 155 k Dn Wt 12,115.0 12,337.0 9/30/2021 07:30 9/30/2021 12:00 4.50 COMPZ1, CASING TRIP T Trip in the hole from 12,337' to 15,373' MD. Washing and reaming through drag in excess of 25 k. 250 gpm 1150 psi 40 rpm 8 k tq 251 k Up Wt 142 k Dn Wt 189 k Rot Wt Interval washed and reamed 13,324' MD 13,617' MD 12,320.0 15,373.0 9/30/2021 12:00 9/30/2021 14:30 2.50 COMPZ1, CASING TRIP T Continue tripping in the hole from 15,373' to 16,400' MD. Washing and reaming through drag in excess of 25 k 250 gpm 1300 psi 40 rpm 9 k tq 251 k Up Wt 138 k Dn Wt 191 k Rot Wt Intervals washed and reamed 15,952' MD 16,094' MD 15,373.0 16,400.0 9/30/2021 14:30 9/30/2021 16:00 1.50 COMPZ1, CASING TRIP T Wiper trip 5 stands from 16,400' to 16033' MD, 251 k Up Wt 143 k Dn Wt 16,400.0 16,400.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 86/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/30/2021 16:00 10/1/2021 00:00 8.00 COMPZ1, CASING TRIP T Continue tripping in the hole from 16,400' to 21,206' MD. Washing and reaming through drag in excess of 25 k 250 gpm 1580 psi 40 rpm 12 k tq 278 k Up Wt 154 k Dn Wt 191 k Rot Wt Washed and reamed through 20.390' MD 20,695' MD 16,400.0 21,206.0 10/1/2021 00:00 10/1/2021 06:00 6.00 COMPZ1, CASING WASH T Wash in the hole from 21,206' to 23,777' MD w/ 4" DP racked back in the derrick. Reaming through drag in excess of 25 k GPM 250 SPP 1550 RPM 40 TQ 12k PU/SO/RTW 324k/121k /192k @ 23,000' MPD PSI 180 Monitored displacement on trip pit. 21,206.0 23,777.0 10/1/2021 06:00 10/1/2021 12:00 6.00 COMPZ1, CASING WASH T Wash in the hole from 23,777' to 25,999' MD w/ 4" DP racked back in the derrick. GPM 250 SPP 1600 RPM 40 TQ 15k PU/RTW 330k/204k @ 25,000' MPD PSI 180 Monitored displacement on trip pit. 23,777.0 25,999.0 10/1/2021 12:00 10/1/2021 13:00 1.00 COMPZ1, CASING WASH T Wash in the hole from 25,999' to 26,149' MD w/ 4" DP racked back in the derrick. GPM 250 SPP 2700 RPM 40 TQ 16-19k PU/RTW 335k/221k @ 26,000' Monitored displacement on trip pit. 25,999.0 26,149.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 87/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/1/2021 13:00 10/1/2021 16:45 3.75 COMPZ1, CASING CIRC T Established circulation at 26,149' MD. Rotated and reciprocated f/ 26,149' to 26,085' MD. GPM 300 SPP 3575 RPM 40 FO% 15 TQ 16-19k Pumped 2 x 40 bbl HiVis Sweeps at 200 gpm w/ 1720 psi. ICP 3750 @ 300 gpm FCP 3085 @ 300 gpm Total strokes pumped 18,000 Spotted 1 ppb of Alpine Drill Beads along open hole. 26,149.0 26,149.0 10/1/2021 16:45 10/1/2021 17:00 0.25 COMPZ1, CASING OWFF T OWFF and performed MPD fingerprint. 26,129.0 26,129.0 10/1/2021 17:00 10/2/2021 00:00 7.00 COMPZ1, CASING STRP T SOOH f/ 26,129' to 19,500' MD. Holding 130 psi in slips and 170 psi out of slips. PU 320k SO 140k 26,129.0 19,500.0 10/2/2021 00:00 10/2/2021 00:30 0.50 COMPZ1, CASING STRP T SOOH f/ 19,500' to 19,156' MD. Holding 130 psi in slips and 170 psi out of slips. PU 320k SO 140k Observed a 50k overpull at 19,349' MD. 19,500.0 19,156.0 10/2/2021 00:30 10/2/2021 01:00 0.50 COMPZ1, CASING TRIP T TIH f/ 19,156' to 19,597' MD. Holding 130 psi in slips and 170 psi out of slips. PU 320k SO 140k Driifted past 19,349' twice and observed no overpull and no obstruction. 19,156.0 19,597.0 10/2/2021 01:00 10/2/2021 06:00 5.00 COMPZ1, CASING STRP T SOOH f/ 19,597' to ~13,495' MD. Holding 130 psi in slips and 120 psi out of slips. PU/SO 255k/143k @ 14,500' MD. Observed 30 k overpull at 14,485' MD. Drifted stand through it and seen no overpull. Monitored displacement on trip pit. 19,597.0 13,495.0 10/2/2021 06:00 10/2/2021 07:30 1.50 COMPZ1, CASING STRP T SOOH f/ 13,495' to 12,147' MD. Holding 130 psi in slips and 120 psi out of slips. PU 240k SO 127k Monitored displacement on trip pit. 13,495.0 12,147.0 10/2/2021 07:30 10/2/2021 09:00 1.50 COMPZ1, CASING CIRC T Circualted surface to surface to strip out beads at 12,150' MD. GPM 275 SPP 971 FO 11% Total strokes pumped = 6000 12,147.0 12,150.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 88/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/2/2021 09:00 10/2/2021 09:45 0.75 COMPZ1, CASING OWFF T OWFF for 30 minutes via MPD port on BOP stack. SIMOPS: Prepped for removing the RCD. PJSM w/ Beyond. 12,150.0 12,150.0 10/2/2021 09:45 10/2/2021 11:15 1.50 COMPZ1, CASING MPDA T Pulled RCD bearing and installed trip nipple. Hooked up hole fill and function tested. Pumped 40 bbl dry job. B/D top drive. 12,150.0 12,150.0 10/2/2021 11:15 10/2/2021 12:00 0.75 COMPZ1, CASING SLPC T Hung the blocks. Slipped and cut 133' of drill line. 12,150.0 12,150.0 10/2/2021 12:00 10/2/2021 12:45 0.75 COMPZ1, CASING SLPC T Spooled on 133' new drill line. Torqued deadline clamps. 12,150.0 12,150.0 10/2/2021 12:45 10/2/2021 13:30 0.75 COMPZ1, CASING SVRG T Serviced top drive and blocks. Calibrated Amphion and Pason. 12,150.0 12,150.0 10/2/2021 13:30 10/2/2021 16:30 3.00 COMPZ1, CASING TRIP T POOH L/D singles of 4" DP to pipeshed f/ 12,143' to 9,296' MD. PU 200k SO 160k Monitored well w/ constant hole fill via trip pit. 12,143.0 9,296.0 10/2/2021 16:30 10/2/2021 17:00 0.50 COMPZ1, CASING SVRG T Rig Service: Pipe Skate. 9,296.0 9,296.0 10/2/2021 17:00 10/2/2021 19:15 2.25 COMPZ1, CASING TRIP T POOH L/D singles of 4" DP to pipeshed f/ 9,296' to 7,267' MD. PU 165k SO 127k Monitored well w/ constant hole fill via trip pit. 9,296.0 7,267.0 10/2/2021 19:15 10/2/2021 21:00 1.75 COMPZ1, CASING TRIP T POOH L/D doubles of 4" DP to pipeshed f/ 7,267' to 5,035' MD. PU 140k SO 112k Monitored well w/ constant hole fill via trip pit. 7,267.0 5,035.0 10/2/2021 21:00 10/2/2021 22:30 1.50 COMPZ1, CASING RGRP T Rig Repair: Unable to lower pipe skate. Actions taken: Verified connections in Pipe Skate control panel. Rebooted CPU for pipe skate. Recalibrated string POD. Problem resolved. 5,035.0 5,035.0 10/2/2021 22:30 10/3/2021 00:00 1.50 COMPZ1, CASING TRIP T POOH L/D doubles of 4" DP to pipeshed f/ 5,035' to 3,397' MD. PU 100k SO 99k Monitored well w/ constant hole fill via trip pit. 5,035.0 3,397.0 10/3/2021 00:00 10/3/2021 00:30 0.50 COMPZ1, CASING TRIP T POOH L/D doubles of 4" DP to pipeshed f/ 3,397' to 2,835' MD. PU 100k SO 99k Monitored well w/ constant hole fill via trip pit. 3,397.0 2,835.0 10/3/2021 00:30 10/3/2021 01:00 0.50 COMPZ1, CASING SVRG T Rig service: Top Drive. 2,835.0 2,835.0 10/3/2021 01:00 10/3/2021 02:00 1.00 COMPZ1, CASING RGRP T Repaired chain on pipe skate. 2,835.0 2,835.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 89/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/3/2021 02:00 10/3/2021 04:00 2.00 COMPZ1, CASING TRIP T POOH L/D doubles of 4" DP to pipeshed f/ 2,835' to 294' MD. PU 52 SO 55k Monitored well w/ constant hole fill via trip pit. 2,835.0 294.0 10/3/2021 04:00 10/3/2021 05:30 1.50 COMPZ1, CASING BHAH T L/D Clean out BHA #10. Monitored well w/ constant hole fill via trip pit #2. 294.0 0.0 10/3/2021 05:30 10/3/2021 06:00 0.50 COMPZ1, CASING CLEN T Clean and clear rig floor. L/D BHI Subs. SIMOPS: Weekly BOP Function Test. 0.0 0.0 10/3/2021 06:00 10/3/2021 07:00 1.00 COMPZ1, CASING RURD T PJSM. w/ SLB wireline. P/U SLB tools and R/U to perform USIT log. 0.0 0.0 10/3/2021 07:00 10/3/2021 10:15 3.25 COMPZ1, CASING ELNE T RIH w/ SLB wireline USIT logging tools. Tools below table at 0725hr. Ran constant hole fill over the top. Monitored displacement in trip pit #2. SLB tool failure at 9,900' MD. 0.0 0.0 10/3/2021 10:15 10/3/2021 12:45 2.50 COMPZ1, CASING ELNE T Diagnosed SLB wireline tools. Cut and reheaded line. 0.0 0.0 10/3/2021 12:45 10/3/2021 13:15 0.50 COMPZ1, CASING ELNE T P/U wireline. Re-attached USIT logging tool. Tested logging tool (Good). 0.0 0.0 10/3/2021 13:15 10/3/2021 21:00 7.75 COMPZ1, CASING ELNE T RIH w/ SLB USIT logging tool on wireline. Tools below rotary at 1320hr. Ran constant hole fill over the top. Monitored displacement in trip pit #2. 0.0 0.0 10/3/2021 21:00 10/4/2021 00:00 3.00 COMPZ1, CASING ELNE T Performed main pass cased hole evaluation w/ USIT logging tool. Ran constant hole fill over the top. Monitored displacement in trip pit #2. 0.0 0.0 10/4/2021 00:00 10/4/2021 03:00 3.00 COMPZ1, CASING ELNE T Performed cased hole evaluation w/ USIT logging tool. Ran constant hole fill over the top. Monitored displacement in trip pit #2. 0.0 0.0 10/4/2021 03:00 10/4/2021 03:45 0.75 COMPZ1, CASING RURD T Rigged down USIT wireline. 0.0 0.0 10/4/2021 03:45 10/4/2021 04:15 0.50 COMPZ1, CASING RURD T M/U 5" test joint and removed wear ring. Pumped out BOP stack and installed test plug. 0.0 0.0 10/4/2021 04:15 10/4/2021 04:30 0.25 COMPZ1, CASING RURD T R/U to test w/ 5" test joint. Worked air out of testing system. 0.0 0.0 10/4/2021 04:30 10/4/2021 05:30 1.00 COMPZ1, CASING BOPE T Tested 5" test joint to 250psi low for 5 minutes and 3500psi high for 10 minutes. Rigged down testing equipment and blow down. 0.0 0.0 10/4/2021 05:30 10/4/2021 06:30 1.00 COMPZ1, CASING RURD T Pull test joint and test plug. Set wear ring. 0.0 0.0 10/4/2021 06:30 10/4/2021 11:45 5.25 COMPZ1, CASING RURD T R/U Doyon casing handling equipment. Swapped out pup joints on frac sleeves #13, #19, #20, and #21. Installed X-O's for 5" liner. 0.0 0.0 10/4/2021 11:45 10/4/2021 12:00 0.25 COMPZ1, CASING RURD T R/U casing running equipment to run 4.5" H563 liner. SIMOPS: Cleaned and cleared rig floor. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 90/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/4/2021 12:00 10/4/2021 17:15 5.25 COMPZ1, CASING PUTB T M/U shoe joint and ran 4.5" L-80 H563 12.6ppf liner to 4,170' MD. PU 88k SO 88k Monitored displacement on trip tank. Topped off every 10 joints. RIH w/ fill up hose. 0.0 4,170.0 10/4/2021 17:15 10/5/2021 00:00 6.75 COMPZ1, CASING PUTB T Coninued to RIH w/ 4.5" L-80 H563 12.6ppf liner f/ 4,170' to 10,283' MD. Obtained PU weights every 1,000'. PU/SO 100k/96k @5,100' PU/SO 111k/100k @6,100' PU/SO 123k/106k @7,100' PU/SO 137k/113k @8,100' PU/SO 150k/118k @9,100' PU/SO 161k/124k @10,100' Monitored displacement on trip tank. Topped off every 10 joints. RIH w/ fill up hose. 4,170.0 10,283.0 10/5/2021 00:00 10/5/2021 03:00 3.00 COMPZ1, CASING PUTB T Coninued to RIH w/ 4.5" L-80 H563 12.6 ppf liner f/ 10,283' to 12,056' MD. Obtained PU weights every 1,000'. PU/SO 169k/127k @ 11,000' MD PU/SO 185k/139k @ 12,000' MD Monitored displacement on trip tank. Topped off every 10 joints. RIH w/ fill up hose. 10,283.0 12,056.0 10/5/2021 03:00 10/5/2021 04:00 1.00 COMPZ1, CASING CIRC T Circulated one liner volume. GPM 200 SPP 248 FO 6% PU 169k SO 127k 12,056.0 12,056.0 10/5/2021 04:00 10/5/2021 06:00 2.00 COMPZ1, CASING PUTB T Coninued to RIH w/ 4.5" x 5" liner as per detail f/ 12,056' to 13,214' MD. Obtained PU weights every 1,000'. PU/SO 187k/140k @ 13,000' MD Monitored displacement on trip tank. Topped off every 10 joints. RIH w/ fill up hose. 12,056.0 13,214.0 10/5/2021 06:00 10/5/2021 09:45 3.75 COMPZ1, CASING PUTB T Coninued to RIH w/ 4.5" x 5" liner as per detail f/ 13,214' to 15,350' MD. Obtained PU weights every 1,000'. PU/SO 208k/144k @ 14,000' MD PU/SO 238k/167k @ 15,000' MD PU/SO 240k/157k @ 15,350' MD Monitored displacement on trip tank. Topped off every 10 joints. RIH w/ fill up hose. 13,214.0 15,350.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 91/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/5/2021 09:45 10/5/2021 10:30 0.75 COMPZ1, CASING PUTB T P/U Baker liner hanger HRD ZXP. Torqued up connections and P/U Innovex Swivel f/ 15,350' to 15,496' MD. PU/SO 244k/160k @ 15,496' MD Confirmed free movement of swivel sub. Pumped through liner hanger: GPM/SPP 42/42 84/93 126/165 168/284. 15,350.0 15,496.0 10/5/2021 10:30 10/5/2021 12:00 1.50 COMPZ1, CASING RUNL T RIH w/ 4" DP & HWDP f/ derrick f/15,946' to 17,010' MD. PU/SO 275k/164k @ 16,900' MD Monitored displacement on trip pit #2. Observed obstruction at 17,008' MD. P/U and established circualtion.. 15,496.0 17,010.0 10/5/2021 12:00 10/5/2021 13:15 1.25 COMPZ1, CASING WASH T Established circulation and worked string f/ 16,982' to 17,012' MD. GPM 250 SPP 820-1020 Max PU 280k Minimum down weight while trying to work in the hole 148k. 17,010.0 17,012.0 10/5/2021 13:15 10/5/2021 13:45 0.50 COMPZ1, CASING PMPO T Pumped out of the hole f/ 17,007' to 16,790' MD. GPM 250 SPP 920 FO 9% PU 275k SO 160k 17,012.0 16,790.0 10/5/2021 13:45 10/5/2021 14:30 0.75 COMPZ1, CASING WASH T Wash in hole w/ 4" HWDP f/ derrick f/ 16,790' to 17,082' MD. PU 275k SO 160k Observed obstructions w/ the following Slack Off weights: 143k @ 16,835' MD 143k @ 16,932' MD 138k @ 16,972' MD 143k @ 16,998' MD 16,790.0 17,082.0 10/5/2021 14:30 10/5/2021 18:00 3.50 COMPZ1, CASING RUNL T RIH w/ 4" DP & HWDP f/ derrick f/17,082' to 19,529' MD. SO 165k @ 17,600' MD @19,250' MD: PU 325k SO 148k RTW 197k @ RPM 40 SO while ROT 158k Filled pipe every 10 stands. Monitored displacement on trip pit #2. 17,082.0 19,529.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 92/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/5/2021 18:00 10/5/2021 18:45 0.75 COMPZ1, CASING WASH T Observed obstruction at 19,529' MD. Attempted to wash/work in hole to 19,559' MD. GPM 50-250 FO 2-9% PU 305k SO 125k 19,529.0 19,559.0 10/5/2021 18:45 10/5/2021 19:00 0.25 COMPZ1, CASING PMPO T Pumped out of the hole f/ 19,559' to 19,333' MD. GPM 250 SPP 920 FO 9% PU 275k SO 160k 19,559.0 19,333.0 10/5/2021 19:00 10/5/2021 21:30 2.50 COMPZ1, CASING WASH T Wash in hole f/ 19,333' to 19,559' MD. GPM 50-250 FO 2-9% PU 335k SO 80k 19,333.0 19,559.0 10/5/2021 21:30 10/6/2021 00:00 2.50 COMPZ1, CASING PMPO T Pumped out of the hole f/ 19,559' to 18,370' MD. GPM 168 SPP 525 FO 4% PU 305k 19,559.0 18,370.0 10/6/2021 00:00 10/6/2021 04:00 4.00 COMPZ1, CASING PMPO T Pumped out of the hole f/ 15,370' to 15,494' MD. GPM 168 SPP 525 FO 4% Up Wt 250k Down Wt 137k B/O and L/D swivel and HWDP. 18,370.0 15,494.0 10/6/2021 04:00 10/6/2021 04:45 0.75 COMPZ1, CASING TRIP T L/D liner hanger and running tool. 15,494.0 15,350.0 10/6/2021 04:45 10/6/2021 05:00 0.25 COMPZ1, CASING RURD T R/U casing handling equipment: Tongs, elevators, c/o slip segments. Circulated across the top of the hole. 15,350.0 15,350.0 10/6/2021 05:00 10/6/2021 06:00 1.00 COMPZ1, CASING TRIP T POOH while L/D 5" 24.1ppf L-80 H563 liner to the pipe shed f/ 15,350' to 15,021' MD. Up Wt 265k, Down Wt 167k @ 15,200' MD. No observed damaged frac sleeves and buckled pipe. 15,350.0 15,000.0 10/6/2021 06:00 10/6/2021 12:00 6.00 COMPZ1, CASING TRIP T POOH while L/D 5" 24.1ppf L-80 H563 liner to the pipe shed f/ 15,021' to 12,385' MD. Up Wt 210k, Down Wt 153k @ 12,385' MD. Observed OP 284k @ 14,960' MD. No observed damaged frac sleeves and buckled pipe. 15,000.0 12,385.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 93/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/6/2021 12:00 10/6/2021 12:30 0.50 COMPZ1, CASING TRIP T POOH while L/D 5" 24.1ppf L-80 H563 liner to the pipe shed f/ 12,385' to 12,016' MD. Up Wt 194k, Down Wt 130k @ 12,016' MD. Observed OP 243k @ 12,290' MD. No observed damaged frac sleeves and buckled pipe. 12,385.0 12,016.0 10/6/2021 12:30 10/6/2021 13:00 0.50 COMPZ1, CASING RURD T Change over liner handling equipment for 4.5" 12.6ppf L-80 H563 liner. 12,016.0 12,016.0 10/6/2021 13:00 10/6/2021 18:00 5.00 COMPZ1, CASING TRIP T POOH while L/D 4.5" 12.6ppf L-80 H563 liner to the pipe shed f/ 12016' to 7,306' MD. Up Wt 130k @ 7300' MD. 12,016.0 7,306.0 10/6/2021 18:00 10/6/2021 21:15 3.25 COMPZ1, CASING TRIP T POOH while L/D 4.5" 12.6ppf L-80 H563 liner to the pipe shed f/ 7,306' to 5,398' MD. Observed damaged liner and jewelry: 1) Varying degrees of severe to lightly bent pipe from joints #173 to #126., Make note that #172 was the most severly bent joint of the lot. 2) Frac sleeves 12 and 11 had bent top and bottom pups. 3) The centralizer on Frac Sleeve 12 showed visbile tear damage on the up stroke.edge. No junk scarring was observed on any of the pipe. Up Wt 103k, Down Wt 94k @ 5,350' MD. 7,306.0 5,398.0 10/6/2021 21:15 10/7/2021 00:00 2.75 COMPZ1, CASING TRIP T POOH while L/D 4.5" 12.6ppf L-80 H563 liner to the pipe shed f/ 5,398' to 2,511' MD. Observed damaged liner and jewelry: 1) Bent joints #112 (Above frac sleeve 8), and #100 . 2) The centralizer on Frac Sleeves 5, 6 & 7 showed visbile damage on the up stroke.edge. No junk scarring was observed on any of the pipe. 5,398.0 2,511.0 10/7/2021 00:00 10/7/2021 00:15 0.25 COMPZ1, CASING TRIP T POOH while L/D 4.5" 12.6ppf L-80 H563 liner to the pipe shed f/ 2,511' to 2,343' MD. No junk scarring was observed on any of the pipe. 2,511.0 2,343.0 10/7/2021 00:15 10/7/2021 00:45 0.50 COMPZ1, CASING SVRG T Rig Service: Iron Roughneck 2,343.0 2,343.0 10/7/2021 00:45 10/7/2021 01:30 0.75 COMPZ1, CASING RGRP T Replaced hose on pipe skate. 2,343.0 2,343.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 94/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/7/2021 01:30 10/7/2021 03:30 2.00 COMPZ1, CASING TRIP T POOH while L/D 4.5" 12.6ppf L-80 H563 liner to the pipe shed f/ 2,343' to surface. The centralizer on Frac Sleeves 4, 3,, 2, & 1. showed visbile damage on the up stroke.edge. No junk scarring was observed on any of the pipe. 2,343.0 0.0 10/7/2021 03:30 10/7/2021 04:15 0.75 COMPZ1, CASING RURD P Rigged down casing handling equipment. L/D frac sleeves and centralizers. Rigged up to trip. Cleaned and cleared rig floor. 0.0 0.0 10/7/2021 04:15 10/7/2021 05:45 1.50 COMPZ1, WELLPR SLPC P Hung the blocks. Slipped and cut 79' of drill line. Calibrated Amphion and 0.0 0.0 10/7/2021 05:45 10/7/2021 06:30 0.75 COMPZ1, WELLPR RURD P M/U mule shoe to HWDP. Installed strip- o-matic. Lined up trip pits. SIMOPS: Derrick inspection and greased crown. 0.0 0.0 10/7/2021 06:30 10/7/2021 11:00 4.50 COMPZ1, WELLPR TRIP P TIH f/ surface to 10,710' MD w/ racked back 4" DP from the derrick. PU/SO 225k/195k @ 10,000' MD. Monitored displacement on trip pit #2. 0.0 10,710.0 10/7/2021 11:00 10/7/2021 12:00 1.00 COMPZ1, WELLPR CIRC P Displaced well over to 9.4 ppg. Cl Brine @ 300 gpm w/ 2,125 psi till even MW in/out. FO 14%. Total strokes = 5350. 10,710.0 10,710.0 10/7/2021 12:00 10/7/2021 12:15 0.25 COMPZ1, WELLPR CIRC P Obtained SPR at 10,679' w/ 9.4 ppg MW. Pump #1: 24 spm = 270 psi, 35 spm = 460 psi Pump #2: 24 spm = 270 psi, 35 spm = 480 psi 10,710.0 10,710.0 10/7/2021 12:15 10/7/2021 12:45 0.50 COMPZ1, WELLPR OWFF P OWFF (Static) 10,710.0 10,710.0 10/7/2021 12:45 10/7/2021 18:00 5.25 COMPZ1, WELLPR TRIP P Pumped 50 bbls 100ppg dry job. B/D top drive. POOH while L/D 4" DP f/ 10,710' to 7,264' MD. PU 205k SO 150k Monitored displacement on trip pit. 10,710.0 7,264.0 10/7/2021 18:00 10/8/2021 00:00 6.00 COMPZ1, WELLPR TRIP P POOH while L/D 4" DP f/ 7,264' to 3,784' MD. PU 140k SO 110k Monitored displacement on trip pit. 7,264.0 3,784.0 10/8/2021 00:00 10/8/2021 02:00 2.00 COMPZ1, WELLPR TRIP P POOH while L/D 4" DP f/ 3,784' to 2,783' MD. PU 123k SO 124k Monitored displacement w/ constant hole fill on trip pit. Monitored well for flow. 3,784.0 2,783.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 95/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/8/2021 02:00 10/8/2021 03:15 1.25 COMPZ1, WELLPR TRIP P RIH w/ 31 stands of 4" 14 ppf DP from the driller's side f/ 2783' to 6,579' MD. PU 179k SO 142k Monitored displacement w/ constant hole fill on trip pit. 2,783.0 6,579.0 10/8/2021 03:15 10/8/2021 06:00 2.75 COMPZ1, WELLPR TRIP P POOH while L/D 4" DP f/ 6,579' to 4,025' MD. PU 143k @ 4,000' MD Monitored displacement w/ constant hole fill on trip pit. 6,579.0 4,000.0 10/8/2021 06:00 10/8/2021 08:00 2.00 COMPZ1, WELLPR TRIP P POOH while L/D 4" DP f/ 4,025' to 2,783' MD. PU 121k @ 2,800' MD Monitored displacement w/ constant hole fill on trip pit. 4,000.0 2,783.0 10/8/2021 08:00 10/8/2021 10:45 2.75 COMPZ1, WELLPR TRIP P POOH while L/D 4" DP f/ 2,783' to Surface. Monitored displacement w/ constant hole fill on trip pit. 2,783.0 0.0 10/8/2021 10:45 10/8/2021 11:30 0.75 COMPZ1, WELLPR WWWH P Washed and drained stack. Pulled wear ring. B/D top drive. 0.0 0.0 10/8/2021 11:30 10/8/2021 12:00 0.50 COMPZ1, RPCOMP RURD P Changed handling equipment to 4.5". R/U double stacked tongs. 0.0 0.0 10/8/2021 12:00 10/8/2021 18:00 6.00 COMPZ1, RPCOMP PUTB P M/U shoe joint. RIH w/ 4.5" L-80 H563 tubiing completion as per detail to 6,172' MD. SO 104k Monitored displacement w/ constant hole fill on trip pit. 0.0 6,172.0 10/8/2021 18:00 10/8/2021 22:00 4.00 COMPZ1, RPCOMP PUTB P M/U shoe joint. RIH w/ 4.5" L-80 H563 tubiing completion as per detail f/ 6,172' to 10,745' MD. SO 125k Monitored displacement w/ constant hole fill on trip pit. 6,172.0 10,745.0 10/8/2021 22:00 10/9/2021 00:00 2.00 COMPZ1, RPCOMP PUTB P M/U shoe joint. RIH w/ 4.5" L-80 H563 tubiing completion as per detail f/ 10,745' to 12,297' MD. Set 30k WOB at 12,297' MD. PU 190k SO 130k Monitored displacement w/ constant hole fill on trip pit. 10,745.0 12,297.0 10/9/2021 00:00 10/9/2021 00:15 0.25 COMPZ1, RPCOMP TRIP T Attemptted to work through obstruction at 12,297' MD. Attempted with varying running speeds and down weight of 5- 15k (Unsuccesssful). 12,297.0 12,297.0 10/9/2021 00:15 10/9/2021 00:45 0.50 COMPZ1, RPCOMP WASH T Attempted to work and wash by obstruction at 12,297' MD (Unsuccessful). GPM 84-126 SPP 70-120 FO 2-3% 12,297.0 12,297.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 96/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/9/2021 00:45 10/9/2021 02:00 1.25 COMPZ1, RPCOMP WASH T Attempted to work and wash by obstruction at 12,297' MD (Unsuccessful). GPM 84-120 SPP 70-200 Down Wt 5-7k Shut down pumps and attempted to work by obstruction to no avail w. 10- 20k down weight. 12,297.0 12,297.0 10/9/2021 02:00 10/9/2021 07:00 5.00 COMPZ1, RPCOMP WASH T Attempted to work and wash by obstruction at 12,297' MD (Unsuccessful). GPM 84-129 SPP 120-383 Down Wt 10-20k Shut down pumps and attempted to work by obstruction to no avail w. 10- 20k down weight. 12,297.0 12,297.0 10/9/2021 07:00 10/9/2021 08:00 1.00 COMPZ1, RPCOMP PULL T PJSM, L/D 3 joints of 4.5'' liner f/ 12,297' t/ 12,181' 12,297.0 12,181.0 10/9/2021 08:00 10/9/2021 09:15 1.25 COMPZ1, RPCOMP THGR P PJSM, M/U FMC hanger & landing joint, RIH t/ 12,219' & hang off 4.5'' liner & Run in lock down pins S/O- 131 12,181.0 12,219.0 10/9/2021 09:15 10/9/2021 09:45 0.50 COMPZ1, RPCOMP THGR P Test tubing hanger seals t/ 2,500 psi f/ 10 min Test OK 12,219.0 12,219.0 10/9/2021 09:45 10/9/2021 12:00 2.25 COMPZ1, RPCOMP PACK P Drop 1.3125'' setting ball & spear w/ waiting on reply f/ BLM SIMOPS- Swap rig over to engine power 12,219.0 12,219.0 10/9/2021 12:00 10/9/2021 14:30 2.50 COMPZ1, RPCOMP PACK P Pressure up down tubing t/ 3,500 psi f/ 30 min. Chart test, Bleed tubing down t/ 1,500 psi, Line up and pressure up IA t/ 2,500 psi f/ 30 min. Chart test, Bleed IA t/ 0 psi, Bleed tubing t/ 0 psi, pressure up on IA t/ 2,350 psi to shear SOV, 12,219.0 12,219.0 10/9/2021 14:30 10/9/2021 15:00 0.50 COMPZ1, RPCOMP OWFF P Flow check well, well static 12,219.0 12,219.0 10/9/2021 15:00 10/9/2021 15:30 0.50 COMPZ1, RPCOMP PULD P PJSM, rig down testing equipment & pull landing joint, Drain stack 12,219.0 12,219.0 10/9/2021 15:30 10/9/2021 16:30 1.00 COMPZ1, RPCOMP DHEQ P Install FMC BPV per FMC Rep, Test same t/ 2,500 psi f/ 10 mi, Test good & charted, Blow down lines & rig down testing equipment 12,219.0 12,219.0 10/9/2021 16:30 10/9/2021 17:00 0.50 COMPZ1, WHDBOP OTHR P Blow down choke, kill line, mud pumps, & hole fill line, Bleed down accumulator 12,219.0 12,219.0 10/9/2021 17:00 10/9/2021 18:30 1.50 COMPZ1, WHDBOP RURD P Pull trip nipple, 90' mouse hole, removed flow line and choke, and kill lines. 12,219.0 12,219.0 10/9/2021 18:30 10/9/2021 20:30 2.00 COMPZ1, WHDBOP NUND P Removed bolts on BOP stack and walk back and store. Removed bolts from HP riser and removed. 12,219.0 12,219.0 10/9/2021 20:30 10/9/2021 22:00 1.50 COMPZ1, WHDBOP NUND P M/U Wellhead adapter and test to 5000 psi for 5 minutes. 0.0 0.0 10/9/2021 22:00 10/10/2021 00:00 2.00 COMPZ1, WHDBOP NUND P N/U FMC 5k Tree. Filled w/ diesel and tested 250 psi (low) for 5 minutes and 5,000 psi (high) for 10 minutes (Charted). SIMOPS: R/D High Pressure mud lines in pump room and mud pits. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 Page 97/97 MT7-06 Report Printed: 10/21/2021 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/10/2021 00:00 10/10/2021 01:15 1.25 COMPZ1, WHDBOP FRZP P R/U and performed freeze protect of IA. Pumped 50 bbls diesel down IA and took returns to the mud pits. ICP 1950 psi @ 1.0 bpm FCP 2450 psi @ 2.0 bpm IA Pressure at the start of U-tubing was 680 psi. 0.0 0.0 10/10/2021 01:15 10/10/2021 03:00 1.75 COMPZ1, WHDBOP FRZP P U-Tube well to a final equalized Tubing/IA pressure of 600 psi. SIMOPS: Secured rig floor. Bridle up t/ scope derrick. Scoped derrick down. Unbridled scoping lines. Pinned top drive. B/D steam and water. 0.0 0.0 10/10/2021 03:00 10/10/2021 06:00 3.00 DEMOB, MOVE RURD P Pulled BPV and installed H-BPV via lubricator. Secured cellar. SIMOPS: Spool off drill line f/ drum & deadman, Clean pits & blow down steam lines, Raise cattle chute Rig released @ 06:00 on 10/10/21 OA 0 psi IA 0 psi Tubing 0 psi 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 10/10/2021 !"# $" !%&' () * $) +$&"$ ) !, ) ) ) ) !" !"$$ ")## $ %&'(!)( -) !"$$$ )*'+ , )$ %&'(!)( ) !" $ *) $*) ( $ .) *$*)- './*0$ 1 './22-1 3 ,3- ,4!( 5 - 6 $ - 66 $ $$ +-") +$") /$ -) -) 0/1& 01& 2$ "+) !" !)! !)! +3.'+3.!)"( 7.3.8")" '!!).$"/$) !)! !9'!:8)(7! 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'+")88 73(!.)" "3+!7) (3(8+)+73".) +3.!.3(!). 7+38)+ 8)+ "3'!)" @AB@@/81 '37".)+ 78).+ '+7)7 73(')7 "3+.+)( (38..)7737')( +3.!.38!)8 7+38++)7 ()! "3'!)!! @AB@@/81 '3."() 7")77 '+.)"8 73(.)( "3"78) (38"")8737.)! +3.!.38')' 7+387")7 8) "38!!) @AB@@/81 '83!"!)! 7.)+. '"!) 73(8)8 "38)" (3888)+73.'). +3.!.3'(!)8 7+3(')' ). "38.8)!" @AB@@/81 '83'+") 7.)"" '"!) 73(8). "37"() (38!')!73.)+ +3.!.3!(7). 7+3(()' !)' "3(7")!! @AB@@/81 '83+')" 7.)"" '"!)'" 73(88)+ "3.+8). (3"7)73.8)' +3.!73.+7)8 7+3("). !)' "3+7)'' @AB@@/81 '838(7)! .!)!8 '"!).. 73(88)7 3!(()7 (38")"73.8)( +3.!737"")+ 7+3+!")( !). "3"')8 @AB@@/81 '83((')8 .!)!" '"!)7 73(88) 3'88)! (3!")'73.8)8 +3.!73)+ 7+3+8()+ !)' "3"')7 @AB@@/81 '83+8+)8 .!)!8 '+.)"7 73(88)" 3')+ (3'()(73.8) +3.!73"77) 7+3+"8) ')8 "37+)+ @AB@@/81 '83"8!)! .!)!8 '+7)8 73(88)" 38'!)! (3'(!)773.8) +3.!73+.7)7 7+3+.()7 ')! 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'+8)! 73(8.) 73+!)8 83"7)"73..)8 +3.!3"(")8 7"3!')7 !) 3.').7 @AB@@/81 '(3"7). .!)!8 '+8).' 73(8.)" 7388+) 83"(+)773..) +3.!3+"!) 7"3!"') !) 73!!")' @AB@@/81 '(37"()8 .!)!. '+8)'( 73(8.)+ 73(!) 83"!8)73..)' +3.!3(8) 7"3'!')8 !)7 73!.()" @AB@@/81 '(3.+.)! .!)' '+)"( 73(8.)( 73+!+)! 83+"!)'73..)! +3.!3877) 7"3'() !)+ 73'7)87 @AB@@/81 '+3!+8)" .!)!" '+8)"! 73(8.) 73+7.)( 83+')873.7)7 +3.!38!) 7"3'7)" ')! 73".).7 @AB@@/81 '+3'(7)+ .!)!" '+8)"' 73(8.)' 73"()( 83(+)'73.7) +3.!3'")+ 7"3)( !)! 738+7)'. @AB@@/81 '+3(8)" .!)!" '+8)7 73(8.)! 73+.) 83(88)!73.7)" +3.!3'8!)' 7"3")' !)8 73((")"" @AB@@/81 '+3887)7 .!)!8 '+).+ 73(87). 737(()7 838.!)(73.7)+ +3.!3!(8)7 7"38!)8 ')! 73+8().7 @AB@@/81 '+3(88)8 .!)!. '+)78 73(87). 73.7). 838()(73.7)+ +3.!"3.+7)" 7"38(8)! !)' 73")8 @AB@@/81 '+3+). .!)!. '+').' 73(87) .3!') 838!8)+73.7)8 +3.!"378)" 7"387()+ ')! 73!.)(. @AB@@/81 '+3")7 .!)!! '+'). 73(87)" .3!.")( 83+7).73.7) +3.!"377)" 7"3(")7 !)' 73.")"( @AB@@/81 '+3'7) .!)'7 '+)"8 73(87)+ .3'7!). 83'()+73.7)' +3.!"3!). 7"3("7)7 !) 7377()+' @AB@@/81 '+37')( .!)!. '+8).. 73(87)8 .3"+)' 83')73.). +3.!"3"')" 7"3+!7)7 ')( 73.')7 @AB@@/81 () * $) +$&"$ ) !, ) ) ) ) !" !"$$ ")## $ %&'(!)( -) !"$$$ )*'+ , )$ %&'(!)( ) !" 3 5 7 345 # 345 0/1& 3 5 01& 3 5 !, 3 5 !, 3 5 $ - 3 5 $ /$ - 3 5 ,$ 3 5 + 34185 !$* '+3.!)' 7.). '+8)8 73(87) .38+!)' 83'8!)+73.)7 +3.!"3+8')" 7"3+(7)' !)8 .3!+.). @AB@@/81 '"3!!)+ .!)!! '+8)87 73(87) .3(8+)+ 83!77)!73.)7 +3.!"3(((). 7"3+77) !)( .3'(7)"7 @AB@@/81 '"3!.)+ 7.). '+8)"( 73(87)8 .3+!)" 83!(+)"73.). +3.!"38+7)7 7"3"7) !)8 .38").! @AB@@/81 '"3'.!) 7.)+ '+8)'' 73(87)+ .3"!8). 83!!8)773.7)' +3.!"3()8 7"3"")" !)" .388)87 @AB@@/81 '"37)! 7.)". '+8). 73(8.)! .3".!)! 3."!)773.7)" +3.!"3'7)! 7"3!7)8 !) .3(')7! @AB@@/81 '"387'). 7.)7 '+8)(! 73(8.)( .3+)! 3.'7)"73..)! +3.!"3'!!). 7"3(7)' !)( .3+!!).. @AB@@/81 '"3("). 7.)". 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'!37.)'" @AB@@/81 '388'). 77)7" '+)!! 73(+8)( '!3"'")+ 3(7)!738'8)! +3.!+3()+ 73'"+)' !)8 '!38+).8 @AB@@/81 '3()' 77) '+)( 73(++)8 '!3!!) 3(88)738'(). +3.!+3'")' 73!)' !)+ '!3("8)+8 @AB@@/81 '3+). 77) '+8)( 73(+)( '!37")' 38.!)(738')! +3.!+3!+)" 73(7)! ')8 '!3++)'7 @AB@@/81 '3"'). 77) '+8)" 73(+.)( '!37')8 38(7)8738'.)! +3.!(3.7.)8 737) !)' '!3"(!)+' @AB@@/81 '3'()! 77) '+8)'( 73("')+ '!3.+) 38!+)738')' +3.!(3.!) 7387)( !)+ '!3.)". @AB@@/81 '37!7)" 77) '+8)7 73("8)+ ''3!(')7 3"8)!7388)' +3.!(37'")+ 738"7) !) '!37')+' @AB@@/81 '3.!8)+ 77) '+8)" 73("+)" ''3'"). 3')'738+) +3.!(38!)8 73(!) !)' '!3.!+)8 @AB@@/81 '3..7) 77) '+8)8( 73(")" ''3')' 3'7)738) +3.!(3"(8). 73(()7 !)( '!3..()8 @AB@@/81 '73!.8)+ 77)7. '+).! 73(".)+ ''3.") 3'8+)7738.)' +3.!(3++7) 73(77)8 !)+ ''3!7)! @AB@@/81 '73'77)8 7.)"8 '+8)+ 73(!)7 ''387')8 3!.8)'7388!)( +3.!(3()( 73+7)" ')' ''3'".)7. @AB@@/81 '7378)! 7.)7 '+8).. 73(')8 ''3("") 3!+')87388!). +3.!(387")8 73+"7)! !)+ ''3+).+ @AB@@/81 '7387)! 7.)7( '+8) 73(')" ''3++')" 3!!.)+7388') +3.!(3..). 73"!)+ !) ''38(")(" @AB@@/81 '73(8). 7.)". '+)' 73()! ''3"8)' '3."")87388')" +3.!(3'8) 73"(7) ')' ''3(8+)7 @AB@@/81 '73+".)" 7.)+! '+)'( 73()" ''3)! '3.)!7388) +3.!(3')' 73".!) !)" ''3+8)+' @AB@@/81 '73""()+ 7.)( '+') 73(8)+ ''37!+)7 '37)(73888)' +3.!(3!()' 738)+ !)( ''3"'!)" @AB@@/81 '73+.)" .!)' '+')+. 73(8)7 ''377.)( '378)873888)( +3.!83.+) 73+) !)7 ''3".). @AB@@/81 '737+(). .!)8 '+)+ 73(8)! ''3.8)+ '37)(7388)" +3.!837'). 737') !). ''37+)8! @AB@@/81 '73.+!) .!)" '+8)+" 73(')7 '3!+7)( '3(()!7388')( +3.!837+). 737+7)7 ')( ''378)(( @AB@@/81 '.3!(+)" .!)++ '+)'+ 73(!)7 '3'(8)8 '3!!)+7388!)( +3.!83"..)7 737..). ')+ ''3."')"+ @AB@@/81 '.3'()' .!)(. '+)7' 73(".). 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Page 1/1 MT7-06 Report Printed: 10/21/2021 Cement Detail Report Cement Details Description Surface String Cement Cementing Start Date 7/23/2021 12:31 Cementing End Date 7/23/2021 15:54 Wellbore Name MT7-06 Comment SLB pump 5 bbls of fresh H2O. Tested lines to 500 psi low/ 3500 psi high, pump 100 bbls of 11.0 ppg Mud Push II @ 5 bbls/min, 340 psi, 12.5% F/O, Dropped bottom plug. Start batching lead. Pump 477 bbls of 11.0 ppg DeepCRETE cement at 5.5 bbls/min, 700 psi ICP, F/O 15%. Batch and pump 69 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 600 psi, F/O 14.7%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg Ksi mud @ 7 bbls/min, 685 psi, F/O 28%. Bump plug with 1050 psi (481 bbls + 20 bbls). 4071 strokes, final circ. PSI 451 @ 3 bpm, Pressure up to 1000 psi & hold for 5 minutes. Bleed off pressure, Check floats, Floats holding, 190 bbls 11.0 ppg cement to surface. Cement Stages Stage # 1 Description Surface String Cement Objective Cement 13 3/8" Casing in place. Top Depth (ftKB) 40.3 Bottom Depth (ftKB) 3,425.0 Full Return? No Vol Cement … 190.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 6 Q Pump Avg (bbl/… 6 P Pump Final (psi) 500.0 P Plug Bump (psi) 1,020.0 Recip? Yes Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB pump 5 bbls of fresh H2O. Tested lines to 500 psi low/ 3500 psi high, pump 100 bbls of 11.0 ppg Mud Push II @ 5 bbls/min, 340 psi, 12.5% F/O, Dropped bottom plug. Start batching lead. Pump 477 bbls of 11.0 ppg DeepCRETE cement at 5.5 bbls/min, 700 psi ICP, F/O 15%. Batch and pump 69 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 600 psi, F/O 14.7%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg Ksi mud @ 7 bbls/min, 685 psi, F/O 28%. Bump plug with 1050 psi (481 bbls + 20 bbls). 4071 strokes, final circ. PSI 451 @ 3 bpm, Pressure up to 1000 psi & hold for 5 minutes. Bleed off pressure, Check floats, Floats holding, 190 bbls 11.0 ppg cement to surface. Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 39.8 Est Btm (ftKB) 2,925.0 Amount (sacks) 1,395 Class G Volume Pumped (bbl) 477.0 Yield (ft³/sack) 1.92 Mix H20 Ratio (gal/sa… 6.73 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 234.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,925.0 Est Btm (ftKB) 3,435.0 Amount (sacks) 331 Class G Volume Pumped (bbl) 69.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sa… 5.06 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 71.0 Thickening Time (hr) 4.17 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Surface String Cement Job: DRILLING ORIGINAL, 7/17/2021 08:00 Page 1/1 MT7-06 Report Printed: 10/21/2021 Cement Detail Report Cement Details Description Intermediate String 1 Cement Cementing Start Date 8/7/2021 01:00 Cementing End Date 8/7/2021 05:35 Wellbore Name MT7-06 Comment SLB pump 5 bbls of fresh H2O. Tested lines to 711 psi low/ 3530 psi high, pump 60 bbls of 12.5 ppg Mud Push II @ 4 bbls/min, 865 psi, Dropped bottom plug. (cement wet @ 02:25) Pump 110 bbls of Class G 15.8 ppg cement @ 4 bbls/min, ICP = 1035 psi, FCP = 398 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 10.4 ppg LSND mud @ 4 bbls/min, ICP = 365 psi, FCP= 520 psi. Total losses during the job, Plug bumped at 6373 strokes (539 bbls). Increased pressure to 1070 psi, Bleed off pressure and check floats, continued to see slow stream. Pressured back up on casing and monitored. CIP 06:34 Hrs 08/07/2021. Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Cement Intermediate 7 5/8" casing in place/ Top Depth (ftKB) 12,240.0 Bottom Depth (ftKB) 12,241.0 Full Return? No Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 4 Q Pump Avg (bbl/… 4 P Pump Final (psi) 676.0 P Plug Bump (psi) 550.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Injected 106.1 bbls class G 15.8 ppg cement Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate String 1 Cement Job: DRILLING ORIGINAL, 7/17/2021 08:00 Page 1/1 MT7-06 Report Printed: 10/21/2021 Cement Detail Report Cement Details Description Cement Squeeze Cementing Start Date 8/12/2021 02:40 Cementing End Date 8/12/2021 04:04 Wellbore Name MT7-06 Comment SLB pump 4 bbls of fresh H2O. Tested lines to 700 psi low/ 3500 psi high, pump 30 bbls of 12.5 ppg Mud Push II @ 4 bbls/min, 490 psi, Batch cement (cement wet @ 02:57) Pump 107.5 bbls of Class G 15.8 ppg cement @ 4 bbls/min, ICP = 520 psi, FCP = 120 psi. Batch and pump 10.1 bbls 12.5 ppg Mud Push II at 4 bbls/min, 92 psi, pump 5.1 bbls fresh water. Swap to rig & displace w/ 10.8 ppg LSND mud @ 4 bbls/min, ICP = 80 psi, FCP= 965 psi. Slow pumps to 0.5 bbls/min, 430 psi. 0 losses during the job, shut down pumps at 1093 strokes (92.5 bbls). CIP 04:04 Hrs 08/12/2021. Cement Stages Stage # <Stage Number?> Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return?Vol Cement …Top Plug? Btm Plug? Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Squeeze Job: DRILLING ORIGINAL, 7/17/2021 08:00 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?MT7-06 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12318 8311 12241 8293 3092 Casing Collapse Structural Conductor Surface 2260 psi Intermediate 6890 psi Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chris Brillon Contact Name:Nina Anderson Wells Engineering Manager Contact Email:nina.anderson@conocophillips.com Contact Phone: 907-229-4008 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 10/9/2021 Perforation Depth MD (ft): 12241 10925 4.5 20 13.375 80.5 7.62512201 3385 5021 psi 120 3043 8293 120 3425 TVD BurstMD 4790 psi P.O. Box 100360, Anchorage AK, 99510-0360 50-103-20831-00-00 ConocoPhillips Length Size Greater Mooses Tooth - Rendezvous Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA081800, 932516000, AA081736 221-048 COMMISSION USE ONLY Authorized Name: Victoria Loepp 10/9/2021 Tubing Grade:Tubing MD (ft): 7740 m n P 2 6 5 6 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:22 am, Oct 12, 2021 321-535 DLB 10/12/2021 file w/ PTD 10-407 VTL 10/13/21 , AA081781 DLB DSR-10/12/21 X Conditions of Approval on original PTD and subsequent sundries apply. X X BOP test to 3500 psig Annular preventer test to 2500 psig JLC 10/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.14 11:52:47 -08'00' RBDMS HEW 10/19/2021 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 11th, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry to Approved Program for MT7-06 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry for change to approved program for MT7-06, an onshore production well from the MT7 drilling pad currently being drilled with the Doyon 25 drilling rig. The 16” surface hole has been drilled to 3,435’ MD / 3049’ TVD with casing run to 3425’ MD / 3043’ TVD. The 9-7/8” x 11” intermediate hole was drilled to 12,318’ MD / 8311’ TVD into the Alpine D sand. Due to continued difficulties in running the production liner on MT7-06, ConocoPhillips proposes to complete this well as a producer with 4-1/2” completion string, production packer, gas lift mandrels, and tested tree. This will allow ConocoPhillips the flexibility flow the well back with gas lift and to also engineer and modify the current well design for a successful liner completion in the future. MT7-06 is planned to be a fracture stimulated horizontal producer within the Rendevouz reservoir. Current and upcoming operations are as follows: x Run 4-1/2” Completion String to ~ 12,219’ MD x Freeze protect through SOV in the lower GLM x Secure the well and RDMO Please find attached the information for your review. Pertinent information attached to this application includes the following: 1.A proposed schematic If you have any questions or require further information, please contact Nina Anderson at 229-4008 (nina.anderson@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: MT7-06 Well File / Jenna Taylor ATO 1560 David Lee ATO 1726 Chris Brillon ATO 1548 Nina Anderson Drilling Engineer Due to continued difficulties in running the production liner on MT7-06, ConocoPhillips proposes to complete this well as agp ,ppp p producer with 4-1/2” completion string, production packer, gas lift mandrels, and tested tree. This will allow ConocoPhillipsppg,pp,g ,p the flexibility flow the well back with gas lift and to also engineer and modify the current well design for a successful lineryggyg completion in the future. MT7-06 is planned to be a fracture stimulated horizontal producer within the Rendevouz reservoir.dd Tubing / Liner Completion: 1) 4-½” x 1” Vanoil KBMG GLM (2x) 2) 4-½” X Landing Nipple (3.813" ID) 3) 4-½” Baker Premier Production Packer 4) 4-½” DB Landing Nipple w/RHC (3.75" ID) 5) 4-½” NS Dissolving Shoe 7-5/8" 29.7# HYD563 and 33.7# L-80 TXP BTC-SR Casing @ 12,241' MD / 8,293' TVD Casing set in the Alpine D Sand 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 4-1/2" 12.6# L-80 Hyd563 Cement Placement per USIT on 8/16 9650' MD to 10,950' MD Top Alpine C 12,411' MD / 8331' TVD MT7-06wp09 - 3 String Producer, As Drilled Schematic (updated 10.10.21) GL 13-3/8" 68# L-80 TXP / HYD 563 Surface Casing set @ 3,425' MD / 3043' TVD Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,442' MD 9-7/8" hole section to ~ 500' above HRZ 11" hole section to TD Remedial Cement Perforations at 10,923 – 10,925' MD 4-½” 12.6# L-80 Hyd563 Liner set HIGH @ ~ 25,254' MD MT7-06PB1 TD @ 26,241' MD / 8,510' TVD Top of Fish in MT7-06PB1 @ 12,985' MD 4 ½” Tubing tail ~12,219' Baker Premier Packer @ 10,143' MT7-06 TD @ 26,154' MD / 8,337' TVD From:WSC Operations Engineer To:Loepp, Victoria T (OGC) Cc:Nagel, Matt B; Njoku, Johnson; Buck, Brian R; Hobbs, Greg S; Anderson, Nina M; WSC Rig Advisor; Klem, Adam Subject:RE: [EXTERNAL]Re: MT7-06 Completion Set Depth Date:Saturday, October 9, 2021 10:20:17 AM Attachments:MT7-06 kill string 10.9.21.pdf Please find attached schematic. Thank you, Sydney From: WSC Operations Engineer Sent: Saturday, October 9, 2021 8:58 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>; 'Njoku, Johnson' <Johnson.Njoku@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; 'Anderson, Nina M' <Nina.Anderson@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com> Subject: RE: [EXTERNAL]Re: MT7-06 Completion Set Depth Thank you very much for your time on the phone and verbal approval to proceed with setting the packer as outlined below. As discussed I will get a completion schematic to you shortly. Sydney From: WSC Operations Engineer Sent: Saturday, October 9, 2021 8:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Anderson, Nina M <Nina.Anderson@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com> Subject: RE: [EXTERNAL]Re: MT7-06 Completion Set Depth The planned packer depth was 10,683’ MD. Sydney From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Saturday, October 9, 2021 8:30 AM To: WSC Operations Engineer <wscopsengineer@conocophillips.com> Subject: [EXTERNAL]Re: MT7-06 Completion Set Depth CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. What was the planned packer depth? Sent from my iPhone On Oct 9, 2021, at 7:32 AM, WSC Operations Engineer <wscopsengineer@conocophillips.com> wrote: Apologies for the typo. The shoe is 12,241’ MD and the completion depth is 12,219’MD. Sydney From: WSC Operations Engineer Sent: Saturday, October 9, 2021 7:24 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Nagel, Matt B <Matt.B.Nagel@conocophillips.com>; Anderson, Nina M <Nina.Anderson@conocophillips.com> Subject: MT7-06 Completion Set Depth Good morning, Doyon 25 is currently running completion on MT7-06. We have been unable to progress the tubing tail into open hole past 12,298’ MD. This is just outside the Intermediate Shoe at 12,219’ MD. We will therefore plan to complete the well to a depth of 12,240’ MD, versus intended 12,759’ MD, which places the packer top at 10,143’ MD. Please let me know if you have any questions or concerns. Thank you, Polaris – WSC Operations Engineer Sydney Deering / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) <image001.png> Tubing / Liner Completion: 1) 4-½” x 1” Vanoil KBMG GLM (2x) 2) 4-½” X Landing Nipple (3.813" ID) 3) 4-½” Baker Premier Production Packer 4) 4-½” DB Landing Nipple w/RHC (3.75" ID) 5) 4-½” NS Dissolving Shoe 7-5/8" 29.7# HYD563 and 33.7# L-80 TXP BTC-SR Casing @ 12,241' MD / 8,293' TVD Casing set in the Alpine D Sand 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 4-1/2" 12.6# L-80 Hyd563 Cement Placement per USIT on 8/16 9650' MD to 10,950' MD Top Alpine C 12,411' MD / 8331' TVD MT7-06wp09 - 3 String Producer, As Drilled/Proposed Schematic (updated 10.6.21) GLGL 13-3/8" 68# L-80 TXP / HYD 563 Surface Casing set @ 3,425' MD / 3043' TVD Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,442' MD 9-7/8" hole section to ~ 500' above HRZ 11" hole section to TD Remedial Cement Perforations at 10,923 – 10,925' MD 4-½” 12.6# L-80 Hyd563 Liner set HIGH @ ~ 25,254' MD MT7-06PB1 TD @ 26,241' MD / 8,510' TVD 4-½” 12.6# L-80 Hyd563 Liner set HIGH @ ~ 25,254' MD MT7-06PB1 TD @ 26,241' MD / 8,510' TVD Top of Fish in MT7-06PB1 @ 12,985' MD 4 ½” Tubing tail ~12,219' Baker Premier Packer @ 10,143' MT7-06 TD @ 26,154' MD / 8,337' TVD MT7-06 TD @ 26,154' MD / 8,337' TVD From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S; Livingston, Erica J; Njoku, Johnson; Anderson, Nina M; Nagel, Matt B; WSC Rig Advisor Cc:Vanderhorst, Mark J; Brillon, Chris L; Lee, David L Subject:MT7-06 Interim Completion (PTD #221-048) Date:Wednesday, October 6, 2021 5:11:21 PM Attachments:image001.png MT7-06 Interim Completion Schematic.pdf Hi Victoria, ConocoPhillips has made several attempts to run the lower completion on MT7-06 with no success. With the continued difficulties of the production liner run, ConocoPhillips is requesting verbal approval to proceed with running an interim completion and please advise on requested documentation required to complete the well as stated. Running the interim completion will provide the time needed to engineer and modify the current well design and allow for a successful completion run that ensures fracture stimulation as originally planned. Currently, ConocoPhillips is laying down the lower completion consisting of 4-1/2” liner, frac sleeves, and swell packers. Once this operation is complete a BOPE test will be conducted if needed to reset the clock, and a 4-1/2” interim completion with a production packer will be run to ~12,755’ MD, and Doyon 25 will rig down and move off MT7-06. Attached is a planned schematic for the interim completion. Thanks, Polaris – WSC Operations Engineer Sydney Deering / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) Tubing / Liner Completion: 1) 4-½” x 1” Vanoil KBMG GLM (2x) 2) 4-½” X Landing Nipple (3.813" ID) 3) 4-½” Baker Premier Production Packer 4) 4-½” DB Landing Nipple w/RHC (3.75" ID) 5) 4-½” NS Dissolving Shoe 7-5/8" 29.7# HYD563 and 33.7# L-80 TXP BTC-SR Casing @ 12,241' MD / 8,293' TVD Casing set in the Alpine D Sand 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 4-1/2" 12.6# L-80 Hyd563 Cement Placement per USIT on 8/16 9650' MD to 10,950' MD Top Alpine C 12,411' MD / 8331' TVD MT7-06wp09 - 3 String Producer, As Drilled/Proposed Schematic (updated 10.6.21) GL 13-3/8" 68# L-80 TXP / HYD 563 Surface Casing set @ 3,425' MD / 3043' TVD Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,442' MD 9-7/8" hole section to ~ 500' above HRZ 11" hole section to TD Remedial Cement Perforations at 10,923 – 10,925' MD 4-½” 12.6# L-80 Hyd563 Liner set HIGH @ ~ 25,254' MD MT7-06PB1 TD @ 26,241' MD / 8,510' TVD Top of Fish in MT7-06PB1 @ 12,985' MD 4 ½” Tubing tail ~200' past sidetrack ~12,755' Baker Premier Packer @ 10,628' MT7-06 TD @ 26,154' MD / 8,337' TVD From:Smith, Travis T To:Wallace, Chris D (OGC); Loepp, Victoria T (OGC) Cc:Earhart, Will C Subject:GMTU MT6-08 (PTD#218-048-0) Patch Troubleshooting Date:Wednesday, September 29, 2021 4:21:24 PM Chris & Victoria— GMTU well MT6-08 (PTD#218-048-0, Sundry #321-459) recently had a retrievable patch set in the tubing to address a suspected leak in a gas lift mandrel. During the subsequent monitoring period of water injection the TxIA communication appears to be ongoing. Our plan forward is to run another acoustic LDL with the tubing patch still in the well and attempt to determine if there is a leak signature at the patch. If so, we will pull and replace the tubing patch. E-line crews are at Alpine currently, but on an uncertain time commitment supporting the drilling rigs. We propose leaving the well on stabilized water injection for the time being such that we can run an acoustic LDL at the first opportunity logistically. After the log is complete we will shut-in the well. We are not intending to perform the MITIA listed in the Sundry unless we can successfully address what looks like an ongoing issue with the patch at the GLM. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com STATE OF ALASKA Reviewed By: `J� Z OIL AND GAS CONSERVATION COMMISSION P.I. Supry t' It Zt I BOPE Test Report for: GMTU MT7-06 - Comm Contractor/Rig No.: Doyon 25 PTD#: 2210480 ' DATE: 9/25/2021 r Inspector Austin McLeod - Insp Source Operator: ConocoPhillips Alaska, Inc. Operator Rep: Tucker/Arthur Rig Rep: Potter/Coleman Inspector Type Operation: DRILL, Sundry No: Test Pressures: Inspection No: bopSAM210926134956 Rams: Annular: Valves: MASP: Type Test: BIWKLY 250/3500 - 250/3500 ' 250/3500. 3092 — Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly _ 1 - P/F Lower Kelly Visual Alarm Time/Pressure PIF Location Gen.: P Trip Tank P - — P System Pressure 3000 - P Housekeeping: _P_ Pit Level Indicators _ P P Pressure After Closure 1_750 P PTD On Location P Flow Indicator P P 200 PSI Attained 14 P " Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 76 - P . Well Sign P H2S Gas Detector P- P _ Blind Switch Covers: All stations - P Drl. Rig P - MS Misc NA NA Nitgn. Bottles (avg) 6 at71983 - P " Hazard Sec. P_- P - Inside Reel Valves 0 -_ NA ACC Misc 0 NA Misc NA Check Valve 0 NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly _ 1 - P -_ Lower Kelly 1 P_ Ball Type 2 P_ Inside BOP 1 P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 15 P Annular Preventer 1- 13-5/8 _FP_ Manual Chokes 1 P #1 Rams —I 2-7/8x5-1/2 -P -__ Hydraulic Chokes I P #2 Rams I Blind/Shear FP CH Misc 0 _ NA #3 Rams 1 2-7/8x5-1/2 P #4 Rams NA #5 Rams _0_ - - — 0 -- __ NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3-1/8 P- Quantity P/F HCR Valves 2 '3-1/8 P - Inside Reel Valves 0 -_ NA Kill Line Valves 2 3-1/8 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 2 �- Test Results ✓ Test Time 5 Remarks: 4"& 4-112" joints. Annular on both (operators discretion). FP on 4 -1/2 -adjust annular psi/function for a pass. Low test blinds FP - bleed down & come back for a pass. DOYON RIG 25 ACCUMULATOR DRAW DOWN WORKSHEET WELL: MT7-06 C7�: 2 -sl DATE: 9/25/21 ACCUMULATOR PSI 3000 MANIFOLD PSI 1450 FUNCTION RAMS/ANNULAR/ HCR -S, DON'T FUNCTION BLINDS! FUNCTION ONE RAM TWICE FT PRSSURE STABILIZE AND RECORD BACK UP NITROGEN BOTTLE'S ACCUMULATOR PSI 1750 NITROGEN BOTTLE'S PSI BOTTLE # 1 2000 BOTTLE # 2 1900 BOTTLE # 3 2000 BOTTLE # 4 2000 BOTTLE # 5 2000 BOTTLE # 6 2000 AVG FOR 6 BOTTLE'S = 1 1983 TURN ON ELEC. PUMP, SEC FOR 200 PSI = 114 sec. TURN ON AIR PUMP'S TIME FOR FULL CHARGE = 176 sec. PRESSURE TEST SCHEDULE 9/25/21 4" Test Joint 1. Annular, Upper IBOP, 4" Rig floor KILL, CMV # 1, 13,14,15 2. Upper Pipe Rams, Lower IBOP , HCR kill, CMV # 2,10,12 3. 4" Dart, Man Kill, CMV # 9,11, 6. 4. 4" FOSV #1, CMV # 5, 7, 8. 5. 4"FOSV#2, CMV #3 6. Lower Pipe Rams 7. Blind Rams, CMV #4 8. Super Choke & Manual Choke 4"Test Joint 9. Upper Pipe Rams, HCR Choke 10. Upper Pipe Rams, Manual Choke 11. Lower Pipe Rams 12. Annular Tested 5 mins 250 low pressure, and 5 min 3500 psi high. Super Choke and Manually Operated choke tested to 2000 psi. SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7T" SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: MT7-06PB1 100 - 26241 7 Boxes SENT BY: M. McCRACKEN RECEIVE® SEP 2 4 2021 A®GCC DATE: September 24, 2021 AIR BILL: N/A CPAI: 2021092401 CHARGE CODE: N/A NAME: MT7-06PB1 NUMBER OF BOXES: 7 Box 103-2-0(331--7o-oo UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN: MIKE McCRACKEN Mike.mccracken@conocophillips.com 1--2RECEIVE,-1 1 �L( D 7/S From:Smith, Travis T To:Loepp, Victoria T (OGC); Wallace, Chris D (OGC) Subject:RE: [EXTERNAL]RE: MT6-08 (PTD 218-048-0)10-403 Tubing Patch Date:Monday, September 13, 2021 10:22:12 AM Thank you so much! This must be lagging in our system getting back to me. Very sorry for the confusion, and thanks again for the help. Travis From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, September 13, 2021 10:08 AM To: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: [EXTERNAL]RE: MT6-08 (PTD 218-048-0)10-403 Tubing Patch This was approved/returned on 9/10/21. From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, September 13, 2021 9:49 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: MT6-08 (PTD 218-048-0)10-403 Tubing Patch Hello Victoria— I left you a voicemail earlier this morning regarding this well / Sundry application. Sorry for the short notice on this work, but it’s a high priority for us and we have an opportunity to set the lower part of this patch tomorrow with e-line at Alpine. I was hoping I could get a confirmation that we are approved to start work on this retrievable patch for MT6-08. Thanks very much for the help! Travis Smith From: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Sent: Wednesday, September 8, 2021 4:25 PM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Cc: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]RE: MT6-08 (PTD 218-048-0)10-403 Tubing Patch CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Received for processing From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Wednesday, September 8, 2021 4:17 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: MT6-08 (PTD 218-048-0)10-403 Tubing Patch Hello, I have attached the 10-403 for GMTU MT6-08 (PTD 218-048-0) Tubing Patch. Please let me know if you need any additional information. Thank you, Amy Amy A. Conklin Well Integrity & Interventions Technical Aide ConocoPhillips Alaska (Fairweather, LLC) 700 G Street, ATO 1307, Anchorage, AK 99501 Office: (907) 265-1484 Cell: (907) 841-2477 Amy.A.Conklin@contractor.conocophillips.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?CO 793 MT7-06 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12318 8311 12241 8293 3092 Casing Collapse Structural Conductor Surface 2260 psi Intermediate 6890 psi Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chris Brillon Contact Name:Nina Anderson Wells Engineering Manager Contact Email:nina.anderson@conocophillips.com Contact Phone: 907-229-4008 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Victoria Loepp 9/3/2021 Tubing Grade:Tubing MD (ft): 7740 Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA081800, 932516000, AA081736 221-048 P.O. Box 100360, Anchorage AK, 99510-0360 50-103-20831-00-00 ConocoPhillips Length Size Greater Mooses Tooth - Rendezvous TVD BurstMD 4790 psi 5021 psi 120 3043 8293 120 3425 20 13.375 80.5 7.62512201 3385 Perforation Depth MD (ft): 12241 10925 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/8/2021 m n P s 2 6 5 6 t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 321-467 By Meredith Guhl at 8:10 am, Sep 13, 2021 DLB 09/13/2021 DSR-9/13/21 X ; AA081781 DLB Conditions of approval on PTD apply VTL 9/21/21 File with PTD 10-407 X BOP test to 3500 psig Annular preventer test to 2500 psig X dts 9/21/2021 JLC 9/21/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.21 15:00:17 -08'00' RBDMS HEW 9/22/2021 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 10, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry to Approved Program for MT7-06 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Change Approved Program for MT7-06, an onshore production well from the MT7 drilling pad currently being drilled with the Doyon 25 drilling rig. MT7-06 is planned to be a fracture stimulated horizontal producer within the Rendevouz reservoir. The 16” surface hole has been drilled to 3,435’ MD / 3049’ TVD with casing run to 3425’ MD / 3043’ TVD. The 9-7/8” x 11” intermediate hole was drilled to 12,318’ MD / 8311’ TVD into the Alpine D sand. While running the 4.5” production liner on MT7-06, we were unable to run liner to the final TD needed with the frac sleeve/swell packer configuration. Subsequent efforts to move the liner resulted in releasing from the liner. Fishing operations were unsuccessful in retrieving the entire liner, therefore the rig moved towards cutting operations to remove enough of the liner to allow for a successful open hole sidetrack below the existing 7-5/8” intermediate casing shoe. Two successful mechanical cuts were made with the deeper of the two at 12,985’ MD.The upper part of the liner was removed from the hole with the remaining liner top at 12,985’ MD. Current and upcoming operations are as follows: x PU 6-1/2” BHA and RIH to open hole sidetrack +/- 12,540’ MD x Directionally Drill 6-1/2” hole to TD paralleling the original MT7-06PB1 wellbore x POOH and prep to run liner x Run 4-1/2” liner with swell packers and frac sleeves to TD x Resume to Planned operations per the original PTD Verbal approval to start sidetrack operations was requested and approved on Friday September 3rd. Please find attached the information for your review. Pertinent information attached to this application includes the following: 1.A proposed schematic 2.Directional Plan Note wellplan is labeled as MT7-06L1 for initial planning. All files and surveys will be corrected for final 10-407 submittal with MT7-06PB1 and MT7-06. If you have any questions or require further information, please contact Nina Anderson at 229-4008 (nina.anderson@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: MT7-06 Well File / Jenna Taylor ATO 1560 David Lee ATO 1726 Chris Brillon ATO 1548 Nina Anderson Drilling Engineer ,p MT7-06 is planned to be a fracture gp y g stimulated horizontal producer within the Rendevouz reservoir. While running the 4.5” production liner on MT7-06, we were unable to run liner to the final TD needed with the frac g p, sleeve/swell packer configuration. Subsequent efforts to move the liner resulted in releasing from the liner. Fishing operationspg q g gp were unsuccessful in retrieving the entire liner, therefore the rig moved towards cutting operations to remove enough of theg,g gp g liner to allow for a successful open hole sidetrack below the existing 7-5/8” intermediate casing shoe.Two successful p g g mechanical cuts were made with the deeper of the two at 12,985’ MD. The upper part of the liner was removed from the holep with the remaining liner top at 12,985’ MD. Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” Vanoil KBMG GLM (2-3x) 3) HES Downhole Gauge 4) 4-½” Baker Premier Production Packer @ ~10,675 MD / 7596' TVD 5) 4-½” DB Landing Nipple w/DFCV (3.75" ID) 6) ZXP Liner Top Packer / Hanger w/ Tie Back sleeve @ ~10,745' MD / 7637' TVD 4-½” 12.6# L-80 Hyd563 Liner w/ swell packers and closeable frac ports set @ ~ 26,241' MD 7-5/8" 29.7# HYD563 and 33.7# L-80 TXP BTC-SR Casing @ 12,241' MD / 8,293' TVD Casing set in the Alpine D Sand 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 4-1/2" 12.6# L-80 Hyd563 Cement Placement per USIT on 8/16 9650' MD to 10,950' MD Top Alpine C (Prognosed) 12,385' MD / 8335' TVD MT7-06wp09 - 3 String Producer, As Drilled/Proposed Schematic (updated 09.10.21) D B GLGL GLGL Downhole Gauge 13-3/8" 68# L-80 TXP Surface Casing set @ 3,435' MD / 3049' TVD (updated with actuals) Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,500' MD 9-7/8" hole section to ~ 500' above HRZ 11" hole section to TD Remedial Cement Perforations at 10,923 – 10,925' MD 4-½” 12.6# L-80 Hyd563 Liner set HIGH @ ~ 25,254' MD MT7-06PB1 TD @ 26,241' MD / 8,510' TVD 4-½” 12.6# L-80 Hyd563 Liner set HIGH @ ~ 25,254' MD MT7-06PB1 TD @ 26,241' MD / 8,510' TVD Top of Fish in MT7-06PB1 @ 12,985' MD 0501 501 1001 1001 1501 1501 2001 2001 2501 2501 3001 3001 5001 5001 8001 8001 12001 12001 18001 18001 28501 MT7-06L1_wp09 Plan Summary 0 3 Dogleg Severity3500 7000 10500 14000 17500 21000 24500 Measured Depth 13 3/8" 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in] 40 990 MT7-03 40 3462 MT7-04 12999 13495 19007 MT7-06 0 4500 True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500 Vertical Section at 175.24° 13 3/8" 0 50 100 Centre to Centre Separation0 1000 2000 3000 4000 5000 6000 7000 Measured Depth Equivalent Magnetic Distance DDI 7.223 SURVEY PROGRAM Date: 2021-08-30T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.55 198.00 0_MT7-06 (MT7-06) GYD-GC-SS 335.14 12524.22 1_MT7-06 (MT7-06) MWD+IFR2+SAG+MS 12524.22 26157.23 MT7-06L1_wp09 (MT7-06L1) MWD+IFR2+SAG+MS Surface Location North / 5915534.76 East / 1429972.89 Ground / 100.90 CASING DETAILS No casing data is available Mag Model & Date: BGGM2020 03-Aug-21 Magnetic North is 14.80° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.41° 57152.00nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 112524.22 79.77 152.11 8361.80 -6288.43 -4543.55 0.00 0.005889.28 212675.32 78.00 158.00 8390.95 -6422.79 -4481.03 4.00 107.586028.37 313019.32 89.89 159.91 8427.18 -6741.48 -4358.48 3.50 9.21 6356.14 413677.26 89.89 159.91 8428.45-7359.41 -4132.52 0.00 0.006990.70 MT7-06L1_Heel 513927.63 87.92 153.32 8433.24 -7589.03 -4033.23 2.75 -106.657227.78 614043.79 87.92 153.32 8437.45 -7692.75 -3981.10 0.00 0.007335.47 MT7-06L1 - Point 2 Rev 3 714278.32 90.22 152.84 8441.26 -7901.82 -3874.94 1.00 -11.667552.64 815557.91 90.22 152.84 8436.37 -9040.34 -3290.90 0.00 0.008735.74 MT7-06L1 - Point 5 915590.24 89.90 152.88 8436.34-9069.11 -3276.15 1.00 173.11 8765.64 1016062.60 89.90 152.88 8437.18 -9489.55 -3060.83 0.00 0.009202.50 MT7-06L1 - Point 6 1116068.08 89.84 152.88 8437.19 -9494.43 -3058.34 1.00 -177.109207.57 1216567.30 89.84 152.88 8438.56 -9938.75 -2830.76 0.00 0.009669.26 MT7-06L1 - Point 7 1316660.29 88.91 152.88 8439.57-10021.51 -2788.37 1.00 179.939755.26 1417072.06 88.91 152.88 8447.38-10387.94 -2600.70 0.00 0.0010136.02 MT7-06L1 - Point 8 1517087.44 88.76 152.88 8447.69-10401.63 -2593.69 1.00 -179.7710150.24 1618081.67 88.76 152.88 8469.22-11286.34 -2140.56 0.00 0.0011069.53 MT7-06L1 - Point 9 1718142.55 89.37 152.88 8470.21-11340.52-2112.81 1.00 0.0511125.82 1818586.39 89.37 152.88 8475.11-11735.54 -1910.50 0.00 0.0011536.28 MT7-06L1 - Point 10 1918731.46 90.82 152.88 8474.87-11864.65 -1844.37 1.00 -0.0311670.44 2020100.60 90.82 152.88 8455.31-13083.13 -1220.29 0.00 0.0012936.55 MT7-06L1 - Point 12 2120225.66 89.57 152.88 8454.89-13194.43 -1163.28 1.00 179.9813052.20 2222119.42 89.57 152.88 8469.16-14879.93 -300.01 0.00 0.0014803.58 MT7-06L1 - Point 13 2322223.52 88.53 152.88 8470.89-14972.57 -252.57 1.00 179.9814899.85 2422624.26 88.53 152.88 8481.19-15329.13 -69.95 0.00 0.0015270.34 MT7-06L1 - Point 14 2522687.01 89.15 152.88 8482.46-15384.97 -41.35 1.00 -0.1015328.36 2623129.01 89.15 152.88 8488.98-15778.32 160.12 0.00 0.0015737.10 MT7-06L1 - Point 15 2723189.04 89.76 152.88 8489.55-15831.75 187.49 1.00 0.0615792.61 2824138.39 89.76 152.88 8493.61-16676.72 620.26 0.00 0.0016670.61 MT7-06L1 - Point 16 2924226.28 90.63 152.88 8493.31-16754.94 660.33 1.00 0.0416751.89 3024643.11 90.63 152.88 8488.70-17125.92 850.32 0.00 0.0017137.36 MT7-06L1 - Point 17 3124699.04 90.07 152.88 8488.35-17175.70 875.82 1.00 -179.8817189.09 3225147.80 90.07 152.88 8487.77-17575.11 1080.40 0.00 0.0017604.12 MT7-06L1 - Point 18 3325200.67 90.60 152.94 8487.46-17622.19 1104.48 1.00 6.8917653.03 3426157.23 90.60 152.94 8477.45-18474.01 1539.58 0.00 0.0018538.05 MT7-06L1_Toe FORMATION TOP DETAILS No formation data is available Actual MT7-06 @ 140.45usft (D25) 040008000True Vertical Depth (2000 usft/in)0 4000 8000 12000 16000Vertical Section at 175.24° (2000 usft/in)MT7-06L1 - Point 9MT7-06L1 - Point 18MT7-06L1 - Point 5MT7-06L1_LandingMT7-06L1 - Point 10MT7-06L1 - Point 7MT7-06L1 - Point 6MT7-06L1 - Point 13MT7-06L1_HeelMT7-06L1 - Point 15MT7-06L1 - Point 17MT7-06L1 - Point 12MT7-06L1 - Point 4MT7-06L1 - Point 19MT7-06L1 - Point 8MT7-06L1_ToeMT7-06L1 - Point 1MT7-06L1 - Point 11MT7-06L1 - Point 3MT7-06L1 - Point 14MT7-06L1 - Point 1613 3/8"100020004000500060007000800090001000011000120001300014000150001700019000 200002100022000230002400026000 MT7-06/MT7-06L1_wp09 Section View Project: Western North SlopeSite: GMT2 Rendezvous PadWell: MT7-06Wellbore: MT7-06L1Design: MT7-06L1_wp09 Plan View Project: Western North SlopeSite: GMT2 Rendezvous PadWell: MT7-06Wellbore: MT7-06L1Design: MT7-06L1_wp09-18000-12000-60000South(-)/North(+) (3000 usft/in)-12000 -6000 0 6000 12000West(-)/East(+) (3000 usft/in)MT7-06L1 - Point 16MT7-06L1 - Point 14MT7-06L1 - Point 2 Rev 3MT7-06L1 - Point 3MT7-06L1 - Point 11MT7-06L1_ToeMT7-06L1 - Point 8MT7-06L1 - Point 12MT7-06L1 - Point 17MT7-06L1 - Point 15MT7-06L1_HeelMT7-06L1 - Point 13MT7-06L1 - Point 6MT7-06L1 - Point 7MT7-06L1 - Point 10MT7-06L1_LandingMT7-06L1 - Point 1813 3/8"40005000600070008000MT7-06/MT7-06L1_wp09 Certificate Of Completion Envelope Id: 339CDDE790264CDA9C7B30C8B5444C5B Status: Completed Subject: Please DocuSign: MT7-06 AOGCC Complete Sundry for OH Sidetrack.pdf Source Envelope: Document Pages: 33 Signatures: 2 Envelope Originator: Certificate Pages: 5 Initials: 0 Nina Anderson AutoNav: Enabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 935 N Eldridge Pkwy Houston, TX 77079 Nina.Anderson@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 9/10/2021 1:50:04 PM Holder: Nina Anderson Nina.Anderson@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Chris Brilon chris.l.brillon@conocophillips.com Wells Engineering Manager Security Level: Email, Account Authentication (None)Signature Adoption: Uploaded Signature Image Using IP Address: 138.32.8.5 Sent: 9/10/2021 1:51:39 PM Viewed: 9/10/2021 4:46:08 PM Signed: 9/10/2021 4:46:53 PM Electronic Record and Signature Disclosure: Accepted: 9/10/2021 4:46:08 PM ID: af06a022-ded1-47b1-b52b-b63b73321b70 Nina Anderson nina.anderson@conocophillips.com Security Level: Email, Account Authentication (None) Signature Adoption: Drawn on Device Using IP Address: 138.32.8.5 Sent: 9/10/2021 1:51:39 PM Viewed: 9/10/2021 1:51:55 PM Signed: 9/10/2021 1:52:01 PM Electronic Record and Signature Disclosure: Accepted: 7/17/2021 3:19:12 PM ID: 2851b920-4f46-4fba-8015-522a50962e70 In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 9/10/2021 1:51:40 PM Certified Delivered Security Checked 9/10/2021 1:51:55 PM Envelope Summary Events Status Timestamps Signing Complete Security Checked 9/10/2021 1:52:01 PM Completed Security Checked 9/10/2021 4:46:53 PM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. 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From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; Buck, Brian R; WSC Rig Advisor; Anderson, Nina M; Klem, Adam; Gorham, Brad Subject:RE: MT7-06 Intermediate Casing Cement Evaluation (PTD #221-048) Date:Tuesday, August 17, 2021 4:44:31 PM Attachments:image001.png SLB_ConocoPhillips Alaska_MT7-06_Quicklook Cement Report_08-16-2021.pdf Hi Victoria, Please see the attached MT7-06 intermediate remedial cement log interpretation from Schlumberger. If you have any questions, please let me know. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) From: WSC Operations Engineer Sent: Tuesday, August 17, 2021 2:52 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Anderson, Nina M <Nina.Anderson@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com>; Gorham, Brad <Brad.Gorham@conocophillips.com> Subject: MT7-06 Intermediate Casing Cement Evaluation (PTD #221-048) Good morning Victoria, Attached is the USIT log for the MT7-06 intermediate remedial cement operation and well schematic. We are currently waiting on Schlumberger cement log interpretation and will provide once completed. As per ConocoPhillips Cementing Subject Matter Expert: Total column of cement from remediation = 9,650’ MD / 6,990’ TVD – 10,950’ MD / 7,753’ TVD (1,300’ MD / 763’ TVD) The Moderate to High Bond rated cement shows some micro-debonding but does not have fluid connectivity. These areas should be considered isolation and equal 525’ MD. The additional 860’ of cement with moderate bond does show some fluid connectivity (potential micro-channels) but would probably not facilitate injection Depth Quality of Bond Length 11,805 – 11,780’ (Moderate to High Bond) 25’ 11,700 – 11,680’ (Moderate to High Bond) 20’ 11,170 – 11,130’ (Moderate to High Bond) 60’ 11,130 – 11,150’ (Moderate Bond) 20’ 10,920 – 10,500’ (Moderate to High Bond) 420’ 10,500 – 10,360’ (Moderate Bond) 140’ 10,350 – 9,650’ (Moderate Bond) 700’ Top of HRZ is at 10,414’ MD / 7,443’ TVD Top of Alpine D is at 12,198’ MD / 8,282’ TVD The Intermediate casing shoe is set at 12,241’ MD / 8,293’ TVD Production packer planned at 10,675’ MD / 7,596’ TVD Liner Top Packer planned at 10,745’ MD / 7,637’ TVD Currently we are conducting a scraper run to remove cement sheath across packer setting depth and will perform an FIT on the perforations to 11.75 ppg EMW. We will then conduct a BOPE test, pick up the production hole drilling assembly, drillout shoe track and 20’ of new formation, conduct an FIT on intermediate casing shoe, and drill the production lateral as per plan. If you have any questions, please let me know. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; Buck, Brian R; WSC Rig Advisor; Anderson, Nina M; Klem, Adam; Gorham, Brad Subject:MT7-06 Intermediate Casing Cement Evaluation (PTD #221-048) Date:Tuesday, August 17, 2021 2:54:56 PM Attachments:image001.png CPAI_MT7-06_USIT_16AUG21_FIELDPRINT (1).Pdf MT7-06wp09_08.17.21.pdf Good morning Victoria, Attached is the USIT log for the MT7-06 intermediate remedial cement operation and well schematic. We are currently waiting on Schlumberger cement log interpretation and will provide once completed. As per ConocoPhillips Cementing Subject Matter Expert: Total column of cement from remediation = 9,650’ MD / 6,990’ TVD – 10,950’ MD / 7,753’ TVD (1,300’ MD / 763’ TVD) The Moderate to High Bond rated cement shows some micro-debonding but does not have fluid connectivity. These areas should be considered isolation and equal 525’ MD. The additional 860’ of cement with moderate bond does show some fluid connectivity (potential micro-channels) but would probably not facilitate injection Depth Quality of Bond Length 11,805 – 11,780’ (Moderate to High Bond) 25’ 11,700 – 11,680’ (Moderate to High Bond) 20’ 11,170 – 11,130’ (Moderate to High Bond) 60’ 11,130 – 11,150’ (Moderate Bond) 20’ 10,920 – 10,500’ (Moderate to High Bond) 420’ 10,500 – 10,360’ (Moderate Bond) 140’ 10,350 – 9,650’ (Moderate Bond) 700’ Top of HRZ is at 10,414’ MD / 7,443’ TVD Top of Alpine D is at 12,198’ MD / 8,282’ TVD The Intermediate casing shoe is set at 12,241’ MD / 8,293’ TVD Production packer planned at 10,675’ MD / 7,596’ TVD Liner Top Packer planned at 10,745’ MD / 7,637’ TVD Currently we are conducting a scraper run to remove cement sheath across packer setting depth and will perform an FIT on the perforations to 11.75 ppg EMW. We will then conduct a BOPE test, pick up the production hole drilling assembly, drillout shoe track and 20’ of new formation, conduct an FIT on intermediate casing shoe, and drill the production lateral as per plan. If you have any questions, please let me know. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” Vanoil KBMG GLM (2-3x) 3) HES Downhole Gauge 4) 4-½” Baker Premier Production Packer 5) 4-½” DB Landing Nipple w/DFCV (3.75" ID) 6) Liner Top Packer / Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner w/ swell packers and closeable frac ports set @ ~ 26,241' MD 7-5/8" 29.7# HYD563 and 33.7# L-80 TXP BTC-SR Casing @ 12,241' MD / 8,293' TVD Casing set in the Alpine D Sand 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface Production Hole TD 26,241' MD / 8,510' TVD 4-1/2" 12.6# L-80 Hyd563 Cement Placement per USIT on 8/16 9650' MD to 10,950' MD Top Alpine C (Prognosed) 12,385' MD / 8335' TVD MT7-06wp09 - 3 String Producer, As Drilled /Proposed Schematic (updated 08.17.21) D B GLGL GLGL Production Packer @ 10,675 MD / 7,596' TVD ZXP Liner Top Packer @ ~ 10,745' MD / 7,637' TVD Downhole Gauge 13 -3/8" 68# L-80 TXP Surface Casing set @ 3,435' MD / 3049' TVD (updated with actuals ) Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,500' MD 9-7/8" hole section to ~ 500' above HRZ 11" hole section to TD Remedial Cement Perforations at 10,923 – 10,925' MD 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?CO 793 MT7-06 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12318 8311 12241 8293 3092 Casing Collapse Structural Conductor Surface 2260 psi Intermediate 6890 psi Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chris Brillon Contact Name:Nina Anderson Wells Engineering Manager Contact Email:nina.anderson@conocophillips.com Contact Phone: 907-229-4008 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Victoria Loepp 8/10/2021 Tubing Grade:Tubing MD (ft): 7740 Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA081800, 932516000, AA081736 221-048 P.O. Box 100360, Anchorage AK, 99510-0360 50-103-20831-00-00 ConocoPhillips Length Size Greater Mooses Tooth - Rendezvous TVD BurstMD 4790 psi 5021 psi 120 3043 8293 120 3425 20 13.375 80.5 7.62512201 3385 Perforation Depth MD (ft): 12241 10925 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/10/2021 m n P 2 6 5 6 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:35 am, Aug 12, 2021 321-396 X DLB 08/12/2021 AA081781 DLB Conditions of approval on PTD apply X X BOP test to 3500 psig Annular preventer test to 2500 psig USIT or CBL required for cement evaluation to float collar. file with PTD 10-407 VTL 8/13/21 dts 8/13/2021 JLC 8/13/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.13 11:14:11 -08'00' ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 11, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry to Change Approved Program for MT7-06 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Change Approved Program for MT7-06, an onshore production well from the MT7 drilling pad currently being drilled with the Doyon 25 drilling rig. MT7-06 is planned to be a fracture stimulated horizontal producer within the Rendevouz reservoir. The 16” surface hole has been drilled to 3,435’ MD / 3049’ TVD with casing run to 3425’ MD / 3043’ TVD. The 9-7/8” x 11” intermediate hole was drilled to 12,318’ MD / 8311’ TVD into the Alpine D sand. The D25 rig team attempted to run the 7-5/8” intermediate casing to the planned set depth of 12,306’ MD. Significant drag and obstructions were encountered while running casing towards the top of the Milluveach around 11,117’ MD. After working the casing in excess of 48 hours, it was run to a depth of 12,241’ MD on Thursday August 5th. The rig worked pipe although they were unable to establish circulation due to high pump pressures and suspected packoffs in the overburden shale package. The decision was made to proceed with cementing operations per procedure following an injectivity test at 4 bpm on August 6th. SLB pumped 110 bbls of Class G 15.8 ppg cement at 4 bpm with zero returns. Plugs were bumped and the floats held per flow check. Cementing equipment was rigged down, 7-5/8” casing was set on emergency slips, and BOPE equipment tested. On Monday August 9th, a SLB USIT log was run on Eline to a depth of 11,802’ MD to evaluate cement behind the 7 -5/8” casing and attempt to determine the location of pack offs. The USIT log results from August 9th indicate insufficient cement in the annular suggesting a remedial cementing job will be necessary to continue drilling operations on MT7-06. The final depths of both the production packer and the liner top packer will be adjusted from the original program and will be based on remedial cement log results. The intention is to continue with the plans to fracture stimulate MT7-06 after the production hole is drilled and completed pending isolation of the reservoir with cement within the confining intervals. Please find attached the information required by 20 ACC 25.280 for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR SUNDRY APPROVAL as per 20 ACC 25.280 2. A description summary of proposed remedial cementing operations 3. A proposed schematic If you have any questions or require further information, please contact Nina Anderson at 229-4008 (nina.anderson@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: MT7-06 Well File / Jenna Taylor ATO 1560 David Lee ATO 1726 Chris Brillon ATO 1548 Nina Anderson Drilling Engineer The USIT log results from August 9th indicate insufficient cement in the annular suggesting a remedial cementing job will begggg g g j necessary to continue drilling operations on MT7-06. The final depths of both the production packer and the liner top packer ygp p pp pp will be adjusted from the original program and will be based on remedial cement log results. The intention is to continue with jgpg g the plans to fracture stimulate MT7-06 after the production hole is drilled and completed pending isolation of the reservoir with p cement within the confining intervals. MT7-06 Intermediate Casing Remedial Cementing Procedure Change Summary: Perforate 7-5/8” casing, Run Cement Retainer, Cement, Run USIT, and Cleanout Casing. 1. PU Halliburton TCP 3-1/8” perf gun and RIH with 4” DP 2. Proposed Perforating depth is +/- 10,925’ MD to 10,926’ MD mid joint per USIT log. a. This is approximately 500’ MD below the top of the HRZ at 10,414’ MD 3. Fire guns per procedure and OWFF 4. Close rams and pump 2-3 bpm to flush perfs taking returns up the annulus 5. Continue circulating and conditioning mud to optimal parameters for cementing operations. Monitor for losses and adjust pump rate as needed. 6. Open rams and observe well for flow 7. Continue RIH with TCP assembly to float collar at ~ 12,153’ MD and spot 55 bbls of 16.0 ppg mud to prevent swapping with the 15.8 ppg cement. Chase with 10.8 ppg LSND mud. 8. POOH with TCP and L/D spent gun assembly. 9. Run 7-5/8” Cement Retainer and set ~ 10,463' MD. 10. Pressure test the retainer 11. Establish circulation at 4 bpm through the perfs and up the annulus 12. Pump cement as per cement program a. 30 bbls 12.5 ppg mud push b. 100 bbls 15.8 ppg Cement tail (minimum volume) c. 10 bbls 12.5 mud push d. 5 bbls fresh water 13. Displace with 10.8 ppg LSND mud 14. Unsting from the retainer and flush DP. Sting back into retainer and perform hesitation squeeze. 15. Unsting from retainer to flush DP. Shut down and OWFF. 16. TOOH and wait on cement ~ 12 hours 17. Rigup and run a USIT log down to retainer. 18. Pickup clean out BHA with 6-1/2” mill tooth bit and Soniscope to evaluate cement below retainer 19. Drill up cement retainer. 20. Circulate hole clean, OWFF. Test perforations to 100 psi over desired FIT pressure per program a. Minimum 11.5 ppg FIT plus 100 psi. Record FIT . 21. Continue RIH to log cement down to the float collar. 22. POOH and lay down cleanout BHA. VTL 8/13/21Run USIT below retainer As Drilled MT7-06 8/11/2021 20" 94# H-40 Welded Conductor 13-3/8"68# L-80 TXP / HYD563 3,425' MD/ 3,043 TVD @ 50϶ inc 9-7/8" x 11" Intermediate 12,318' MD/ 8,311' TVD @ 76.6϶ inc Mud Weight 10.8 ppg in Casing 10.8 ppg in annulus 7-5/8" 33.7 / 29.7# L-80 TXP / HYD563 12,241' MD/8,293' TVD @ 75.9°inc Top of Alpine D 12,198' MD/ 8,282' TVD Top of HRZ 10,414' MD/ 7,443' TVD Perforations 10,925' MD/ 7,740' TVD 6 spf, 60°phasing Target 500' MD / 291' TVD of Cement From:Loepp, Victoria T (CED) To:WSC Operations Engineer Subject:Re: MT7-06 request for remedial cementing operations-APPROVED Date:Tuesday, August 10, 2021 2:05:42 AM Attachments:image001.png Scott, Approval is granted to proceed with remedial operations as outlined below. Please submit a change of approved program sundry as soon as possible. A cement evaluation log is required after the cement job and before proceeding. Victoria Sent from my iPhone On Aug 9, 2021, at 10:53 PM, WSC Operations Engineer <wscopsengineer@conocophillips.com> wrote: Victoria, Thanks for being available to discuss the MT7-06 status and plan for remedial cementing operations on the 7 5/8” casing. The D25 rig team attempted to run the 7-5/8” intermediate casing to the planned set depth of 12,306’ MD. Significant drag and an obstruction was encountered while running the casing towards the top of the Milluveach around 11,117’ MD. After working the casing in excess of 48 hours the casing was run to a depth of 12,241’ MD on Thursday August 5th. The rig worked pipe although they were unable to establish circulation due to high pump pressures and suspected packoffs in the overburden shale package. The decision was made to proceed with cementing operations following an injectivity test at 4 bpm on August 6th. SLB pumped 110 bbls of Class G 15.8 ppg cement at 4 bpm with zero returns. Plugs were bumped and following a thorough flow check, cementing equipment was rigged down. This cement has not been logged, but as much as 43’ of cement may be around the casing shoe in the Alpine D interval. The 7-5/8” casing was set on emergency slips and BOPE equipment tested. On Monday August 9th, a SLB USIT log was run on Eline to a depth of 11,802’ MD to evaluate cement behind the 7-5/8” casing and attempt to determine the location of pack offs. The logs indicate insufficient cement in the annular and that a remedial cementing job is necessary to be able to fracture stimulate MT7-06 per plan. The depths of both the production packer and the liner top packer will be based on remedial cement log results although estimated depths are ~ 10,820’ MD and 10,800’ MD respectively. The intention is to continue with the plans to fracture stimulate MT7-06 after the production hole is drilled and completed pending log showing isolation of the reservoir with cement in the confining intervals. MT7-06 Remedial Cementing Procedure: 1. PU Halliburton TCP 3-1/8” perf gun and RIH with 4” DP 2. Proposed Perforating depth is +/- 10,925’ MD to 10,926’ MD mid joint per USIT log. a. This is approximately 500’ MD below the top of the HRZ at 10,414’ MD 3. Fire guns per procedure and OWFF 4. Close rams and pump 2-3 bpm to flush perfs taking returns up the annulus a. If unable to circulate, the team will determine the next perforation depth above the top HRZ 5. Continue circulating and conditioning mud to optimal parameters for cementing operations. Monitor for losses and adjust pump rate as needed. 6. Open rams and Observe well for flow 7. Continue RIH with TCP assembly to float collar at ~ 12,153’ MD and place 50 bbls of 16.0 ppg mud to prevent swapping with the 15.8 ppg cement 8. POOH with TCP and L/D spent gun assembly. 9. Run 7-5/8” Cement Retainer and set ~ 40’ MD above perforations 10. PT the retainer 11. Establish circulation 12. Pump cement as per cement program a. 30 bbls 12.5 ppg mud push b. 50 bbls 15.8 ppg Cement tail (minimum volume) c. 20 bbls fresh water 13. Displace with 10.8 ppg LSND mud at 6 bpm 14. TOOH and wait on cement ~ 12 hours 15. Perform Clenaout run with soniscope to evaluate cement 16. POOH and lay down cleanout BHA Verbal approval is requested to proceed with remedial cementing operations per the procedure referenced above. Attached is a current schematic to show proposed cementing interval along with a copy of the MT7-06 cementing log. Please reach out to this positional email address or Nina Anderson with additional questions and if a sundry is required. Thanks, Scott Kolstad Polaris – WSC Operations Engineer Sydney Deering / Scott Kolstad wscopsengineer@conocophillips.com 907.263.4544 (Office) <image001.png> Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 <MT7-06 Intermediate Schematics - Updated 8-9-21.pdf> <Main Pass_USIT_Log_(_USI_Cement_)_09Aug21_185135.pdf> From:WSC Operations Engineer To:Loepp, Victoria T (OGC) Cc:WSC Rig Advisor; Lee, David L; Anderson, Nina M; Drilling Supervisor, Doyon 25; Njoku, Johnson Subject:MT7-06 request for remedial cementing operations Date:Monday, August 9, 2021 10:53:26 PM Attachments:image001.png MT7-06 Intermediate Schematics - Updated 8-9-21.pdf Main Pass_USIT_Log_(_USI_Cement_)_09Aug21_185135.pdf Victoria, Thanks for being available to discuss the MT7-06 status and plan for remedial cementing operations on the 7 5/8” casing. The D25 rig team attempted to run the 7-5/8” intermediate casing to the planned set depth of 12,306’ MD. Significant drag and an obstruction was encountered while running the casing towards the top of the Milluveach around 11,117’ MD. After working the casing in excess of 48 hours the casing was run to a depth of 12,241’ MD on Thursday August 5th. The rig worked pipe although they were unable to establish circulation due to high pump pressures and suspected packoffs in the overburden shale package. The decision was made to proceed with cementing operations following an injectivity test at 4 bpm on August 6th. SLB pumped 110 bbls of Class G 15.8 ppg cement at 4 bpm with zero returns. Plugs were bumped and following a thorough flow check, cementing equipment was rigged down. This cement has not been logged, but as much as 43’ of cement may be around the casing shoe in the Alpine D interval. The 7-5/8” casing was set on emergency slips and BOPE equipment tested. On Monday August 9th, a SLB USIT log was run on Eline to a depth of 11,802’ MD to evaluate cement behind the 7-5/8” casing and attempt to determine the location of pack offs. The logs indicate insufficient cement in the annular and that a remedial cementing job is necessary to be able to fracture stimulate MT7-06 per plan. The depths of both the production packer and the liner top packer will be based on remedial cement log results although estimated depths are ~ 10,820’ MD and 10,800’ MD respectively. The intention is to continue with the plans to fracture stimulate MT7-06 after the production hole is drilled and completed pending log showing isolation of the reservoir with cement in the confining intervals. MT7-06 Remedial Cementing Procedure: 1. PU Halliburton TCP 3-1/8” perf gun and RIH with 4” DP 2. Proposed Perforating depth is +/- 10,925’ MD to 10,926’ MD mid joint per USIT log. a. This is approximately 500’ MD below the top of the HRZ at 10,414’ MD 3. Fire guns per procedure and OWFF 4. Close rams and pump 2-3 bpm to flush perfs taking returns up the annulus a. If unable to circulate, the team will determine the next perforation depth above the top HRZ 5. Continue circulating and conditioning mud to optimal parameters for cementing operations. Monitor for losses and adjust pump rate as needed. 6. Open rams and Observe well for flow 7. Continue RIH with TCP assembly to float collar at ~ 12,153’ MD and place 50 bbls of 16.0 ppg mud to prevent swapping with the 15.8 ppg cement 8. POOH with TCP and L/D spent gun assembly. 9. Run 7-5/8” Cement Retainer and set ~ 40’ MD above perforations 10. PT the retainer 11. Establish circulation 12. Pump cement as per cement program a. 30 bbls 12.5 ppg mud push b. 50 bbls 15.8 ppg Cement tail (minimum volume) c. 20 bbls fresh water 13. Displace with 10.8 ppg LSND mud at 6 bpm 14. TOOH and wait on cement ~ 12 hours 15. Perform Clenaout run with soniscope to evaluate cement 16. POOH and lay down cleanout BHA Verbal approval is requested to proceed with remedial cementing operations per the procedure referenced above. Attached is a current schematic to show proposed cementing interval along with a copy of the MT7-06 cementing log. Please reach out to this positional email address or Nina Anderson with additional questions and if a sundry is required. Thanks, Scott Kolstad Polaris – WSC Operations Engineer Sydney Deering / Scott Kolstad wscopsengineer@conocophillips.com 907.263.4544 (Office) Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 As Drilled 1 2 3 FIT at Surface Shoe 18 ppg 4 Tested BOPE 5 Last Test: Upper VBR: Lower VBR: Formation tops TVD MD HRZ 7443.2 10414.4 Kalubik 7500.93 10511.89 K1 7536.29 10571.65 LCU 7622.13 10718.76 Miluveach 7622.13 10718.77 Alpine D 8282.49 12198.26 2-7/8" x 5-1/2" Current BOP Configuration 8/9/2021 7-5/8" Solid Body Rams MT7-06 8/9/2021 Current Barriers Kill Weight Fluid Tested Surface Casing 20" 94# H-40 Welded Conductor 13-3/8"68# L-80 HYD563 x BTCM 3,523' MD/ 3,057 TVD @ 50⁰ inc 9-7/8" x 11" Intermediate 12,318' MD/ 8,311' TVD @ 76.6⁰ inc Mud Weight 10.8 ppg in Casing 11.3 ppg in annulus 7-5/8" 33.7 / 29.7# L-80 TXP / HYD563 12,241' MD/8,293' TVD Top of Alpine D Top of HRZ 10,414' MD/ 7,443' TVD Proposed Perforations within +/-10,914' MD/ 7,734' TVD to avoid a casing collar Target 500' MD / 291' TVD of Cement From:Drilling Supervisor, Doyon 25 To:Regg, James B (OGC); WSC Rig Advisor Cc:WSC Operations Engineer; Hobbs, Greg S; Njoku, Johnson; Vanderhorst, Mark J; AOGCC; Earl, Adam G (OGC); Bixby, Brian D (OGC); DOA AOGCC Prudhoe Bay; AOGCC Web (CED sponsored); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]RE: MT7-06 (PTD #221-048) BOPE Test Extension Request Date:Saturday, August 7, 2021 2:20:50 PM All, We could be ready to test BOPE first thing in the morning 8/8. I can manage time as needed to accommodate witness if desired. Rob Reinhardt / Michael Tucker ConocoPhillips AK Doyon 25 Drilling Supervisors 907-670-4970 From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Friday, August 6, 2021 2:42 PM To: WSC Rig Advisor <wscrigadvisor@conocophillips.com> Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; WSC Operations Engineer <wscopsengineer@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Vanderhorst, Mark J <Mark.J.Vanderhorst@conocophillips.com>; AOGCC <'AOGCC.Inspectors@alaska.gov'>; Earl, Adam G (CED) <adam.earl@alaska.gov>; Bixby, Brian D (CED) <brian.bixby@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; AOGCC Web (CED sponsored) <aogcc.web@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE: MT7-06 (PTD #221-048) BOPE Test Extension Request CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Extension request is approved. Please continue to update our Inspectors on test timing. Sent via the Samsung Galaxy S8 Active, an AT&T 5G Evolution capable smartphone -------- Original message -------- From: WSC Rig Advisor <wscrigadvisor@conocophillips.com> Date: 8/6/21 9:32 AM (GMT-09:00) To: "Regg, James B (CED)" <jim.regg@alaska.gov> Cc: "Drilling Supervisor, Doyon 25" <d25cm@conocophillips.com>, WSC Operations Engineer <wscopsengineer@conocophillips.com>, WSC Rig Advisor <wscrigadvisor@conocophillips.com>, "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com>, "Njoku, Johnson" <Johnson.Njoku@conocophillips.com>, "Vanderhorst, Mark J" <Mark.J.Vanderhorst@conocophillips.com>, AOGCC <'AOGCC.Inspectors@alaska.gov'>, "Earl, Adam G (CED)" <adam.earl@alaska.gov>, "Bixby, Brian D (CED)" <brian.bixby@alaska.gov>, DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>, "AOGCC Web (CED sponsored)" <aogcc.web@alaska.gov>, "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov> Subject: MT7-06 (PTD #221-048) BOPE Test Extension Request Hi Jim, The 2-week BOPE test on Doyon 25 is due on August 7, 2021 at 23:59 hrs. The Company Man submitted a BOPE test notification to the AOGGC on August 2, 2021 and updated the timing on August 4, 2021 (email notification is attached). The rig has successfully run the 7-5/8” intermediate casing to TD and is currently attempting to establish circulation prior to cementing operations. Due to several pack-off events, establishing circulation and conditioning mud before the cement job will take longer than planned. The upper pipe rams and annular preventer were tested with the 7-5/8” test joint before running casing on July 31, 2021. ConocoPhillips is requesting an extension to test the BOPE at the end of the cementing operations. Thank-you for the consideration. John Egbejimba / Ken Harding CPAI WSC Rig Advisor wscrigadvisor.conocophillips.com 1-907-263-4546 From:Elganzoory, Mutasim H To:Drilling Supervisor, Doyon 25; Sawyer, Quinn M; Mabry, Monte D; BLM_AK_AKSO_EnergySection_Notifications; Loepp, Victoria T (OGC) Cc:WSC Rig Advisor; WSC Operations Engineer Subject:Re: [EXTERNAL] MT7-06 BOPE Tests Date:Sunday, July 25, 2021 5:51:57 PM Test results received Thank you Get Outlook for iOS From: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com> Sent: Sunday, July 25, 2021 2:12:30 AM To: Sawyer, Quinn M <qsawyer@blm.gov>; Mabry, Monte D <mmabry@blm.gov>; BLM_AK_AKSO_EnergySection_Notifications <BLM_AK_AKSO_EnergySection_Notifications@blm.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: WSC Rig Advisor <wscrigadvisor@conocophillips.com>; WSC Operations Engineer <wscopsengineer@conocophillips.com> Subject: [EXTERNAL] MT7-06 BOPE Tests This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or responding. Sir/Madame, Attached for your perusal is the test chart and BOPE test report for MT7-06. Thanks, Brandon Book/ Pierre Castro ConocoPhillips AK Doyon 25 Drilling Supervisors 907-670-4970 From: Rig 25 <rig25@doyondrilling.com> Sent: Saturday, July 24, 2021 5:16 PM To: AOGCC <AOGCC.Inspectors@alaska.gov>; jim.regg@alaska.gov; Brooks, Poebe L)CED <phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc: DOYON DRILLING <ahonea@doyondrilling.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com> Subject: [EXTERNAL]BOP Test CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Rig 25 BOP Test 7/24/21 Zak Coleman Rig 25 Tourpusher rig25@doyondrilling.com 907-670-4971 From:Drilling Supervisor, Doyon 25 To:qsawyer@blm.gov; mmabry@blm.gov; BLM_AK_AKSO_EnergySection_Notifications@blm.gov; Loepp, Victoria T (OGC) Cc:WSC Rig Advisor; WSC Operations Engineer Subject:MT7-06 BOPE Tests Date:Sunday, July 25, 2021 2:14:54 AM Attachments:Doyon 25 MT7-06 7-24-21.xlsx Doyon 25 BOP Chart 7-24-21.pdf Doyon 25 Test Sequence 7-24-21.pdf Sir/Madame, Attached for your perusal is the test chart and BOPE test report for MT7-06. Thanks, Brandon Book/ Pierre Castro ConocoPhillips AK Doyon 25 Drilling Supervisors 907-670-4970 From: Rig 25 <rig25@doyondrilling.com> Sent: Saturday, July 24, 2021 5:16 PM To: AOGCC <AOGCC.Inspectors@alaska.gov>; jim.regg@alaska.gov; Brooks, Poebe L)CED <phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc: DOYON DRILLING <ahonea@doyondrilling.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com> Subject: [EXTERNAL]BOP Test CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Rig 25 BOP Test 7/24/21 Zak Coleman Rig 25 Tourpusher rig25@doyondrilling.com 907-670-4971 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Contractor: Rig No.:25 DATE: 7/24/21 Rig Rep.: Rig Phone: 670-4971 Operator: Op. Phone: 670-4970 Rep.: E-Mail Well Name: PTD #2210240 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 MASP: 3092 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8''x5000psi P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 ½ VBR P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8 x 5 ½ VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/8''x5000psi P Inside Reel valves 0NA HCR Valves 2 3-1/8''x5000psi P Kill Line Valves 2 3-1/8''x5000psi P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1450 P Quantity Test Result 200 psi Attained (sec)15 P No. Valves 15 P Full Pressure Attained (sec)109 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 1866 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:5.3 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7/22/21 10:14AM Waived By Test Start Date/Time: 7/24/2021 5:30AM (date) (time)Witness Test Finish Date/Time: 7/24/2021 10:45AM BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Test Annular, Ram #1 & #3 w/ 5" test jt. Test Rams #2 to 250/3500 psi f/ 5/10 min . Test 1 ea 5" FOSV and 1 Dart valve 250/3500psi f/ 5/10 min. Function primary & remote BOPE control stations. Tested LEL and H2S alarms. BLM Rep. Quinn Sawyer waived witness of test. Z.Coleman/B.Marmon CPAI B.Book / P. Castro MT7-06 Test Pressure (psi): rig25@doyondrilling.com Form 10-424 (Revised 04/2018) Doyon 25 MT7-06 7-24-21 (002).xlsx From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; WSC Rig Advisor; Anderson, Nina M Subject:MT7-06 Surface Casing Pressure Test and FIT Form Date:Sunday, July 25, 2021 12:36:28 PM Attachments:image001.png MT7-6 AD FIT 7-25-21.pdf MT7-6 AD FIT 7-25-21.xlsx Hi Victoria, Attached is the MT7-06 surface casing pressure test and formation integrity test form and sheet. The surface casing pressure test achieved 3,500 psi for 30 minutes and the FIT achieved 18.5 ppg EMW. If you have any questions, please let us know. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) Well Name:Rig:Date: Drilling Supervisor:Pump used:3 Barrels Barrels 4 5 2 Casing Test Pressure Integrity Test Hole Size:5 11 RKB-CHF:39.6 Ft 3425.0 Ft-MD 3052.4 Ft-TVD 3455.0 Ft-MD 3071.6 Ft-TVD Bbls psi Min psi Bbls psi Min psi 12.42 2 0 39 0 3639 0.5 140 0.00 1430 0.5 39 1 3638 1 351 0.25 1404 Enter outer casing shoe test results in comments Mud Weight:9.6 ppg 1 680 2 3638 1.5 590 0.50 1380 Casing description references outer casing string.Inner casing OD:12.4 In.1.5 850 3 3637 2 821 1.00 1348 Hole Size is that drilled below outer casing.2 1092 4 3635 2.5 1027 1.50 1337 Use estimated TOC for Hole Depth. 2.5 1300 5 3630 3 1219 2.00 1318 Enter inner casing OD at right. Desired PIT EMW:18.5 ppg 3 1563 6 3628 3.5 1403 2.50 1302 Estimates for Test:1413 psi 0 bbls 3.5 1783 7 3625 3.6 1430 3.00 1284 1 1 4 2050 8 3623 3.50 1272 EMW = Leak-off Pressure + Mud Weight =4.5 2342 9 3621 4.00 1261 0.052 x TVD 0.052 x 3052.4 5 2585 10 3619 4.50 1250 18.6 5.5 2881 15 3612 5.00 1240 6 3130 20 3608 5.50 1231 6.5 3639 25 3603 6.00 1222 30 3598 6.50 1215 7.00 1207 7.50 1201 8.00 1195 8.50 1190 9.00 1185 9.50 1180 10.00 1176 6.5 Bbls 6.5 Bbls 3.6 Bbls 3.5 Bbls Comments: Volume Bled Back Shut-in Pumping Shut-in Volume Pumped PRESSURE INTEGRITY TEST Type of Test: Changes for Annular Adequacy Test Pressure IntegrityTest Hole DepthCasing Shoe Depth Casing Size and Description: Pump Rate: 7/25/2021 Brandon Book/P. Castro 0.50 Pumping 0.1183 MT7-06 Doyon 25 Surface FIT 18.5 PPG, 1,421 PSI CONOCOPHILLIPS Alaska, Inc. Pumping down EMW at 3425 Ft-MD (3052.4 Ft-TVD) =1404 9.61421+PIT 15 Second Shut-in Pressure, psi Volume Pumped Volume Bled Back Volume Input 0 500 1000 1500 2000 2500 3000 3500 4000 0 1 2 3 4 5 6 7PRESSURE CASING TEST LEAK-OFF TEST PIT Point Barrels 0 5 10 15 20 25 30 Shut-In time, Minutes Lost 41 psi during test, held 98.9% of test pressure. MT7-6 AD FIT 7-25-21.xlsx Summary From:Anderson, Nina M To:Loepp, Victoria T (OGC) Cc:Hobbs, Greg S; Livingston, Erica J Subject:Adjustments to approved MT7-06 PTD #221-048 Date:Thursday, July 22, 2021 3:10:27 PM Attachments:MT7-06 Selective Underream.pdf Victoria – Currently we are running our surface casing on MT7-06. Looking ahead at the intermediate hole section, there are a few operational adjustments we would like to implement to improve our performance for both drilling and running casing. We recently received results of our geomechanical model for the shale package at MT7. It has been suggested to increase base mud weight along with MPD backpressure while drilling to limit our breakout in the shales. Additionally, to improve hole cleaning in our upper intermediate sections yet still allow clearance and relief in our lower shales, we will selectively underream only the shale package to 11” hole size. See below for more information, a diagram of the wellbore, and operational steps. We intend to increase all of our limits by 0.5 ppg. Below is a list of the adjustments to our MT7-06 drilling program: 1. Drill out surface shoe with our planned 9-7/8” intermediate bit following our clean out run with 9.6 ppg MW and minimum FIT to 12.5 ppg. a. Do not open the reamer as originally planned – continue to drill 9-7/8” hole down to ~ 500’ above the HRZ at 9836’ MD. This will result in a 9-7/8” hole per the attached diagram down to the shales. 2. Prior to drilling ahead, open the flow-activated underreamer to open the 11” blade. 3. Weight up and Drill the shales with a 10.8 ppg MW while targeting a 12.0 ppg. This is an increase from a 10.3 ppg mud and an 11.5 ppg EMW MPD back pressure. Do not exceed 12.5 ppg EMW at the HRZ. 4. Drill an 11” hole from ~ 9836’ MD down through the shales and to our intermediate casing point TD. a. Intermediate casing point has been slightly adjusted up to land in the Alpine D sand. 5. For the trip out we will maintain our MW at 10.8 ppg. Once above the shales we will circulate 3 BU while weighting up to an 11.3 ppg for the remaining trip out of the hole. Please verify if the AOGCC concurs with the newly adjusted plan or has any further questions. If a sundry is required for the mentioned changes please advise. Thanks Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 Design Change for MT7-06 – Selective Underreaming 5 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?MT7-06 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 3434 3058 3434 3058 2023 Casing Collapse Structural Conductor Surface 2260 psi Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Yes Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chris Brillon Contact Name:Nina Anderson Wells Engineering Manager Contact Email:nina.anderson@conocophillips.com Contact Phone: 907-229-4008 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Victoria Loepp 7/23/2021 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA081800, AA081781, AA081736 221-048 P.O. Box 100360 Anchorage, Alaska 99510-0360 50-103-20831-00-00 ConocoPhillips Length Size Greater Mooses Tooth / Rendezvous TVD BurstMD 5020 psi 120 3058 120 3425 20 13.375 80.5 3385 Perforation Depth MD (ft): Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 7/24/2021 m n P 2 6 5 6 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 3:03 pm, Jul 23, 2021 321-368 BOP test to 3500 psig Annular preventer test to 2500 psig All conditions on original PTD 221-048 apply DLB 07/23/2021 File w/ PTD 10-407 X DSR-7/23/21 X X VTL 07/26/21 dts 7/26/2021 JLC 7/26/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.26 12:14:21 -08'00' MT7-06 Intermediate Selective Underreaming and Increased Mud Weight Procedure Change Summary: Drill 9-7/8” upper intermediate hole down to ~ 500’ above the top HRZ. Open the reamer and drill an 11” underreamed hole through the shale package with an increased MW of 0.5 ppg from the original program. 1. Drill out surface shoe with planned 9-7/8” intermediate bit following clean out run with 9.6 ppg MW and minimum FIT to 12.5 ppg. a. Do not open the reamer as originally planned – continue to drill 9-7/8” hole down to ~ 500’ above the HRZ at 9836’ MD. This will result in a 9-7/8” hole per the attached diagram down to the shales. 2. Prior to drilling ahead, open the flow-activated underreamer to open the 11” blade. 3. Weight up and Drill the shales with a 10.8 ppg MW while targeting a 12.0 ppg. This is an increase from a 10.3 ppg mud and an 11.5 ppg EMW MPD back pressure. Do not exceed 12.5 ppg EMW at the HRZ. 4. Drill an 11” hole from ~ 9836’ MD down through the shales and to our intermediate casing point TD. 5. For the trip out maintain MW at 10.8 ppg. Once above the shales circulate 3 BU while weighting up to an 11.3 ppg for the remaining trip out of the hole. Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” Vanoil KBMG GLM (2-3x) 3) HES Downhole Gauge 4) 4-½” Baker Premier Production Packer 5) 4-½” DB Landing Nipple w/DFCV (3.75" ID) 6) Liner Top Packer / Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner w/ swell packers and closeable frac ports set @ ~ 26,986' MD 7-5/8" 29.7# HYD563 and 33.7# L-80 TXP BTC-SR Casing @ 12,394' MD / 8,328' TVD Casing set in the Alpine D Sand 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface Production Hole TD 26,394' MD / 8,510' TVD 4-1/2" 12.6# L-80 Hyd563 TOC @ 10,973' MD / 7740' TVD Top Alpine C (Prognosed) 12,509' MD / 8350' TVD MT7-06wp09 - 3 String Producer, Proposed Schematic (updated 07.23.21) D B GLGL GLGL 07/23/21 NA Production Packer @ 12,197 MD / 8,280' TVD ZXP Liner Top Packer 150' From Casing Pt @ ~ 12,247' MD Downhole Gauge 13-3/8" 68# L-80 TXP Surface Casing set @ 3,425' MD / 3058' TVD (updated with actuals) Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,500' MD (4,485' of 33.7#) 9-7/8" hole section to ~ 500' above HRZ 11" hole section to TD ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 23, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry to Change Approved Program for MT7-06 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Change Approved Program for MT7-06, an onshore production well from the MT7 drilling pad currently being drilled with the Doyon 25 drilling rig. MT7-06 is planned to be a horizontal producer within the Rendevouz reservoir. The 16” surface hole has been drilled to 3,434’ MD / 3059’ TVD with casing run to 3425’ MD / 3058’ TVD. There are a few operational adjustments ConcoPhillips would like to implement to improve our performance for both drilling and running intermediate casing. Results of our geomechanical modeling have shown than an increased based mud weight is requireded to reduce wellbore breakout in the HRZ and Kalubik shales. Additionally, to improve hole cleaning in our upper intermediate sections ConocoPhillips intends to selectively underream only the shale package to 11” hole size. The uppermost part of the intermediate hole will be 9-7/8”. Please find attached the information required by 20 ACC 25.280 for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR SUNDRY APPROVAL as per 20 ACC 25.280 2. A description summary of proposal 3. A proposed schematic If you have any questions or require further information, please contact Nina Anderson at 229-4008 (nina.anderson@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: MT7-06 Well File / Jenna Taylor ATO 1560 David Lee ATO 1726 Chris Brillon ATO 1548 Nina Anderson Drilling Engineer pppp g Results of our geomechanical modeling have shown than an increased based mud weight isggggg requireded to reduce wellbore breakout in the HRZ and Kalubik shales. Additionally, to improve hole cleaning in our upper q y, p gpp intermediate sections ConocoPhillips intends to selectively underream only the shale package to 11” hole size. The uppermost p part of the intermediate hole will be 9-7/8”. From:Loepp, Victoria T (CED) To:Anderson, Nina M Subject:MT7-06 PTD #221-048: Change of Approved Program. Approval to proceed Date:Friday, July 23, 2021 10:38:11 AM Nina, Verbal approval is granted to proceed as outlined below. Submission of the 10-403 is required today. Thanx, Victoria Sent from my iPhone On Jul 23, 2021, at 9:32 AM, Anderson, Nina M <Nina.Anderson@conocophillips.com> wrote: Victoria – I will submit a 10-403 today with the proposed changes. Based on our forecast, we could be picking up our intermediate BHA this weekend. Will a verbal approval be needed to proceed with operations? Thanks. Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, July 23, 2021 9:08 AM To: Anderson, Nina M <Nina.Anderson@conocophillips.com> Subject: [EXTERNAL]Re: Adjustments to approved MT7-06 PTD #221-048 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Nina, Please submit a 10-403, Change of Approved program with proposed changes. Thank you, Victoria Sent from my iPhone On Jul 22, 2021, at 3:10 PM, Anderson, Nina M <Nina.Anderson@conocophillips.com> wrote: Victoria – Currently we are running our surface casing on MT7-06. Looking ahead at the intermediate hole section, there are a few operational adjustments we would like to implement to improve our performance for both drilling and running casing. We recently received results of our geomechanical model for the shale package at MT7. It has been suggested to increase base mud weight along with MPD backpressure while drilling to limit our breakout in the shales. Additionally, to improve hole cleaning in our upper intermediate sections yet still allow clearance and relief in our lower shales, we will selectively underream only the shale package to 11” hole size. See below for more information, a diagram of the wellbore, and operational steps. We intend to increase all of our limits by 0.5 ppg. Below is a list of the adjustments to our MT7-06 drilling program: 1. Drill out surface shoe with our planned 9-7/8” intermediate bit following our clean out run with 9.6 ppg MW and minimum FIT to 12.5 ppg. a. Do not open the reamer as originally planned – continue to drill 9-7/8” hole down to ~ 500’ above the HRZ at 9836’ MD. This will result in a 9-7/8” hole per the attached diagram down to the shales. 2. Prior to drilling ahead, open the flow-activated underreamer to open the 11” blade. 3. Weight up and Drill the shales with a 10.8 ppg MW while targeting a 12.0 ppg. This is an increase from a 10.3 ppg mud and an 11.5 ppg EMW MPD back pressure. Do not exceed 12.5 ppg EMW at the HRZ. 4. Drill an 11” hole from ~ 9836’ MD down through the shales and to our intermediate casing point TD. a. Intermediate casing point has been slightly adjusted up to land in the Alpine D sand. 5. For the trip out we will maintain our MW at 10.8 ppg. Once above the shales we will circulate 3 BU while weighting up to an 11.3 ppg for the remaining trip out of the hole. Please verify if the AOGCC concurs with the newly adjusted plan or has any further questions. If a sundry is required for the mentioned changes please advise. Thanks Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 <MT7-06 Selective Underream.pdf> Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Rendezvous Pool, MT7-06 ConocoPhillips Alaska, Inc. Permit to Drill Number: 221-048 Surface Location: 968' FSL, 1859' FWL, SESW, S32, T10N, R2E Bottomhole Location: 1932' FSL, 976' FEL, NESE, S20, T9N, R2E Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of July, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.06 17:00:39 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6.Proposed Depth: 12. Field/Pool(s): MD: 28085 TVD:8525 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8.DNR Approval Number: 13. Approximate Spud Date: 7/11/2021 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 2158' to AA093135 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 100 15.Distance to Nearest Well Open Surface: x-5915791 y-289937 Zone-4 39.5 to Same Pool: 3212' to Rendezvous2 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H40 Welded 80.5 40 40 120 120 16" 13.375" 68 L80 TXP 3456 40 40 3495 3093 11" 7.625" 29.7 L80 Hyd563 12943 40 40 12982 8388 6.5" 4.5" 12.6 L80 Hyd563 15253 12832 8388 28085 8525 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Nina Anderson Chris Brillon Contact Email:nina.anderson@cop.com Wells Engineering Manager Contact Phone:907-265-6403 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature:22-Jun-21 Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Perforation Depth TVD (ft): Intermediate Production Liner Conductor/Structural Surface Casing Length Size Cement Volume MD 10 yds 2310sx 11 ppg, 310sx 15.8 ppg 610sx 15.8 ppg Class G Uncemented liner w/ frac sleeves Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): (including stage data) 4827' FSL,2663' FWL,SESW S7 T9N R2E 932535000, 932516000, 300840000 1932' FSL, 976' FEL, NESE S20 T9N R2E 3776, 5720, 4464 GL / BF Elevation above MSL (ft): 3945 3092 18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks P.O. Box 100360 Anchorage, Alaska, 99510-0360 Greater Mooses Tooth Rendezvous 968' FSL, 1859' FWL, SESW S32 T10N R2E AA081800, AA081781, AA081736 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips 59-52-180 MT7-06 Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Samantha Carlisle at 2:02 pm, Jun 22, 2021 Digitally signed by David Lee DN: C=US, O=ConocoPhillips, CN=David Lee, E=david.l.lee@cop.com Reason: I am the author of this document Location: your signing location here Date: 2021.06.22 13:55:33-08'00' Foxit PhantomPDF Version: 10.1.3 David Lee BOPtestto3500psig Annularpreventertestto2500psig 50-103-20831-00-00 DLB 06/24/2021 SeeattachedConditionsofApprovalfortheintermediate cementjobandsonic logging CBLmayberequireddependingonresultsoftheSonic log.SurfacecasingLOTresultstoAOGCCassoonasobtained X 221-048 X X X X X X 5915791 DLB289937 DSR-6/24/21 X VTL 7/6/21 Diverter variance granted per 20 AAC25.035(h)(2) dts 7/6/2021 7/6/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.06 17:00:56 -08'00' GMT MT7-06(PTD 221-048) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well GMT MT7-06 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 22, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-06 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand Producer well from the MT7 drilling pad. The intended spud date for this well is 7/11/2021. It is intended that Doyon 25 be used to drill the well. MT7-06 will utilize a 16” surface hole and will TD above the K3 sand and then 13.375” casing will be set and cemented to surface. The 11” intermediate hole will be drilled into the top of the Alpine C and landed at an inclination of ~ 89°. A 7.625” casing string will be set and cemented from TD to secure the shoe and cover 500’MD or 250’TVD above any hydrocarbon- bearing zones. The production interval will be comprised of a 6.5” horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as a fracture stimulated Producer with 4.5” uncemented liner with frac sleeves and swell packers. The upper completion will incude a production packer with GLM’s and tied back to surface. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT7, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265-6403 (nina.anderson@conocophillips.com) or Chris Brillon at 265-6120. Sincerely, cc: MT7-06 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1726 Nina Anderson Chris Brillon ATO 1548 Drilling Engineer Kathryn Hoffmeister ATO 1760 a variance of the diverter requirement under 20 AAC 25.035 (h)(2) i d Concur. DLB 06/28/2021 Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 1 of 11 Printed: 22-Jun-21 MT7-06 Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ............................................................ 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................ 2 3. Proposed Drilling Program ...................................................................................... 3 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 4 5. MASP Calculations ................................................................................................... 4 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 5 7. Casing and Cementing Program ............................................................................. 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 7 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 (Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 7 14. Drilling Hazards Summary ....................................................................................... 9 15. Proposed Completion Schematic ......................................................................... 11 Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 2 of 11 Printed: 22-Jun-21 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-06 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 968' FSL, 1859' FWL, SESW S32 T10N R2E, UM NAD 1927 Northings: 5915791 Eastings: 289937 RKB Elevation 39.5’ AMSL Pad Elevation 100.0’ AMSL Top of Productive Horizon (Heel) 4827' FSL, 2663' FWL , SESW S7 T9N R2E, UM NAD 1927 Northings: 5909214 Eastings: 285407 Measured Depth, RKB: 12982’ Total Vertical Depth, RKB: 8388’ Total Vertical Depth, SS: 8248’ Total Depth (Toe) 1932' FSL, 976' FEL, NESE S20 T9N R2E, UM NAD 1927 Northings: 5895574 Eastings: 291886 Measured Depth, RKB: 28085’ Total Vertical Depth, RKB: 8525’ Total Vertical Depth, SS: 8386’ Pad Layout Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 3 of 11 Printed: 22-Jun-21 Well Stick Diagram 3. Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 25 onto MT7-06 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan (LWD Program: GR). 4. Run and cement 13.375” surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 3500 psi high (24-48 hr regulatory notice). 7. Pick up and run in hole with 9-7/8 x 11” drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3000 psi for 30 minutes. 9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 10. Drill 9-7/8 x 11” hole to section TD, using Managed Pressure Drilling to maintain near constant bottom hole pressure on connections in shale formation (LWD Program: GR/RES). 11. Change out upper pipe rams to 7.625” solid bodies and test same to 3,500 psi. 12. Run 7.625” casing and cement to 250’ TVD above the hydrocarbon bearing zones (cementing schematic attached). 13. Change upper pipe rams to 3-1/2” x 6” VBRs. Submit results of intermediate cementing job to AOGCC AS SOON AS AVAILABLE VTL 6/28/21 Refer to AOGCC Industry Guidance Bulletin 13-01:Remedial Cementing for Surface Casing if top job is required. . Submit LOT results to AOGCC as soon as available. VTL 6/28/21 VTL 6/28/21 Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 4 of 11 Printed: 22-Jun-21 14. Test BOPE to 250 psi low / 3,500 psi high (24-48 Regulatory notice). 15. Pick up and run in hole with 6.5” drilling BHA. Log top of cement with sonic tool in recorded mode. 16. Chart casing pressure test to 3500 psi for 30 minutes. 17. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 16.0 ppg. Minimum required leak-off value is 11.0 ppg EMW. 18. Drill 6.5” hole to section TD (LWD Program: GR/RES). 19. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC. 20. Run 4.5” liner with frac sleeves and swell packers with liner hanger to TD. 21. Run 4.5” upper completion with production packer, landing nipple, ball seat, gas lift mandrel(s), and downhole gauge. Displace mud in production casing to kill weight brine, space out and land tubing hanger with pre- installed and pre-tested BPV. 22. Pressure test hanger seals to 5,000 psi. 23. Drop ball and rod to set production packer, test tubing to 4200 psi, chart test. 24. Bleed tubing pressure to 2200 psi and test IA to 4200 psi, chart test. 25. Install HP-BPV and test to 2500 psi. 26. Nipple down BOP. 27. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 28. Freeze protect down tubing and annulus. 29. Secure well. Rig down and move out. 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP schematics on file for Doyon 25. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT7, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 120 / 120 10.9 51 54 13.375 3495/ 3093 14.5 1383 2023 7.625 12982/ 8388 12.5 3,751 3093 4.5 28085/ 8525 12.5 3,945 n/a PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB Results of sonic log to be submitted to AOGCC forreview and approval before drilling ahead. VTL 6/28/21 See Conditions of Approval for the intermediate cement job and sonic logging VTL 6/28/21 VTL 6/28/21 3945/8525*1/.052=8.9 ppg EMW Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 5 of 11 Printed: 22-Jun-21 OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 115 = 54 psi OR ASP = FPP – (0.1 x D) = 1383 – (0.1 x 3093) = 1074 psi 2. Drilling below 13.375” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3093= 2023 psi OR ASP = FPP – (0.1 x D) = 3751 – (0.1 x 8388) = 2912 psi 3. Drilling below 7.625” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8388= 4613 psi OR ASP = FPP – (0.1 x D) = 3945– (0.1 x 8525= 3093 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 16 68 L-80 TXP Cement to Surface = 3093 psi Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 6 of 11 Printed: 22-Jun-21 7.625 9-7/8 x 11 29.7 L80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper most producing zone 4.5 6.5 12.6 L-80 Hyd563 Uncemented liner with frac sleeves Cementing Calculations 13.375” Surface Casing run to 3495’ MD / 3093’ TVD Cement from 3495’ MD to 2995' (500’ of tail) with DeepCRETE + Add's. @ 11 PPG, and from 2995' to surface with 11 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1325’ MD), zero excess in 20” conductor. Lead slurry from 2995’ MD to surface with Arctic Lite Crete @ 11 ppg Total Volume = 4409 ft3 => 2310 sx of 11ppg DeepCRETE + Add's @ 1.91 ft3 /sk Tail slurry from 3495’ MD to 2995’ MD with 15.8 ppg DeepCRETE + Add's Total Volume = 349 ft3 => 310.0 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 7.625” Intermediate Casing run to 12982’ MD / 8388’ TVD Top of slurry is designed to be at 11558’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Alpine C. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2 stage cement job will be performed to isolate this zone. Assume 40% excess annular volume. Tail slurry from 12982’ MD to 11558’ MD with 15.8 ppg Class G + Add's Total Volume = 7924ft3 => 610 sx of 15.8 ppg Class G + Add's@ 1.16 ft3/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 16 9-7/8 x 11 6.5 Casing Size in. 13.375 7.625 4.5 Density PPG 9.0 – 10.5 9.6 – 11.2 8.8 – 9.5 PV cP 30 - 80 10 10 YP lb./100 ft2 100 - 200 20 - 28 10 - 15 Funnel Viscosity s/qt. 300 50 - 60 40 - 50 Initial Gels lb./100 ft2 50 10 6 10 Minute Gels lb./100 ft2 60 15 8 API Fluid Loss cc/30 min. N.C. – 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 10.0 8.9 EMW calc needed in prod. section DLB Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 7 of 11 Printed: 22-Jun-21 pH 11.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A potassium silicate freshwater drilling fluid will be used for the surface interval. Mud engineer to perform regular mud checks to maintain proper levels of silicate concentration and pH level. The mud weight will be maintained at 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 11.2 ppg for formation stability and be prepared to add loss circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.8 – 11.2 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill-in fluid (FloPro) weighted to 8.8 – 9.5 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT7-06 will be injected into a permitted annulus on the MT7 pad or hauled to an approved Class 1 disposal well on CD1. ()g d utilize MPD for adding backpressure during connections. Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigateg shale instability and cycling. Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 8 of 11 Printed: 22-Jun-21 The MT7-06 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to ~2000' TVD. There will be 500’ of cement placed above the top of the Alpine reservoir along with 500’ above any other reservoir that is encountered per regulations. Once MT7-06 has been drilled and completed, consideration may be given to submit this well for annular injection sundry approval. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in shale near the base of the C5 interval, above the K3. The upper confining barrier is composed of 1,000 feet TVD of shale and siltstone of the Upper Cretaceous Colville Group. The lower barrier is composed of over 3,000 feet TVD of Torok Group, primarily marine shale with some interbedded thin sands. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig’s specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3093’) + 1,500 psi = 3430 psi Pore Pressure = 1,208 psi Therefore Differential = 3430– 1,208 = 2222 psi. The internal casing pressure is conservative since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 13.375” 68 L-80 3 TXP 2260 psi 1921 psi 5020 psi 4267 psi 7.625” 29.7 L80 3 Hyd563 4790 psi 4071 psi 6890 psi 5856 psi Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 9 of 11 Printed: 22-Jun-21 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Surface Formations Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running speeds 9-7/8 x 11” Hole /7.625” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Sloughing shale, Tight hole Medium MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner 6.5” Hole / 4.5” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 10 of 11 Printed: 22-Jun-21 proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design if needed, to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. yqggy Managed Pressure Drilling will be used in conjunction with a 4-string casing design if needed, toyg mitigate shale instability i Application for Permit to Drill, MT7-06 Saved: 22-Jun-21 MT7-06 APD Page 11 of 11 Printed: 22-Jun-21 15. Proposed Completion Schematic Tubing / Liner Completion: 1) 4-½” Landing Nipple (3.813" ID) 2) 4-½” x 1” GLM (2-3x) 3) HES Downhole Gauge 4) Production Packer 5) 4-½” Landing Nipple (3.75" ID) 6) Liner Top Packer / Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner w/ swell packers and closeable frac ports set @ 28,492' MD 7-5/8" 29.7#/33.7# L-80 TXP BTC-SR Casing @ 12,982' MD / 8,387' TVD 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface Production Hole TD 28,085' MD / 8,525' TVDss 4-1/2" 12.6# L-80 Hyd563 TOC @ 11,558' MD / 8,053' TVD Top Alpine C 12,274' MD / 8,303' TVD MT7-06wp06 - 3 String Producer, Proposed Schematic (updated 05.18.21) D B GL GL 05/18/21 NA Production Packer @ 12,782' MD / 8,399' TVD ZXP Liner Top Packer @ 12,832' MD Downhole Gauge 13-3/8" 68# L-80 TXP Surface Casing set @ 3,495' MD / 3093' TVD Top of 7-5/8" 33.7# L-80 TXP BTC-SR Casing @ ~8,500' MD (4,485' of 33.7#) 40 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 5000 5000 8000 8000 12000 12000 18000 18000 28500 MT7-06_wp06 Plan Summary 0 3 Dogleg Severity4000 8000 12000 16000 20000 24000 28000 Measured Depth 13-3/8" x 16"7-5/8" x 11" 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in] 40 MT7-01 wp05 40500 1968 MT7-02 wp04 100 1088 MT7-03 wp03 40 1490 24752969 3465 MT7-04 2970 3467 MT7-04 wp03 40500 993 MT7-05 wp03 40 992 MT7-07 wp02 40 992 MT7-09 wp02 1151628 2653 GMT2-210 wp01 115 GMT2-211 wp01 50 GMT2-112 wp01 0 4500 True Vertical Depth0 2750 5500 8250 11000 13750 16500 19250 Vertical Section at 153.00° 13-3/8" x 16" 7-5/8" x 11" 0 50 100 Centre to Centre Separation0 1000 2000 3000 4000 5000 6000 7000 Measured Depth Equivalent Magnetic Distance DDI 7.174 SURVEY PROGRAM Date: 2017-03-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.50 1000.00 MT7-06_wp06 (MT7-06) GYD-GC-SS 1000.00 2500.00 MT7-06_wp06 (MT7-06) MWD OWSG 1000.00 3490.00 MT7-06_wp06 (MT7-06) MWD+IFR2+SAG+MS 3490.00 3590.00 MT7-06_wp06 (MT7-06) MWD-INC_ONLY (INC>10°) 3590.00 5090.00 MT7-06_wp06 (MT7-06) MWD OWSG 3590.00 12982.00 MT7-06_wp06 (MT7-06) MWD+IFR2+SAG+MS 12982.00 13982.00 MT7-06_wp06 (MT7-06) MWD-INC_ONLY (INC>10°) 13982.00 15482.00 MT7-06_wp06 (MT7-06) MWD OWSG 13982.00 28085.49 MT7-06_wp06 (MT7-06) MWD+IFR2+SAG+MS Surface Location North / 5915534.76 East / 1429972.89 Ground / 100.00 CASING DETAILS TVD MD Name 3093.00 3495.22 13-3/8" x 16" 8387.62 12982.76 7-5/8" x 11" Mag Model & Date: BGGM2020 10-Jul-21 Magnetic North is 14.82° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.41° 57154.92nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 330.00 500.00 0.00 0.00 0.00 330.00 0.00 Start Build 1.50 3 700.00 3.00 330.00 699.91 4.53 -2.62 1.50 -30.00 -5.23 Start Build 2.00 41000.00 9.00 330.00 998.13 31.68 -18.29 2.00 0.00 -36.53 Start DLS 2.50 TFO -108.51 53122.07 50.50 227.00 2855.65 -415.35 -753.34 2.50 -109.82 28.07 68822.07 50.50 227.00 6481.29 -3414.95 -3970.02 0.00 0.001240.39 7 9378.54 53.20 206.00 6827.40 -3764.09 -4226.52 3.00 -87.351435.03 810678.54 53.20 206.00 7606.13 -4699.69 -4682.84 0.00 0.002061.49 912708.08 85.00 147.50 8379.50 -6457.78 -4475.20 3.06 -74.103722.23 1012728.08 85.00 147.50 8381.24 -6474.58 -4464.49 0.00 0.003742.06 1112777.76 88.95 152.45 8383.87-6517.51 -4439.68 12.73 51.513791.57 1213085.21 88.95 152.45 8389.50 -6790.05 -4297.49 0.00 0.004098.95 MT7-06_Heel_05132021 1313123.62 89.48 153.00 8390.03 -6824.18 -4279.89 2.00 46.064137.36 1428085.49 89.48 153.00 8525.00-20154.81 2512.31 0.00 0.0019098.63 MT7-06 TD 102620 FORMATION TOP DETAILS TVDPathFormation 949.50Base Perm 1397.50 C40 1658.95 C30 2006.41 C10 3043.06 K3 3625.06 Albian 97 3850.49 Albian 96 4013.56 Albian 95 4405.92 Albian 94 4878.49 Albian 93 6170.14 Albian 92 7339.29 HRZ 7579.25 LCU 8303.17 Alpine C / TPI By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan 100+39.5 @ 139.50usft 0500010000True Vertical Depth (2500 usft/in)0 5000 10000 15000 20000Vertical Section at 153.00° (2500 usft/in)MT7-06 TD 102620MT7-06_Heel_05132021MT7-06 TD QM13-3/8" x 16"7-5/8" x 11"10002000300040005000600070008000900010000110001200013000140001500016000170001800019000200002100022000230002400025000260002700028000MT7-06 (GMT2 SW06-209)/MT7-06_wp06Section View Project: Western North SlopeSite: GMT2 Rendezvous PadWell: MT7-06 (GMT2 SW06-209)Wellbore: MT7-06Design: MT7-06_wp06 Plan View Project: Western North SlopeSite: GMT2 Rendezvous PadWell: MT7-06 (GMT2 SW06-209)Wellbore: MT7-06Design: MT7-06_wp06-21000-14000-70000South(-)/North(+) (3500 usft/in)-14000 -7000 0 7000 14000West(-)/East(+) (3500 usft/in)13-3/8" x 16"7-5/8" x 11"1000300040005000600070008000MT7-06 (GMT2 SW06-209)/MT7-06_wp06 From:Anderson, Nina M To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMT MT7-06(PTD 221-048) Kick Tolerance Calculation Date:Monday, June 28, 2021 2:18:40 PM Attachments:MT7-06 KT Surface_06_28_21.xlsx Victoria – Attached is the kick tolerance spreadsheet . The minimum LOT for the surface casing shoe on MT7- 06 to drill ahead is (PTD 221-048) is 12.0 ppg. Thanks Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, June 28, 2021 9:36 AM To: Anderson, Nina M <Nina.Anderson@conocophillips.com> Subject: [EXTERNAL]GMT MT7-06(PTD 221-048) Kick Tolerance Calculation CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Nina, Please provide the kick tolerance calculation the minimum LOT for the surface casing shoe. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov MT7-06 KT Surface_06_28_21 (002).xlsx 4/11/2022 10:19 AM Well: MT7-06 <== Data Input Name: Nina Anderson <== Data Input Mud Weight (ppg) 9.50 <== Data Input Weak point or LOT - Measured depth (ft) 3,495'<== Data Input Weak point or LOT True vertical depth (ft) 3,093'<== Data Input Weak point or LOT - Hole angle (deg) 50.5º<== Data Input Weak point or LOT - Hole size (in) 11.000"<== Data Input Weak point pressure or LOT - EMW (ppg) 12.00 <== Data Input Zone of interest - Measured depth (ft) 12,243'<== Data Input Zone of interest - True vertical depth (ft) 8,303'<== Data Input Zone of interest - Hole angle (deg) 76.0º<== Data Input Zone of interest - Hole size (in) 11.000"<== Data Input Zone of interest - Pore pressure EMW (ppg) 9.40 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Bottom hole assembly length (ft)300'<== Data Input Drill pipe OD (in) 5.000"<== Data Input BHA annular vol. @ zone of interest (bbl/ft)0.0733 DP annular vol. @ zone of interest (bbl/ft)0.0933 DP annular vol. @ weak point (bbl/ft)0.0933 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi):Plo 1,930 psi Weak point pressure - Safety margin:Pmax 1,930 psi Pmax EMW 12.00 ppg Max anticipated formation pressure (psi):Pf 4,059 psi Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}5,210' Weak Pt to Zone of Interest distance (MD ft):OH {MD}8,748' Maximum influx height at the bit (TVD ft):H {TVD}1,130' Maximum influx height at the bit (MD ft):H {MD}4,671' Calc. volume of {H} around BHA:V1bha 22.0 bbl Calc. volume of {H} around drill pipe:V1dp 407.7 bbl Calc. volume that H equals @ initial shut in:V1 429.6 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 165.7 bbl Calc. volume of Vwp @ initial shut in:V2 78.8 bbl Kick Tolerance: V2 78.8 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. X Greater Mooses Tooth 2 221-048 X MT7-06 Rendezvous X WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT 7-06Initial Class/TypeDEV / PENDGeoArea890Unit10750On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2210480GRTR MOOSES TTH, ALPINE UN OIL - 282050NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesDirectional plan view included, no land plat.8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor driven18Conductor string providedYesSurface casing set to 3495' MD19Surface casing protects all known USDWsYes225% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented perforated joints22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete, no major risk failures26Adequate wellbore separation proposedYesDiverter waived per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax reservoir pressure is 3945 psig(8.9 ppg EMW);will drill w/ 8.8-9.5 ppg EMW; MPD will be used28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 3092 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)YesVery low risk of H2S, new pad w/o mature waterflood established.35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate6/23/2021ApprVTLDate7/6/2021ApprDLBDate6/23/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03