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Home My WebLink About192-050192-050 T38884 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.11 14:51:34 -08'00' 192-050 T38884 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.11 14:56:00 -08'00' 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. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 192-050/ 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: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 105' 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: CBL/Caliper 23. BOTTOM 16" H-40 121' 9-5/8" L-80/ J-55 2792' 7" J-55 6348' 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 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. 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, TUBING RECORD 206 sx Class G8-1/2" 6990'3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 1/28/2024 192-050/ 323-659/ 323-447 50-103-20171-00-00 KRU 2M-24 ADL0025586 114' FSL, 554' FWL, Sec. 27, T11N, R8E, UM 1182' FNL, 1313' FEL, Sec. 37, T11N, R8E, UM 92-50, ALK2672 6/14/1992 7450' MD/ 6360' TVD 6427' MD/ 5507' TVD 146' P.O. Box 100360, Anchorage, AK 99510-0360 488394 5948985 1118' FNL, 1509' FEL, Sec. 34, T11N, R8E, UM CASING WT. PER FT.GRADE 6/18/1992 CEMENTING RECORD 5947749 1400' MD/ 1361' TVD SETTING DEPTH TVD 5942402 TOP HOLE SIZE AMOUNT PULLED 491612 502034 TOP SETTING DEPTH MD 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 BOTTOM SIZE DEPTH SET (MD) 6961' MD/ 5949' TVD PACKER SET (MD/TVD) 24" 12-1/4" 220 sx AS I 42'613 sx PF E, 483 sx Class G 42' 3146'42' 42' 26# 39' 62.5# 47#/ 36# 121' 39' 7436' Plugged and Abandoned 7070-7079' MD and 6040-6048' TVD (cemented) 7103-7112' MD and 6068-6075' TVD (cemented) 7122-7137' MD and 6084-6096' TVD (cemented) 7156-7182' MD and 6112-6134' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Kuparuk River Field/ N/A -Abandoned N/A Oil-Bbl: Water-Bbl: 6427-6925' 10.7 bbls 15.8 ppg Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 3:20 pm, Mar 04, 2024 323-302 JSB Abandoned 1/28/2024 JSB RBDMS JSB 030724 xG Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD surface surface 1400' 1361' Top of Productive Interval 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Elliott Tuttle Digital Signature with Date:Contact Email: elliott.tuttle@conocophillips.com Contact Phone:(907) 263-4742 Senior RWO/CTD Engineer 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: Formation Name at TD: 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. 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 N/A suspended INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Authorized Title: 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. 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. 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 N/A suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips , CN=Elliott Tuttle, E=elliott.tuttle@conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.27 10:28:05-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC corrected by E-Line) 6,570.0 2M-24 11/24/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: W/O Suspend 2M-24 2/23/2024 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS FCO'd ON 4/28/2020. 4/28/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread PRODUCTION (Original KOP@6,565') 7 6.28 6,565.0 7,436.3 6,348.5 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 6,565.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,409.0 5,492.7 34.95 WHIPSTOCK WS set on cement, 45° LOHS Baker Gen 2 Whipstoc k 10841 11048 12/28/2023 0.000 6,565.0 5,620.5 34.93 CUT WellTech Mechanical cutter made tubing cut @ 6565' RKB. Tied into GLM and corrected TOC depth. All indications of good cut. 11/24/2023 2.990 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,925.0 5,919.1 33.63 CEMENT RETAINER 10/30/2023 0.000 6,970.0 5,956.6 33.49 TUBING PUNCH 2" x 3' TBG PUNCH, 3/8" TITAN KNOCKOUT CHARGES, 7g, 6 SPF, 0 DEG PHASING 6/29/2023 2.992 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN 1 1/2 0.0 10/31/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60° phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60° phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60° phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180° phasing; Oriented 77° CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180° phasing; Oriented 81.8° CCW; SWS 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,354.0 7,582.0 5,447.6 Plug – Plug Back / Abandonment Plug 49 BBL's 15.3 # Cement below retainer 2 BBL's on top of retainer 1/26/2024 6,427.0 6,925.0 5,507.5 5,919.1 Cement Plug 10.7 bbls15.8 PPG CLASS G 11/1/2023 Cement Squeeze 1/26/2024 2M-24, 2/26/2024 5:08:33 PM Vertical schematic (actual) PRODUCTION (Original KOP@6,565'); 1,795.0-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 CUT; 6,565.0 Cement Plug; 6,427.0 ftKB WHIPSTOCK; 6,409.0 Plug – Plug Back / Abandonment Plug; 6,354.0 ftKB PRODUCTION (Moved to A); 1,795.0-6,565.0 SURFACE; 41.9-3,146.4 Tie-Back String; 39.1-1,798.0 Production String 1 Cement; 39.0 ftKB CONDUCTOR; 42.0-121.0 Hanger; 39.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: W/O Suspend 2M-24A 2/23/2024 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,789.8 47.00 L-80 BTC ABMOD Tie-Back String 7 6.28 39.1 1,798.0 1,697.7 26.00 L-80 HYD563 OPEN HOLE 7 6,565.0 7,560.0 6,217.7 PRODUCTION (Moved to A) 7 6.28 38.8 6,565.0 5,612.1 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 39.0 Set Depth … 2,304.3 Set Depth … 2,099.7 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 39.0 39.0 0.04 Hanger 7.063 4 1/2" Completion Gen 4 Tubing Hanger FMC Gen 4 3.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,399.0 5,482.2 34.96 CEMENT RETAINER 1/25/2024 0.000 7,191.0 5,994.0 53.19 FISH 4.75" Baker motor and MWD, Well commander, 4" HWDP- 4 jts, 4.75" YJ drilling Jars 1/22/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,783.8 1,686.3 36.92 Cementing Nipple 8.300 7" ES Cementer (SN#: 102463867 -A) Halliburto n HES Cementer 6.171 6,565.0 5,612.1 42.58 Open Hole 7.000 2M-24A, 2/26/2024 5:08:34 PM Vertical schematic (actual) OPEN HOLE; 6,565.0-7,560.0 FISH; 7,191.0 PRODUCTION (Moved to A); 1,795.0-6,565.0 CEMENT RETAINER; 6,399.0 PRODUCTION (Original KOP@6,565'); 1,795.0-7,436.3 SURFACE; 41.9-3,146.4 Tie-Back String; 39.1-1,798.0 Production String 1 Cement; 39.0 ftKB CONDUCTOR; 42.0-121.0 Hanger; 39.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24A ... TD Act Btm (ftKB) 7,560.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017101 Wellbore Status PROD Max Angle & MD Incl (°) 55.73 MD (ftKB) 6,844.55 WELLNAME WELLBORE2M-24 Annotation End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Page 1/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2023 03:00 12/2/2023 06:00 3.00 MIRU, MOVE MOB P Prep rig for truck and transport down well row to 2M-24, TH and Roads and pads prepping around well 0.0 0.0 12/2/2023 06:00 12/2/2023 10:00 4.00 MIRU, MOVE MOB P Pad prep and move hardline for kill tanks. Gadre pad remove excess snow and level for rig. 0.0 0.0 12/2/2023 10:00 12/2/2023 14:00 4.00 MIRU, MOVE MOB P MIRU. Spot dance floor around well 24 spread pit liner and stage equipment in cellar area. Spot in pit module, Hook up interconnect, Berm in rig. Complete pre accept checklist. Hook up hardline to kill tanks. Open SSV on tree. 0.0 0.0 12/2/2023 14:00 12/2/2023 18:00 4.00 MIRU, MOVE RURD P Start loading pits with 8.5# seawater. Complete setting kill tanks and installing hardline to tanks. Spot in MWD cabin and hook up to generator power 0.0 0.0 12/2/2023 18:00 12/2/2023 19:00 1.00 MIRU, MOVE PRTS P Pressure test lines to tiger tank // line up for circulating well 0.0 0.0 12/2/2023 19:00 12/2/2023 22:45 3.75 MIRU, MOVE DISP P Displace well to 8.6 seawater // 22 spm @ 3900 psi down tubing no open gas lift circulating through weltec cut 0.0 0.0 12/2/2023 22:45 12/2/2023 23:15 0.50 MIRU, MOVE OWFF P OWFF 30 min no flow 0.0 0.0 12/2/2023 23:15 12/3/2023 00:00 0.75 MIRU, WELCTL MPSP P Install ISA BPV // Test 1000psi 10 min good test 0.0 0.0 12/3/2023 00:00 12/3/2023 01:00 1.00 MIRU, WELCTL RURD P D/D lines and 2nd Kill line. R/D circulating eq. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 01:00 12/3/2023 03:00 2.00 MIRU, WHDBOP RURD P Bleed adapter void N/D tree and adpater and hang in cellar. Clean and inspect hanger theads, function test X-O in hanger threads 9 rotations. install external blanking plug Simultaneously Change out saver sub ion TD to XT-39. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 03:00 12/3/2023 06:00 3.00 MIRU, WHDBOP NUND P NU DSA and BOPS torque all connections to BOP's install riser in BOP stack. Install Baker MWD tee sensor and line on goose neck. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 06:00 12/3/2023 08:00 2.00 MIRU, WHDBOP RURD P RU to test BOP's MU XO's to test joints. flood stack with fresh water perform shell test. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 08:00 12/3/2023 09:00 1.00 MIRU, WHDBOP BOPE P Test BR, CMV1,2,3,456 and 16. HCR kill,Rig floor kill, outer and inner test spool 2" valve IBOP, manual IBOP 0.0 0.0 12/3/2023 09:00 12/3/2023 11:30 2.50 MIRU, WHDBOP RURD P LDS on TBG head started leaking attempted to tighten LDS. Unable to stop leakage. Called out FMC to remove LDS chase threads and replace LDS. Continue loading 260 joints DP in the shed. RIG up coms to MWD shack. Continue R/U MWD. Moved test plug and wear ring to rig floor. Load floor with X-O's 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 2/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2023 11:30 12/3/2023 18:30 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint to 3500psi , UVBR's, LVBR's w/3-1/2" and 4 " test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1550 PSI, 200 PSI attained =20 sec, full recovery attained = 108 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Austin McLeod. 0.0 0.0 12/3/2023 18:30 12/3/2023 19:30 1.00 SLOT, RPCOMP PRTS P Pressure test stand pipe MWD connection, re-tighten fittings test again 3700 psi 0.0 0.0 12/3/2023 19:30 12/3/2023 21:00 1.50 SLOT, RPCOMP MPSP P Pull blanking plug, pick up t-bar and pull ISA BPV 0.0 0.0 12/3/2023 21:00 12/3/2023 22:00 1.00 SLOT, RPCOMP THGR T Attempt to pull completion @ 135K 6 times no movement on completion // Discuss with town engineer, pull to 160K 6 times no movement on hanger 0.0 0.0 12/3/2023 22:00 12/4/2023 00:00 2.00 SLOT, RPCOMP CIRC P Circulate S x S // 2.8 bbls per min @ 2700 psi // Hold up wt attempt to free pipe // Mobilize SL and EL 6,565.0 6,565.0 12/4/2023 00:00 12/4/2023 00:30 0.50 SLOT, RPCOMP PULL T Pull on pipe up to 160K 6 times no movement 6,565.0 6,565.0 12/4/2023 00:30 12/4/2023 02:00 1.50 SLOT, RPCOMP CIRC T Continue to circulate while holding 150K up // wait for slick line 01:45 - Attempt to pull free up to 160K no movement 6,565.0 6,565.0 12/4/2023 02:00 12/4/2023 04:00 2.00 SLOT, RPCOMP SLKL T SL on location @ 14:00 // Spot truck have PJSM // Land hanger in profile // Rig up slick line 6,565.0 6,565.0 12/4/2023 04:00 12/4/2023 07:45 3.75 SLOT, RPCOMP SLKL T 04:00 SL run in hole to pull hold open sleeve from SSSV 04:25 SL out of hole hold open sleeve pulled from SSSV Ran New 2.29" ID hold open sleeve set in SSSV at 1805' RD Slick line 6,565.0 6,565.0 12/4/2023 07:45 12/4/2023 09:00 1.25 SLOT, RPCOMP WAIT T Wait on engineering to make decision on plan forward. Spot in E-line unit while waiting on town for decision. RU E-Line 6,565.0 6,565.0 12/4/2023 09:00 12/4/2023 12:30 3.50 SLOT, RPCOMP ELNE T RIH with 2" RCT correct back to mandrel at 6094' RIH set RCT EMA cutter at 6180' cut tubing. POOH W/Eline and stand back. 6,108.0 6,108.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 3/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/4/2023 12:30 12/4/2023 13:00 0.50 SLOT, RPCOMP PULL T LD Safety valve and X-O to landing joint. MU X-O 3.5" EUE x XT-39 to topdrive PU WT=110K, weight broke back to 85K. Pulled hanger to floor. 6,108.0 6,083.0 12/4/2023 13:00 12/4/2023 14:45 1.75 SLOT, RPCOMP CIRC T Circulate SxS F/6183' @ 51 SPM 244 PSI Complete R/D E-Line. 6,083.0 6,083.0 12/4/2023 14:45 12/4/2023 15:15 0.50 SLOT, RPCOMP OWFF T OWFF while L/D tubing hanger. Blow down top drive 6,083.0 6,083.0 12/4/2023 15:15 12/4/2023 17:00 1.75 SLOT, RPCOMP PULL T L/D 33 joints fill hole every 15. Band control line anbd tape back to tubing. 6,083.0 5,060.0 12/4/2023 17:00 12/4/2023 22:30 5.50 SLOT, RPCOMP CIRC T Well out of balance, kelly up and circulate the well SxS. Pump sweep as lots of cement coming out of hole 5,060.0 5,060.0 12/4/2023 22:30 12/4/2023 23:30 1.00 SLOT, RPCOMP PUTB T Blow down TD, RIH w/ 6-1/8" string mill to drift casing // Unable to pass string mill through 7" well head // Pick up XT- 39 drill pipe ( Hard band 5.25" ) Unable to pass hard band through well head // lay down drillpipe and mills 5,060.0 5,060.0 12/4/2023 23:30 12/5/2023 00:00 0.50 SLOT, RPCOMP PULL P Lay down 3.5" tubing 5,060.0 4,800.0 12/5/2023 00:00 12/5/2023 01:30 1.50 SLOT, RPCOMP PULL P Lay down 3.5" completion // SSSV tag WH as expected remove control line from well 4,800.0 4,400.0 12/5/2023 01:30 12/5/2023 02:30 1.00 SLOT, RPCOMP CLEN P Clean up floor for running in hole with GS on completion to drop off // rig down spooler and set outside 4,400.0 4,400.0 12/5/2023 02:30 12/5/2023 03:00 0.50 SLOT, RPCOMP BHAH P Pick up 4" GS BHA 4,400.0 4,400.0 12/5/2023 03:00 12/5/2023 05:30 2.50 SLOT, RPCOMP PUTB P Run completion down to stump picking up singles of 3.5" completion tubing // Tag stump // Obtain Pu Wt 80K 4,400.0 6,180.0 12/5/2023 05:30 12/5/2023 06:00 0.50 SLOT, RPCOMP OTHR P Set tubing on stump // Pump 3 bpm 2300 psi // Pu 40K pipe released on stump 6,180.0 2,000.0 12/5/2023 06:00 12/5/2023 07:30 1.50 SLOT, RPCOMP TRIP P TOOH for IBP racking stands in derrick 2,000.0 0.0 12/5/2023 07:30 12/5/2023 09:30 2.00 SLOT, RPCOMP MPSP P Set IBP // COE 100' // Pressure up in stages per baker rep // trouble setting packer // consult baker IBP rep continue with set // indications of good set 0.0 100.0 12/5/2023 09:30 12/5/2023 10:00 0.50 SLOT, RPCOMP PRTS P Pressure test IBP 1000psi 100.0 0.0 12/5/2023 10:00 12/5/2023 11:00 1.00 SLOT, RPCOMP NUND P Nipple down BOPs for grow and stretch 0.0 0.0 12/5/2023 11:00 12/5/2023 15:00 4.00 SLOT, RPCOMP OTHR P Rig up and grow casing // 29.5" of growth before stretch 0.0 0.0 12/5/2023 15:00 12/5/2023 16:00 1.00 SLOT, RPCOMP OTHR P Remove casing head // casing bottlenecked // cut off bottle neck for spear // 421K pushing up on casing head 0.0 0.0 12/5/2023 16:00 12/5/2023 17:00 1.00 SLOT, RPCOMP OTHR P Pick up casing spear w/ packoff, RH release grapple, spear casing, pull 169K, additional growth=16" 45.5" total growth Dress casing w/FMC 0.0 0.0 12/5/2023 17:00 12/5/2023 19:15 2.25 SLOT, RPCOMP NUND P N/U Casing Spool and torque up to spec w/sweeney wrench. 0.0 0.0 12/5/2023 19:15 12/5/2023 19:45 0.50 SLOT, RPCOMP NUND P P/T Pack-off void to 3,000 psi and hold for 15 mins 0.0 0.0 12/5/2023 19:45 12/5/2023 21:45 2.00 SLOT, RPCOMP NUND P N/U BOPE, flood surface lines and stack. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 4/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/5/2023 21:45 12/5/2023 23:15 1.50 SLOT, RPCOMP BOPE P R/U, Test BOPE break 250/4,000 psi 0.0 0.0 12/5/2023 23:15 12/5/2023 23:30 0.25 SLOT, RPCOMP OTHR P Pull Test plug, install wear ring 0.0 0.0 12/5/2023 23:30 12/6/2023 00:00 0.50 SLOT, RPCOMP TRIP P TIH on singles 3.5" Tubing w/Baker pulling tool 0.0 100.0 12/6/2023 00:00 12/6/2023 00:15 0.25 SLOT, RPCOMP OTHR P Pull and L/D IBP 0.0 0.0 12/6/2023 00:15 12/6/2023 00:30 0.25 SLOT, RPCOMP BHAH P M/U 4" GS, BHA Length - 4.72' 0.0 6.2 12/6/2023 00:30 12/6/2023 02:00 1.50 SLOT, RPCOMP TRIP P TIH on 3.5" tubing // Latch into tubing pu wt 80K 6.2 1,790.0 12/6/2023 02:00 12/6/2023 09:30 7.50 SLOT, RPCOMP PULL P PU wt 80K // Lay down 3.5" completion // Cut jt 18.8' long // Total full jts laid down 196 *** Note: Recover 23.5 stainless bands from well 6,180.0 0.0 12/6/2023 09:30 12/6/2023 10:00 0.50 SLOT, RPCOMP CLEN P Clean up floor prep for picking up overshot BHA, 0.0 0.0 12/6/2023 10:00 12/6/2023 11:00 1.00 SLOT, RPCOMP BHAH P Bait overshot , pick up BHA 0.0 150.0 12/6/2023 11:00 12/6/2023 17:00 6.00 SLOT, RPCOMP PUTB P RIH picking up drill pipe 150.0 6,100.0 12/6/2023 17:00 12/6/2023 18:30 1.50 SLOT, RPCOMP CIRC P Circulate S x S 6,100.0 6,100.0 12/6/2023 18:30 12/6/2023 19:30 1.00 SLOT, RPCOMP CIRC P Dump 35 bbl overboard (dirty returns) Mix high vis pill Tag TOF @ 6157.86', PUH 6,153', SOW=95, PUW=130, continue to circulate SxS with pill @ 6 bpm/103 stks/min 6,100.0 6,157.1 12/6/2023 19:30 12/6/2023 20:15 0.75 SLOT, RPCOMP CIRC P Circulate SxS with pill @ 6 bpm/103 stks/min 6,157.1 6,153.0 12/6/2023 20:15 12/6/2023 22:30 2.25 SLOT, RPCOMP FISH P RIH pumping 3.0 bpm @ 320 psi, rotate over 4' of fish Jar 56 hits @ 200 k, straight pull 245 k, pull 95% to 265 k no movement Phone town team, rotate off fish, PUW=130 k PUH 6,120' 6,153.0 6,120.0 12/6/2023 22:30 12/6/2023 23:00 0.50 SLOT, RPCOMP SVRG P Perform Derrick inspection 6,120.0 6,120.0 12/6/2023 23:00 12/7/2023 00:00 1.00 SLOT, RPCOMP TRIP P TOOH F/6,120' T/2,780' 6,120.0 2,780.0 12/7/2023 00:00 12/7/2023 01:00 1.00 SLOT, RPCOMP TRIP P Continue TOOH w/DP F/2,780' 2,780.0 134.2 12/7/2023 01:00 12/7/2023 01:30 0.50 SLOT, RPCOMP BHAH P L/D fishing assembly, inspect overshot 134.2 0.0 12/7/2023 01:30 12/7/2023 02:00 0.50 SLOT, RPCOMP SVRG P Service Rig 0.0 0.0 12/7/2023 02:00 12/7/2023 02:30 0.50 SLOT, RPCOMP BHAH P M/U 5-3/4" over shot (loaded) *** Note: Min ID 2.5" confirmed 0.0 730.0 12/7/2023 02:30 12/7/2023 06:30 4.00 SLOT, RPCOMP TRIP P TIH above fish 730.0 6,031.0 12/7/2023 06:30 12/7/2023 13:30 7.00 SLOT, RPCOMP CIRC P Circulate well while waiting for E-line // 4 bpm @ 350 psi // 6,031.0 6,031.0 12/7/2023 13:30 12/7/2023 16:00 2.50 SLOT, RPCOMP ELNE P Rig up e-line 6,031.0 6,160.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 5/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/7/2023 16:00 12/7/2023 22:00 6.00 SLOT, RPCOMP ELNE P RIH w/eline run CBL down to 6,508', pull heavy, freely moving up hole, down load and corrilate logs, confer with town team plan forward, POOH with E-line 6,160.0 6,160.0 12/7/2023 22:00 12/7/2023 23:00 1.00 SLOT, RPCOMP ELNE P L/D CBL, M/U RTC Cutter. 6,160.0 6,160.0 12/7/2023 23:00 12/8/2023 00:00 1.00 SLOT, RPCOMP ELNE P RIH w\RTC cutter 6,160.0 6,160.0 12/8/2023 00:00 12/8/2023 01:45 1.75 SLOT, RPCOMP ELNE P E-line - CCL, perform cut @ 6,278', POOH w/e-lin, R/D AK-E-line 6,160.0 6,160.0 12/8/2023 01:45 12/8/2023 03:00 1.25 SLOT, RPCOMP FISH P PUW 127 k, SOW=95 k, Pull on fish, working up to 100% of tensile 275 k, pressure up to 3,200 psi, no movement, confer with town team, blow down top drive, kelley up, rotate off fish 6,160.0 6,160.0 12/8/2023 03:00 12/8/2023 05:30 2.50 SLOT, RPCOMP TRIP P TOOH, w/overshot 6,160.0 0.0 12/8/2023 05:30 12/8/2023 06:00 0.50 SLOT, RPCOMP BHAH P L/D BHA #6, M/U fishing assembly 0.0 134.0 12/8/2023 06:00 12/8/2023 08:00 2.00 SLOT, RPCOMP TRIP P TIH F/surface T/6163' 7ES RKB 134.0 6,163.0 12/8/2023 08:00 12/8/2023 10:00 2.00 SLOT, RPCOMP JAR P PUW=134K SOW=98K Hit 55 Jar hit working up to 225K before jar hit 270K after hit. 6,163.0 6,136.0 12/8/2023 10:00 12/8/2023 11:00 1.00 SLOT, RPCOMP SFTY P Inspect derrrick post jarring activities. No deficiencies were found. 6,163.0 6,163.0 12/8/2023 11:00 12/8/2023 11:30 0.50 SLOT, RPCOMP JAR P Continue jarring 225K pre jar hit work up to 270K after jar hit. 6,163.0 6,163.0 12/8/2023 11:30 12/8/2023 12:00 0.50 SLOT, RPCOMP SVRG P Pre job safety meeting with new day crew. Replace black jack on top drive. 6,163.0 6,163.0 12/8/2023 12:00 12/8/2023 12:30 0.50 SLOT, RPCOMP SVRG P Replace black jack on top drive. 6,163.0 6,163.0 12/8/2023 12:30 12/8/2023 15:45 3.25 SLOT, RPCOMP JAR P Continue jarring 225K pre jar hit work up to 270K after jar hit. Jarred on fish a total of 240 hits up and 40 down. Unable to see any movement. Release overshot from tubing stump. PUW=130K 6,163.0 6,163.0 12/8/2023 15:45 12/8/2023 16:45 1.00 SLOT, RPCOMP SFTY P Perform derrick inspection while circulating. Circulate at 3BPM 300 PSI. 6,163.0 6,163.0 12/8/2023 16:45 12/8/2023 20:00 3.25 SLOT, RPCOMP TRIP P TOOH 6,163.0 134.7 12/8/2023 20:00 12/8/2023 20:30 0.50 SLOT, RPCOMP BHAH P L/D fishing assembly BHA #8 134.7 0.0 12/8/2023 20:30 12/8/2023 21:00 0.50 SLOT, RPCOMP SVRG P Rig Service/adjust break bands 0.0 0.0 12/8/2023 21:00 12/8/2023 21:15 0.25 SLOT, RPCOMP SFTY P Crew change/PJSM, with fresh crew, 0.0 0.0 12/8/2023 21:15 12/9/2023 00:00 2.75 SLOT, RPCOMP BHAH P M/U milling assembly w/wavy bottom burn shoe 5-3/4", unable to pass through 255' 0.0 255.0 12/9/2023 00:00 12/9/2023 01:00 1.00 SLOT, RPCOMP TRIP T Work wash pipe, unable to pass 255', stand back and L/D BHA #8 255.0 0.0 12/9/2023 01:00 12/9/2023 01:30 0.50 SLOT, RPCOMP BHAH T P/U drift BHA #9 w/5.95" swedge 0.0 134.0 12/9/2023 01:30 12/9/2023 03:00 1.50 SLOT, RPCOMP TRIP T TIH on stands T/1,555' 134.0 1,555.0 12/9/2023 03:00 12/9/2023 04:30 1.50 SLOT, RPCOMP TRIP T TOOH F/1555' T/Surface 1,555.0 134.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 6/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/9/2023 04:30 12/9/2023 06:00 1.50 SLOT, RPCOMP BHAH T Swap out swedge to 6.10" 134.0 134.0 12/9/2023 06:00 12/9/2023 08:00 2.00 SLOT, RPCOMP TRIP T TIH on stands F/Surface T/1,555' 134.0 1,555.0 12/9/2023 08:00 12/9/2023 09:00 1.00 SLOT, RPCOMP TRIP T TOOH F/1555 T/137' Work swedge F/295.74' T/247.56' 1,555.0 134.0 12/9/2023 09:00 12/9/2023 09:30 0.50 SLOT, RPCOMP BHAH T LD swedge/mill drift BHA. 134.0 0.0 12/9/2023 09:30 12/9/2023 10:00 0.50 SLOT, RPCOMP SVRG T C/O Spinner on iron rough neck 0.0 0.0 12/9/2023 10:00 12/9/2023 16:30 6.50 SLOT, RPCOMP ELNE T RU E-line RIH W. 2.75" CBL 3 Centralizers GR CCL. F/surface T/Top of tubing stump 6,175' M/U 40 arm caliper, RIH, Log Caliper F/6,175' T/350' 0.0 0.0 12/9/2023 16:30 12/9/2023 21:00 4.50 SLOT, RPCOMP ELNE T Caliper failure, POOH, trouble shoot tools, M/U 40 arm caliper on memory 0.0 0.0 12/9/2023 21:00 12/10/2023 00:00 3.00 SLOT, RPCOMP ELNE T Trouble shoot tools, M/U 40 arm caliper on memory 0.0 0.0 12/10/2023 00:00 12/10/2023 01:00 1.00 SLOT, RPCOMP ELNE T RIH w/ 40 arm caliper on memory, log F/350' T/surface. R/D E-line, 0.0 0.0 12/10/2023 01:00 12/10/2023 02:00 1.00 SLOT, RPCOMP BHAH T M/U RBP 0.0 52.7 12/10/2023 02:00 12/10/2023 03:30 1.50 SLOT, RPCOMP TRIP T TIH, PUW=64k, SOW=58k, Set G- lock/RBP 5.968" S/N 13728217, COE @ 2,350' 52.7 2,350.0 12/10/2023 03:30 12/10/2023 04:00 0.50 SLOT, RPCOMP PRTS T Line up, P/T RBP T/2,500 psi 2,350.0 2,350.0 12/10/2023 04:00 12/10/2023 05:30 1.50 SLOT, RPCOMP OTHR T TOOH, L/D setting tools 2,350.0 0.0 12/10/2023 05:30 12/10/2023 07:30 2.00 SLOT, RPCOMP NUND T N/D BOPE 0.0 0.0 12/10/2023 07:30 12/10/2023 09:30 2.00 SLOT, RPCOMP NUND T Bleed of casing pack off void. Remove tubing head. remove pack off. Spear casing and pull 215K total blocks=30K 185K set on slips. 0.0 0.0 12/10/2023 09:30 12/10/2023 11:30 2.00 SLOT, RPCOMP BHAH T MU 120' of wash pipe andRIH to 253' set down 5K unable to get any deeper. TOOH 0.0 253.0 12/10/2023 11:30 12/10/2023 12:00 0.50 SLOT, RPCOMP SVRG T Service draw works and iron rough neck 0.0 0.0 12/10/2023 12:00 12/10/2023 16:30 4.50 SLOT, RPCOMP NUND T NU DSA to casing head and BOP stack tighten choke hose. Install riser. Fill stack with fresh water. 0.0 0.0 12/10/2023 16:30 12/10/2023 18:00 1.50 SLOT, RPCOMP TRIP T MU bull nose to bottom of stand 1 and TIH F/surface to 2250' 0.0 2,250.0 12/10/2023 18:00 12/11/2023 00:00 6.00 SLOT, RPCOMP OTHR T Dump 26 60# sacks and let fall 2,250.0 2,250.0 12/11/2023 00:00 12/11/2023 01:15 1.25 SLOT, RPCOMP OTHR T Continue dumping sand w/K-bar 1000 2,250.0 2,250.0 12/11/2023 01:15 12/11/2023 02:30 1.25 SLOT, RPCOMP NUND T Let sand fall 2,250.0 2,250.0 12/11/2023 02:30 12/11/2023 02:45 0.25 SLOT, RPCOMP TRIP T TIH, tag top of sand @ 2,286', 65' of sand on top of plug 2,250.0 2,286.0 12/11/2023 02:45 12/11/2023 03:30 0.75 SLOT, RPCOMP TRIP T TOOH & L/D bull nose 2,286.0 0.0 12/11/2023 03:30 12/11/2023 04:30 1.00 SLOT, RPCOMP BHAH T M/U Baker MSC 0.0 565.0 12/11/2023 04:30 12/11/2023 06:00 1.50 SLOT, RPCOMP TRIP T TIH, w/DP & MSC locate collar and space out for cutting casing. 565.0 1,786.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 7/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/11/2023 06:00 12/11/2023 07:00 1.00 SLOT, RPCOMP CUTP T Space out for cut. M/U T. Cut 7" csg W/MSC. at 1765' RPM-65 RPM 1.3K Tq off 1.8 Tq. on 5 BPM=850 PSI. Set down 5K Cut through casg saw weight drop off. shut down pump and Slack off through cut. PU to rig floor shut in LPR B/D top drive 1,786.0 1,786.0 12/11/2023 07:00 12/11/2023 07:30 0.50 SLOT, RPCOMP CIRC T R/U to Circ. opn the floor and in the cellar. 1,786.0 1,786.0 12/11/2023 07:30 12/11/2023 08:00 0.50 SLOT, RPCOMP SFTY T Hold PJSM W/CPAI, Nabors, LRS, MI, and ASRC for pumping operations. 1,786.0 1,786.0 12/11/2023 08:00 12/11/2023 09:00 1.00 SLOT, RPCOMP RURD T R/U LRS and Pressure test LRS lines to rig and cement lines to rig floor to 2500 PSI. 1,786.0 1,786.0 12/11/2023 09:00 12/11/2023 09:30 0.50 SLOT, RPCOMP CIRC T Begin displacing OA with diesel down the DP up the OA T/open top tank 1.5 BBL/MIN 250 PSI 15 BBL's away LRS blew hose inside unit. Shut in DP &OA B/D lines T/open top. 1,786.0 1,786.0 12/11/2023 09:30 12/11/2023 10:00 0.50 SLOT, RPCOMP SVRG T Change dies in iron rough neck. 1,786.0 1,786.0 12/11/2023 10:00 12/11/2023 12:00 2.00 SLOT, RPCOMP WAIT T Mechanical failure in pump truck that was dispatched wainting on second truck. perform general housekeeping on rig. 1,786.0 1,786.0 12/11/2023 12:00 12/11/2023 14:00 2.00 SLOT, RPCOMP CIRC T LRS on location Prejob walkdown and safety meeting with LRS. R/U and PT lines to 2500 PSI. Start displacing OA W/140* diesel 1.2 BPM=250 PSI. 52 BBL's pumped, diesel at surface. Swap to hot seawater 1.2BPM 140* 1,786.0 1,786.0 12/11/2023 14:00 12/11/2023 15:00 1.00 SLOT, RPCOMP RURD T Blow down R/D LRS Blow down cement line and kill tnak line. 1,786.0 1,786.0 12/11/2023 15:00 12/11/2023 15:30 0.50 SLOT, RPCOMP OWFF T OWFF for 30 minutes. 1,786.0 1,786.0 12/11/2023 15:30 12/11/2023 16:30 1.00 SLOT, RPCOMP TRIP T TOOH 1,786.0 1,786.0 12/11/2023 16:30 12/11/2023 17:00 0.50 SLOT, RPCOMP BHAH T L/D BHA. 1,786.0 1,786.0 12/11/2023 17:00 12/11/2023 18:00 1.00 SLOT, RPCOMP BHAH T M/U Spear BHA. MU Head pin T/single joint RIH spear 7" casing, pull T45K M/U cement hose and valves T/head pin. R/U tiger tank line. 1,786.0 1,786.0 12/11/2023 18:00 12/11/2023 18:30 0.50 SLOT, RPCOMP SFTY T Hold PJSM with all parties involved. CPAI, LRS, Nabors. 1,786.0 1,786.0 12/11/2023 18:30 12/11/2023 21:00 2.50 SLOT, RPCOMP CIRC T LRS PT lines to 2500 PSI. Open well to LRS. Attempt to circulate down 7" casing up the OA. stage up to 1200 PSI no circulation. Work pipe PU WT= 215K. Stage up to 2000 PSI established circulation. Close rams and attempt to circulate work pressure up to 2000 PSI. Continue to maintain 2000 PSI. Slowly moving fluid to kill tank. Pressure locked at 2200 PSI. Pressured up and relieved the pressure cycling back and forth attempting to regain circulation. unable to make any progress. Held 2000 PSI on casing for 15 minutes no change. Bled off casing. discussed options with town engineer. Decision point to pull slips out of wellhead. 1,786.0 1,786.0 12/11/2023 21:00 12/11/2023 21:15 0.25 SLOT, RPCOMP SFTY T PJSM to N/D BOP stack and remove casing, slips hazards and mitigations discussed. 1,786.0 1,786.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 8/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/11/2023 21:15 12/11/2023 21:30 0.25 SLOT, RPCOMP OWFF T OWFF for 15 minutes. No Flow. 1,786.0 1,786.0 12/11/2023 21:30 12/12/2023 00:00 2.50 SLOT, RPCOMP NUND T N/D BOP stack. pick up stack, remove 7" casing slips 1,786.0 1,786.0 12/12/2023 00:00 12/12/2023 01:30 1.50 SLOT, RPCOMP RURD T N/U BOPE 1,786.0 1,786.0 12/12/2023 01:30 12/12/2023 03:30 2.00 SLOT, RPCOMP CIRC T Work pipe up to 300k, attempt to break circulation up to 1,500 psi, brake circulation, bring pressure up to 2,000 psi, getting minor returns, bleed pressure off, work pipe up to 300k, bring pressure back up to 1,500 psi, increase pressure 2,000 psi, holding like a rock, bleed pressure to zero, work pipe, park @ 125k, bring pump up to 1,000 psi, montior pressure, bring pressure up to 2,000 psi, pressure holding, monitor, bleed pressure off, blow down tiger tank line. Confer with town engineer plan forward. Secure LRS 1,786.0 1,786.0 12/12/2023 03:30 12/12/2023 05:30 2.00 SLOT, RPCOMP NUND T PJSM to N/D BOP stack and re-install casing slips, slips hazards and mitigations discussed. Release spear, set casing in slips with 185k tention 1,786.0 0.0 12/12/2023 05:30 12/12/2023 07:30 2.00 SLOT, RPCOMP NUND T N/U BOPE 0.0 0.0 12/12/2023 07:30 12/12/2023 08:00 0.50 SLOT, RPCOMP BHAH T M/U Drift assembly w/6.10" swedge 0.0 42.2 12/12/2023 08:00 12/12/2023 08:36 0.60 SLOT, RPCOMP TRIP T TIH w/drift BHA F/surface T/800' 42.2 800.0 12/12/2023 08:36 12/12/2023 09:21 0.75 SLOT, RPCOMP TRIP T TOOH, 800.0 0.0 12/12/2023 09:21 12/12/2023 10:06 0.75 SLOT, RPCOMP BHAH T M/U Baker TTS-3 packer, TIH 0.0 428.0 12/12/2023 10:06 12/12/2023 10:36 0.50 SLOT, RPCOMP RURD T R/U cement hose, pump in sub, and head pin crossover. 428.0 428.0 12/12/2023 10:36 12/12/2023 11:36 1.00 SLOT, RPCOMP RURD T R/U E-line grease head, and sheaves 428.0 428.0 12/12/2023 11:36 12/12/2023 12:06 0.50 SLOT, RPCOMP SVRG P Service rig 428.0 12/12/2023 12:06 12/12/2023 13:06 1.00 SLOT, RPCOMP WAIT T Standby for guns to be delivered from Deadhorse. 428.0 428.0 12/12/2023 13:06 12/12/2023 14:06 1.00 SLOT, RPCOMP ELNE T E-line - M/U guns 428.0 428.0 12/12/2023 14:06 12/12/2023 15:21 1.25 SLOT, RPCOMP ELNE T E-line - RIH w/casing punch 3' 6 shots per foot, large charges Top Shot 580' - 583'. Tools free, POOH L/D Tools, R/D E-line 428.0 428.0 12/12/2023 15:21 12/12/2023 15:51 0.50 SLOT, RPCOMP TRIP T TIH, 2 stands Set TSS-3 Test packer, COE @ 705' 428.0 705.0 12/12/2023 15:51 12/12/2023 16:36 0.75 SLOT, RPCOMP CIRC T PJSM w/rig team, Line up LRS, pressure up 0.2 bbls away, hold 2,000 psi for 15 mins, bleed pressure. 705.0 705.0 12/12/2023 16:36 12/12/2023 16:51 0.25 SLOT, RPCOMP RURD T R/D cement hose and pump in sub. 705.0 705.0 12/12/2023 16:51 12/12/2023 17:06 0.25 SLOT, RPCOMP OTHR T Release packer 705.0 705.0 12/12/2023 17:06 12/12/2023 17:36 0.50 SLOT, RPCOMP ELNE T R/U E-line 705.0 705.0 12/12/2023 17:36 12/12/2023 19:00 1.40 SLOT, RPCOMP ELNE T RIH with tubing punch and punch casing at 830'. POOH and RD E-line. 705.0 705.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 9/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/12/2023 19:00 12/12/2023 19:30 0.50 SLOT, RPCOMP CIRC T RIH and set test packer at 893'. 705.0 893.0 12/12/2023 19:30 12/12/2023 23:00 3.50 SLOT, RPCOMP CIRC T RU pump in sub and LRS PT lines to 2500 psi.LRS stage pumps 500 psi to 2000 psi trying to establish circulation to circ out arctic pack. Failed to get any kind of circulation. 893.0 893.0 12/12/2023 23:00 12/13/2023 00:00 1.00 SLOT, RPCOMP RURD T RD LRS, blow down all lines, clear rig floor, prep to POOH. Release test packer and let well stabilize. 893.0 0.0 12/13/2023 00:00 12/13/2023 03:00 3.00 SLOT, RPCOMP CUTP T MU and RIH with MSC to 420 ' and cut 7" casing. 0.0 420.0 12/13/2023 03:00 12/13/2023 06:00 3.00 SLOT, RPCOMP CIRC T Line up LRS, bring on line 3 bpm/400 psi, continue circulating through cut @ 420', shut down pump, swap to seawater, bring pump online 3 bpm/400 psi for 45 bbls, returns cleaned up, shut down pump, blow down tiger tank line 420.0 420.0 12/13/2023 06:00 12/13/2023 08:00 2.00 SLOT, RPCOMP CIRC T Release packer, seems Arctic Pak is swapping out. let u-tube, circulate 20 bbls down the DP up the 7"xDP annulus. OWFF. looks good. 420.0 420.0 12/13/2023 08:00 12/13/2023 08:30 0.50 SLOT, RPCOMP TRIP T TOOH w/DP stands, L/D Baker Test Packer 420.0 0.0 12/13/2023 08:30 12/13/2023 09:30 1.00 SLOT, RPCOMP OTHR T Flush stack and surface lines through the HCR, shut down, suck out stack, open OA and monitor well in cellar. 0.0 0.0 12/13/2023 09:30 12/13/2023 10:30 1.00 SLOT, RPCOMP NUND T N/D BOPE, lift stack off well head, slide stack back and place on stump. 0.0 0.0 12/13/2023 10:30 12/13/2023 12:00 1.50 SLOT, RPCOMP OTHR T M/U Baker Spear on joint of DP, stab casing, PU to unset and remove pac-off and casing slips, Set back down, setting high, push down with Top Drive. 0.0 0.0 12/13/2023 12:00 12/13/2023 12:30 0.50 SLOT, RPCOMP SVRG P Service Rig/Top Drive/Drawworks/Mud pumps 0.0 0.0 12/13/2023 12:30 12/13/2023 13:00 0.50 SLOT, RPCOMP SVRG P Service HCR valves and choke manifold. 0.0 0.0 12/13/2023 13:00 12/13/2023 16:30 3.50 SLOT, RPCOMP NUND T Pull stack off of stump and spot over well head flange, swap out rams to 7" fixed. 0.0 0.0 12/13/2023 16:30 12/13/2023 17:00 0.50 SLOT, RPCOMP PULL T Bring up GBR tongs and rig up on rig floor. 0.0 0.0 12/13/2023 17:00 12/13/2023 19:30 2.50 SLOT, RPCOMP PULL T P/U, spear 7" casing, pull and lay down to pipe shed. UPWT 45K. 0.0 0.0 12/13/2023 19:30 12/13/2023 21:00 1.50 SLOT, RPCOMP CLEN T Clean and clear rig floor. Set test plug and PU 7" test joint. 0.0 0.0 12/13/2023 21:00 12/13/2023 22:30 1.50 SLOT, RPCOMP BOPE T Test HCR chokeand 7" rams 250 low and 4000 high and chart. 0.0 0.0 12/13/2023 22:30 12/13/2023 23:00 0.50 SLOT, RPCOMP RURD T RD all test equipment and pull test plug. 0.0 0.0 12/13/2023 23:00 12/14/2023 00:00 1.00 SLOT, RPCOMP BHAH T MU BHA #22 spear and RIH. 0.0 428.0 12/14/2023 00:00 12/14/2023 03:00 3.00 SLOT, RPCOMP JAR T RIH w/BHA #22 and spear 7" casing at 428'. Jar on 7" casing 47 jar hits w/no movement. break circulation 6 bpm/230 psi, Release spear and POOH. LD BHA #22. 428.0 0.0 12/14/2023 03:00 12/14/2023 04:00 1.00 SLOT, RPCOMP BHAH T M/U Baker MSC BHA #23, TIH, F/surface T/859', locate collars, make cut @ 925', 5 bpm/640 psi, shut down pump and monitor well, static, B/D top drive and blow down, 0.0 859.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 10/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/14/2023 04:00 12/14/2023 05:30 1.50 SLOT, RPCOMP TRIP T TOOH, F/925' T/surface, L/D cutter BHA #23 859.0 0.0 12/14/2023 05:30 12/14/2023 06:30 1.00 SLOT, RPCOMP BHAH T M/U BHA #24 w/spear 0.0 0.0 12/14/2023 06:30 12/14/2023 08:00 1.50 SLOT, RPCOMP TRIP T TIH F/surface T/420', sting into fish, pull free PUW=50k 0.0 769.0 12/14/2023 08:00 12/14/2023 10:30 2.50 SLOT, RPCOMP CIRC T park @ 769', PJSM w/LRS and rig crew, bring pump on line @ 1.0 bpm at 90° temp, circulate until returns are clean, switch to SW 170° @ 1 bpm. 769.0 769.0 12/14/2023 10:30 12/14/2023 11:00 0.50 SLOT, RPCOMP TRIP T Shut down pumping, R/D head pin and equipment off of RF. Blow down surface lines and secure tiger tank line 769.0 769.0 12/14/2023 11:00 12/14/2023 12:30 1.50 SLOT, RPCOMP TRIP T TOOH w/fish F/769' T/surface, stand back DC, L/D spear. L/D casing to pipe shed with GBR. 769.0 0.0 12/14/2023 12:30 12/14/2023 14:00 1.50 SLOT, RPCOMP PULL T L/D 7" casing to pipe shed w/GBR 0.0 0.0 12/14/2023 14:00 12/14/2023 14:30 0.50 SLOT, RPCOMP SVRG P Service rig 0.0 0.0 12/14/2023 14:30 12/14/2023 18:30 4.00 SLOT, RPCOMP BHAH T PU BHA #25 spear assy with jars. RIH to 925'. Up wt 45K. Tag top of casing at 925', set down 10K. Fire jars at 150K, and straight pull 350K. Work moltiple times with not movement. Trip out of hole and LD BHA. 0.0 0.0 12/14/2023 18:30 12/14/2023 21:30 3.00 SLOT, RPCOMP BHAH T MU BHA #26 Baker MSC and RIH and recut at 1786' and make new cut at 1566'. POOH. 0.0 0.0 12/14/2023 21:30 12/14/2023 23:00 1.50 SLOT, RPCOMP BHAH T MU BHA #27 spear with jars. RIH to 925' and pull fish free at 60K. 0.0 925.0 12/14/2023 23:00 12/15/2023 00:00 1.00 SLOT, RPCOMP CIRC T Circulate arctic pack out of hole with hot diesel. 925.0 925.0 12/15/2023 00:00 12/15/2023 01:30 1.50 SLOT, RPCOMP TRIP T POOH with 7" casing and fish from cut @ 1566' to surface. 925.0 0.0 12/15/2023 01:30 12/15/2023 01:45 0.25 SLOT, RPCOMP BHAH T M/U Spear/Jars, BHA #28 0.0 141.4 12/15/2023 01:45 12/15/2023 03:15 1.50 SLOT, RPCOMP TRIP T TIH, spear 7" section @ 1,566' and fish 1,786' (220') pull free, observe 6k over pull 141.4 1,566.0 12/15/2023 03:15 12/15/2023 06:30 3.25 SLOT, RPCOMP CIRC T PUH, gas/arctic pak in returns, circulate hole clean 1,566.0 1,566.0 12/15/2023 06:30 12/15/2023 08:00 1.50 SLOT, RPCOMP TRIP T TOOH, on stands 1,566.0 361.4 12/15/2023 08:00 12/15/2023 09:30 1.50 SLOT, RPCOMP BHAH T L/D spear and fish 361.4 0.0 12/15/2023 09:30 12/15/2023 10:00 0.50 SLOT, RPCOMP OTHR T Clean RF of arctic pak 0.0 0.0 12/15/2023 10:00 12/15/2023 10:30 0.50 SLOT, RPCOMP SVRG P Service Rig 0.0 0.0 12/15/2023 10:30 12/15/2023 12:00 1.50 SLOT, RPCOMP BHAH T M/U Drift/dress off assembly BHA #29 0.0 166.1 12/15/2023 12:00 12/15/2023 12:15 0.25 SLOT, RPCOMP SFTY T Rig Crew Change 166.1 166.1 12/15/2023 12:15 12/15/2023 12:45 0.50 SLOT, RPCOMP TRIP T TIH, w/sizing shoe 8.375", 17 stands and a single 166.1 220.0 12/15/2023 12:45 12/15/2023 13:15 0.50 SLOT, RPCOMP TRIP T Unable to pass 224', PUH, L/D sizing shoe, load one 4-3/4" DC, 2 8.5" string mills, and flex joint 220.0 151.4 12/15/2023 13:15 12/15/2023 15:15 2.00 SLOT, RPCOMP BHAH T M/U string mills x 2, flex joint, and 4-3/4" DC 151.4 204.4 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 11/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/15/2023 15:15 12/15/2023 15:45 0.50 SLOT, RPCOMP TRIP T TIH 204.4 241.9 12/15/2023 15:45 12/15/2023 23:30 7.75 SLOT, RPCOMP MILL T Wash and reaml 9-5/8". PUW=40k, SOW=37k, ROT 60-90 rpm, torque off bottom 850, torque on bottom 4-6K, pumping 5 bpm/215 gpm at 55 psi. 241.9 818.0 12/15/2023 23:30 12/16/2023 00:00 0.50 SLOT, RPCOMP SVRG P Service rig floor equipment. 818.0 818.0 12/16/2023 00:00 12/16/2023 02:00 2.00 SLOT, RPCOMP MILL T Wash and ream 9-5/8". PUW=45k, SOW=45k, ROT 100 rpm, torque 1200- 6000, pumping 5 bpm at 60 psi. 818.0 1,059.0 12/16/2023 02:00 12/16/2023 02:30 0.50 SLOT, RPCOMP CIRC T Pump a bottoms up at 5 BPM/80 psi. 1,059.0 1,059.0 12/16/2023 02:30 12/16/2023 03:00 0.50 SLOT, RPCOMP OWFF T OWFF, No flow. 1,059.0 1,059.0 12/16/2023 03:00 12/16/2023 04:00 1.00 SLOT, RPCOMP TRIP T TOOH standing back drill pipe. 1,059.0 204.4 12/16/2023 04:00 12/16/2023 04:30 0.50 SLOT, RPCOMP BHAH T L/D BHA BHA #30 Gauge mills - 7/16" under gauged 204.4 0.0 12/16/2023 04:30 12/16/2023 05:15 0.75 SLOT, RPCOMP BHAH T M/U Drift/dress off BHA #31 0.0 151.1 12/16/2023 05:15 12/16/2023 06:00 0.75 SLOT, RPCOMP TRIP T TIH, stack out at 255' 7es RKB. work pipe, unable to pass through area 151.1 255.0 12/16/2023 06:00 12/16/2023 08:00 2.00 SLOT, RPCOMP TRIP T TOOH, L/D Drift assembly BHA #31 *** Note: No marks on bottom of sizing shoe, observed marks on 8.5" crossover. 255.0 0.0 12/16/2023 08:00 12/16/2023 09:00 1.00 SLOT, RPCOMP BHAH T Break out triple drive bushing from drift assembly 0.0 0.0 12/16/2023 09:00 12/16/2023 09:45 0.75 SLOT, RPCOMP OTHR T Load 7 inch test joint into pipe shed, grease BOP and choke manifold, hook up test hose in cellar to test valves 0.0 0.0 12/16/2023 09:45 12/16/2023 10:15 0.50 SLOT, RPCOMP SVRG P Service Rig 0.0 0.0 12/16/2023 10:15 12/16/2023 11:00 0.75 SLOT, RPCOMP OTHR T M/U Johnny Wacker, Jet BOPE and surface lines 0.0 0.0 12/16/2023 11:00 12/16/2023 11:45 0.75 SLOT, RPCOMP WAIT T Prep for BOPE test, M/U 7" test joint, drain stack, install 7" test plug 0.0 0.0 12/16/2023 11:45 12/16/2023 12:00 0.25 SLOT, RPCOMP OTHR T Flood stack and surface lines, obtain shell test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 12/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/16/2023 12:00 12/16/2023 18:30 6.50 SLOT, RPCOMP BOPE P Bi-weekly BOPE test, Tested BOPE at 250/2,500 PSI for 5 Min each, Tested annular on 3-1/2" test joint to 2,500 psi , UVBR's, LVBR's w/3-1/2" and 7" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2,050 PSI, after closure=1500 PSI, 16 PSI attained =20 sec, full recovery attained = 116 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook, Brian Bixby, and Josh Hunt. Verbal approval granted for 2,500 psi test - 11"/3k flange - will need to perform full pressure test after 7 inch spool is installed. 0.0 0.0 12/16/2023 18:30 12/16/2023 19:30 1.00 SLOT, RPCOMP OTHR T R/D & Blow down testing equipment, L/D test joints. Suck out the stack. 0.0 0.0 12/16/2023 19:30 12/16/2023 21:30 2.00 SLOT, RPCOMP RURD T Clean and clear the rig floor. Install wear ring. 0.0 0.0 12/16/2023 21:30 12/16/2023 23:30 2.00 SLOT, RPCOMP BHAH T PU BHA #32. Two 8.5" sting mills with a 6.75" drill collar. 0.0 0.0 12/16/2023 23:30 12/17/2023 00:00 0.50 SLOT, RPCOMP SVRG P Service rig. 0.0 0.0 12/17/2023 00:00 12/17/2023 00:30 0.50 SLOT, RPCOMP BHAH T Finish PU BHA #32 8.5" string mills and 6.75" collar. 0.0 240.0 12/17/2023 00:30 12/17/2023 06:00 5.50 SLOT, RPCOMP MILL T Reaming and washing from 240' to 290'. UPWT45K, DNWT 45K, Pump 5BPM at 50 psi. TQ 1900-5800 ft-lbs. With 40lbs of metal returned to shakers, this spot in the 9-5/8" is still not cleaning up. 240.0 312.0 12/17/2023 06:00 12/17/2023 06:30 0.50 SLOT, RPCOMP MILL T Continue milling/reaming from 312'-391', PUW=45k, SOW=45k, 87 spm/5 bpm @ 82 psi. 312.0 391.0 12/17/2023 06:30 12/17/2023 08:30 2.00 SLOT, RPCOMP MILL T Continue milling/reaming from 391'- 1,059', PUW=55k, SOW=50k, 88 spm/5 bpm @ 83 psi 391.0 1,059.0 12/17/2023 08:30 12/17/2023 09:00 0.50 SLOT, RPCOMP TRIP T TOOH 1,059.0 213.0 12/17/2023 09:00 12/17/2023 11:00 2.00 SLOT, RPCOMP BHAH T L/D BHA #32 213.0 0.0 12/17/2023 11:00 12/17/2023 13:30 2.50 SLOT, RPCOMP BHAH T M/U Drift assembly BHA #33 0.0 159.7 12/17/2023 13:30 12/17/2023 15:30 2.00 SLOT, RPCOMP TRIP T TIH, set down 10k @ 225'-264', rotate through area, continue IH to next set down @ 780', unable to pass through area, confer with engineer on call, 159.7 787.0 12/17/2023 15:30 12/17/2023 17:00 1.50 SLOT, RPCOMP TRIP T TOOH, park @ 627', perform slip and cut of drill line. 787.0 627.0 12/17/2023 17:00 12/17/2023 17:30 0.50 SLOT, RPCOMP TRIP T Continue TOOH 627.0 159.7 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 13/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/17/2023 17:30 12/17/2023 19:30 2.00 SLOT, RPCOMP BHAH T L/D Drift assembly 159.7 0.0 12/17/2023 19:30 12/17/2023 21:30 2.00 SLOT, RPCOMP BHAH T M/U milling assembly BHA #34 w/triple 8.5" string reamers, remove flex joint, 6- 1/2" Drill Collar. 0.0 250.0 12/17/2023 21:30 12/17/2023 23:30 2.00 SLOT, RPCOMP MILL T Milling 9-5/8" casing with string reamers from 250' to XXXX'. Up WT 45K, circ 50 BPM at 50 psi. Free torque 2600 ft-lbs, TQ on bottom 3500-6900 ft-lbs 250.0 295.0 12/17/2023 23:30 12/18/2023 00:00 0.50 SLOT, RPCOMP SVRG P Service rig. 295.0 295.0 12/18/2023 00:00 12/18/2023 04:00 4.00 SLOT, RPCOMP MILL T Milling 9-5/8" casing with string reamers F/250' T/865'. Up WT 45K, circ 50 BPM at 50 psi. Free torque 2600 ft-lbs, TQ on bottom 3500-6900 ft-lbs 295.0 408.0 12/18/2023 04:00 12/18/2023 09:30 5.50 SLOT, RPCOMP MILL T Continue Mill through 9-5/8" casing F/409' T/865' 408.0 865.0 12/18/2023 09:30 12/18/2023 12:00 2.50 SLOT, RPCOMP TRIP T Continue drift in hole F/865' T/1,509', observed a little torque 2,200 lbs, continued IH F/1,509' T/1,801' 865.0 1,801.0 12/18/2023 12:00 12/18/2023 13:00 1.00 SLOT, RPCOMP CIRC T Circulate Sweep around, arctic pak coming back across shakers, hole clean 1,801.0 1,801.0 12/18/2023 13:00 12/18/2023 14:30 1.50 SLOT, RPCOMP TRIP T TOOH on stands to surface F/1,801' T/231', dragging -18k, back ream area x 3, Rot=80 rpm, Rot Torq=1,000 lbs 1,801.0 231.0 12/18/2023 14:30 12/18/2023 16:15 1.75 SLOT, RPCOMP BHAH T TOOH, L/D Milling BHA #34 231.0 0.0 12/18/2023 16:15 12/18/2023 18:00 1.75 SLOT, RPCOMP BHAH T M/U BHA #35 w/8.5" string reamers x 3, no flex joint 0.0 160.0 12/18/2023 18:00 12/18/2023 19:30 1.50 SLOT, RPCOMP TRIP T TIH, w/polish shoe, inner dress off mill, XO, drive bushing, LBS, jars, intensifier, XO, magnets x 2, and XO 160.0 1,786.0 12/18/2023 19:30 12/18/2023 20:15 0.75 SLOT, RPCOMP MILL T Mill/Dress off top of 7" casing stump 1,786.0 1,786.0 12/18/2023 20:15 12/18/2023 22:15 2.00 SLOT, RPCOMP TRIP T TOOH 1,786.0 160.0 12/18/2023 22:15 12/19/2023 00:00 1.75 SLOT, RPCOMP BHAH T L/D Dress off assembly BHA #35 160.0 0.0 12/19/2023 00:00 12/19/2023 02:00 2.00 SLOT, RPCOMP BHAH T L/D Dress off assembly BHA #35 0.0 0.0 12/19/2023 02:00 12/19/2023 03:00 1.00 SLOT, RPCOMP RURD T RU to run 7" HYD563 casing. 0.0 0.0 12/19/2023 03:00 12/19/2023 09:00 6.00 SLOT, RPCOMP PUTB T RIH with 7" HYD 563 casing. UPWT=73K DWT=60K. 0.0 1,744.0 12/19/2023 09:00 12/19/2023 10:00 1.00 SLOT, RPCOMP BHAH T Space out and clear floor. 1,744.0 1,744.0 12/19/2023 10:00 12/19/2023 12:00 2.00 SLOT, RPCOMP CIRC T Circulate a couple bottoms. 4 BPM at 70 psi. 1,744.0 1,744.0 12/19/2023 12:00 12/19/2023 12:30 0.50 SLOT, CEMENT RURD T Land casing, pull 25K and set in slips.RU Cement head. PT casing to 2500 psi for 30 minutes. Close lower rams. PT surface lines. 1,744.0 1,744.0 12/19/2023 12:30 12/19/2023 14:00 1.50 SLOT, CEMENT CMNT T Cementing the OA 7" x 9.625" Pump 10 bbl fresh water spacer, followed by 81 bbl 15.3 ppg cement followed by 10 bbl fresh water spacer. We got 10 bbls of cement back to surface. 1,744.0 1,788.0 12/19/2023 14:00 12/19/2023 16:00 2.00 SLOT, CEMENT RURD T RD cementers, RD cemenet head, Clean cement ffrom manifold. 0.0 0.0 12/19/2023 16:00 12/19/2023 22:00 6.00 SLOT, CEMENT WOC T Clean out ram and stack cavities // wait on cement to cure. Waited 8.23 hours to get to 100 psi compressive strength. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 14/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/19/2023 22:00 12/20/2023 00:00 2.00 SLOT, CSGRCY NUND T Break bolts on adapter and bottom spool of bops, air down boots on riser // pick stack to install slips on 7" 0.0 0.0 12/20/2023 00:00 12/20/2023 03:00 3.00 SLOT, WELLPR NUND T Nipple down well head adapter install packoffs nipple up tubing adapter 0.0 0.0 12/20/2023 03:00 12/20/2023 04:00 1.00 SLOT, WELLPR PRTS T Pressure test packoffs 3000 // Bled air out of void several times // good test 10 min 3000 psi 0.0 0.0 12/20/2023 04:00 12/20/2023 06:00 2.00 SLOT, WELLPR NUND T Nipple up adapter DSA // Nipple up BOPs 0.0 0.0 12/20/2023 06:00 12/20/2023 09:30 3.50 SLOT, WELLPR RURD T Swapped lower rams from 7" fixed to 3.5x5.5" variables.Fill BOP stack purged out air and shell test. 0.0 0.0 12/20/2023 09:30 12/20/2023 15:30 6.00 SLOT, WHDBOP BOPE T BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3- 1/2" test joint to 3500psi , UVBR's, LVBR's w/3-1/2" and 4 " test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4-1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1550 PSI, 200 PSI attained =20 sec, full recovery attained = 108 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Austin McLeod. 0.0 0.0 12/20/2023 15:30 12/20/2023 16:30 1.00 SLOT, RPCOMP RURD T RD BOP testing equipment. 0.0 0.0 12/20/2023 16:30 12/20/2023 19:30 3.00 SLOT, RPCOMP BHAH T Install wear ring. PU and RIH with milling assembly with junk basket and magnets in BHA. // Bootbaskets not cleaned out on previous run and frozen // Pick up magnets and collars 0.0 182.0 12/20/2023 19:30 12/20/2023 21:00 1.50 SLOT, RPCOMP TRIP T TIH T/ 1700' kelly up on stand 17 to wash down to plug 182.0 1,700.0 12/20/2023 21:00 12/20/2023 21:30 0.50 SLOT, RPCOMP WASH T Wash down to 1745' tag // Pump 3 bbls/min @ 140 psi 1,700.0 1,745.0 12/20/2023 21:30 12/21/2023 00:00 2.50 SLOT, RPCOMP MILL T Mill cement stringers F/ 1745' T/ 1772' // Pump 3 bbls/ min @ 150 psi // Rot 40 rpm @ 1700 ft/lbs // Mill on cement plug F/ 1772' T/ 1775.6 // Pump 5 bbls/min @ 325 psi Rot 80 rpm @ 1500 ft/lbs // unable to make progress with 1,745.0 1,775.6 12/21/2023 00:00 12/21/2023 01:00 1.00 SLOT, RPCOMP MILL T Mill on plug unable to make progress with junk mill. Set down 10K, PU off bottom and set RPM to 80, torque 1130- 1800 ft-lbs, pumping 5 BPM at 470 psi and WOB 3-15K. 1,775.6 1,775.6 12/21/2023 01:00 12/21/2023 02:30 1.50 SLOT, RPCOMP TRIP T TOOH for roller cone bit // once on surface found cement mounded in center of mill in shape of BOP nut 1,775.6 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 15/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2023 02:30 12/21/2023 04:30 2.00 SLOT, RPCOMP BHAH T BHA# 37 RCJB pick up and run in hole 0.0 185.0 12/21/2023 04:30 12/21/2023 08:30 4.00 SLOT, RPCOMP FISH T TIH with junk basket, circ at 9 bpm at 1520 psi, 5 RPM with 1200-1500TQ. Trip out of hole and LD BHA. No fish. 185.0 0.0 12/21/2023 08:30 12/21/2023 12:00 3.50 SLOT, RPCOMP FISH T TIH with junk basket, circ at 9 bpm at 1520 psi, 5 RPM with 1200-1500TQ. Trip out of hole and LD BHA. No fish. 0.0 0.0 12/21/2023 12:00 12/21/2023 16:30 4.50 SLOT, RPCOMP FISH T TIH with junk basket, circ at 9.7 bpm at 1780 psi, 63 RPM with 1650 TQ. WOB 5K. Trip out of hole and LD BHA. No fish! 0.0 0.0 12/21/2023 16:30 12/21/2023 17:00 0.50 SLOT, RPCOMP SVRG T Service rig. 0.0 0.0 12/21/2023 17:00 12/21/2023 17:30 0.50 SLOT, RPCOMP BHAH T Make up Magnet BHA # 38 0.0 150.0 12/21/2023 17:30 12/21/2023 19:00 1.50 SLOT, RPCOMP TRIP T TIH with magnet 150.0 1,770.0 12/21/2023 19:00 12/21/2023 19:30 0.50 SLOT, RPCOMP FISH T Attempt to fish nut with magnet 1,770.0 1,775.0 12/21/2023 19:30 12/21/2023 20:30 1.00 SLOT, RPCOMP TRIP T TOOH to inspect magnet 1,775.0 150.0 12/21/2023 20:30 12/21/2023 21:00 0.50 SLOT, RPCOMP BHAH T Rack collars and lay down magnet BHA 150.0 0.0 12/21/2023 21:00 12/21/2023 22:00 1.00 SLOT, RPCOMP BHAH T Make up BHA# 39 , tri-cone bit 0.0 150.0 12/21/2023 22:00 12/21/2023 23:30 1.50 SLOT, RPCOMP TRIP T TIH to top of plug 150.0 1,770.0 12/21/2023 23:30 12/22/2023 00:00 0.50 SLOT, RPCOMP MILL T Mill plug F/ 1775 T/ 1776 // Pump Rate 4 bpm @ 250 psi Rot 65 rpm @ 1000 ft/lbs free spin 1,770.0 1,776.0 12/22/2023 00:00 12/22/2023 04:00 4.00 SLOT, RPCOMP MILL T Mill Plug F/ 1776 T/ 1790' // 4 bbls/min 250 psi, Rot 65 rpm @ 1200 ft/lbs, Hold 5k wob // continue down to 1845' ensure string mills work across cementer 1,776.0 1,845.0 12/22/2023 04:00 12/22/2023 04:30 0.50 SLOT, RPCOMP TRIP T TIH to top of sand @ 2281' 1,845.0 2,281.0 12/22/2023 04:30 12/22/2023 05:30 1.00 SLOT, RPCOMP MILL T Wash top of sand and grind any debris down to 2300' 2,281.0 2,300.0 12/22/2023 05:30 12/22/2023 09:30 4.00 SLOT, RPCOMP TRIP T TOOH and LD 6-1/8" tri-cone bit, magnets and junk baskets. 2,300.0 0.0 12/22/2023 09:30 12/22/2023 11:30 2.00 SLOT, RPCOMP TRIP T PU RCJB's and RIH to 2300' UPW=656K, DNW=59K. 0.0 2,300.0 12/22/2023 11:30 12/22/2023 12:30 1.00 SLOT, RPCOMP MILL T Washing and reaming with 9 BPM/1530 psi, ROT 10 rpm, TQ 1050.Pump Hi-Vis sweep. 2,300.0 2,308.0 12/22/2023 12:30 12/22/2023 13:00 0.50 SLOT, RPCOMP OWFF T Flow check the well 2,308.0 2,308.0 12/22/2023 13:00 12/22/2023 15:30 2.50 SLOT, RPCOMP TRIP T Trip out fo the hole. UWT=65K DWT=59K. LD BHA #42. Clean Boot baskets and discuss with town next BHA to run. 2,308.0 0.0 12/22/2023 15:30 12/22/2023 17:30 2.00 SLOT, RPCOMP TRIP T PU RCJB's and RIH to 2308' 0.0 2,308.0 12/22/2023 17:30 12/22/2023 19:30 2.00 SLOT, RPCOMP WASH T Wash hole down to 2340' pump sweeps // Circulate S x S twice to clean up sand in returns 2,308.0 2,340.0 12/22/2023 19:30 12/22/2023 21:00 1.50 SLOT, RPCOMP TRIP T TOOH inspect boot baskets and RCJB 2,340.0 150.0 12/22/2023 21:00 12/22/2023 21:30 0.50 SLOT, RPCOMP BHAH T Laydown and inspect RCJB bha no metal on magnets 150.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 16/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/22/2023 21:30 12/22/2023 22:00 0.50 SLOT, RPCOMP BHAH T Pick up BHA# 43, G-lock retrieval BHA 0.0 170.0 12/22/2023 22:00 12/22/2023 23:30 1.50 SLOT, RPCOMP TRIP T TIH tag sand @ 2338 170.0 2,338.0 12/22/2023 23:30 12/23/2023 00:00 0.50 SLOT, RPCOMP CIRC T Circulate sand from top of plug // Pump sweeps clean out hole 2,338.0 2,340.0 12/23/2023 00:00 12/23/2023 01:00 1.00 SLOT, RPCOMP CIRC T Circulate sand from top of plug // 4bbls/min @ 310 psi // Pump sweeps get sand off top of G-Lock 2,340.0 2,340.0 12/23/2023 01:00 12/23/2023 02:00 1.00 SLOT, RPCOMP FISH T Attempt to was down on fish neck of G- plug // unable to pass 2340' // Pump sweeps no progress past 2340' 2,340.0 2,340.0 12/23/2023 02:00 12/23/2023 03:00 1.00 SLOT, RPCOMP TRIP T TOOH for RCJB 2,340.0 0.0 12/23/2023 03:00 12/23/2023 03:45 0.75 SLOT, RPCOMP BHAH T Make up BHA# 46 RCJB 0.0 170.0 12/23/2023 03:45 12/23/2023 05:30 1.75 SLOT, RPCOMP TRIP T TIH with RCJB 170.0 2,247.0 12/23/2023 05:30 12/23/2023 10:00 4.50 SLOT, RPCOMP FISH T CO run, 10 BPM at 1850 psi, Rotary 1350, UPWT=65K, DNWT= 59K, Pump 20 BBL hi-vis sweep. 2,247.0 2,247.0 12/23/2023 10:00 12/23/2023 11:00 1.00 SLOT, RPCOMP RURD T Cleaning rig floor and boot baskets. 0.0 0.0 12/23/2023 11:00 12/23/2023 12:00 1.00 SLOT, RPCOMP SVRG T Grease and inspect crown, blocks and drawworks. 0.0 0.0 12/23/2023 12:00 12/23/2023 16:15 4.25 SLOT, RPCOMP BHAH T Make up BHA# 47 RCJB and TIH to fish. Pump a high vis sweep. 0.0 2,248.0 12/23/2023 16:15 12/23/2023 17:45 1.50 SLOT, RPCOMP TRIP T Trip out of the hole with BHA #47 2,248.0 160.0 12/23/2023 17:45 12/23/2023 18:30 0.75 SLOT, RPCOMP BHAH T Lay down and inspect BHA 160.0 0.0 12/23/2023 18:30 12/23/2023 19:30 1.00 SLOT, RPCOMP TRIP T BHA# 48 G-plug retrieval tool // TIH to top of plug @ 2348' // Latch into G-plug and release 0.0 2,348.0 12/23/2023 19:30 12/23/2023 20:30 1.00 SLOT, RPCOMP CIRC T Plug pulling heavy, circulate sweeps sand found in returns 2,348.0 2,310.0 12/23/2023 20:30 12/23/2023 22:45 2.25 SLOT, RPCOMP TRIP T TOOH with plug // Pull out of hole slow with plug due to overpulls 2,310.0 0.0 12/23/2023 22:45 12/23/2023 23:30 0.75 SLOT, RPCOMP BHAH T Lay down G-Plug 0.0 0.0 12/23/2023 23:30 12/24/2023 00:00 0.50 SLOT, RPCOMP PRTS T Rig up and purge lines for casing test 0.0 0.0 12/24/2023 00:00 12/24/2023 01:00 1.00 SLOT, RPCOMP PRTS T Pressure test 7 in casing 2500 for 30 min good test // Rig down test equip prep for picking up BHA 0.0 0.0 12/24/2023 01:00 12/24/2023 03:00 2.00 SLOT, RPCOMP BHAH T Pick up BHA# 49 // Wavy bottom 5.75" OD 4.938" ID with 120' of wash pipe // 0.0 255.0 12/24/2023 03:00 12/24/2023 06:00 3.00 SLOT, RPCOMP TRIP T Trip in hole from 255' to 6150'. UPWT 130K/ DWT 95K 255.0 6,150.0 12/24/2023 06:00 12/24/2023 11:30 5.50 SLOT, RPCOMP MILL T Reaming and washing. Tag at 6156'. Wash down to top of cement at 6190'. Ream down to 6211'. 6,150.0 6,211.0 12/24/2023 11:30 12/24/2023 12:00 0.50 SLOT, RPCOMP SVRG T Service rig. 6,211.0 6,211.0 12/24/2023 12:00 12/24/2023 17:00 5.00 SLOT, RPCOMP TRIP T Trip out of hole with BHA #49. 6,211.0 150.0 12/24/2023 17:00 12/24/2023 17:45 0.75 SLOT, RPCOMP BHAH T Lay down BHA# 49 // Burn shoe cracked from use 150.0 0.0 12/24/2023 17:45 12/24/2023 18:30 0.75 SLOT, RPCOMP BHAH T Pick up BHA# 50 // 6" OD burn shoe 0.0 150.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 17/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/24/2023 18:30 12/24/2023 21:30 3.00 SLOT, RPCOMP TRIP T Trip in hole with burn shoe and washpipe BHA# 50 150.0 6,180.0 12/24/2023 21:30 12/25/2023 00:00 2.50 SLOT, RPCOMP MILL T Mill ahead F/ 6211 T/ 6229 // WOB 2K- 3K // Rot 40 RPM @ 6K-7K TQ //Pump 4 bbls/min @ 450 psi // 6,180.0 6,229.0 12/25/2023 00:00 12/25/2023 03:30 3.50 SLOT, RPCOMP MILL T Mill ahead F/ 6229' T/ 6242.5 // WOB 2K-3K // Rot 40 RPM @ 6K-7K TQ //Pump 4 bbls/min @ 450 psi // Progress slowed @ 03:00 attempt to get consistent ROP for 30 min unable decision made to TOOH inspect burn shoe 6,229.0 6,242.5 12/25/2023 03:30 12/25/2023 04:30 1.00 SLOT, RPCOMP CIRC T Circulate Sweep S x S ensure hole clean 6,242.5 6,242.0 12/25/2023 04:30 12/25/2023 10:30 6.00 SLOT, RPCOMP TRIP T TOOH to inspect BHA #50. Pulled 5 pieces of 3-1/2" tubing out of the wash pipe. The peices (17.5', 31.2', 17.53', 5.11' and 2.63') were a total of 73.97' long. These are not exact lengths since the pipe was shaved off on low side, twisted and stretched alittle. 6,242.0 0.0 12/25/2023 10:30 12/25/2023 11:30 1.00 SLOT, RPCOMP BHAH T PU BHA #51, burn over shoe and 188' of wash pipe. 0.0 255.0 12/25/2023 11:30 12/25/2023 12:00 0.50 SLOT, RPCOMP SVRG T Service rig. 255.0 252.0 12/25/2023 12:00 12/25/2023 15:30 3.50 SLOT, RPCOMP TRIP T TIH with BHA #51 255.0 6,242.0 12/25/2023 15:30 12/26/2023 00:00 8.50 SLOT, RPCOMP MILL T Mill ahead F/ 6242' T/ 6255.9' // WOB 8K-10K // Rot 40 RPM @ 6K-7K TQ //Pump 4 bbls/min @ 780 psi // Slow progress unable to proceed at acceptable rate 6,242.0 6,255.9 12/26/2023 00:00 12/26/2023 00:30 0.50 SLOT, RPCOMP MILL T Attempt to mill ahead no progress 6,255.9 6,255.9 12/26/2023 00:30 12/26/2023 03:30 3.00 SLOT, RPCOMP TRIP T Sweep hole pull 2 stands to 6050' to perform casing test // stop to test casing, drill pipe not bleeding off look to have plugged up or partially plugged washpipe, elected to continue out of hole ensure retain fish 6,255.9 150.0 12/26/2023 03:30 12/26/2023 04:30 1.00 SLOT, RPCOMP BHAH T Lay down BHA# 50 // Found tubing stuck in washpipe // Recovered ~18' of tubing 150.0 0.0 12/26/2023 04:30 12/26/2023 05:15 0.75 SLOT, RPCOMP PRTS T Pressure test casing 2500 15min good test // rig down test equipment 0.0 0.0 12/26/2023 05:15 12/26/2023 06:15 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 51 6" OD 4.75ID burn shoe with wash pipe 0.0 150.0 12/26/2023 06:15 12/26/2023 10:00 3.75 SLOT, RPCOMP TRIP T TIH with burn shoe and washpipe 150.0 6,255.0 12/26/2023 10:00 12/26/2023 18:00 8.00 SLOT, RPCOMP MILL T Mill ahead F/6251' T/6278' WOB 3K-5K. Rot 40 RPM @ 5K-7K TQ. Pump 4 bbls/min @ 405 psi. 6,255.0 6,278.0 12/26/2023 18:00 12/26/2023 19:00 1.00 SLOT, RPCOMP CIRC T Circulate 100 Vis. sweep at 3BPM=755PSI SxS 6,278.0 6,278.0 12/26/2023 19:00 12/26/2023 20:30 1.50 SLOT, RPCOMP TRIP T TOOH T/ 6244' Pull heavy 160K, work pipe back to 6275' to continue mill on cemtent to free fish, torque up 10K, 6,278.0 6,278.0 12/26/2023 20:30 12/26/2023 22:30 2.00 SLOT, RPCOMP MILL T Attempt to mill ahead no progress 6,278.0 6,278.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 18/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/26/2023 22:30 12/26/2023 23:00 0.50 SLOT, RPCOMP TRIP T TOOH to inspect BHA Start pulling heavy @ 6240' 160K popped free worked up to 6050' still dragging elected to pump sweep and clean hole 6,278.0 6,050.0 12/26/2023 23:00 12/27/2023 00:00 1.00 SLOT, RPCOMP CIRC T Sweep hole and ensure hole clean 6,050.0 6,050.0 12/27/2023 00:00 12/27/2023 02:30 2.50 SLOT, RPCOMP TRIP T Continue out of hole to inspect BHA no overpulls past 6240' 6,050.0 150.0 12/27/2023 02:30 12/27/2023 03:45 1.25 SLOT, RPCOMP BHAH T Lay down and inspect BHA // Found more 3.5" completion bound up in washpipe //tubing found in washpipe, unable to break off burn shoe and retrieve fish out of washpipe // lay down as one piece return to baker 150.0 0.0 12/27/2023 03:45 12/27/2023 04:30 0.75 SLOT, RPCOMP PRTS T Pressure test casing 2500 psi 15min // Good Test // bleed off blow down surface lines 0.0 0.0 12/27/2023 04:30 12/27/2023 06:00 1.50 SLOT, RPCOMP BHAH T Pick up BHA# 52 // 6.125 OD 4.625 ID w/ 3 jts washpipe 0.0 110.0 12/27/2023 06:00 12/27/2023 08:00 2.00 SLOT, RPCOMP TRIP T TIH W/BHA F/110' T/6275' Establish milling parameters PR=3BPM 400PSI Rot=30RPM Free Tq.=6K 110.0 6,275.0 12/27/2023 08:00 12/27/2023 13:30 5.50 SLOT, RPCOMP MILL T Start milling F/6278' unable to make any hole adjusted parameters unable to make shoe bite. 6,278.0 6,278.0 12/27/2023 13:30 12/27/2023 14:30 1.00 SLOT, RPCOMP TRIP T TOOH to 5900' 6,278.0 5,900.0 12/27/2023 14:30 12/27/2023 15:30 1.00 SLOT, RPCOMP SLPC T Slip and cut drilling line. 5,900.0 5,900.0 12/27/2023 15:30 12/27/2023 18:00 2.50 SLOT, RPCOMP TRIP T TOOH for junk mill 5,900.0 150.0 12/27/2023 18:00 12/27/2023 19:00 1.00 SLOT, RPCOMP BHAH T Lay down BHA // two 8' slabs recovered from washpipe 150.0 0.0 12/27/2023 19:00 12/27/2023 20:00 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 53 6-1/8" Junk mill 0.0 120.0 12/27/2023 20:00 12/27/2023 23:00 3.00 SLOT, RPCOMP TRIP T TIH with junk mill 120.0 6,280.0 12/27/2023 23:00 12/28/2023 00:00 1.00 SLOT, RPCOMP MILL Mill F/ 6277' T/ 6277' 70 spm @ 450psi DN Wt. Up Wt. Rot 31 rpm @ 6000 tq free spin Time mill due to stalling to establish pattern 6,277.0 6,277.0 12/28/2023 00:00 12/28/2023 13:00 13.00 SLOT, RPCOMP MILL T Mill F/ 6277' T/ 6311.3' 70 spm @ 450psi DN Wt. Up Wt. Rot 31 rpm @ 6000 tq free spin 6,277.0 6,311.3 12/28/2023 13:00 12/28/2023 15:00 2.00 SLOT, RPCOMP CIRC T Circulate 15 BBL sweep cleared the bit and increased rate to circulate trash OOH. PUH to clean well bore started pulling tight. Worked up hole to 6277' continue to work pipe send another sweep PR=5.5 BPM CP=675 PSI PUW=125K. Continue to work pipe to free up debris from around the BHA. F/6309' T/6266' Erratic torque and weight swings while working pipe. PUW F/110K T/125K Torque to 13K Free Tq=6K 6,311.3 6,275.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 19/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/28/2023 15:00 12/28/2023 16:00 1.00 SLOT, RPCOMP MILL T Rack back 1 stand and continue to work pipe. F/6275 T/6175' No weight changes or torque increases observed. Clean up and down shut off rotation stroked DP 100' no notable changes observed. shut off pump work pipe 100' no changes. Rot=40 RPM PR= 5.5 BPM @ 645 PSI Tq.= 6K PUW=112K SOW=95K 6,275.0 6,175.0 12/28/2023 16:00 12/29/2023 00:00 8.00 SLOT, RPCOMP MILL T Make connection work pipe F/6275' T/6309' Worked pipe back to 6311' clean up and down. Return to milling F/6311' T/6335' Rot=40 RPM, PR= 4 BPM @ 400 PSI, Free Tq.= 6K, PUW=112K, SOW=95K Perform wipers and sweeps as needed to support milling operations 6,275.0 6,335.0 12/29/2023 00:00 12/29/2023 03:30 3.50 SLOT, RPCOMP MILL T Continue milling F/6335' T/6341' Rot=40 RPM, PR= 4 BPM @ 400 PSI, Free Tq.= 6K, PUW=112K, SOW=95K Perform wipers and sweeps as needed to support milling operations Mill show signs worn out @ 6341' inconsistant torque total milled with junk mill 64' 6,335.0 6,341.0 12/29/2023 03:30 12/29/2023 04:30 1.00 SLOT, RPCOMP CIRC T Circulate sweeps clean well bore for TOOH for junk mill 6,341.0 6,177.0 12/29/2023 04:30 12/29/2023 07:30 3.00 SLOT, RPCOMP TRIP T TOOH for junk mill 6,177.0 188.0 12/29/2023 07:30 12/29/2023 09:00 1.50 SLOT, RPCOMP BHAH T LD Mill and empty boot baskets.. recovered 1.5 gallons metal debris from boot baskets. 188.0 0.0 12/29/2023 09:00 12/29/2023 10:00 1.00 SLOT, RPCOMP PRTS T RU to test, PT 7" casing to 2500 PSI for 15 minutes. Tested good. RD test equipment and blow down lines. 0.0 0.0 12/29/2023 10:00 12/29/2023 11:00 1.00 SLOT, RPCOMP SVRG T Inspect top drive and linktilt 0.0 0.0 12/29/2023 11:00 12/29/2023 12:00 1.00 SLOT, RPCOMP BHAH T PU BHA #54 0.0 188.0 12/29/2023 12:00 12/29/2023 16:15 4.25 SLOT, RPCOMP TRIP T TIH F/188 T/6325' Attempt to establish milling parmeters. Roll pump and DP psi increased to 3500 PSI. Blow down top drive and pump lines RU to Reverse circulate attempt to clear DP. 188.0 6,325.0 12/29/2023 16:15 12/29/2023 17:45 1.50 SLOT, RPCOMP CIRC T Reverse circulate DP clean .5 BPM to start. Maintain circulation 6,325.0 6,325.0 12/29/2023 17:45 12/30/2023 00:00 6.25 SLOT, RPCOMP MILL T ROT=60 RPM, PR=4 BPM @ 350 PSI, Free Tq 5800 Ft./Lbs. Start milling F/6338' T/6348' 6,325.0 6,348.0 12/30/2023 00:00 12/30/2023 00:30 0.50 SLOT, RPCOMP MILL T ROT=60 RPM, PR=4 BPM @ 350 PSI, Free Tq 5800 Ft./Lbs. Start milling F/6348' T/6350' 6,348.0 6,350.0 12/30/2023 00:30 12/30/2023 01:30 1.00 SLOT, RPCOMP DISP T Displace well with new sea water 6,350.0 6,350.0 12/30/2023 01:30 12/30/2023 06:00 4.50 SLOT, RPCOMP MILL T Rot= 70 rpm , PR= 3.5 bpm @ 299 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Mill F/6350' T/ 6359 6,350.0 6,359.0 12/30/2023 06:00 12/30/2023 07:30 1.50 SLOT, RPCOMP CIRC T Circ sweep SxS 5 BPM 550 PSI Reciprocate pipe rotating 65 RPM. 6,359.0 6,359.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 20/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/30/2023 07:30 12/31/2023 00:00 16.50 SLOT, RPCOMP MILL T Rot= 70 rpm , PR= 3.5 bpm @ 299 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Continue milling F/6350' T/6387' 6,359.0 6,387.0 12/31/2023 00:00 12/31/2023 07:00 7.00 SLOT, RPCOMP MILL T Rot= 70 rpm , PR= 3.5 bpm @ 299 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Continue milling F/6387' T/6394.8' Unable to get deeper. Changed milling parameters including PR WOB RPM worked pipe up to 6366' Pump on rot off attempt to get torque back unable to establish mill work. 6,387.0 6,394.0 12/31/2023 07:00 12/31/2023 08:30 1.50 SLOT, RPCOMP CIRC T Continued to change milling parameters including PR WOB RPM worked pipe up to 6366' Pump on rot off attempt to get torque back unable to establish mill work. Rot at 40 RPM 50 RPM 60 RPM Pump on and off unable to establish work. Sweep hole W/15 BBL 100 Vis pill imcreased PR T/6 BPM work pipe. unable to make torque. Circulate sweep out of hole. Continue to work pipe and attempt to regain milling work. 6,394.0 6,394.0 12/31/2023 08:30 12/31/2023 17:30 9.00 SLOT, RPCOMP TRIP T TOOH F/6394' PUW=120K PUH 100' started pulling 70K over. Work pipe free travel down, SOW=100-105K. Pulling heavy T/188' 6,394.0 188.0 12/31/2023 17:30 12/31/2023 19:00 1.50 SLOT, RPCOMP BHAH T LD BHA. Empty boot baskets, inspect mill. OD measured 5.75"" face showed complete wear. Carbide inserts appeared ground down with center hole cored out. 188.0 0.0 12/31/2023 19:00 12/31/2023 19:30 0.50 SLOT, RPCOMP CLEN T Clean floor prep for casing test 0.0 0.0 12/31/2023 19:30 12/31/2023 20:00 0.50 SLOT, RPCOMP PRTS T Pressure test casing 2500 for 15 min good test 0.0 0.0 12/31/2023 20:00 12/31/2023 20:30 0.50 SLOT, RPCOMP SVRG T Service wash pipe and crown 0.0 0.0 12/31/2023 20:30 12/31/2023 21:30 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 55 junk mill 0.0 194.0 12/31/2023 21:30 1/1/2024 00:00 2.50 SLOT, RPCOMP TRIP T TIH T/6100' 194.0 6,100.0 1/1/2024 00:00 1/1/2024 01:00 1.00 SLOT, RPCOMP TRIP T TIH T/ 6394' 6,100.0 6,394.0 1/1/2024 01:00 1/1/2024 17:00 16.00 SLOT, RPCOMP MILL T Rot= 60 rpm , PR= 3.5 bpm @ 338 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Continue milling F/6394.8' T/ 6425 Pump pressure increased to 1200 PSI at 1600. Mill appears to have plugged jet. 6,394.0 6,425.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 21/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/1/2024 17:00 1/1/2024 19:00 2.00 SLOT, RPCOMP MILL T Recieved call from CPF 2 dump truck contacted high line feeding 7ES. swapped off high line Continued milling F/6425 T/6427' ROT 60 RPM, Tq on=7000 WOB=10K PR=2.75 BPM @1000 PSI BHA plugged up pumping .8 bbls/min @ 2600 psi 6,425.0 6,427.0 1/1/2024 19:00 1/1/2024 22:30 3.50 SLOT, RPCOMP TRIP T TOOH for clean out run in prep for E- line work 6,427.0 200.0 1/1/2024 22:30 1/1/2024 23:30 1.00 SLOT, RPCOMP BHAH T Break down BHA found 8' spiral of casing cored into BHA and 5 of 6 jets plugged , boot baskets contained 1/4 of 5 gal bucket of metall chips 200.0 0.0 1/1/2024 23:30 1/2/2024 00:00 0.50 SLOT, RPCOMP CLEN T Clean floor from wet trip out of hole 0.0 1/2/2024 00:00 1/2/2024 01:00 1.00 SLOT, RPCOMP PRTS T Rig up and test casing 2500 psi 15 min good test // rig down test equipment 0.0 0.0 1/2/2024 01:00 1/2/2024 02:00 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 56 // RCJB, string mills and magnets 0.0 178.0 1/2/2024 02:00 1/2/2024 05:30 3.50 SLOT, RPCOMP TRIP T TIH with clean out assembly T/6426' Pump down lastF/6358' set down. Tagged at 6426' PU off bottom. Rot=13 RPM, PR=70 SPM @ 1600 PSI Free torque=3500 Ft/Lbs PUW=135K SOW=100K. 15K over pull initial off bottom. Worked back to 6427' SO 15K WOB. Worked pipe till clean pu and slack off. 178.0 6,427.0 1/2/2024 05:30 1/2/2024 10:00 4.50 SLOT, RPCOMP CIRC T Start sweep down DP PR=160 SPM @2000 PSI RPM=15 Circ SxS till clean pumping 15 BBL 100 vis sweeps untill clean. 6,427.0 6,427.0 1/2/2024 10:00 1/2/2024 13:00 3.00 SLOT, RPCOMP TRIP T TOOH F/6427' T/1730' 6,427.0 1,730.0 1/2/2024 13:00 1/2/2024 13:30 0.50 SLOT, RPCOMP SVRG T Service top drive. 1,730.0 1,730.0 1/2/2024 13:30 1/2/2024 16:30 3.00 SLOT, RPCOMP MPSP T PU Storm packer rack back 2 Set storm packer at 67'. Test to 2500 PSI. Blow down all lines. 1,730.0 1,730.0 1/2/2024 16:30 1/2/2024 17:00 0.50 SLOT, RPCOMP RURD T Prep for BOP test. 1,730.0 1,730.0 1/2/2024 17:00 1/3/2024 00:00 7.00 SLOT, RPCOMP WAIT T Phase 3 called on 2M pulled storm packer. prepared to circulate. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/3/2024 00:00 1/4/2024 00:00 24.00 SLOT, RPCOMP WAIT T Phase 3 called on 2M pulled storm packer. prepared to circulate. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/4/2024 00:00 1/5/2024 00:00 24.00 SLOT, RPCOMP WAIT T Phase 3. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/5/2024 00:00 1/6/2024 00:00 24.00 SLOT, RPCOMP WAIT T Phase 3. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/6/2024 00:00 1/6/2024 04:30 4.50 SLOT, RPCOMP WAIT T Phase 3. Circ the top of the well SxS to 1700' 1,730.0 1,730.0 1/6/2024 04:30 1/6/2024 05:30 1.00 SLOT, RPCOMP BHAH T Re-build storm packer for hanging off BHA. 1,730.0 1,730.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 22/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/6/2024 05:30 1/6/2024 06:30 1.00 SLOT, RPCOMP MPSP T PU and RIH with storm packer. Set Sorm packer W/1700' of DP hung off at 67' COEmLD running tool. PT storm packer to 2500 PSI for 15 minutes. 1,730.0 1,730.0 1/6/2024 06:30 1/6/2024 09:30 3.00 SLOT, RPCOMP RURD T Pull wear ring and clean stack with stack cleaner. grease choke manifold. mark donut joint for BOP test. flood stack and surface lines. 1,730.0 1,730.0 1/6/2024 09:30 1/6/2024 16:00 6.50 SLOT, RPCOMP BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = 115 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Brian Bixby 1,730.0 1,730.0 1/6/2024 16:00 1/6/2024 17:00 1.00 SLOT, RPCOMP RURD T R/D testing equipment, blow down choke manifold, Set up safety valve for DP. get floor ready to TOOH and R/U E- line. 1,730.0 1,730.0 1/6/2024 17:00 1/6/2024 18:00 1.00 SLOT, RPCOMP MPSP T Pull storm packer // circulate S x S prior to pulling to surface // pressure increase 1300 psi @ 1 bbl/min 1,730.0 1,730.0 1/6/2024 18:00 1/6/2024 19:00 1.00 SLOT, RPCOMP TRIP T TOOH 17 stands 1,730.0 190.0 1/6/2024 19:00 1/6/2024 20:30 1.50 SLOT, RPCOMP BHAH T Lay down BHA // Found storm valve plugged // 1/4 bucket on magnets, 1/4 bucket metal out of boot baskets 190.0 0.0 1/6/2024 20:30 1/6/2024 21:30 1.00 SLOT, RPCOMP CLEN T Clean up floor from wet trip out of hole due to plugged storm valve, remove fishing tools from rig floor 0.0 0.0 1/6/2024 21:30 1/6/2024 22:30 1.00 SLOT, RPCOMP ELNE T Rig up E-line 0.0 0.0 1/6/2024 22:30 1/7/2024 00:00 1.50 SLOT, RPCOMP ELNE T Perform CBL/CCL run 22:30- RIH with logging tools 23:30- Log CBL and CCL up to 6000' show good cement to 6290' 0.0 0.0 1/7/2024 00:00 1/7/2024 01:00 1.00 SLOT, RPCOMP ELNE P POOH with E-line for caliper run 0.0 0.0 1/7/2024 01:00 1/7/2024 02:00 1.00 SLOT, RPCOMP ELNE P Lay down CCL/CBL tools // Pick up and test READ caliper 0.0 0.0 1/7/2024 02:00 1/7/2024 04:00 2.00 SLOT, RPCOMP ELNE P Perform Caliper log of WS setting area 02:00 - RIH with caliper 03:00 - POOH with caliper 03:48 - Break down E-line and caliper tools 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 23/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/7/2024 04:00 1/7/2024 04:30 0.50 SLOT, RPCOMP ELNE P Rig down E-line 0.0 0.0 1/7/2024 04:30 1/7/2024 05:30 1.00 SLOT, RPCOMP BHAH P Pick up BHA# 59 6.151" whip stock drift run BHA. Hold PJSM to PU BHA. Pick up 6-1/8" junk mill with 6.151" smooth od string mil. l 0.0 174.0 1/7/2024 05:30 1/7/2024 07:00 1.50 SLOT, RPCOMP TRIP P TIH F/173.9' T/3476.73' Phase 3 called at 0706 AM. Stop TIH. 174.0 3,476.0 1/7/2024 07:00 1/8/2024 00:00 17.00 SLOT, RPCOMP WAIT T Waiting on weather Phase 3 called at 0706 AM. 3,476.0 1/8/2024 00:00 1/8/2024 04:00 4.00 SLOT, RPCOMP WAIT T Waiting on weather Phase 3 called at 0706 AM. 3,476.0 3,476.0 1/8/2024 04:00 1/8/2024 05:30 1.50 SLOT, RPCOMP TRIP P TIH with drillpipe T/ 6428', no obstructions 3,476.0 6,428.0 1/8/2024 05:30 1/8/2024 07:00 1.50 SLOT, RPCOMP CIRC P Circulate well ensure hole clean // Pump 100 vis sweeps 6,428.0 6,428.0 1/8/2024 07:00 1/8/2024 08:00 1.00 SLOT, RPCOMP DISP P Displace well with clean seawater 8.5# 6,428.0 6,428.0 1/8/2024 08:00 1/8/2024 08:15 0.25 SLOT, RPCOMP OWFF P OWFF no flow prep to TOOH 6,428.0 6,428.0 1/8/2024 08:15 1/8/2024 11:15 3.00 SLOT, RPCOMP TRIP P TOOH racking stands in derrick 6,428.0 150.0 1/8/2024 11:15 1/8/2024 12:45 1.50 SLOT, WHPST BHAH P Lay down BHA inspect boot baskets and magnets // boot baskets and magnets full // clean up and prep to run back in hole 150.0 0.0 1/8/2024 12:45 1/8/2024 13:45 1.00 SLOT, WHPST BHAH P Pick up clean out BHA #60 0.0 173.0 1/8/2024 13:45 1/8/2024 16:30 2.75 SLOT, WHPST TRIP P TIH to 6428', tag on depth. UPW=135K/ DNW=98K 173.0 6,428.0 1/8/2024 16:30 1/8/2024 18:00 1.50 SLOT, WHPST DISP P Displace 8.5 ppg seawater out of hole with 11.6 ppg LSND mud. 6,428.0 6,428.0 1/8/2024 18:00 1/8/2024 20:30 2.50 SLOT, WHPST TRIP P POOH standing back DP in derrick. 6,428.0 173.0 1/8/2024 20:30 1/8/2024 21:00 0.50 SLOT, WHPST BHAH P LD BHA #60. Clean magnets and junk baskets. Both magnets and boot baskets were full. 173.0 0.0 1/8/2024 21:00 1/8/2024 22:00 1.00 SLOT, WHPST BHAH P MU CO BHA #61 (same BHA as #60) 0.0 173.0 1/8/2024 22:00 1/9/2024 00:00 2.00 SLOT, WHPST TRIP P TIH to 4490' at midnight. 173.0 4,490.0 1/9/2024 00:00 1/9/2024 01:00 1.00 SLOT, WHPST TRIP P TIH from 4490' to 6351'. PUW 135K/ SOW 100K. 4,490.0 6,428.0 1/9/2024 01:00 1/9/2024 03:00 2.00 SLOT, WHPST CIRC P Pump two 22 BBL HI vis sweeps SXS at 5BPM/1000 psi. Build a dry job to POOH. 6,428.0 6,428.0 1/9/2024 03:00 1/9/2024 05:30 2.50 SLOT, WHPST TRIP P TOOH from 6428' UWT 130K to 174' UWT 36K. 6,428.0 174.0 1/9/2024 05:30 1/9/2024 07:00 1.50 SLOT, WHPST BHAH P LD BHA #61 clean magnets and boot baskets. 174.0 0.0 1/9/2024 07:00 1/9/2024 08:30 1.50 SLOT, WHPST BHAH P PU BHA #62. Same as BHA #61 plus picking up 4 more magnets and float sub with ported float. 0.0 223.0 1/9/2024 08:30 1/9/2024 09:30 1.00 SLOT, WHPST SVRG P Service rig. Greaase crown, blocks, drawworks, topdrive and roughneck. 223.0 223.0 1/9/2024 09:30 1/9/2024 14:00 4.50 SLOT, WHPST TRIP P TIH w/float in string Filling every 5 stands 223.0 6,428.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 24/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/9/2024 14:00 1/9/2024 16:30 2.50 SLOT, WHPST CIRC P Brake Circulation, TIH slowly tag bottom @ 6,425', PUW 137 k, SOW 118 k Wash down to 6,427.3', recep pipe ~30' rotating 30-80 rpm 6,425' circulate SXS w/20 bbls sweeps x 2 Nothing observed at surface on either sweep 6,428.0 6,428.0 1/9/2024 16:30 1/9/2024 17:15 0.75 SLOT, WHPST TRIP P 6,428', PUH T/6,167', Slip and cut drill line. 6,428.0 6,167.0 1/9/2024 17:15 1/9/2024 20:00 2.75 SLOT, WHPST TRIP P Pump dry job 20 bbl/13.5 ppg, TOOH F/6,167' to surface. PUW 38K. 6,167.0 223.0 1/9/2024 20:00 1/9/2024 21:30 1.50 SLOT, WHPST BHAH P L/D BHA #62, inspect magnets 223.0 0.0 1/9/2024 21:30 1/9/2024 23:00 1.50 SLOT, WHPST BHAH P MU BHA #63 clean out assembly 0.0 234.0 1/9/2024 23:00 1/10/2024 00:00 1.00 SLOT, WHPST TRIP P Trip in hole from 234' to 2780' SOW 60K 234.0 2,780.0 1/10/2024 00:00 1/10/2024 03:00 3.00 SLOT, WHPST TRIP P Trip in hole from 2780' to 6427' PUW 130 k, SOW 95 k, Tag 20 k 6,428' 2,780.0 6,427.0 1/10/2024 03:00 1/10/2024 05:30 2.50 SLOT, WHPST WASH P Wash down @ 5 bpm/900 psi, recep pipe 80 rpm, 4k torque, pump 20 bbl sweeps x 2, on second sweep pump @ 8 bpm/1,850 psi, OWFF, pump dry job 13.5 ppg 6,427.0 6,427.0 1/10/2024 05:30 1/10/2024 08:00 2.50 SLOT, WHPST TRIP P TOOH w/CO BHA #63 F/6,427' T/Surface 6,427.0 193.0 1/10/2024 08:00 1/10/2024 10:00 2.00 SLOT, WHPST BHAH P L/D and inspect BHA Minor metal hair like on magnets Lower magnet a few large pieces M/T junk baskets-minor big pieces and one rock Confer with town team, unanimous decision - Run WS L/D CO Assembly 193.0 0.0 1/10/2024 10:00 1/10/2024 13:00 3.00 SLOT, WHPST BHAH P M/U WS/Milling assembly BHA #64 0.0 198.0 1/10/2024 13:00 1/10/2024 18:30 5.50 SLOT, WHPST TRIP P TIH, stand #3 Surface test (good test), continue to trip in hole. 130K PUW/ 95K SOW 198.0 6,380.0 1/10/2024 18:30 1/10/2024 19:00 0.50 SLOT, WHPST WPST P Set whipstock per Baker rep. Set down on anchors with 12K. PU 10K over to ensure set. Set down 30K and shear out of whipstock. 6,380.0 6,409.0 1/10/2024 19:00 1/10/2024 23:30 4.50 SLOT, WHPST MILL P MIlling window per Baker rep from 6409.5' to 6411.5'. 130K PUW, 95K SOW, 110KRWT, 80 RPM, 4.5 TQ off, 5- 8K TQ on, 1K WOB, 4BPM at 975psi. 6,409.0 6,412.0 1/10/2024 23:30 1/11/2024 00:00 0.50 SLOT, WHPST SVRG P Service the rig, C/O Hyd motor on Iron Roughneck. 6,412.0 6,412.0 1/11/2024 00:00 1/11/2024 05:30 5.50 SLOT, WHPST MILL P MIlling window per Baker rep from 6412'. 130K PUW, 95K SOW, 110KRWT, 80 RPM, 4.5 TQ off, 5-8K TQ on, 1K WOB, 4BPM at 975psi. 6,412.0 6,427.0 1/11/2024 05:30 1/11/2024 09:00 3.50 SLOT, WHPST MILL P Continue milling/drilling rat hole F/6,427' T/6,440' 80 RPM / 4.6K torque / 11 k WOB 6,427.0 6,440.0 1/11/2024 09:00 1/11/2024 10:45 1.75 SLOT, WHPST MILL P Continue milling/drilling rat hole F/6,440' T/6,448' Pumping 4.0 bpm/67 spm/1,016 psi - mud pump #1 Rot=81 rpm / 4,800 ft-bls torque 6,440.0 6,448.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 25/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2024 10:45 1/11/2024 11:30 0.75 SLOT, WHPST REAM P Back ream window exit Rot=80 rpm / 4 k torq / pumping 4.0 bpm / 973 psi PUW=120 k, SOW 94 k Stop Rot, clean pass through window exit 6,448.0 6,448.0 1/11/2024 11:30 1/11/2024 13:00 1.50 SLOT, WHPST CIRC P 6,445' park and circulate 20 bbl sweep around Pull above window, circulate 20 bbls sweep BU 6,448.0 6,400.0 1/11/2024 13:00 1/11/2024 15:45 2.75 SLOT, WHPST TRIP P TOOH 6,400.0 198.0 1/11/2024 15:45 1/11/2024 18:30 2.75 SLOT, WHPST BHAH P L/D Window Miling Assembly 198.0 0.0 1/11/2024 18:30 1/11/2024 19:00 0.50 SLOT, WHPST SVRG P Service rig 0.0 0.0 1/11/2024 19:00 1/11/2024 21:30 2.50 SLOT, WHPST BHAH P MU drilling BHA. 0.0 354.0 1/11/2024 21:30 1/12/2024 00:00 2.50 SLOT, WHPST TRIP P TIH from 354 tp 5580'. At 383' SOW 38K. Perform shallow hole test at 825', 5 BPM at 1000psi, Good test. 354.0 5,580.0 1/12/2024 00:00 1/12/2024 00:30 0.50 SLOT, WHPST TRIP P TIH from 5580 to 6340'. 120K PUW/90K SOW 5,580.0 6,340.0 1/12/2024 00:30 1/12/2024 06:00 5.50 SLOT, WHPST CIRC T Circulate SXS 2BPM at 900 psi. Decision made to not drill ahead and open the time sensitive shales until after phase 3. 6,340.0 6,340.0 1/12/2024 06:00 1/13/2024 00:00 18.00 SLOT, WHPST CIRC T Continue to circulate lowering the pump rate to 60 gpm Phase 2 weather conditions. Called phase 3 at 20:30. Off highline power at 20:30. 6,340.0 6,340.0 1/13/2024 00:00 1/13/2024 16:30 16.50 SLOT, WHPST WAIT T Wait on Phase 3 weather 6,340.0 6,340.0 1/13/2024 16:30 1/13/2024 18:00 1.50 PROD1, DRILL DDRL P Kelly up at 6344' UPW 130/ DNW 95. Orientate tool face and slide through window. Stage pump to 180 GPM at 1460 psi. Start slide drilling at 6447' as per DD. 6,340.0 6,447.0 1/13/2024 18:00 1/13/2024 22:00 4.00 PROD1, DRILL DDRL P Drill F/6447' T/6498'. PUW 125K/SOW 95K, WOB10-20K, 6 BPM at 1940 psi off bottom/2100 psi on bottom. 6,447.0 6,498.0 1/13/2024 22:00 1/13/2024 23:00 1.00 PROD1, DRILL DDRL P Drill F/6498' T/6534'. PUW 125K/SOW 105K/ RWT 105K/ 40 RPM/ 4.8K TQ Off bottom/ 5.4K TQ on bottom. WOB10- 20K, 6 BPM at 1940 psi off bottom/2250 psi on bottom. Take survey @ 6515'. 6,498.0 6,534.0 1/13/2024 23:00 1/14/2024 00:00 1.00 PROD1, DRILL DDRL P Take survey, slide drill F/6534' T/6546' per DD. PUW 125K/SOW 95K/ WOB 5- 10K/ 6 BPM at 1940 off bottom and 2100 psi on botom. Mud wt 11.5+ ppg. 6,515.0 6,546.0 1/14/2024 00:00 1/14/2024 02:00 2.00 PROD1, DRILL DDRL P Slide Drill F/6,546' T/6,589' per DD. 125 k PUW, 95 k SOW, 5-10 k WOB, 112 GPM, 2050 psi off bottom, 2,170 psi on bottom, Take survey @ 6,568', Mud wt 11.5+ ppg. 6,546.0 6,568.0 1/14/2024 02:00 1/14/2024 03:00 1.00 PROD1, DRILL DDRL P Rotary Drilling F/6,589' T/6,630' as per DD, 125 k PUW, 90 k SOW, 105 RWT, 50 rpm, 5 k TQ off bottom, 5.8 k TQ on bottom, 5-8 k WOB, 112 GPM, 2,050 off bottom, 2,300 on bottom 6,568.0 6,630.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 26/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/14/2024 03:00 1/14/2024 05:00 2.00 PROD1, DRILL DDRL P Slide Drill F/6,630' T/6,710' AS per baker DD - 125 k PUW, 90 k SOW, 5-10 k WOB, 112 GPM, 2,100 psi off bottom, 2,220 psi 6,630.0 6,710.0 1/14/2024 05:00 1/14/2024 06:00 1.00 PROD1, DRILL DDRL P Rotary Drill F/6,710' T/6,724' as per baker DD, 125 k PUW, 90 k SOW, 105 k RWT, 50 RPM, 5 k TQ Off, 5.8 k TQ on, 5-8 k WOB, 112 GPM, 2,050 psi off, 2,300 psi on bottom, Take Survey @ 6,724' 6,710.0 6,724.0 1/14/2024 06:00 1/14/2024 09:30 3.50 PROD1, DRILL DDRL P Slide Drill F/6,724' T/6,816', as per Baker DD, PUW 131 k, SOW 95 k, 5 k WOB, 111 gpm, 2,050 psi off bottom, 2,240 psi on bottom, Take survey @ 6,749', 11.5+ ppg Mud Wt. Continue Slide Drill F/6,816' T/6,870' 6,724.0 6,870.0 1/14/2024 09:30 1/14/2024 11:15 1.75 PROD1, DRILL DDRL P Rotary Drill, F/6,870' T/6,912' as per Baker DD, PUW 131 k, SOW 95 k, 100 k RWT, 50 RPM, 4.8 k TQ off, TQ 5.5 k on bottom, 113 gpm, 6,870.0 6,912.0 1/14/2024 11:15 1/14/2024 12:15 1.00 PROD1, DRILL DDRL P PU stand, Rotary Drill F/6,912' T/7,000' as per Baker DD, PUW 125 k, SOW 87 k, 107 k RTW, 50 rpm, 10 k WOB, TQ on bottom 6,100 lbs, TQ off bottom 5.7 k, 11.5 ppg LSND 6,912.0 6,940.0 1/14/2024 12:15 1/14/2024 13:30 1.25 PROD1, DRILL DDRL P Rotary Drill F/6,940' T/7,005' as per Baker DD, jWOB 5-10 k WOB, GPM=270, Psi On bottom 2,300 psi, Off bottom 2,100 psi, Rot 50 rpm,TQ on bottom 6.4 k, TQ off bottom 5.2 k, PUW 125 k, SOW 87 k, RTW 107 6,940.0 7,005.0 1/14/2024 13:30 1/14/2024 17:00 3.50 PROD1, DRILL CIRC P Clean hole, recep pipe, swap hole over to 13.4 ppg LSND Mud w/40 bbl sweep 7,005.0 7,005.0 1/14/2024 17:00 1/14/2024 19:00 2.00 PROD1, DRILL DDRL P Rotary Drill F/7,005' T/7023 as per Baker DD, WOB 10-13 k, 80 RPM, TQ 4,000 lbs off bottom, TQ on bottom 5040lbs, GPM 160, PSI off bottom 1,300, PSI on bottom 1570, ECD 14.6 ppg, UPW 130K/DNW 97K/RTW 109K. Drilling break and take losses at 7022'. 7,005.0 7,023.0 1/14/2024 19:00 1/14/2024 22:30 3.50 PROD1, DRILL DISP P PU off bottom and establish loss rate of 190 BPH at 4 BPM.Shut down pumps and monitor well for flow, track and verify flow is slowing down. Circulate 2BPM at 800 psi with 1 BPM losses. Mix LCM pill and cut mud WT back from 13.55 ppg tpo 13..40 ppg. 7,023.0 7,023.0 1/14/2024 22:30 1/15/2024 00:00 1.50 PROD1, DRILL CIRC P Pump 40 bbl LCM pill followed by 13.4 ppg LSND. PUmp 2 BPM at 840 psi, spot pill on bottom. Close Annular and pump down kill line to squeeze pill into formation at 1.5 BPM not to exceed 420 psi (14.7 ppg ECD equivalnt). 7,023.0 7,023.0 1/15/2024 00:00 1/15/2024 00:30 0.50 PROD1, DRILL CIRC P Sqeeze 40 bbl LCM pill followed by 13.4 ppg LSND. PUmp 2 BPM at 840 psi, spot pill on bottom. Close Annular and pump down kill line to squeeze pill into formation at 1.5 BPM not to exceed 420 psi (14.7 ppg ECD equivalnt). 7,023.0 7,023.0 1/15/2024 00:30 1/15/2024 02:30 2.00 PROD1, DRILL OWFF P Watch for flow to decrease to zero then open Annular. 7,023.0 7,023.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 27/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2024 02:30 1/15/2024 03:45 1.25 PROD1, DRILL DDRL P On bottom drilling from 7023' to 7053' with losses at 106 bph (74.2 gpm). Pumping 145 gpm at 14.3 ECD. PUW 130K, SOW 95K, RWT 110K, 10-15K WOB, 40 RPM, 4.5K TQ Off bottom, 5.2K TQ on bottom, 1350 psi off bottom and 1450 psi on bottom. 7,023.0 7,053.0 1/15/2024 03:45 1/15/2024 06:00 2.25 PROD1, DRILL CIRC T Pick up off bottom, watch well for flow. Then circulate at minimum rate until we can get more 13.4 ppg mud wieghted up and/or the 2 trucks of 13.4 ppg mud get here. No losses while only pumping 67 gpm. 7,053.0 7,053.0 1/15/2024 06:00 1/15/2024 12:15 6.25 PROD1, DRILL CIRC T Continue circulating off bottom, 60 gpm, with minimal losses (4 bph), 749 psi, Continue weighting up 11.5 ppg to 13.4 ppg. 7,053.0 7,053.0 1/15/2024 12:15 1/15/2024 14:30 2.25 PROD1, DRILL DDRL P Rotary Drill F/7,053' T/7,104.8' as per Baker DD, WOB 10-13 k, 58 RPM, TQ 5,500 lbs off bottom, TQ on bottom 7,300 lbs, GPM 156, PSI off bottom 1,480, PSI on bottom 1830, ECD 14.3 ppg, UPW 130K/DNW 97K/RTW 109K. Short Drilling break @ 7,061' 7,053.0 7,105.0 1/15/2024 14:30 1/15/2024 17:30 3.00 PROD1, DRILL DDRL P Make connection, 7,105', Rotary Drill F/7,105' T/7,141' as per Baker DD, WOB 5-10 k, 58 RPM, TQ 5,100 lbs off bottom, TQ on bottom 6,000 lbs, GPM 135, PSI off bottom 1,580, PSI on bottom 2,042, ECD 14.7 ppg, PUW 126K/SOW 97K/RTW 60K. 7,105.0 7,141.0 1/15/2024 17:30 1/16/2024 00:00 6.50 PROD1, DRILL DDRL P Rotary Drill F/7,141' T/7,220' as per Baker DD, WOB 33-35 k,70 RPM, TQ 5,600 lbs on bottom, TQ off bottom 5,000 lbs, GPM 148, PSI off bottom 1,480, PSI on bottom 2,107 psi, ECD 14.5 ppg, UPW 130K/DNW 97K/RTW 109K. Short Drilling break @ 7,061' 7,141.0 7,220.0 1/16/2024 00:00 1/16/2024 18:00 18.00 PROD1, DRILL DDRL P Drilling ahead on losses. F/ 7220 TD 7560' Losses @ 45 bbls/hr 7,220.0 7,560.0 1/16/2024 18:00 1/16/2024 21:00 3.00 PROD1, DRILL CIRC P Circulate hole clean while recip pipe , pump 20 bbl sweeps X 2 , 100 vis with 40 lbs/bbl LCM, continue to circulate hole clean, losses down to 10 bbls/hr, 7,560.0 7,560.0 1/16/2024 21:00 1/16/2024 21:15 0.25 PROD1, DRILL OWFF P Flow check well 15 min // Flow out drop to 31% stabilized not decreasing still showing cuttings across shaker 7,560.0 7,560.0 1/16/2024 21:15 1/17/2024 00:00 2.75 PROD1, DRILL CIRC P Circulate B/U @ 3.5 bbls/min , pump away all fluid gained on flow check, mud wt at B/U 13.4 in and out still getting cuttings, lower pump rate to 1 bbl/min to relax formation while building sweeps // 1 bbls/min @ 661psi Retrun flow 29% 7,560.0 7,560.0 1/17/2024 00:00 1/17/2024 01:00 1.00 PROD1, DRILL CIRC P Continue circulating @ 1 bbl/min while building sweeps, 1 bbl/min @ 663 psi 29% return flow rate, Mud wt. 13.4 in and out 42 vis 7,560.0 7,560.0 1/17/2024 01:00 1/17/2024 02:30 1.50 PROD1, DRILL CIRC P Pump sweeps 13.4 ppg @ 90 vis // 3.5 bbls/min @ 1300 psi 32.5% 7,560.0 7,560.0 1/17/2024 02:30 1/17/2024 04:30 2.00 PROD1, DRILL OWFF P Shut down pumps OWFF, well still flowing , shut in well observe 140 psi pressure build up, blow down TD allow well to breath, continue to flow, shut in well observe 140 psi build. 7,560.0 7,560.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 28/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/17/2024 04:30 1/17/2024 10:30 6.00 PROD1, DRILL CIRC P Circulate 2 BPM down DP taking returns through choke to pits. Maintaining 13.4 ppg mud in and out. 7,560.0 7,560.0 1/17/2024 10:30 1/17/2024 18:30 8.00 PROD1, DRILL OWFF P Shut down pumps. Close annular bag for 10 minutes and write down the casing pressure. Open the supper choke, taking returns to trip tank for 15 minutes and write down the amount returned or lost. Open well to circulate clean 7,560.0 7,560.0 1/17/2024 18:30 1/17/2024 19:30 1.00 PROD1, DRILL OTHR P Work stuck pipe apperar to be packed off // Turn on pumps 3 bbls / min @ 1300 psi // Torque stalled out with 10rpm 10K torque // Work pipe down hole free up on 3rd attempt 7,560.0 7,560.0 1/17/2024 19:30 1/18/2024 00:00 4.50 PROD1, DRILL COND P Condition mud back to 13.4 in and out // 12.9 observed at shakers // excessive cuttings at shaker build sweeps to clean hole // 60 spm @ 1300 psi Up wt 120K Dn 115K 7,560.0 7,560.0 1/18/2024 00:00 1/18/2024 09:00 9.00 PROD1, DRILL COND P Condition mud to 13.7 ppg // Sweeps cleaned up hole // Pump 13.7 @ 1.5 bpm to control losses 700 psi pump pressure // Rot 10 rpm while circulating heavy mud 7,560.0 7,560.0 1/18/2024 09:00 1/18/2024 10:30 1.50 PROD1, DRILL Flow check. 7,560.0 7,560.0 1/18/2024 10:30 1/18/2024 18:00 7.50 PROD1, DRILL JAR T Work pipe 7,451.0 7,451.0 1/18/2024 18:00 1/18/2024 18:30 0.50 PROD1, DRILL SVRG T Stop jarring to inspect TD and Derrick // Total jar hits 142 // 7,451.0 7,451.0 1/18/2024 18:30 1/18/2024 21:30 3.00 PROD1, DRILL DISP T Trap 10K TQ in string, work DN to 50K on hook Work pipe up to 200-205K 10K TQ trapped in string Note @ 19:11 HRS start pumping 13.4 PPG mud down hole @ 1.4 BPM 830 PSI, 2 BPM 966 PSI Note @ 19:45 HRS 13.4 PPG mud out of the bit Continue to work pipe down with 10K TQ trapped in string 7,451.0 7,451.0 1/18/2024 21:30 1/19/2024 00:00 2.50 PROD1, DRILL JAR T Work torque into string 10K RH Torque // Jar down on string 50K down wt // 22:30- Release torque from drill string jar up // P/U 250K jars hit straight pull to 300K 15 Jar hits up no movement // Pump 30 bbl sweep 100 vis // 12:00- Swap to running down with torque in string prepping for LVT pill 7,451.0 7,451.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 29/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/19/2024 00:00 1/19/2024 02:30 2.50 PROD1, DRILL JAR T Circulate 30 bbls sweep around, 00:00 - Start jarring down with 10K RH torque in pipe 01:15 - Pump 5 bbls LVT 6.9# to bit and spot out around BHA 1BBL at a time // 5 bbls cover ~413' of open hole around BHA (Delta TVD ~ 246' Delta pressue 83 psi) 01:30 - Spot 2 bbls LVT out in open hole jar down 5 times no movement let soak 10 min Jar 5 times let soak 10 min Jar 5 times, pump 2 more bbls out in hole jar down 5 times let soak 10 min jar down 5 times pump 2 bbls out in hole all LVT in hole jar down 5 times no movement ( jars stop fireing in down direction ) 7,451.0 7,451.0 1/19/2024 02:30 1/19/2024 03:30 1.00 PROD1, DRILL CIRC T Circulate light LVT out of well, work pipe while circulating // Pump rate 3.5 bbls/min @ 1078 psi *****Jars quit firing up or down***** 7,451.0 7,451.0 1/19/2024 03:30 1/19/2024 06:00 2.50 PROD1, DRILL CIRC T Circulate S x S ensure 13.4 ppg in and out at 3BPM and 980 psi.Pump 35 bbl 13.4 ppg nutplug pill. 7,451.0 7,451.0 1/19/2024 06:00 1/19/2024 09:30 3.50 PROD1, DRILL JAR T Work stuck pipe, 2-3 BPM at 940-1050 PSI. Torque Pipe to 10K lock in and attempt to drive down, set all weight down, pulled to 250K up, chase down,jars not working. 7,451.0 7,451.0 1/19/2024 09:30 1/19/2024 10:00 0.50 PROD1, DRILL SVRG T Conduct derrick jarring inspection. 7,451.0 7,451.0 1/19/2024 10:00 1/19/2024 12:00 2.00 PROD1, DRILL JAR T Jars started working in up stoke, continue jarring. Fire at 200K up pull to 360K pumping 2-3 BPM at 950 PSI. Shut pumps off, no change, attempt to TQ in pipe drive down no change 7,451.0 7,451.0 1/19/2024 12:00 1/19/2024 17:30 5.50 PROD1, DRILL JAR T Continue jarring, fire at 200K up, pull to 360K, Pumping 2-3 BPM at 950 psi,shut pumps off, no change, attempt10K torque in pipe and drive down no change. MWT = 13.4 ppg, attempt to jar down set at 125K up jar down, All string weight 83K,with and without 9K TQ in string, without pumps. 7,451.0 7,451.0 1/19/2024 17:30 1/19/2024 18:00 0.50 PROD1, DRILL SVRG T Conduct derrick inspection 7,451.0 7,451.0 1/19/2024 18:00 1/19/2024 19:00 1.00 PROD1, DRILL CIRC T Circulate while rigging up LRS // build 30 bbl bead pill 2ppg 7,451.0 7,451.0 1/19/2024 19:00 1/19/2024 20:15 1.25 PROD1, DRILL CIRC T Pump 30 bbls sweep with 2ppg beads // follow that with 8 bbls dead crude// line up mud pump spot dead crude around BHA 1300 stks Pump rate 3 bbls/min @ 1218 psi Spot dead crude with pipe in compression // Shut annular to hold around BHA 7,451.0 7,451.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 30/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/19/2024 20:15 1/19/2024 21:45 1.50 PROD1, DRILL JAR T Spot half of crud around BHA 5 bbls let soak 20:10- Crude spotted letting soak 20:40- Open up well work pipe down 5 times work pipe up 5 time no movement spot rest of crude 21:05- Let crude soak 21:30- Work pipe no movement 7,451.0 7,451.0 1/19/2024 21:45 1/19/2024 23:45 2.00 PROD1, DRILL CIRC T Circulate out dead crude, load 15 bbls dead crude in drill pipe, displace down to BHA let soak 23:45 - Crude spotted and soaking with pipe squatted ( Hook load 30K ) 7,451.0 7,451.0 1/19/2024 23:45 1/20/2024 00:00 0.25 PROD1, DRILL OTHR T Let crude soak around BHA 7,451.0 7,451.0 1/20/2024 00:00 1/20/2024 00:30 0.50 PROD1, DRILL OTHR T Let crude soak around BHA 7,451.0 7,451.0 1/20/2024 00:30 1/20/2024 01:00 0.50 PROD1, DRILL JAR T Work stuck pipe, 5 down hits 5 pulls to 360K // 10 down hits no movement // Spot second half of crude in open hole // 7,451.0 7,451.0 1/20/2024 01:00 1/20/2024 02:00 1.00 PROD1, DRILL OTHR T Let crude soak around BHA 7,451.0 7,451.0 1/20/2024 02:00 1/20/2024 02:30 0.50 PROD1, DRILL JAR T Work stuck pipe down w/ 10K RH torque // 10 down hits // 5 pick ups jars not fireing on up stroke 7,451.0 7,451.0 1/20/2024 02:30 1/20/2024 03:30 1.00 PROD1, DRILL CIRC T Circulate dead crude out of well 7,451.0 7,451.0 1/20/2024 03:30 1/20/2024 04:00 0.50 PROD1, DRILL CIRC T Circulate black magic pill down to bit spot 7 bbls around BHA 7,451.0 7,451.0 1/20/2024 04:00 1/20/2024 05:00 1.00 PROD1, DRILL WAIT T Let 7 bbls Black Magic soak around BHA 7,451.0 7,451.0 1/20/2024 05:00 1/20/2024 12:00 7.00 PROD1, DRILL JAR T Work stuck pipe for 30 minutes then pump 1 bbl Black Magic out of bit into open hole. Work stuck pipe for 30 more minutes then pump another bb1 of Black Magic and repeat for 13 bbls. 7,451.0 7,451.0 1/20/2024 12:00 1/20/2024 19:00 7.00 PROD1, DRILL ELNE T RU Eline for a string shot back off at the IF connection right below the jars. Put 7K (70% of 10K 3-1/2"IF connection) left hand torque into the drill pipe. RIH and string shot at 7220'. 7,451.0 7,451.0 1/20/2024 19:00 1/20/2024 20:30 1.50 PROD1, DRILL ELNE T RIH with E-line log for depth control set up for spotting Black magic pill 7,451.0 7,451.0 1/20/2024 20:30 1/20/2024 21:15 0.75 PROD1, DRILL CIRC T Spot 13.7 Black Magic pill around BHA 7,451.0 7,451.0 1/20/2024 21:15 1/20/2024 22:00 0.75 PROD1, DRILL ELNE T Secure floor and equipment for shooting string shot // 7339.1 ELD XO above well commander // Fire string shot @ 22:00 7,451.0 7,451.0 1/20/2024 22:00 1/20/2024 23:00 1.00 PROD1, DRILL ELNE T Rig up lines to grease head // POOH with E-Line to inspect tools // Indicated good fire on string shot 7,451.0 7,451.0 1/20/2024 23:00 1/20/2024 23:30 0.50 PROD1, DRILL RURD T Stand back e-line equipment prep to check for free pipe 7,451.0 7,451.0 1/20/2024 23:30 1/21/2024 00:00 0.50 PROD1, DRILL OTHR T Make up TD to string // Introduce back torque into string 9K LH indicated on rig watch // work torque down to bha while counting turns indication back off successful // 150k PU wt. // Pump 62 spm @ 700 psi ( MWD not turning on ) indication BHA left down hole 7,451.0 7,339.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 31/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/21/2024 00:00 1/21/2024 04:00 4.00 PROD1, DRILL TRIP T TOOH to window // Pu Wt 150 ( 110 while rotating ) // Trip out while pumping // tool joints hard to break had to use rig tongs to break 7,339.0 6,200.0 1/21/2024 04:00 1/21/2024 05:30 1.50 PROD1, DRILL TRIP T Circulate 13.4 ppg mud 4 BPM at 660 psi. SxS 6,200.0 6,200.0 1/21/2024 05:30 1/21/2024 06:00 0.50 PROD1, DRILL OWFF T Flow check. Still has a little flow, but is dying. 6,200.0 6,200.0 1/21/2024 06:00 1/21/2024 08:00 2.00 PROD1, DRILL CIRC T Circulate 13.4 ppg mud 4 BPM at 660 psi. SxS 6,200.0 6,200.0 1/21/2024 08:00 1/21/2024 09:00 1.00 PROD1, DRILL OWFF T Flow check. Well static. Pump 15 bbl slug. 6,200.0 6,200.0 1/21/2024 09:00 1/21/2024 14:00 5.00 PROD1, DRILL TRIP T POOH from window standing back Drill Pipe. UPW=110K 6,200.0 0.0 1/21/2024 14:00 1/21/2024 16:00 2.00 PROD1, DRILL RURD T RU to test BOPE, drain stack, fill stack and set test plug. 0.0 0.0 1/21/2024 16:00 1/21/2024 22:30 6.50 PROD1, DRILL BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = 115 sec. UVBR's= 5 sec, Annular= 25 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 2 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Kam StJohn 0.0 0.0 1/21/2024 22:30 1/21/2024 23:30 1.00 PROD1, DRILL RURD T Rig down test equipment and blow down choke manifold 0.0 0.0 1/21/2024 23:30 1/22/2024 00:00 0.50 PROD1, DRILL OTHR T Install wear bushing 0.0 0.0 1/22/2024 00:00 1/22/2024 01:30 1.50 PROD1, DRILL BHAH T Pick up and make up BHA #66 // Screw in sub, side port circ sub Min ID = 2.188" in side port circ sub Max OD= 5.125" XO from BHA to DP Screw in sub 3.5" IF with cut lip for guided entry, side port circ sub 3500 psi differential burst disc 0.0 196.0 1/22/2024 01:30 1/22/2024 05:30 4.00 PROD1, DRILL TRIP T TIH with drill pipe and fishing bha #66. UWT=125K, DWT=90K. 196.0 6,855.0 1/22/2024 05:30 1/22/2024 08:30 3.00 PROD1, DRILL CIRC T Wash down from 6855 to 7110'. 1 BPM at 300 psi. Work stuck pipe and jar free. 6,855.0 7,110.0 1/22/2024 08:30 1/22/2024 09:00 0.50 PROD1, DRILL CIRC T Reciprocate from 6855' to 6982'. Pump 2x bottoms up. 13.4 ppg in and 13.4 ppg out 7,110.0 6,855.0 1/22/2024 09:00 1/22/2024 11:00 2.00 PROD1, DRILL TRIP T TOOH from 6855' to 6316' UWT=120K, DWT=90K 6,855.0 6,316.0 1/22/2024 11:00 1/22/2024 11:30 0.50 PROD1, DRILL OWFF T Flow check, no flow. 6,316.0 6,316.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 32/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/22/2024 11:30 1/22/2024 12:00 0.50 PROD1, DRILL SVRG T Service rig 6,316.0 6,316.0 1/22/2024 12:00 1/22/2024 14:30 2.50 PROD1, DRILL TRIP T TOOH with fishing BHA #65. 6,316.0 199.0 1/22/2024 14:30 1/22/2024 15:30 1.00 PROD1, DRILL BHAH T LD fishing BHA #65 199.0 0.0 1/22/2024 15:30 1/22/2024 16:00 0.50 PROD1, DRILL BHAH T MU CO BHA #66 0.0 981.0 1/22/2024 16:00 1/22/2024 20:00 4.00 PROD1, DRILL TRIP T TIH with CO BHA #66 981.0 6,400.0 1/22/2024 20:00 1/22/2024 22:00 2.00 PROD1, DRILL CIRC T Circulate ensure mud in good shape for cleanout // 13.4 in and out 42 vis // 6,400.0 6,400.0 1/22/2024 22:00 1/23/2024 00:00 2.00 PROD1, DRILL REAM T Wash through window clean to 6435' reamer outside of window // Ream down 20 rpm 63 spm @ 760 psi // RIH @ 10'/min // Ream to 6580' 6,400.0 6,580.0 1/23/2024 00:00 1/23/2024 02:00 2.00 PROD1, DRILL REAM T Ream down 20 rpm 63 spm @ 760 psi string wt 100K // RIH @ 10'/min // Ream F/ 6580' T/ 6727' Stall and heavy pick ups @ 6696', 6702', and 6727' Last pick up at 6727' 100K over string wt work rot up to 40 rpm Phase called field wide PJSM trip out to shoe 6,580.0 6,727.0 1/23/2024 02:00 1/23/2024 03:00 1.00 PROD1, DRILL TRIP T TOOH to window Pump and back ream to window // 40 rpm 65spm @ 790 psi 6,727.0 6,400.0 1/23/2024 03:00 1/23/2024 11:00 8.00 PROD1, DRILL WAIT T Phase 3 waiting on weather Pump 1.5 bpm to keep fluid moving in casing 6,400.0 6,400.0 1/23/2024 11:00 1/23/2024 13:00 2.00 PROD1, DRILL CIRC T Build and pump dry job 6,400.0 6,386.0 1/23/2024 13:00 1/23/2024 15:30 2.50 PROD1, DRILL TRIP T TOOH F/6402' T/949.25 6,386.0 949.3 1/23/2024 15:30 1/23/2024 16:30 1.00 PROD1, DRILL BHAH T LD BHA per BOT rep F/949 T surface 949.3 0.0 1/23/2024 16:30 1/23/2024 17:00 0.50 PROD1, DRILL RURD T Clear BOT tools off rig floor that aren't required. 0.0 0.0 1/23/2024 17:00 1/23/2024 18:30 1.50 PROD1, DRILL RURD T Empty stack pull wear ring. 0.0 0.0 1/23/2024 18:30 1/23/2024 22:30 4.00 COMPZN, CEMENT RURD T RU to test BOP's 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 33/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/23/2024 22:30 1/24/2024 00:00 1.50 COMPZN, CEMENT BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 4" test joint, UVBR's, LVBR's w/4-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 4" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = XXX sec. UVBR's= X sec, Annular= XX sec. Simulated blinds= X sec. LVBR’s=5 sec. HCR choke & kill= 2 sec each. 5 back up nitrogen bottles average = XXXX PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Guy Cook 0.0 0.0 1/24/2024 00:00 1/24/2024 08:30 8.50 COMPZN, CEMENT BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 4" test joint, UVBR's, LVBR's w/4-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 4" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = XXX sec. UVBR's= X sec, Annular= XX sec. Simulated blinds= X sec. LVBR’s=5 sec. HCR choke & kill= 2 sec each. 5 back up nitrogen bottles average = XXXX PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Guy Cook 0.0 0.0 1/24/2024 08:30 1/25/2024 00:00 15.50 COMPZN, CEMENT RGRP T Remove and repair internal ram seal on UPR. Bonnett removed to truck shop for proper repair. 0.0 1/25/2024 00:00 1/25/2024 11:00 11.00 COMPZN, CEMENT RGRP T Remove and repair internal ram seal on UPR. Bonnett removed to truck shop for proper repair. Repairs completed, reinstalled completed and function tested. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 34/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/25/2024 11:00 1/25/2024 15:00 4.00 COMPZN, CEMENT BOPE T Continue testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 4" test joint, UVBR's, LVBR's w/4-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 4" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =15 sec, full recovery attained = 117 sec. UVBR's= 5 sec, Annular= 31 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Guy Cook 0.0 0.0 1/25/2024 15:00 1/25/2024 16:30 1.50 COMPZN, CEMENT RURD T RD from testing blow down choke, mud manifold and kill lines empty stack. pull test plug. Install wear ring. fill stack with 13.4# LSND 0.0 0.0 1/25/2024 16:30 1/25/2024 17:00 0.50 COMPZN, CEMENT BHAH T PU Cement retainer. 0.0 13.7 1/25/2024 17:00 1/25/2024 22:30 5.50 COMPZN, CEMENT TRIP T TIH F/13.73' T/6379' Top of retainer at 6379' 13.7 6,380.0 1/25/2024 22:30 1/25/2024 23:30 1.00 COMPZN, CEMENT CIRC T Circulate S x S even out mud @ 13.4 6,380.0 6,380.0 1/25/2024 23:30 1/26/2024 00:00 0.50 COMPZN, CEMENT PRTS T Perform injection test // Pump 1 bpm initial break over and circ @ 750psi, bump pump rate up to 2 bpm pressure initially stabilize out @ 750 psi then climb to 1500 and hold // shut down pump no blead off // Open BOPs and circulate for plan forward 6,380.0 6,380.0 1/26/2024 00:00 1/26/2024 00:30 0.50 COMPZN, CEMENT PRTS T Close BOPs and perform injection test again // Pressure up 800 psi shut down pump pressure slowly bleed to 720psi over 2 min // Pressure up 1400psi break over down to 1200 psi @ 2 bpm, continue pumping pressure up again to 1400 psi pressure break over to 1100psi @ 2 bpm 6,380.0 6,380.0 1/26/2024 00:30 1/26/2024 03:00 2.50 COMPZN, CEMENT MPSP T Set cement retainer top @ 6379' // unable to set, pump, reverse pump, rotate while RIH, pick up and slack off multiple times // Rotate while moving up slips set TOR 6377' 6,380.0 6,379.0 1/26/2024 03:00 1/26/2024 06:00 3.00 COMPZN, CEMENT HOSO T Lay down 2 jts, pick up 30.47' of pups ( 5.15', 10.17', 10.15', 5.0' ) , pick up 1 full jt space out @ floor with full jt across BOPs // PT retainer ensure good set 500 psi no communication good test 6,379.0 6,377.0 1/26/2024 06:00 1/26/2024 06:30 0.50 COMPZN, CEMENT SFTY T PJSM with Nabors/HES/CPAI for pumping cement. 6,377.0 6,377.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 35/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/26/2024 06:30 1/26/2024 10:00 3.50 COMPZN, CEMENT CMNT T Line up HES. take on water start building lead spacer. Pump 10 BBL's 80* water ahead to warm lines. PT surface lines to 250/3500 PSI. Bleed off pressure good test. Open up to well start cement ops. HES PR 2BPM 7BBL 14 PPG spacer 1.5BPM 1200 PSI 52 BBL 15.3 PPG Cement 1BPM 950 PSI 720AM 20BBLS 700 PSI 40 BBL 444PSI 45 BBL 396 52 330PSI 10 BBL 8.5 H2O spacer 1BPM 370 Shut down HES cement. 818AM shut down Online with rig pump Chase cement at 1BPM 10 BBLs contaminate pill Swap to 9.5# CI displace 49 BBL's to formation final squeeze 1550 PSI Sting out of retainer pump 1BBL PUH to 6315 Lay in 2BBLs 15.3# at .5BPM PUH at 70 FPM. Complete displacing casing and DP W/210 BBLs 9.5# CI. 6,377.0 6,315.0 1/26/2024 10:00 1/26/2024 10:30 0.50 COMPZN, CEMENT OWFF T OWFF Well Static 6,315.0 6,315.0 1/26/2024 10:30 1/26/2024 11:30 1.00 COMPZN, CEMENT RURD T Break out DP, blow down cement manifold and cementing lines RD Cement X-O's and lay down space out pups. 6,315.0 6,290.0 1/26/2024 11:30 1/26/2024 13:30 2.00 COMPZN, CEMENT TRIP T TOOH for tag assembly 6,290.0 0.0 1/26/2024 13:30 1/26/2024 14:00 0.50 COMPZN, CEMENT BHAH T Pick up tag assembly, 6-1/8" rock bit w/ 1 stand collars 0.0 120.0 1/26/2024 14:00 1/26/2024 16:00 2.00 COMPZN, CEMENT TRIP T TIH to tag cement // Stop at 6300' to wait for state rep 120.0 6,300.0 1/26/2024 16:00 1/26/2024 18:00 2.00 COMPZN, CEMENT WAIT T Wait for state rep // Prep for laying down dp 6,300.0 6,300.0 1/26/2024 18:00 1/26/2024 21:30 3.50 COMPZN, CEMENT PRTS T Tag top cement w/ 10K WOB @ 6332' ( 45' good cement ) // Pressure test 2500 psi 30min good test AOGCC Witnessed Josh Hunt 6,300.0 6,332.0 1/26/2024 21:30 1/26/2024 23:30 2.00 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 6,332.0 4,000.0 1/26/2024 23:30 1/27/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig Grease DW 4,000.0 4,000.0 1/27/2024 00:00 1/27/2024 01:30 1.50 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 4,000.0 2,800.0 1/27/2024 01:30 1/27/2024 02:30 1.00 COMPZN, RPCOMP SVRG P Replace switch on iron roughneck 2,800.0 2,800.0 1/27/2024 02:30 1/27/2024 08:00 5.50 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 2,800.0 92.0 1/27/2024 08:00 1/27/2024 08:30 0.50 COMPZN, RPCOMP BHAH P LD BHA collars and Bit 92.0 0.0 1/27/2024 08:30 1/27/2024 13:30 5.00 COMPZN, RPCOMP PUTB P RIH with 4.5" 12.6# L-80 Hyd 563 kill string to 2304.32 0.0 2,304.3 1/27/2024 13:30 1/27/2024 14:00 0.50 COMPZN, RPCOMP THGR P MU hanger to string Land hanger RILDS 2,304.3 2,304.3 1/27/2024 14:00 1/27/2024 15:00 1.00 COMPZN, RPCOMP MPSP P Set BPV. RU LRS. LRS test under BPV to 1000 PSI 2,304.3 2,304.3 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 36/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/27/2024 15:00 1/27/2024 21:30 6.50 COMPZN, RPCOMP NUND P ND BOPE NU tree and adapter. P/T 5000 good test 2,304.3 2,304.3 1/27/2024 21:30 1/27/2024 23:00 1.50 DEMOB, MOVE FRZP P Line up pump 80 bbls diesel freeze protect with LRS 2,304.3 2,304.0 1/27/2024 23:00 1/28/2024 00:00 1.00 DEMOB, MOVE RURD P Rig down LRS let well u-tube **** Release rig 00:00 on 1/28/24 2,304.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 DTTMSTART JOBTYP SUMMARYOPS 10/26/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 10/28/2023 ACQUIRE DATA BRUSH W/ 3-1/2 BLB TO ROCK SCREEN @ 6961' RKB. DRIFT W/ 2.75" DMY CEMENT RETAINER TO 6961' RKB, TIGHT SPOTS 5600-5700' RKB, PRESSURE UP TBG TO 2000 PSI UNABLE TO PUMP INTO WELL, SET 1.5" DMY IN ST#7 @ 6892' RKB, READY FOR COIL. 10/29/2023 ACQUIRE DATA MIRU, BOP TEST, CUT 250' OF PIPE, 8020' OF COIL REMAINING. SET CEMENT RETAINER AT 6925' RKB, MID JOINT. PRESSURED UP TO 5100 PSI, WELL HAS ZERO INJECTIVITY. WAIT ON ENGINEER TO DISCUSS WITH AOGCC. RIG DOWN AND STAGE UNIT ON 2M PAD FOR PLAN FORWARD. 10/31/2023 REPAIR WELL PULLED 1.5'' DMY VLV ST#7 6892' RKB, READY FOR COIL. 10/31/2023 REPAIR WELL PERFORM GENERAL MAINTENANCE WHILE STANDING BY ON EOP FOR SLICKLINE TO PULL DV. MIRU CTU 6 POST SLICKLINE. DRIFT COIL. RECOVER 1/2" BRASS BALL. MAKE UP TOOLS. 11/1/2023 REPAIR WELL MIRU TO PUMP BALANCED CEMENT PLUG. CIRC WELL OUT TO 9.8 PPG BRINE. PUMP 13 BBLS OF 15.8 PPG CLASS G CEMENT. PUMP 7.7 BBLS IN IA, LAY 5.3 BBLS ON TOP OF RETAINER. CLEAN OUT EXCESS CEMENT. ESTIMATED TOC 6600' RKB. READY FOR SLICKLINE TO FREEZE PROTECT WITHIN 24 HRS. 11/2/2023 REPAIR WELL PULLED DMY @ 3214' RKB. CIRC IN 70 BBLS DIESEL FOR FREEZE PROTECT. RE-SET DV @ 3214' RKB. TAGGED TOC @ 6559' RKB. READY FOR (AOGCC WITNESS 11/5/23) 11/3/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/5/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/6/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/7/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/12/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/13/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/14/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/15/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/17/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR IN PROGRESS. 11/23/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 6559' RKB, CONDUCT AOGCC WITNESSED (JOSH HUNT) CMIT TXIA TO 2820 PSI, ATTEMPT TO PULL DMY VALVE IN STA #5 @ 6094' RKB, SHUCK OFF VALVE, RUN CHECK SET TO ENSURE VALVE IS STILL IN POCKET... READY FOR ELINE TO MAKE CUT ON TBG 11/24/2023 ACQUIRE DATA TUBING CUT AT 6565' WITH WELLTECH MECHANICAL CUTTER, TOC TAGGED AT 6570' CCL TO BLADE: 18FT CCL STOP DEPTH: 6547' 11/25/2023 ACQUIRE DATA DRIFT W/ 2.83" GAUGE RING TO SSSV @ 1808' RKB, SET HOLD-OPEN SLEEVE ACROSS SSSV. JOB COMPLETE 12/2/2023 RECOMPLETION Tested tubing and casing, freeze protected well. RDMO 2M-15. MIRU on 2M-24. Accepted rig at 1400. bring on 8.6# seawater displace well @ 1.5 bpm due to limited flow path at weltec cut, flow check dead well, install ISA BPV 12/3/2023 RECOMPLETION Test BOPs, AOGCC witness waived Austin McLeod, rig down test equipment, test MWD connection on stand pipe, re-tighten, make up landing jt attempt to pull completion, no movement circulate S x S 12/4/2023 RECOMPLETION Rig up slick line, pull sleeve and run 2.29 ID Sleeve in hole, RIH with 2" RCT cutter, cut pipe @ 6180', lay down 1000' of tubing, well u-tube up pipe circulate well to remove bad cement and mud from system, attempt to drift casing unable to pass well head with 5.25 drift, lay down tubing to get control line out of well 12/4/2023 SUPPORT OTHER OPERATIONS ( RIG JOB ON 7ES, CHARGING TO NETWORK # 10451426) PULLED 2.83'' NO-GO HOLD OPEN SLEEVE(1.58''ID). RAN FLAPPER CHECKER ON SSSV @1808' RKB, UNABLE TO CATCH. SET 2.83'' NO-GO HOLD OPEN SLEEVE (OAL 64'')(ID 2.29''). READY FOR E-LINE & TBG CUT. 12/4/2023 SUPPORT OTHER OPERATIONS CUT 3.5" TUBING @ 6180' RKB W/ 2" RCT CUTTER, CCL TO CUTTER = 10.2', CCL STOP = 6169.8', RIG HAD PIPE MOVING AND RELEASED AKE ELINE. JOB COMPLETE. NETWORK # 10451426 NOTE: ACTUAL START TIME WAS 12/4/23 @ 4:30 AM. UNABLE TO HAVE WSR'S OVER-LAP TIME WITH SL WSR. 12/5/2023 RECOMPLETION Continue L/D 3.5" completion, unable to pull through tubing spool, P/U 4" GS, TIH on 3.5" singles drop off tubing on stump, set and test IBP, N/D BOPE , strech casing, M/U tubing spool, N/U/ test BOPE break, pull test plug, set wear ring, TIH to retrieve IBP 12/6/2023 RECOMPLETION Pull IBP, L/D pulling tools, M/U grapple, TIH w/3.5" tubing out of derrick, pull/LD 3.5" completion, TIH w/DP, overshot, latch onto fish jar 56 times, and straight pull to 95%-264 k, no movement, TOOH F/6,158' T/2,780' 12/7/2023 RECOMPLETION Continue TOOH F/2,780', L/D BHA and DC, M/U overshot, TIH w/DP, rotate over stump, R/U E-line, log CBL 12/7/2023 ACQUIRE DATA PERFORM CBL. TOP OF CEMENT FOUND AT 6260'. JOB IN PROGRESS 12/8/2023 RECOMPLETION E-line, log CBL, perform RTC cut @ 6,278', POOH-R/D w/E-line, P/U fishing tools, TIH, jar on fish 86 hits, no movement, rotate off fish, TOOH, L/D fishing tools, P/U burn shoe w/4 jts of wash pipe, set down @ 255' 12/8/2023 ACQUIRE DATA CUT TUBING WITH 2" RCT AT 6278.0', CCL TO CUTTER = 13.1', CCL STOP DEPTH = 6264.9' 12/9/2023 RECOMPLETION Work wash pipe, unable to pass, stand back wash pipe, and lay down BHA, drift well w/5.95" swedge/6.10" swedge. Run CBL w/E-line F/6,170 T/350', E-line caliper failure, trouble shoot tools 12/9/2023 ACQUIRE DATA RUN 1: LOG CBL IN 7" CASING FROM 6175' - SURFACE. TOP OF CEMENT FOUND AT 2000' RUN 2: PERFORM READ 40 ARM CALIPER FROM 6175' - 350', TOOLS STOP WORKING. POOH TO TROUBLESHOOT AND SWAP TO MEMORY TOOLS, JOB IN PROGRESS 12/10/2023 RECOMPLETION M/U 40 arm caliper on memory, RIH, log 7" F/350' T/surface, R/D E-line, P/U & set G-lock, test plug T/2,500 psi, TOOH, L/D setting tools, N/D BOPE & Adaptor, remove packoff, spear 7" casing, pull into tention 185k over blocks, drift casing through damaged casing area, unable to drift 253', TOOH, L/D wash pipe, N/U BOPE/Adaptor, TIH F/surface T/2250', dump ~50' of sand on plug, 12/10/2023 ACQUIRE DATA JOB CONTINUED FROM 12/09/2023. CONTINUE RIGGING UP MEMORY CALIPER. FINISH LOG FROM 350' TO SURFACE. 2M-24 Summary of Operations 12/11/2023 RECOMPLETION TOOH, L/D Bull nose, M/U MSC, RIH T/1,786', cut casing, Space out, R/U LRS, Open well to LRS. Attempt to circulate down 7" casing up the OA. stage up to 1200 PSI no circulation. Work pipe PU WT= 215K. Stage up to 2000 PSI established circulation. Close rams and attempt to circulate work pressure up to 2000 PSI. Continue to maintain 2000 PSI. Slowly moving fluid to kill tank. Pressure locked at 2200 PSI. Pressured up and relieved the pressure cycling back and forth attempting to regain circulation. unable to make any progress. Held 2000 PSI on casing for 15 minutes no change. Bled off casing. discussed options with town engineer. Decision point to pull slips out of wellhead. 12/12/2023 RECOMPLETION Try to pull casing free, RIH with a tubing punch to regain circulation and circulate arctic pack out of the hole. Failed to circulate, RIH with MSC to cut casing at 420' circulate and pull casing out of hole. 12/12/2023 ACQUIRE DATA RUN 1: CASING PUNCH INTERVAL: 580' - 583', CCO TO TOP SHOT = 6.6', CCL STOP DEPTH = 573.4' RUN 2: CASING PUNCH INTERVAL: 830' - 833', CCL TO TOP SHOT = 6.6', CCL STOP DEPTH = 823.4' 12/13/2023 RECOMPLETION ND BOPE, pull casing slips, NU BOPE swaping lower rams to 7", Pull 7" from 428'. RIH spear 7" casing and try to jar free. 12/14/2023 RECOMPLETION MU MSC and RIH and cut 7" casing at 925', 1566' and again at 1786' and pull casing from 1566'. 12/15/2023 RECOMPLETION Finish pulling casing from 1786'. Wash and ream 9-5/8" down to 1000' 12/16/2023 RECOMPLETION Test BOPE. MU BHA with string mills to clean up 9-5/8"casing. 12/17/2023 RECOMPLETION Mill 9-5/8" casing and TOOH. MU and RIH to dress 7" tubing stub at 1786'. Would not drift. MU mills and go back to washing and reaming. 12/18/2023 RECOMPLETION Milled 9-5/8" casing F/250' T/865', drifted to tubing stump F/865' T/1,780', circulated high vis sweep, TOOH, L/D milling assembly, P/U drift/dress off BHA#35, drifted and dressed top of 7" stump F/surface T/1,787.3', TOOH, L/D drift assembly 12/19/2023 RECOMPLETION L/D dress off BHA #35, Run & cement 7" casing. 12/20/2023 RECOMPLETION Completed nipple up of BOPs, Perform full bop test 250/4000 witnessed by AOGCC Austin McLeod, pick up plug mill bha, tih mill out cement plug, unable to make progress on plug, 12/21/2023 RECOMPLETION Upon inspection of mill looked to be bolt impression, attempt fish with RCJB and Magnet, no fish, pick up rock bit TIH start milling @ 1775' 12/22/2023 RECOMPLETION Complete milling out cement plug, TOOH pick up and run RCJB 2 runs, pick up and run g-lock retrieval tool, TIH tag sand @ 2338' circulate sand off of plug 12/23/2023 RECOMPLETION Unable to get to plug with pulling assembly, complete 2 more runs with RCJB, first run lost fingers, picked up second RCJB with larger offset from end of tool to fingers, TIH able to wash to top of plug, TOOH pick up retrieval tools, latch into plug pull to surface, over pull till above cement tool in 7 in 10K - 15K , rig up to test casing 12/24/2023 RECOMPLETION Pressure test casing 2500 psi 30 min good test, pick up wavy bottom burn shoe TIH mill around casing, Top of fish 6180, top of cement 6190, mill to 6211 unable to make progress, tooh inspect mill found to be stress fractured and all of cutting material gone, pick up burn shoe with larger ID 4.75" and TIH with burn shoe and 120' wash pipe, start milling @ 6211' to 6229' 12/25/2023 RECOMPLETION Continued to mill down to 6242', progress slowed, pump hole clean with sweeps, TOOH to inspect BHA, found ~60' of 3.5" completion in wash pipe, lay down and inspect washpipe, pick up burn shoe, TIH w/ 6" OD 4.75" ID burn shoe, mill T/ 6256' progress slowed pump sweeps to clean hole 12/26/2023 RECOMPLETION Circ hole clean, TOOH T/6050', perform casing test 2500 psi for 30 min, could not get pipe to bleed off indicating partial plug of washpipe, TOOH and recovered 18' of 3.5" tubing, Test casing 2500 15min good test, pick up wash over assembly RIH and continue to mill over completion T/ 6278', torque spikes and unable to proceed, sweep hole, attempt trip out pull heavy @ 6240', work back in hole attempt to mill again no progress, tooh hang up @ 6240' wait for jars to hit, prior to jars hitting popped free, TOOH T/ 6050' circulate sweep ensure hole clean 12/27/2023 RECOMPLETION Inspect BHA, portion of fish was recovered in wash pipe. Attempt to burn over top of tubing, unable to pass 6278'. Routine slip and cut drilling line. TOOH for junk mill run, lay down washpipe bha recover two 8' slabs from washpipe, pick up junk mill BHA# 53, TIH start milling F/ 6277' 12/28/2023 RECOMPLETION Continue milling with 6.125" junk mill F/6277', perform wipers and sweeps as needed T/ 6535' 12/29/2023 RECOMPLETION Milled to 6341' 7ES RKB. TOOH for bit. gauged 6.125" OD face worn some carbide left. TIH and continue milling F/6341' T/ 6348 12/30/2023 RECOMPLETION Continued milling ahead F/6348' T/ 6387' 12/31/2023 RECOMPLETION Continued milling F/ 6387' T/ 6394' , unable to proceed, tooh pulling heavy, pump out of the hole, change BHA, RIH with 6-1/8" junk mill, TIH T/ 6100' 1/1/2024 RECOMPLETION Trip in hole tag bottom @ 6394', get perameters and mill ahead T/ 6427.35', pressure spike, TOOH to inspect BHA found 8' of spiral tubing cored into mill and up into BHA, lay down BHA clean floor 1/2/2024 RECOMPLETION Cleaned out to 6427' with cleanout BHA., trip out of hole set storm packer @ ~1730' for BOP test, phase 3 called on 2M pad, pull packer circulate well 1/3/2024 RECOMPLETION Waited on weather 1/3/2024 SUPPORT OTHER OPERATIONS 1/4/2024 RECOMPLETION Waiting on weather 1/5/2024 RECOMPLETION Waiting on weather 1/6/2024 RECOMPLETION Continue to wait on weather conditions to improve and for roads to be cleared, 04:30 phase conditions lifted, re-build storm packer and set @ 65', rig up and perform full bop test 250/4000 , retrieve storm packer circulate SxS pump pressure steady increase, blow down TD, TOOH, lay down BHA and inspect, found 1/2 bucket of metal on magnet and bootbaskets, rig up E- line tag cement 6448' ELM , log cement T/ 6290' ELM 1/6/2024 ACQUIRE DATA STANDBY FOR RIG, RIG UP CBL AND RIH. JOB IN PROGRESS 1/7/2024 ACQUIRE DATA JOB CONTINUED FROM 01/06/2024 RUN 1: PERFORM CBL FROM 6433' - 6000'. TOP OF CEMENT FOUND AT 6250' RUN 2: PERFORM 40 ARM CALIPER FROM 6440' - 6000' 1/7/2024 RECOMPLETION Complete CBL/CCL run, pick up caliper, caliper TD up to 6000', pull caliper out of hole rig down E-line, Phase 3 called wait on weather 1/8/2024 RECOMPLETION Performed a clean out run and displaced the well to mud. TOOH and lay down clean out BHA. RIH with same BHA to make a second cleanout run. 1/9/2024 RECOMPLETION Performed another clean out run. TOOH and lay down clean out BHA. RIH to make a another cleanout run. 1/10/2024 RECOMPLETION Pick up WS, TIH set on depth, shear out of WS, mill window per baker rep. 1/11/2024 RECOMPLETION Continue milling window per baker rep, then rat hole per Baker directional, TOOH for drilling assembly. MU drilling BHA and RIH to window. Shutdown and wait for weather. 1/11/2024 SUPPORT OTHER OPERATIONS 1/12/2024 RECOMPLETION Waiting on Phase 3 Weather 1/13/2024 RECOMPLETION WOW then Drill from window at 6,344' to 6,706'. 1/14/2024 RECOMPLETION Drilled 30' with 50% losses. Losses never healed up. 1/15/2024 RECOMPLETION Drilled to 7220' with 60 BPH losses. 1/16/2024 RECOMPLETION Continue drilling ahead to TD @ 7560', pump sweeps and circulate hole clean, perform flow check, return flow drop to 31% and stabilized, turn on pumps circulate B/U @ 3.5 bbls/min 1250 psi 33% return flow, Mud wt @ B/U 13.4 in and out 42 vis, still getting cuttings across shaker, lower pump to 1 bbl/min while building sweeps to "relax" formation 1/17/2024 RECOMPLETION Continue to monitor well for ballooning , open well and work stuck pipe free, circulate and condition mud to 13.4 in and out // clean well bore 1/18/2024 RECOMPLETION Continued to clean well bore, displaced well to 13.7 ppg mud, perform flow check became diff stuck, work stuck pipe while swapping mud back to 13.4 ppg mud 1/19/2024 RECOMPLETION Continue to work stuck pipe, spot dead crude around BHA let soak no movement, spot second crude sweep around BHA let soak while mixing up black magic pill 1/19/2024 SUPPORT OTHER OPERATIONS CALLED OUT TO RIG, JOB POSTPONED WHILE DECISION ON NEW PLAN FORWARD IS MADE. TRAVEL TO DEADHORSE TO OP-CHECK TOOLS 1/20/2024 RECOMPLETION Continue to work pipe with black magic, unsuccessful, call out e-line and rig up, introduce and hold 8K left torque into string, run string shot on E-line and fire @ 7339.1', POOH with e-line indication good fire, stand back e-line make up TD to stump introduce 9K LH torque and work down to BHA, count turns pick up good indication back off, pick up pipe moving @ 150K up wt 1/20/2024 SUPPORT OTHER OPERATIONS RU E-LINE W/ GREASE HEAD & PIS, RIH W/ 1-7/16" CHD (1" FN), 7' X 1-11/16" WEIGHT BAR, 1-11/16" CCL, BACK-OFF BAR (LOADED 8' W/ 3 STRANDS OF 80 GRAIN DET CORD), SHOOT BACK-OFF W/ CCL OFFSET=5.8', MID BACK- OFF=7345', CCL STOP DEPTH=7339.2', TOOLS OUT OF HOLE, STAND BY FOR RIG TO PULL ON PIPE, JOB CONTINUED TO NEXT DAY. 1/21/2024 SUPPORT OTHER OPERATIONS JOB CONTINUED FROM 20-JAN-2024, RIG ABLE TO WORK PIPE FREE. RD AFTER THEY PULL ONE JOINT OOH, LEAVE LOCATION. 1/21/2024 RECOMPLETION TOOH to shoe, circulate well clean, perform flow check, circulate B/U pump dry job, TOOH, bha recovered above jars, rig up and test BOPs 250/4000 witness waived AOGCC Kam StJohn, rig down test equipment install wear ring 1/22/2024 RECOMPLETION MU and RIH with fishing BHA #65, Hole real sticky. POOH. MU and RIH with clean out BHA #66.Stop at window and ensure mud properties good 1/23/2024 RECOMPLETION Attempted clean out to top of fish, made it to 6727' multiple stack outs and overpulls, phase 3 called, back ream to window and wait on weather, TOOH prep and start full bop test 250/4000 1/24/2024 RECOMPLETION Complete BOP ram seal replacment/repair. Continue testing BOPs, failure on top ram bonnet, remove and perform repairs 1/25/2024 RECOMPLETION Complete testing BOPE RIH with cement retainer to 6395' 1/26/2024 RECOMPLETION Suspend well with 47 BBL's cement. perform state witnessed tag and test. L/D drill pipe 1/27/2024 RECOMPLETION Continue laying down drill pipe from hole, RIH with 4.5" 12.6# Hyd 563 L-80 kill string to 2300' N/D BOP NU dry hole tree and adapter. 1 Conklin, Amy A From:Long, Sydney Sent:Tuesday, February 20, 2024 2:51 PM To:Conklin, Amy A Subject:Fw: [EXTERNAL]Re: 2M-24 KOP Plan Forward Thank you, Sydney Long Senior Rig Workover Engineer From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 8, 2023 11:02 AM To: Long, Sydney <Sydney.Long@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]Re: 2M-24 KOP Plan Forward 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. Sydney, Verbal approval is granted for the milling and potential change in kickoff point. This will require a change of approved program for the motherbore sundry. We will discuss location of a new kickoff point on Monday when milling results are known and discussed with the AOGCC. It is understood that a CBL , a CCL and a caliper will be run and results shared with the AOGCC. Victoria Sent from my iPhone On Dec 8, 2023, at 10:16BAM, Long, Sydney <Sydney.Long@conocophillips.com> wrote: Good morning, I would appreciate chatting with you about the current situation on 2M-24. This well is a sidetrack on 7ES. I would like to discuss our kickoff location and contingencies before we get into the weekend. The planned KOP for 2M-24 was 6550’ and the tubing was cut pre rig at 6565’. However, when we went to pull the tubing, we found ourselves unable to do so. We then went and cut the tubing at 6180’, which You don't often get email from sydney.long@conocophillips.com. Learn why this is important 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. 2 pulled successfully, and then ran a CBL as it was suspected that cement from the abandonments cement job was holding us on the outside of the tubing. We found that there was a significant amount of cement on the outside of the tubing with good bonding. We are currently in the process of attempting to gain access to the planned KOP. Our proposed plan forward is as follows: 1. Cut again at 6278’ (complete) 2. Attempt to fish tubing from 6180’ to 6278’ and break free from the poorer bonded cement (in progress) 3. Begin milling tubing and cement inside the 7” casing down to the planned KOP a. Contingency – Seeking your approval for If progress is unable to be made or we believe we are unable to proceed without causing damage to the well or adding significant risk to the project, stop milling and move KOP to the deepest depth achieved. 4. Run a CCL, CBL and Caliper of the 7” casing 5. Set whipstock and begin exit a. If the CBL shows good bonding on the outside of the 7” casing at the KOP, proceed per procedure b. If the CBL shows weak or poor bonding on the outside of the 7” casing at the KOP, mill out window and 20’ of new formation and perform FIT to 15 ppg before proceeding 6. Drill sidetrack per plan. Attached are the logs from the primary 7” cement job in 1992, the CBL of the cement on the outside of the 3-1/2” tubing, and the geologic interpretation from our geophysicist. Also attached is the APD. Thank you for your consideration of the above plan. I will be following up this email with a call. Thank you, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 <Shallower KOP Considerations 12-8-2023.pptx> <2M-24 Tubing CBL.pdf> <2M-24 CBL 7in Casing.TIF> <Permit_223-073_100423.pdf> 1 Conklin, Amy A From:Long, Sydney Sent:Tuesday, February 20, 2024 2:50 PM To:Conklin, Amy A Subject:Fw: [EXTERNAL]Re: 2M-24 Full Subsidence Plan Forward Thank you, Sydney Long Senior Rig Workover Engineer From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Sunday, December 10, 2023 1:21 PM To: Long, Sydney <Sydney.Long@conocophillips.com> SCcuebt: [EXTERNAL]Re: 2M-24 Full Subsidence Plan Forward 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. Sydney, Verbal approval is granted for the subsidence repair. Please submit a change of approved program sundry by the end of day tomorrow, Monday, December 11, 2023. Victoria Sent from my iPhone On Dec 10, 2023, at 12:57:PM, Long, Sydney <Sydney.Long@conocophillips.com> wrote: Victoria, I apologize but after further discussion with the team we would request that we test the break on the BOPE to the 3k allowed by the flange as soon as we are able to place a test plug in the stack. We would advise against exposing the full casing to the 3k test. Thank you very much for your time, Sydney You don't often get email from sydney.long@conocophillips.com. Learn why this is important 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. 2 Get Outlook for iOS From: Long, Sydney Sent: Sunday, December 10, 2023 11:59:51 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> jb: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> SCcuebt: 2M-24 Full Subsidence Plan Forward Good morning, I apologize for contacting you over the weekend. However, it has been discovered that the 7” casing on 2M-24 is compromised at approximately 270’ RKB. While still holding pressure, the casing is buckled and we have compromised drift. We will not be able to proceed with the sidetrack operations (including the recovery of the KOP we discussed on Friday) until the casing is repaired. Our current plan forward is below: 1. Perform CBL and caliper of 7” casing from Surface casing shoe up. - Complete 2. Set RBP at 2300’ and test as a barrier. Place sand on top of the RBP. – In Progress 3. Cut 7” casing at approximately 1785’ RKB and circulate. Close VBR rams or Annular as necessary while circulating 4. ND BOPE and ND tubing spool. NU BOPE to 11” 3k flange. Shell test to 3K (Note: Will not test above 3k due to flange rating. BOPE test pressure 4,000 psi) 5. Pull 7” casing and lay down 6. PU mills and bore our 9-5/8” as necessary to obtain drift for new 7” tieback. 7. Run new 7” 26# L80 Hyd563 casing and engage stub with overshot casing patch 8. Test casing to 2500 psi 9. Shift open cementing sleeve and cement the 7” x 9-5/8” annulus to surface 10. ND BOPE. Set slips and cut remaining casing. NU tubing spool and BOPE and shell test to 4k psi. 11. Cleanout casing and pull RBP 12. Return to previously discussed plan forward. Thank you very much. I will follow this email up with a call. Thank you, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7450'feet 6247'feet true vertical 6360' feet 7130' feet Effective Depth measured 6427'feet 6961'feet true vertical 5507' feet 5949' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 6990' MD 5973' TVD Packers and SSSV (type, measured and true vertical depth) 6961' MD N/A 5949' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 bbls (7.7 bbls in IA, 5.3 bbls above retainer) 15.8 ppg Class G Cement 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 323-447/ 323-659 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 6427-6925' MD Packer: Baker HB Retrvbl Packer SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Senior RWO/CTD Engineer 7070-7079', 7103-7112', 712-7137', 7156-7182' (cemented) 6040-6048', 6068-6075', 6084-6096', 6112-6134' (cemented) measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~~~ ~~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-050 50-103-20171-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025586 Kuparuk River Field/ Kuparuk River Oil Pool -Abandoned KRU 2M-24 Plugs Junk measured Length Production Liner 7397' Casing 6348'7436' 3104' 121'Conductor Surface Intermediate 16" 9-5/8" 79' 3146' 2792' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:47 am, Feb 29, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.27 10:27:24-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle DSR-3/4/24 RBDMS JSB 022924 Page 1/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2023 03:00 12/2/2023 06:00 3.00 MIRU, MOVE MOB P Prep rig for truck and transport down well row to 2M-24, TH and Roads and pads prepping around well 0.0 0.0 12/2/2023 06:00 12/2/2023 10:00 4.00 MIRU, MOVE MOB P Pad prep and move hardline for kill tanks. Gadre pad remove excess snow and level for rig. 0.0 0.0 12/2/2023 10:00 12/2/2023 14:00 4.00 MIRU, MOVE MOB P MIRU. Spot dance floor around well 24 spread pit liner and stage equipment in cellar area. Spot in pit module, Hook up interconnect, Berm in rig. Complete pre accept checklist. Hook up hardline to kill tanks. Open SSV on tree. 0.0 0.0 12/2/2023 14:00 12/2/2023 18:00 4.00 MIRU, MOVE RURD P Start loading pits with 8.5# seawater. Complete setting kill tanks and installing hardline to tanks. Spot in MWD cabin and hook up to generator power 0.0 0.0 12/2/2023 18:00 12/2/2023 19:00 1.00 MIRU, MOVE PRTS P Pressure test lines to tiger tank // line up for circulating well 0.0 0.0 12/2/2023 19:00 12/2/2023 22:45 3.75 MIRU, MOVE DISP P Displace well to 8.6 seawater // 22 spm @ 3900 psi down tubing no open gas lift circulating through weltec cut 0.0 0.0 12/2/2023 22:45 12/2/2023 23:15 0.50 MIRU, MOVE OWFF P OWFF 30 min no flow 0.0 0.0 12/2/2023 23:15 12/3/2023 00:00 0.75 MIRU, WELCTL MPSP P Install ISA BPV // Test 1000psi 10 min good test 0.0 0.0 12/3/2023 00:00 12/3/2023 01:00 1.00 MIRU, WELCTL RURD P D/D lines and 2nd Kill line. R/D circulating eq. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 01:00 12/3/2023 03:00 2.00 MIRU, WHDBOP RURD P Bleed adapter void N/D tree and adpater and hang in cellar. Clean and inspect hanger theads, function test X-O in hanger threads 9 rotations. install external blanking plug Simultaneously Change out saver sub ion TD to XT-39. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 03:00 12/3/2023 06:00 3.00 MIRU, WHDBOP NUND P NU DSA and BOPS torque all connections to BOP's install riser in BOP stack. Install Baker MWD tee sensor and line on goose neck. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 06:00 12/3/2023 08:00 2.00 MIRU, WHDBOP RURD P RU to test BOP's MU XO's to test joints. flood stack with fresh water perform shell test. Load pipe shed W/260 joints of XT-39 0.0 0.0 12/3/2023 08:00 12/3/2023 09:00 1.00 MIRU, WHDBOP BOPE P Test BR, CMV1,2,3,456 and 16. HCR kill,Rig floor kill, outer and inner test spool 2" valve IBOP, manual IBOP 0.0 0.0 12/3/2023 09:00 12/3/2023 11:30 2.50 MIRU, WHDBOP RURD P LDS on TBG head started leaking attempted to tighten LDS. Unable to stop leakage. Called out FMC to remove LDS chase threads and replace LDS. Continue loading 260 joints DP in the shed. RIG up coms to MWD shack. Continue R/U MWD. Moved test plug and wear ring to rig floor. Load floor with X-O's 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 2/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2023 11:30 12/3/2023 18:30 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint to 3500psi , UVBR's, LVBR's w/3-1/2" and 4 " test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1550 PSI, 200 PSI attained =20 sec, full recovery attained = 108 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Austin McLeod. 0.0 0.0 12/3/2023 18:30 12/3/2023 19:30 1.00 SLOT, RPCOMP PRTS P Pressure test stand pipe MWD connection, re-tighten fittings test again 3700 psi 0.0 0.0 12/3/2023 19:30 12/3/2023 21:00 1.50 SLOT, RPCOMP MPSP P Pull blanking plug, pick up t-bar and pull ISA BPV 0.0 0.0 12/3/2023 21:00 12/3/2023 22:00 1.00 SLOT, RPCOMP THGR T Attempt to pull completion @ 135K 6 times no movement on completion // Discuss with town engineer, pull to 160K 6 times no movement on hanger 0.0 0.0 12/3/2023 22:00 12/4/2023 00:00 2.00 SLOT, RPCOMP CIRC P Circulate S x S // 2.8 bbls per min @ 2700 psi // Hold up wt attempt to free pipe // Mobilize SL and EL 6,565.0 6,565.0 12/4/2023 00:00 12/4/2023 00:30 0.50 SLOT, RPCOMP PULL T Pull on pipe up to 160K 6 times no movement 6,565.0 6,565.0 12/4/2023 00:30 12/4/2023 02:00 1.50 SLOT, RPCOMP CIRC T Continue to circulate while holding 150K up // wait for slick line 01:45 - Attempt to pull free up to 160K no movement 6,565.0 6,565.0 12/4/2023 02:00 12/4/2023 04:00 2.00 SLOT, RPCOMP SLKL T SL on location @ 14:00 // Spot truck have PJSM // Land hanger in profile // Rig up slick line 6,565.0 6,565.0 12/4/2023 04:00 12/4/2023 07:45 3.75 SLOT, RPCOMP SLKL T 04:00 SL run in hole to pull hold open sleeve from SSSV 04:25 SL out of hole hold open sleeve pulled from SSSV Ran New 2.29" ID hold open sleeve set in SSSV at 1805' RD Slick line 6,565.0 6,565.0 12/4/2023 07:45 12/4/2023 09:00 1.25 SLOT, RPCOMP WAIT T Wait on engineering to make decision on plan forward. Spot in E-line unit while waiting on town for decision. RU E-Line 6,565.0 6,565.0 12/4/2023 09:00 12/4/2023 12:30 3.50 SLOT, RPCOMP ELNE T RIH with 2" RCT correct back to mandrel at 6094' RIH set RCT EMA cutter at 6180' cut tubing. POOH W/Eline and stand back. 6,108.0 6,108.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 3/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/4/2023 12:30 12/4/2023 13:00 0.50 SLOT, RPCOMP PULL T LD Safety valve and X-O to landing joint. MU X-O 3.5" EUE x XT-39 to topdrive PU WT=110K, weight broke back to 85K. Pulled hanger to floor. 6,108.0 6,083.0 12/4/2023 13:00 12/4/2023 14:45 1.75 SLOT, RPCOMP CIRC T Circulate SxS F/6183' @ 51 SPM 244 PSI Complete R/D E-Line. 6,083.0 6,083.0 12/4/2023 14:45 12/4/2023 15:15 0.50 SLOT, RPCOMP OWFF T OWFF while L/D tubing hanger. Blow down top drive 6,083.0 6,083.0 12/4/2023 15:15 12/4/2023 17:00 1.75 SLOT, RPCOMP PULL T L/D 33 joints fill hole every 15. Band control line anbd tape back to tubing. 6,083.0 5,060.0 12/4/2023 17:00 12/4/2023 22:30 5.50 SLOT, RPCOMP CIRC T Well out of balance, kelly up and circulate the well SxS. Pump sweep as lots of cement coming out of hole 5,060.0 5,060.0 12/4/2023 22:30 12/4/2023 23:30 1.00 SLOT, RPCOMP PUTB T Blow down TD, RIH w/ 6-1/8" string mill to drift casing // Unable to pass string mill through 7" well head // Pick up XT- 39 drill pipe ( Hard band 5.25" ) Unable to pass hard band through well head // lay down drillpipe and mills 5,060.0 5,060.0 12/4/2023 23:30 12/5/2023 00:00 0.50 SLOT, RPCOMP PULL P Lay down 3.5" tubing 5,060.0 4,800.0 12/5/2023 00:00 12/5/2023 01:30 1.50 SLOT, RPCOMP PULL P Lay down 3.5" completion // SSSV tag WH as expected remove control line from well 4,800.0 4,400.0 12/5/2023 01:30 12/5/2023 02:30 1.00 SLOT, RPCOMP CLEN P Clean up floor for running in hole with GS on completion to drop off // rig down spooler and set outside 4,400.0 4,400.0 12/5/2023 02:30 12/5/2023 03:00 0.50 SLOT, RPCOMP BHAH P Pick up 4" GS BHA 4,400.0 4,400.0 12/5/2023 03:00 12/5/2023 05:30 2.50 SLOT, RPCOMP PUTB P Run completion down to stump picking up singles of 3.5" completion tubing // Tag stump // Obtain Pu Wt 80K 4,400.0 6,180.0 12/5/2023 05:30 12/5/2023 06:00 0.50 SLOT, RPCOMP OTHR P Set tubing on stump // Pump 3 bpm 2300 psi // Pu 40K pipe released on stump 6,180.0 2,000.0 12/5/2023 06:00 12/5/2023 07:30 1.50 SLOT, RPCOMP TRIP P TOOH for IBP racking stands in derrick 2,000.0 0.0 12/5/2023 07:30 12/5/2023 09:30 2.00 SLOT, RPCOMP MPSP P Set IBP // COE 100' // Pressure up in stages per baker rep // trouble setting packer // consult baker IBP rep continue with set // indications of good set 0.0 100.0 12/5/2023 09:30 12/5/2023 10:00 0.50 SLOT, RPCOMP PRTS P Pressure test IBP 1000psi 100.0 0.0 12/5/2023 10:00 12/5/2023 11:00 1.00 SLOT, RPCOMP NUND P Nipple down BOPs for grow and stretch 0.0 0.0 12/5/2023 11:00 12/5/2023 15:00 4.00 SLOT, RPCOMP OTHR P Rig up and grow casing // 29.5" of growth before stretch 0.0 0.0 12/5/2023 15:00 12/5/2023 16:00 1.00 SLOT, RPCOMP OTHR P Remove casing head // casing bottlenecked // cut off bottle neck for spear // 421K pushing up on casing head 0.0 0.0 12/5/2023 16:00 12/5/2023 17:00 1.00 SLOT, RPCOMP OTHR P Pick up casing spear w/ packoff, RH release grapple, spear casing, pull 169K, additional growth=16" 45.5" total growth Dress casing w/FMC 0.0 0.0 12/5/2023 17:00 12/5/2023 19:15 2.25 SLOT, RPCOMP NUND P N/U Casing Spool and torque up to spec w/sweeney wrench. 0.0 0.0 12/5/2023 19:15 12/5/2023 19:45 0.50 SLOT, RPCOMP NUND P P/T Pack-off void to 3,000 psi and hold for 15 mins 0.0 0.0 12/5/2023 19:45 12/5/2023 21:45 2.00 SLOT, RPCOMP NUND P N/U BOPE, flood surface lines and stack. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 4/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/5/2023 21:45 12/5/2023 23:15 1.50 SLOT, RPCOMP BOPE P R/U, Test BOPE break 250/4,000 psi 0.0 0.0 12/5/2023 23:15 12/5/2023 23:30 0.25 SLOT, RPCOMP OTHR P Pull Test plug, install wear ring 0.0 0.0 12/5/2023 23:30 12/6/2023 00:00 0.50 SLOT, RPCOMP TRIP P TIH on singles 3.5" Tubing w/Baker pulling tool 0.0 100.0 12/6/2023 00:00 12/6/2023 00:15 0.25 SLOT, RPCOMP OTHR P Pull and L/D IBP 0.0 0.0 12/6/2023 00:15 12/6/2023 00:30 0.25 SLOT, RPCOMP BHAH P M/U 4" GS, BHA Length - 4.72' 0.0 6.2 12/6/2023 00:30 12/6/2023 02:00 1.50 SLOT, RPCOMP TRIP P TIH on 3.5" tubing // Latch into tubing pu wt 80K 6.2 1,790.0 12/6/2023 02:00 12/6/2023 09:30 7.50 SLOT, RPCOMP PULL P PU wt 80K // Lay down 3.5" completion // Cut jt 18.8' long // Total full jts laid down 196 *** Note: Recover 23.5 stainless bands from well 6,180.0 0.0 12/6/2023 09:30 12/6/2023 10:00 0.50 SLOT, RPCOMP CLEN P Clean up floor prep for picking up overshot BHA, 0.0 0.0 12/6/2023 10:00 12/6/2023 11:00 1.00 SLOT, RPCOMP BHAH P Bait overshot , pick up BHA 0.0 150.0 12/6/2023 11:00 12/6/2023 17:00 6.00 SLOT, RPCOMP PUTB P RIH picking up drill pipe 150.0 6,100.0 12/6/2023 17:00 12/6/2023 18:30 1.50 SLOT, RPCOMP CIRC P Circulate S x S 6,100.0 6,100.0 12/6/2023 18:30 12/6/2023 19:30 1.00 SLOT, RPCOMP CIRC P Dump 35 bbl overboard (dirty returns) Mix high vis pill Tag TOF @ 6157.86', PUH 6,153', SOW=95, PUW=130, continue to circulate SxS with pill @ 6 bpm/103 stks/min 6,100.0 6,157.1 12/6/2023 19:30 12/6/2023 20:15 0.75 SLOT, RPCOMP CIRC P Circulate SxS with pill @ 6 bpm/103 stks/min 6,157.1 6,153.0 12/6/2023 20:15 12/6/2023 22:30 2.25 SLOT, RPCOMP FISH P RIH pumping 3.0 bpm @ 320 psi, rotate over 4' of fish Jar 56 hits @ 200 k, straight pull 245 k, pull 95% to 265 k no movement Phone town team, rotate off fish, PUW=130 k PUH 6,120' 6,153.0 6,120.0 12/6/2023 22:30 12/6/2023 23:00 0.50 SLOT, RPCOMP SVRG P Perform Derrick inspection 6,120.0 6,120.0 12/6/2023 23:00 12/7/2023 00:00 1.00 SLOT, RPCOMP TRIP P TOOH F/6,120' T/2,780' 6,120.0 2,780.0 12/7/2023 00:00 12/7/2023 01:00 1.00 SLOT, RPCOMP TRIP P Continue TOOH w/DP F/2,780' 2,780.0 134.2 12/7/2023 01:00 12/7/2023 01:30 0.50 SLOT, RPCOMP BHAH P L/D fishing assembly, inspect overshot 134.2 0.0 12/7/2023 01:30 12/7/2023 02:00 0.50 SLOT, RPCOMP SVRG P Service Rig 0.0 0.0 12/7/2023 02:00 12/7/2023 02:30 0.50 SLOT, RPCOMP BHAH P M/U 5-3/4" over shot (loaded) *** Note: Min ID 2.5" confirmed 0.0 730.0 12/7/2023 02:30 12/7/2023 06:30 4.00 SLOT, RPCOMP TRIP P TIH above fish 730.0 6,031.0 12/7/2023 06:30 12/7/2023 13:30 7.00 SLOT, RPCOMP CIRC P Circulate well while waiting for E-line // 4 bpm @ 350 psi // 6,031.0 6,031.0 12/7/2023 13:30 12/7/2023 16:00 2.50 SLOT, RPCOMP ELNE P Rig up e-line 6,031.0 6,160.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 5/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/7/2023 16:00 12/7/2023 22:00 6.00 SLOT, RPCOMP ELNE P RIH w/eline run CBL down to 6,508', pull heavy, freely moving up hole, down load and corrilate logs, confer with town team plan forward, POOH with E-line 6,160.0 6,160.0 12/7/2023 22:00 12/7/2023 23:00 1.00 SLOT, RPCOMP ELNE P L/D CBL, M/U RTC Cutter. 6,160.0 6,160.0 12/7/2023 23:00 12/8/2023 00:00 1.00 SLOT, RPCOMP ELNE P RIH w\RTC cutter 6,160.0 6,160.0 12/8/2023 00:00 12/8/2023 01:45 1.75 SLOT, RPCOMP ELNE P E-line - CCL, perform cut @ 6,278', POOH w/e-lin, R/D AK-E-line 6,160.0 6,160.0 12/8/2023 01:45 12/8/2023 03:00 1.25 SLOT, RPCOMP FISH P PUW 127 k, SOW=95 k, Pull on fish, working up to 100% of tensile 275 k, pressure up to 3,200 psi, no movement, confer with town team, blow down top drive, kelley up, rotate off fish 6,160.0 6,160.0 12/8/2023 03:00 12/8/2023 05:30 2.50 SLOT, RPCOMP TRIP P TOOH, w/overshot 6,160.0 0.0 12/8/2023 05:30 12/8/2023 06:00 0.50 SLOT, RPCOMP BHAH P L/D BHA #6, M/U fishing assembly 0.0 134.0 12/8/2023 06:00 12/8/2023 08:00 2.00 SLOT, RPCOMP TRIP P TIH F/surface T/6163' 7ES RKB 134.0 6,163.0 12/8/2023 08:00 12/8/2023 10:00 2.00 SLOT, RPCOMP JAR P PUW=134K SOW=98K Hit 55 Jar hit working up to 225K before jar hit 270K after hit. 6,163.0 6,136.0 12/8/2023 10:00 12/8/2023 11:00 1.00 SLOT, RPCOMP SFTY P Inspect derrrick post jarring activities. No deficiencies were found. 6,163.0 6,163.0 12/8/2023 11:00 12/8/2023 11:30 0.50 SLOT, RPCOMP JAR P Continue jarring 225K pre jar hit work up to 270K after jar hit. 6,163.0 6,163.0 12/8/2023 11:30 12/8/2023 12:00 0.50 SLOT, RPCOMP SVRG P Pre job safety meeting with new day crew. Replace black jack on top drive. 6,163.0 6,163.0 12/8/2023 12:00 12/8/2023 12:30 0.50 SLOT, RPCOMP SVRG P Replace black jack on top drive. 6,163.0 6,163.0 12/8/2023 12:30 12/8/2023 15:45 3.25 SLOT, RPCOMP JAR P Continue jarring 225K pre jar hit work up to 270K after jar hit. Jarred on fish a total of 240 hits up and 40 down. Unable to see any movement. Release overshot from tubing stump. PUW=130K 6,163.0 6,163.0 12/8/2023 15:45 12/8/2023 16:45 1.00 SLOT, RPCOMP SFTY P Perform derrick inspection while circulating. Circulate at 3BPM 300 PSI. 6,163.0 6,163.0 12/8/2023 16:45 12/8/2023 20:00 3.25 SLOT, RPCOMP TRIP P TOOH 6,163.0 134.7 12/8/2023 20:00 12/8/2023 20:30 0.50 SLOT, RPCOMP BHAH P L/D fishing assembly BHA #8 134.7 0.0 12/8/2023 20:30 12/8/2023 21:00 0.50 SLOT, RPCOMP SVRG P Rig Service/adjust break bands 0.0 0.0 12/8/2023 21:00 12/8/2023 21:15 0.25 SLOT, RPCOMP SFTY P Crew change/PJSM, with fresh crew, 0.0 0.0 12/8/2023 21:15 12/9/2023 00:00 2.75 SLOT, RPCOMP BHAH P M/U milling assembly w/wavy bottom burn shoe 5-3/4", unable to pass through 255' 0.0 255.0 12/9/2023 00:00 12/9/2023 01:00 1.00 SLOT, RPCOMP TRIP T Work wash pipe, unable to pass 255', stand back and L/D BHA #8 255.0 0.0 12/9/2023 01:00 12/9/2023 01:30 0.50 SLOT, RPCOMP BHAH T P/U drift BHA #9 w/5.95" swedge 0.0 134.0 12/9/2023 01:30 12/9/2023 03:00 1.50 SLOT, RPCOMP TRIP T TIH on stands T/1,555' 134.0 1,555.0 12/9/2023 03:00 12/9/2023 04:30 1.50 SLOT, RPCOMP TRIP T TOOH F/1555' T/Surface 1,555.0 134.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 6/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/9/2023 04:30 12/9/2023 06:00 1.50 SLOT, RPCOMP BHAH T Swap out swedge to 6.10" 134.0 134.0 12/9/2023 06:00 12/9/2023 08:00 2.00 SLOT, RPCOMP TRIP T TIH on stands F/Surface T/1,555' 134.0 1,555.0 12/9/2023 08:00 12/9/2023 09:00 1.00 SLOT, RPCOMP TRIP T TOOH F/1555 T/137' Work swedge F/295.74' T/247.56' 1,555.0 134.0 12/9/2023 09:00 12/9/2023 09:30 0.50 SLOT, RPCOMP BHAH T LD swedge/mill drift BHA. 134.0 0.0 12/9/2023 09:30 12/9/2023 10:00 0.50 SLOT, RPCOMP SVRG T C/O Spinner on iron rough neck 0.0 0.0 12/9/2023 10:00 12/9/2023 16:30 6.50 SLOT, RPCOMP ELNE T RU E-line RIH W. 2.75" CBL 3 Centralizers GR CCL. F/surface T/Top of tubing stump 6,175' M/U 40 arm caliper, RIH, Log Caliper F/6,175' T/350' 0.0 0.0 12/9/2023 16:30 12/9/2023 21:00 4.50 SLOT, RPCOMP ELNE T Caliper failure, POOH, trouble shoot tools, M/U 40 arm caliper on memory 0.0 0.0 12/9/2023 21:00 12/10/2023 00:00 3.00 SLOT, RPCOMP ELNE T Trouble shoot tools, M/U 40 arm caliper on memory 0.0 0.0 12/10/2023 00:00 12/10/2023 01:00 1.00 SLOT, RPCOMP ELNE T RIH w/ 40 arm caliper on memory, log F/350' T/surface. R/D E-line, 0.0 0.0 12/10/2023 01:00 12/10/2023 02:00 1.00 SLOT, RPCOMP BHAH T M/U RBP 0.0 52.7 12/10/2023 02:00 12/10/2023 03:30 1.50 SLOT, RPCOMP TRIP T TIH, PUW=64k, SOW=58k, Set G- lock/RBP 5.968" S/N 13728217, COE @ 2,350' 52.7 2,350.0 12/10/2023 03:30 12/10/2023 04:00 0.50 SLOT, RPCOMP PRTS T Line up, P/T RBP T/2,500 psi 2,350.0 2,350.0 12/10/2023 04:00 12/10/2023 05:30 1.50 SLOT, RPCOMP OTHR T TOOH, L/D setting tools 2,350.0 0.0 12/10/2023 05:30 12/10/2023 07:30 2.00 SLOT, RPCOMP NUND T N/D BOPE 0.0 0.0 12/10/2023 07:30 12/10/2023 09:30 2.00 SLOT, RPCOMP NUND T Bleed of casing pack off void. Remove tubing head. remove pack off. Spear casing and pull 215K total blocks=30K 185K set on slips. 0.0 0.0 12/10/2023 09:30 12/10/2023 11:30 2.00 SLOT, RPCOMP BHAH T MU 120' of wash pipe andRIH to 253' set down 5K unable to get any deeper. TOOH 0.0 253.0 12/10/2023 11:30 12/10/2023 12:00 0.50 SLOT, RPCOMP SVRG T Service draw works and iron rough neck 0.0 0.0 12/10/2023 12:00 12/10/2023 16:30 4.50 SLOT, RPCOMP NUND T NU DSA to casing head and BOP stack tighten choke hose. Install riser. Fill stack with fresh water. 0.0 0.0 12/10/2023 16:30 12/10/2023 18:00 1.50 SLOT, RPCOMP TRIP T MU bull nose to bottom of stand 1 and TIH F/surface to 2250' 0.0 2,250.0 12/10/2023 18:00 12/11/2023 00:00 6.00 SLOT, RPCOMP OTHR T Dump 26 60# sacks and let fall 2,250.0 2,250.0 12/11/2023 00:00 12/11/2023 01:15 1.25 SLOT, RPCOMP OTHR T Continue dumping sand w/K-bar 1000 2,250.0 2,250.0 12/11/2023 01:15 12/11/2023 02:30 1.25 SLOT, RPCOMP NUND T Let sand fall 2,250.0 2,250.0 12/11/2023 02:30 12/11/2023 02:45 0.25 SLOT, RPCOMP TRIP T TIH, tag top of sand @ 2,286', 65' of sand on top of plug 2,250.0 2,286.0 12/11/2023 02:45 12/11/2023 03:30 0.75 SLOT, RPCOMP TRIP T TOOH & L/D bull nose 2,286.0 0.0 12/11/2023 03:30 12/11/2023 04:30 1.00 SLOT, RPCOMP BHAH T M/U Baker MSC 0.0 565.0 12/11/2023 04:30 12/11/2023 06:00 1.50 SLOT, RPCOMP TRIP T TIH, w/DP & MSC locate collar and space out for cutting casing. 565.0 1,786.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 7/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/11/2023 06:00 12/11/2023 07:00 1.00 SLOT, RPCOMP CUTP T Space out for cut. M/U T. Cut 7" csg W/MSC. at 1765' RPM-65 RPM 1.3K Tq off 1.8 Tq. on 5 BPM=850 PSI. Set down 5K Cut through casg saw weight drop off. shut down pump and Slack off through cut. PU to rig floor shut in LPR B/D top drive 1,786.0 1,786.0 12/11/2023 07:00 12/11/2023 07:30 0.50 SLOT, RPCOMP CIRC T R/U to Circ. opn the floor and in the cellar. 1,786.0 1,786.0 12/11/2023 07:30 12/11/2023 08:00 0.50 SLOT, RPCOMP SFTY T Hold PJSM W/CPAI, Nabors, LRS, MI, and ASRC for pumping operations. 1,786.0 1,786.0 12/11/2023 08:00 12/11/2023 09:00 1.00 SLOT, RPCOMP RURD T R/U LRS and Pressure test LRS lines to rig and cement lines to rig floor to 2500 PSI. 1,786.0 1,786.0 12/11/2023 09:00 12/11/2023 09:30 0.50 SLOT, RPCOMP CIRC T Begin displacing OA with diesel down the DP up the OA T/open top tank 1.5 BBL/MIN 250 PSI 15 BBL's away LRS blew hose inside unit. Shut in DP &OA B/D lines T/open top. 1,786.0 1,786.0 12/11/2023 09:30 12/11/2023 10:00 0.50 SLOT, RPCOMP SVRG T Change dies in iron rough neck. 1,786.0 1,786.0 12/11/2023 10:00 12/11/2023 12:00 2.00 SLOT, RPCOMP WAIT T Mechanical failure in pump truck that was dispatched wainting on second truck. perform general housekeeping on rig. 1,786.0 1,786.0 12/11/2023 12:00 12/11/2023 14:00 2.00 SLOT, RPCOMP CIRC T LRS on location Prejob walkdown and safety meeting with LRS. R/U and PT lines to 2500 PSI. Start displacing OA W/140* diesel 1.2 BPM=250 PSI. 52 BBL's pumped, diesel at surface. Swap to hot seawater 1.2BPM 140* 1,786.0 1,786.0 12/11/2023 14:00 12/11/2023 15:00 1.00 SLOT, RPCOMP RURD T Blow down R/D LRS Blow down cement line and kill tnak line. 1,786.0 1,786.0 12/11/2023 15:00 12/11/2023 15:30 0.50 SLOT, RPCOMP OWFF T OWFF for 30 minutes. 1,786.0 1,786.0 12/11/2023 15:30 12/11/2023 16:30 1.00 SLOT, RPCOMP TRIP T TOOH 1,786.0 1,786.0 12/11/2023 16:30 12/11/2023 17:00 0.50 SLOT, RPCOMP BHAH T L/D BHA. 1,786.0 1,786.0 12/11/2023 17:00 12/11/2023 18:00 1.00 SLOT, RPCOMP BHAH T M/U Spear BHA. MU Head pin T/single joint RIH spear 7" casing, pull T45K M/U cement hose and valves T/head pin. R/U tiger tank line. 1,786.0 1,786.0 12/11/2023 18:00 12/11/2023 18:30 0.50 SLOT, RPCOMP SFTY T Hold PJSM with all parties involved. CPAI, LRS, Nabors. 1,786.0 1,786.0 12/11/2023 18:30 12/11/2023 21:00 2.50 SLOT, RPCOMP CIRC T LRS PT lines to 2500 PSI. Open well to LRS. Attempt to circulate down 7" casing up the OA. stage up to 1200 PSI no circulation. Work pipe PU WT= 215K. Stage up to 2000 PSI established circulation. Close rams and attempt to circulate work pressure up to 2000 PSI. Continue to maintain 2000 PSI. Slowly moving fluid to kill tank. Pressure locked at 2200 PSI. Pressured up and relieved the pressure cycling back and forth attempting to regain circulation. unable to make any progress. Held 2000 PSI on casing for 15 minutes no change. Bled off casing. discussed options with town engineer. Decision point to pull slips out of wellhead. 1,786.0 1,786.0 12/11/2023 21:00 12/11/2023 21:15 0.25 SLOT, RPCOMP SFTY T PJSM to N/D BOP stack and remove casing, slips hazards and mitigations discussed. 1,786.0 1,786.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 8/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/11/2023 21:15 12/11/2023 21:30 0.25 SLOT, RPCOMP OWFF T OWFF for 15 minutes. No Flow. 1,786.0 1,786.0 12/11/2023 21:30 12/12/2023 00:00 2.50 SLOT, RPCOMP NUND T N/D BOP stack. pick up stack, remove 7" casing slips 1,786.0 1,786.0 12/12/2023 00:00 12/12/2023 01:30 1.50 SLOT, RPCOMP RURD T N/U BOPE 1,786.0 1,786.0 12/12/2023 01:30 12/12/2023 03:30 2.00 SLOT, RPCOMP CIRC T Work pipe up to 300k, attempt to break circulation up to 1,500 psi, brake circulation, bring pressure up to 2,000 psi, getting minor returns, bleed pressure off, work pipe up to 300k, bring pressure back up to 1,500 psi, increase pressure 2,000 psi, holding like a rock, bleed pressure to zero, work pipe, park @ 125k, bring pump up to 1,000 psi, montior pressure, bring pressure up to 2,000 psi, pressure holding, monitor, bleed pressure off, blow down tiger tank line. Confer with town engineer plan forward. Secure LRS 1,786.0 1,786.0 12/12/2023 03:30 12/12/2023 05:30 2.00 SLOT, RPCOMP NUND T PJSM to N/D BOP stack and re-install casing slips, slips hazards and mitigations discussed. Release spear, set casing in slips with 185k tention 1,786.0 0.0 12/12/2023 05:30 12/12/2023 07:30 2.00 SLOT, RPCOMP NUND T N/U BOPE 0.0 0.0 12/12/2023 07:30 12/12/2023 08:00 0.50 SLOT, RPCOMP BHAH T M/U Drift assembly w/6.10" swedge 0.0 42.2 12/12/2023 08:00 12/12/2023 08:36 0.60 SLOT, RPCOMP TRIP T TIH w/drift BHA F/surface T/800' 42.2 800.0 12/12/2023 08:36 12/12/2023 09:21 0.75 SLOT, RPCOMP TRIP T TOOH, 800.0 0.0 12/12/2023 09:21 12/12/2023 10:06 0.75 SLOT, RPCOMP BHAH T M/U Baker TTS-3 packer, TIH 0.0 428.0 12/12/2023 10:06 12/12/2023 10:36 0.50 SLOT, RPCOMP RURD T R/U cement hose, pump in sub, and head pin crossover. 428.0 428.0 12/12/2023 10:36 12/12/2023 11:36 1.00 SLOT, RPCOMP RURD T R/U E-line grease head, and sheaves 428.0 428.0 12/12/2023 11:36 12/12/2023 12:06 0.50 SLOT, RPCOMP SVRG P Service rig 428.0 12/12/2023 12:06 12/12/2023 13:06 1.00 SLOT, RPCOMP WAIT T Standby for guns to be delivered from Deadhorse. 428.0 428.0 12/12/2023 13:06 12/12/2023 14:06 1.00 SLOT, RPCOMP ELNE T E-line - M/U guns 428.0 428.0 12/12/2023 14:06 12/12/2023 15:21 1.25 SLOT, RPCOMP ELNE T E-line - RIH w/casing punch 3' 6 shots per foot, large charges Top Shot 580' - 583'. Tools free, POOH L/D Tools, R/D E-line 428.0 428.0 12/12/2023 15:21 12/12/2023 15:51 0.50 SLOT, RPCOMP TRIP T TIH, 2 stands Set TSS-3 Test packer, COE @ 705' 428.0 705.0 12/12/2023 15:51 12/12/2023 16:36 0.75 SLOT, RPCOMP CIRC T PJSM w/rig team, Line up LRS, pressure up 0.2 bbls away, hold 2,000 psi for 15 mins, bleed pressure. 705.0 705.0 12/12/2023 16:36 12/12/2023 16:51 0.25 SLOT, RPCOMP RURD T R/D cement hose and pump in sub. 705.0 705.0 12/12/2023 16:51 12/12/2023 17:06 0.25 SLOT, RPCOMP OTHR T Release packer 705.0 705.0 12/12/2023 17:06 12/12/2023 17:36 0.50 SLOT, RPCOMP ELNE T R/U E-line 705.0 705.0 12/12/2023 17:36 12/12/2023 19:00 1.40 SLOT, RPCOMP ELNE T RIH with tubing punch and punch casing at 830'. POOH and RD E-line. 705.0 705.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 9/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/12/2023 19:00 12/12/2023 19:30 0.50 SLOT, RPCOMP CIRC T RIH and set test packer at 893'. 705.0 893.0 12/12/2023 19:30 12/12/2023 23:00 3.50 SLOT, RPCOMP CIRC T RU pump in sub and LRS PT lines to 2500 psi.LRS stage pumps 500 psi to 2000 psi trying to establish circulation to circ out arctic pack. Failed to get any kind of circulation. 893.0 893.0 12/12/2023 23:00 12/13/2023 00:00 1.00 SLOT, RPCOMP RURD T RD LRS, blow down all lines, clear rig floor, prep to POOH. Release test packer and let well stabilize. 893.0 0.0 12/13/2023 00:00 12/13/2023 03:00 3.00 SLOT, RPCOMP CUTP T MU and RIH with MSC to 420 ' and cut 7" casing. 0.0 420.0 12/13/2023 03:00 12/13/2023 06:00 3.00 SLOT, RPCOMP CIRC T Line up LRS, bring on line 3 bpm/400 psi, continue circulating through cut @ 420', shut down pump, swap to seawater, bring pump online 3 bpm/400 psi for 45 bbls, returns cleaned up, shut down pump, blow down tiger tank line 420.0 420.0 12/13/2023 06:00 12/13/2023 08:00 2.00 SLOT, RPCOMP CIRC T Release packer, seems Arctic Pak is swapping out. let u-tube, circulate 20 bbls down the DP up the 7"xDP annulus. OWFF. looks good. 420.0 420.0 12/13/2023 08:00 12/13/2023 08:30 0.50 SLOT, RPCOMP TRIP T TOOH w/DP stands, L/D Baker Test Packer 420.0 0.0 12/13/2023 08:30 12/13/2023 09:30 1.00 SLOT, RPCOMP OTHR T Flush stack and surface lines through the HCR, shut down, suck out stack, open OA and monitor well in cellar. 0.0 0.0 12/13/2023 09:30 12/13/2023 10:30 1.00 SLOT, RPCOMP NUND T N/D BOPE, lift stack off well head, slide stack back and place on stump. 0.0 0.0 12/13/2023 10:30 12/13/2023 12:00 1.50 SLOT, RPCOMP OTHR T M/U Baker Spear on joint of DP, stab casing, PU to unset and remove pac-off and casing slips, Set back down, setting high, push down with Top Drive. 0.0 0.0 12/13/2023 12:00 12/13/2023 12:30 0.50 SLOT, RPCOMP SVRG P Service Rig/Top Drive/Drawworks/Mud pumps 0.0 0.0 12/13/2023 12:30 12/13/2023 13:00 0.50 SLOT, RPCOMP SVRG P Service HCR valves and choke manifold. 0.0 0.0 12/13/2023 13:00 12/13/2023 16:30 3.50 SLOT, RPCOMP NUND T Pull stack off of stump and spot over well head flange, swap out rams to 7" fixed. 0.0 0.0 12/13/2023 16:30 12/13/2023 17:00 0.50 SLOT, RPCOMP PULL T Bring up GBR tongs and rig up on rig floor. 0.0 0.0 12/13/2023 17:00 12/13/2023 19:30 2.50 SLOT, RPCOMP PULL T P/U, spear 7" casing, pull and lay down to pipe shed. UPWT 45K. 0.0 0.0 12/13/2023 19:30 12/13/2023 21:00 1.50 SLOT, RPCOMP CLEN T Clean and clear rig floor. Set test plug and PU 7" test joint. 0.0 0.0 12/13/2023 21:00 12/13/2023 22:30 1.50 SLOT, RPCOMP BOPE T Test HCR chokeand 7" rams 250 low and 4000 high and chart. 0.0 0.0 12/13/2023 22:30 12/13/2023 23:00 0.50 SLOT, RPCOMP RURD T RD all test equipment and pull test plug. 0.0 0.0 12/13/2023 23:00 12/14/2023 00:00 1.00 SLOT, RPCOMP BHAH T MU BHA #22 spear and RIH. 0.0 428.0 12/14/2023 00:00 12/14/2023 03:00 3.00 SLOT, RPCOMP JAR T RIH w/BHA #22 and spear 7" casing at 428'. Jar on 7" casing 47 jar hits w/no movement. break circulation 6 bpm/230 psi, Release spear and POOH. LD BHA #22. 428.0 0.0 12/14/2023 03:00 12/14/2023 04:00 1.00 SLOT, RPCOMP BHAH T M/U Baker MSC BHA #23, TIH, F/surface T/859', locate collars, make cut @ 925', 5 bpm/640 psi, shut down pump and monitor well, static, B/D top drive and blow down, 0.0 859.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 10/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/14/2023 04:00 12/14/2023 05:30 1.50 SLOT, RPCOMP TRIP T TOOH, F/925' T/surface, L/D cutter BHA #23 859.0 0.0 12/14/2023 05:30 12/14/2023 06:30 1.00 SLOT, RPCOMP BHAH T M/U BHA #24 w/spear 0.0 0.0 12/14/2023 06:30 12/14/2023 08:00 1.50 SLOT, RPCOMP TRIP T TIH F/surface T/420', sting into fish, pull free PUW=50k 0.0 769.0 12/14/2023 08:00 12/14/2023 10:30 2.50 SLOT, RPCOMP CIRC T park @ 769', PJSM w/LRS and rig crew, bring pump on line @ 1.0 bpm at 90° temp, circulate until returns are clean, switch to SW 170° @ 1 bpm. 769.0 769.0 12/14/2023 10:30 12/14/2023 11:00 0.50 SLOT, RPCOMP TRIP T Shut down pumping, R/D head pin and equipment off of RF. Blow down surface lines and secure tiger tank line 769.0 769.0 12/14/2023 11:00 12/14/2023 12:30 1.50 SLOT, RPCOMP TRIP T TOOH w/fish F/769' T/surface, stand back DC, L/D spear. L/D casing to pipe shed with GBR. 769.0 0.0 12/14/2023 12:30 12/14/2023 14:00 1.50 SLOT, RPCOMP PULL T L/D 7" casing to pipe shed w/GBR 0.0 0.0 12/14/2023 14:00 12/14/2023 14:30 0.50 SLOT, RPCOMP SVRG P Service rig 0.0 0.0 12/14/2023 14:30 12/14/2023 18:30 4.00 SLOT, RPCOMP BHAH T PU BHA #25 spear assy with jars. RIH to 925'. Up wt 45K. Tag top of casing at 925', set down 10K. Fire jars at 150K, and straight pull 350K. Work moltiple times with not movement. Trip out of hole and LD BHA. 0.0 0.0 12/14/2023 18:30 12/14/2023 21:30 3.00 SLOT, RPCOMP BHAH T MU BHA #26 Baker MSC and RIH and recut at 1786' and make new cut at 1566'. POOH. 0.0 0.0 12/14/2023 21:30 12/14/2023 23:00 1.50 SLOT, RPCOMP BHAH T MU BHA #27 spear with jars. RIH to 925' and pull fish free at 60K. 0.0 925.0 12/14/2023 23:00 12/15/2023 00:00 1.00 SLOT, RPCOMP CIRC T Circulate arctic pack out of hole with hot diesel. 925.0 925.0 12/15/2023 00:00 12/15/2023 01:30 1.50 SLOT, RPCOMP TRIP T POOH with 7" casing and fish from cut @ 1566' to surface. 925.0 0.0 12/15/2023 01:30 12/15/2023 01:45 0.25 SLOT, RPCOMP BHAH T M/U Spear/Jars, BHA #28 0.0 141.4 12/15/2023 01:45 12/15/2023 03:15 1.50 SLOT, RPCOMP TRIP T TIH, spear 7" section @ 1,566' and fish 1,786' (220') pull free, observe 6k over pull 141.4 1,566.0 12/15/2023 03:15 12/15/2023 06:30 3.25 SLOT, RPCOMP CIRC T PUH, gas/arctic pak in returns, circulate hole clean 1,566.0 1,566.0 12/15/2023 06:30 12/15/2023 08:00 1.50 SLOT, RPCOMP TRIP T TOOH, on stands 1,566.0 361.4 12/15/2023 08:00 12/15/2023 09:30 1.50 SLOT, RPCOMP BHAH T L/D spear and fish 361.4 0.0 12/15/2023 09:30 12/15/2023 10:00 0.50 SLOT, RPCOMP OTHR T Clean RF of arctic pak 0.0 0.0 12/15/2023 10:00 12/15/2023 10:30 0.50 SLOT, RPCOMP SVRG P Service Rig 0.0 0.0 12/15/2023 10:30 12/15/2023 12:00 1.50 SLOT, RPCOMP BHAH T M/U Drift/dress off assembly BHA #29 0.0 166.1 12/15/2023 12:00 12/15/2023 12:15 0.25 SLOT, RPCOMP SFTY T Rig Crew Change 166.1 166.1 12/15/2023 12:15 12/15/2023 12:45 0.50 SLOT, RPCOMP TRIP T TIH, w/sizing shoe 8.375", 17 stands and a single 166.1 220.0 12/15/2023 12:45 12/15/2023 13:15 0.50 SLOT, RPCOMP TRIP T Unable to pass 224', PUH, L/D sizing shoe, load one 4-3/4" DC, 2 8.5" string mills, and flex joint 220.0 151.4 12/15/2023 13:15 12/15/2023 15:15 2.00 SLOT, RPCOMP BHAH T M/U string mills x 2, flex joint, and 4-3/4" DC 151.4 204.4 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 11/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/15/2023 15:15 12/15/2023 15:45 0.50 SLOT, RPCOMP TRIP T TIH 204.4 241.9 12/15/2023 15:45 12/15/2023 23:30 7.75 SLOT, RPCOMP MILL T Wash and reaml 9-5/8". PUW=40k, SOW=37k, ROT 60-90 rpm, torque off bottom 850, torque on bottom 4-6K, pumping 5 bpm/215 gpm at 55 psi. 241.9 818.0 12/15/2023 23:30 12/16/2023 00:00 0.50 SLOT, RPCOMP SVRG P Service rig floor equipment. 818.0 818.0 12/16/2023 00:00 12/16/2023 02:00 2.00 SLOT, RPCOMP MILL T Wash and ream 9-5/8". PUW=45k, SOW=45k, ROT 100 rpm, torque 1200- 6000, pumping 5 bpm at 60 psi. 818.0 1,059.0 12/16/2023 02:00 12/16/2023 02:30 0.50 SLOT, RPCOMP CIRC T Pump a bottoms up at 5 BPM/80 psi. 1,059.0 1,059.0 12/16/2023 02:30 12/16/2023 03:00 0.50 SLOT, RPCOMP OWFF T OWFF, No flow. 1,059.0 1,059.0 12/16/2023 03:00 12/16/2023 04:00 1.00 SLOT, RPCOMP TRIP T TOOH standing back drill pipe. 1,059.0 204.4 12/16/2023 04:00 12/16/2023 04:30 0.50 SLOT, RPCOMP BHAH T L/D BHA BHA #30 Gauge mills - 7/16" under gauged 204.4 0.0 12/16/2023 04:30 12/16/2023 05:15 0.75 SLOT, RPCOMP BHAH T M/U Drift/dress off BHA #31 0.0 151.1 12/16/2023 05:15 12/16/2023 06:00 0.75 SLOT, RPCOMP TRIP T TIH, stack out at 255' 7es RKB. work pipe, unable to pass through area 151.1 255.0 12/16/2023 06:00 12/16/2023 08:00 2.00 SLOT, RPCOMP TRIP T TOOH, L/D Drift assembly BHA #31 *** Note: No marks on bottom of sizing shoe, observed marks on 8.5" crossover. 255.0 0.0 12/16/2023 08:00 12/16/2023 09:00 1.00 SLOT, RPCOMP BHAH T Break out triple drive bushing from drift assembly 0.0 0.0 12/16/2023 09:00 12/16/2023 09:45 0.75 SLOT, RPCOMP OTHR T Load 7 inch test joint into pipe shed, grease BOP and choke manifold, hook up test hose in cellar to test valves 0.0 0.0 12/16/2023 09:45 12/16/2023 10:15 0.50 SLOT, RPCOMP SVRG P Service Rig 0.0 0.0 12/16/2023 10:15 12/16/2023 11:00 0.75 SLOT, RPCOMP OTHR T M/U Johnny Wacker, Jet BOPE and surface lines 0.0 0.0 12/16/2023 11:00 12/16/2023 11:45 0.75 SLOT, RPCOMP WAIT T Prep for BOPE test, M/U 7" test joint, drain stack, install 7" test plug 0.0 0.0 12/16/2023 11:45 12/16/2023 12:00 0.25 SLOT, RPCOMP OTHR T Flood stack and surface lines, obtain shell test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 12/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/16/2023 12:00 12/16/2023 18:30 6.50 SLOT, RPCOMP BOPE P Bi-weekly BOPE test, Tested BOPE at 250/2,500 PSI for 5 Min each, Tested annular on 3-1/2" test joint to 2,500 psi , UVBR's, LVBR's w/3-1/2" and 7" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2,050 PSI, after closure=1500 PSI, 16 PSI attained =20 sec, full recovery attained = 116 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook, Brian Bixby, and Josh Hunt. Verbal approval granted for 2,500 psi test - 11"/3k flange - will need to perform full pressure test after 7 inch spool is installed. 0.0 0.0 12/16/2023 18:30 12/16/2023 19:30 1.00 SLOT, RPCOMP OTHR T R/D & Blow down testing equipment, L/D test joints. Suck out the stack. 0.0 0.0 12/16/2023 19:30 12/16/2023 21:30 2.00 SLOT, RPCOMP RURD T Clean and clear the rig floor. Install wear ring. 0.0 0.0 12/16/2023 21:30 12/16/2023 23:30 2.00 SLOT, RPCOMP BHAH T PU BHA #32. Two 8.5" sting mills with a 6.75" drill collar. 0.0 0.0 12/16/2023 23:30 12/17/2023 00:00 0.50 SLOT, RPCOMP SVRG P Service rig. 0.0 0.0 12/17/2023 00:00 12/17/2023 00:30 0.50 SLOT, RPCOMP BHAH T Finish PU BHA #32 8.5" string mills and 6.75" collar. 0.0 240.0 12/17/2023 00:30 12/17/2023 06:00 5.50 SLOT, RPCOMP MILL T Reaming and washing from 240' to 290'. UPWT45K, DNWT 45K, Pump 5BPM at 50 psi. TQ 1900-5800 ft-lbs. With 40lbs of metal returned to shakers, this spot in the 9-5/8" is still not cleaning up. 240.0 312.0 12/17/2023 06:00 12/17/2023 06:30 0.50 SLOT, RPCOMP MILL T Continue milling/reaming from 312'-391', PUW=45k, SOW=45k, 87 spm/5 bpm @ 82 psi. 312.0 391.0 12/17/2023 06:30 12/17/2023 08:30 2.00 SLOT, RPCOMP MILL T Continue milling/reaming from 391'- 1,059', PUW=55k, SOW=50k, 88 spm/5 bpm @ 83 psi 391.0 1,059.0 12/17/2023 08:30 12/17/2023 09:00 0.50 SLOT, RPCOMP TRIP T TOOH 1,059.0 213.0 12/17/2023 09:00 12/17/2023 11:00 2.00 SLOT, RPCOMP BHAH T L/D BHA #32 213.0 0.0 12/17/2023 11:00 12/17/2023 13:30 2.50 SLOT, RPCOMP BHAH T M/U Drift assembly BHA #33 0.0 159.7 12/17/2023 13:30 12/17/2023 15:30 2.00 SLOT, RPCOMP TRIP T TIH, set down 10k @ 225'-264', rotate through area, continue IH to next set down @ 780', unable to pass through area, confer with engineer on call, 159.7 787.0 12/17/2023 15:30 12/17/2023 17:00 1.50 SLOT, RPCOMP TRIP T TOOH, park @ 627', perform slip and cut of drill line. 787.0 627.0 12/17/2023 17:00 12/17/2023 17:30 0.50 SLOT, RPCOMP TRIP T Continue TOOH 627.0 159.7 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 13/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/17/2023 17:30 12/17/2023 19:30 2.00 SLOT, RPCOMP BHAH T L/D Drift assembly 159.7 0.0 12/17/2023 19:30 12/17/2023 21:30 2.00 SLOT, RPCOMP BHAH T M/U milling assembly BHA #34 w/triple 8.5" string reamers, remove flex joint, 6- 1/2" Drill Collar. 0.0 250.0 12/17/2023 21:30 12/17/2023 23:30 2.00 SLOT, RPCOMP MILL T Milling 9-5/8" casing with string reamers from 250' to XXXX'. Up WT 45K, circ 50 BPM at 50 psi. Free torque 2600 ft-lbs, TQ on bottom 3500-6900 ft-lbs 250.0 295.0 12/17/2023 23:30 12/18/2023 00:00 0.50 SLOT, RPCOMP SVRG P Service rig. 295.0 295.0 12/18/2023 00:00 12/18/2023 04:00 4.00 SLOT, RPCOMP MILL T Milling 9-5/8" casing with string reamers F/250' T/865'. Up WT 45K, circ 50 BPM at 50 psi. Free torque 2600 ft-lbs, TQ on bottom 3500-6900 ft-lbs 295.0 408.0 12/18/2023 04:00 12/18/2023 09:30 5.50 SLOT, RPCOMP MILL T Continue Mill through 9-5/8" casing F/409' T/865' 408.0 865.0 12/18/2023 09:30 12/18/2023 12:00 2.50 SLOT, RPCOMP TRIP T Continue drift in hole F/865' T/1,509', observed a little torque 2,200 lbs, continued IH F/1,509' T/1,801' 865.0 1,801.0 12/18/2023 12:00 12/18/2023 13:00 1.00 SLOT, RPCOMP CIRC T Circulate Sweep around, arctic pak coming back across shakers, hole clean 1,801.0 1,801.0 12/18/2023 13:00 12/18/2023 14:30 1.50 SLOT, RPCOMP TRIP T TOOH on stands to surface F/1,801' T/231', dragging -18k, back ream area x 3, Rot=80 rpm, Rot Torq=1,000 lbs 1,801.0 231.0 12/18/2023 14:30 12/18/2023 16:15 1.75 SLOT, RPCOMP BHAH T TOOH, L/D Milling BHA #34 231.0 0.0 12/18/2023 16:15 12/18/2023 18:00 1.75 SLOT, RPCOMP BHAH T M/U BHA #35 w/8.5" string reamers x 3, no flex joint 0.0 160.0 12/18/2023 18:00 12/18/2023 19:30 1.50 SLOT, RPCOMP TRIP T TIH, w/polish shoe, inner dress off mill, XO, drive bushing, LBS, jars, intensifier, XO, magnets x 2, and XO 160.0 1,786.0 12/18/2023 19:30 12/18/2023 20:15 0.75 SLOT, RPCOMP MILL T Mill/Dress off top of 7" casing stump 1,786.0 1,786.0 12/18/2023 20:15 12/18/2023 22:15 2.00 SLOT, RPCOMP TRIP T TOOH 1,786.0 160.0 12/18/2023 22:15 12/19/2023 00:00 1.75 SLOT, RPCOMP BHAH T L/D Dress off assembly BHA #35 160.0 0.0 12/19/2023 00:00 12/19/2023 02:00 2.00 SLOT, RPCOMP BHAH T L/D Dress off assembly BHA #35 0.0 0.0 12/19/2023 02:00 12/19/2023 03:00 1.00 SLOT, RPCOMP RURD T RU to run 7" HYD563 casing. 0.0 0.0 12/19/2023 03:00 12/19/2023 09:00 6.00 SLOT, RPCOMP PUTB T RIH with 7" HYD 563 casing. UPWT=73K DWT=60K. 0.0 1,744.0 12/19/2023 09:00 12/19/2023 10:00 1.00 SLOT, RPCOMP BHAH T Space out and clear floor. 1,744.0 1,744.0 12/19/2023 10:00 12/19/2023 12:00 2.00 SLOT, RPCOMP CIRC T Circulate a couple bottoms. 4 BPM at 70 psi. 1,744.0 1,744.0 12/19/2023 12:00 12/19/2023 12:30 0.50 SLOT, CEMENT RURD T Land casing, pull 25K and set in slips.RU Cement head. PT casing to 2500 psi for 30 minutes. Close lower rams. PT surface lines. 1,744.0 1,744.0 12/19/2023 12:30 12/19/2023 14:00 1.50 SLOT, CEMENT CMNT T Cementing the OA 7" x 9.625" Pump 10 bbl fresh water spacer, followed by 81 bbl 15.3 ppg cement followed by 10 bbl fresh water spacer. We got 10 bbls of cement back to surface. 1,744.0 1,788.0 12/19/2023 14:00 12/19/2023 16:00 2.00 SLOT, CEMENT RURD T RD cementers, RD cemenet head, Clean cement ffrom manifold. 0.0 0.0 12/19/2023 16:00 12/19/2023 22:00 6.00 SLOT, CEMENT WOC T Clean out ram and stack cavities // wait on cement to cure. Waited 8.23 hours to get to 100 psi compressive strength. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 14/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/19/2023 22:00 12/20/2023 00:00 2.00 SLOT, CSGRCY NUND T Break bolts on adapter and bottom spool of bops, air down boots on riser // pick stack to install slips on 7" 0.0 0.0 12/20/2023 00:00 12/20/2023 03:00 3.00 SLOT, WELLPR NUND T Nipple down well head adapter install packoffs nipple up tubing adapter 0.0 0.0 12/20/2023 03:00 12/20/2023 04:00 1.00 SLOT, WELLPR PRTS T Pressure test packoffs 3000 // Bled air out of void several times // good test 10 min 3000 psi 0.0 0.0 12/20/2023 04:00 12/20/2023 06:00 2.00 SLOT, WELLPR NUND T Nipple up adapter DSA // Nipple up BOPs 0.0 0.0 12/20/2023 06:00 12/20/2023 09:30 3.50 SLOT, WELLPR RURD T Swapped lower rams from 7" fixed to 3.5x5.5" variables.Fill BOP stack purged out air and shell test. 0.0 0.0 12/20/2023 09:30 12/20/2023 15:30 6.00 SLOT, WHDBOP BOPE T BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3- 1/2" test joint to 3500psi , UVBR's, LVBR's w/3-1/2" and 4 " test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4-1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1550 PSI, 200 PSI attained =20 sec, full recovery attained = 108 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Austin McLeod. 0.0 0.0 12/20/2023 15:30 12/20/2023 16:30 1.00 SLOT, RPCOMP RURD T RD BOP testing equipment. 0.0 0.0 12/20/2023 16:30 12/20/2023 19:30 3.00 SLOT, RPCOMP BHAH T Install wear ring. PU and RIH with milling assembly with junk basket and magnets in BHA. // Bootbaskets not cleaned out on previous run and frozen // Pick up magnets and collars 0.0 182.0 12/20/2023 19:30 12/20/2023 21:00 1.50 SLOT, RPCOMP TRIP T TIH T/ 1700' kelly up on stand 17 to wash down to plug 182.0 1,700.0 12/20/2023 21:00 12/20/2023 21:30 0.50 SLOT, RPCOMP WASH T Wash down to 1745' tag // Pump 3 bbls/min @ 140 psi 1,700.0 1,745.0 12/20/2023 21:30 12/21/2023 00:00 2.50 SLOT, RPCOMP MILL T Mill cement stringers F/ 1745' T/ 1772' // Pump 3 bbls/ min @ 150 psi // Rot 40 rpm @ 1700 ft/lbs // Mill on cement plug F/ 1772' T/ 1775.6 // Pump 5 bbls/min @ 325 psi Rot 80 rpm @ 1500 ft/lbs // unable to make progress with 1,745.0 1,775.6 12/21/2023 00:00 12/21/2023 01:00 1.00 SLOT, RPCOMP MILL T Mill on plug unable to make progress with junk mill. Set down 10K, PU off bottom and set RPM to 80, torque 1130- 1800 ft-lbs, pumping 5 BPM at 470 psi and WOB 3-15K. 1,775.6 1,775.6 12/21/2023 01:00 12/21/2023 02:30 1.50 SLOT, RPCOMP TRIP T TOOH for roller cone bit // once on surface found cement mounded in center of mill in shape of BOP nut 1,775.6 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 15/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2023 02:30 12/21/2023 04:30 2.00 SLOT, RPCOMP BHAH T BHA# 37 RCJB pick up and run in hole 0.0 185.0 12/21/2023 04:30 12/21/2023 08:30 4.00 SLOT, RPCOMP FISH T TIH with junk basket, circ at 9 bpm at 1520 psi, 5 RPM with 1200-1500TQ. Trip out of hole and LD BHA. No fish. 185.0 0.0 12/21/2023 08:30 12/21/2023 12:00 3.50 SLOT, RPCOMP FISH T TIH with junk basket, circ at 9 bpm at 1520 psi, 5 RPM with 1200-1500TQ. Trip out of hole and LD BHA. No fish. 0.0 0.0 12/21/2023 12:00 12/21/2023 16:30 4.50 SLOT, RPCOMP FISH T TIH with junk basket, circ at 9.7 bpm at 1780 psi, 63 RPM with 1650 TQ. WOB 5K. Trip out of hole and LD BHA. No fish! 0.0 0.0 12/21/2023 16:30 12/21/2023 17:00 0.50 SLOT, RPCOMP SVRG T Service rig. 0.0 0.0 12/21/2023 17:00 12/21/2023 17:30 0.50 SLOT, RPCOMP BHAH T Make up Magnet BHA # 38 0.0 150.0 12/21/2023 17:30 12/21/2023 19:00 1.50 SLOT, RPCOMP TRIP T TIH with magnet 150.0 1,770.0 12/21/2023 19:00 12/21/2023 19:30 0.50 SLOT, RPCOMP FISH T Attempt to fish nut with magnet 1,770.0 1,775.0 12/21/2023 19:30 12/21/2023 20:30 1.00 SLOT, RPCOMP TRIP T TOOH to inspect magnet 1,775.0 150.0 12/21/2023 20:30 12/21/2023 21:00 0.50 SLOT, RPCOMP BHAH T Rack collars and lay down magnet BHA 150.0 0.0 12/21/2023 21:00 12/21/2023 22:00 1.00 SLOT, RPCOMP BHAH T Make up BHA# 39 , tri-cone bit 0.0 150.0 12/21/2023 22:00 12/21/2023 23:30 1.50 SLOT, RPCOMP TRIP T TIH to top of plug 150.0 1,770.0 12/21/2023 23:30 12/22/2023 00:00 0.50 SLOT, RPCOMP MILL T Mill plug F/ 1775 T/ 1776 // Pump Rate 4 bpm @ 250 psi Rot 65 rpm @ 1000 ft/lbs free spin 1,770.0 1,776.0 12/22/2023 00:00 12/22/2023 04:00 4.00 SLOT, RPCOMP MILL T Mill Plug F/ 1776 T/ 1790' // 4 bbls/min 250 psi, Rot 65 rpm @ 1200 ft/lbs, Hold 5k wob // continue down to 1845' ensure string mills work across cementer 1,776.0 1,845.0 12/22/2023 04:00 12/22/2023 04:30 0.50 SLOT, RPCOMP TRIP T TIH to top of sand @ 2281' 1,845.0 2,281.0 12/22/2023 04:30 12/22/2023 05:30 1.00 SLOT, RPCOMP MILL T Wash top of sand and grind any debris down to 2300' 2,281.0 2,300.0 12/22/2023 05:30 12/22/2023 09:30 4.00 SLOT, RPCOMP TRIP T TOOH and LD 6-1/8" tri-cone bit, magnets and junk baskets. 2,300.0 0.0 12/22/2023 09:30 12/22/2023 11:30 2.00 SLOT, RPCOMP TRIP T PU RCJB's and RIH to 2300' UPW=656K, DNW=59K. 0.0 2,300.0 12/22/2023 11:30 12/22/2023 12:30 1.00 SLOT, RPCOMP MILL T Washing and reaming with 9 BPM/1530 psi, ROT 10 rpm, TQ 1050.Pump Hi-Vis sweep. 2,300.0 2,308.0 12/22/2023 12:30 12/22/2023 13:00 0.50 SLOT, RPCOMP OWFF T Flow check the well 2,308.0 2,308.0 12/22/2023 13:00 12/22/2023 15:30 2.50 SLOT, RPCOMP TRIP T Trip out fo the hole. UWT=65K DWT=59K. LD BHA #42. Clean Boot baskets and discuss with town next BHA to run. 2,308.0 0.0 12/22/2023 15:30 12/22/2023 17:30 2.00 SLOT, RPCOMP TRIP T PU RCJB's and RIH to 2308' 0.0 2,308.0 12/22/2023 17:30 12/22/2023 19:30 2.00 SLOT, RPCOMP WASH T Wash hole down to 2340' pump sweeps // Circulate S x S twice to clean up sand in returns 2,308.0 2,340.0 12/22/2023 19:30 12/22/2023 21:00 1.50 SLOT, RPCOMP TRIP T TOOH inspect boot baskets and RCJB 2,340.0 150.0 12/22/2023 21:00 12/22/2023 21:30 0.50 SLOT, RPCOMP BHAH T Laydown and inspect RCJB bha no metal on magnets 150.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 16/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/22/2023 21:30 12/22/2023 22:00 0.50 SLOT, RPCOMP BHAH T Pick up BHA# 43, G-lock retrieval BHA 0.0 170.0 12/22/2023 22:00 12/22/2023 23:30 1.50 SLOT, RPCOMP TRIP T TIH tag sand @ 2338 170.0 2,338.0 12/22/2023 23:30 12/23/2023 00:00 0.50 SLOT, RPCOMP CIRC T Circulate sand from top of plug // Pump sweeps clean out hole 2,338.0 2,340.0 12/23/2023 00:00 12/23/2023 01:00 1.00 SLOT, RPCOMP CIRC T Circulate sand from top of plug // 4bbls/min @ 310 psi // Pump sweeps get sand off top of G-Lock 2,340.0 2,340.0 12/23/2023 01:00 12/23/2023 02:00 1.00 SLOT, RPCOMP FISH T Attempt to was down on fish neck of G- plug // unable to pass 2340' // Pump sweeps no progress past 2340' 2,340.0 2,340.0 12/23/2023 02:00 12/23/2023 03:00 1.00 SLOT, RPCOMP TRIP T TOOH for RCJB 2,340.0 0.0 12/23/2023 03:00 12/23/2023 03:45 0.75 SLOT, RPCOMP BHAH T Make up BHA# 46 RCJB 0.0 170.0 12/23/2023 03:45 12/23/2023 05:30 1.75 SLOT, RPCOMP TRIP T TIH with RCJB 170.0 2,247.0 12/23/2023 05:30 12/23/2023 10:00 4.50 SLOT, RPCOMP FISH T CO run, 10 BPM at 1850 psi, Rotary 1350, UPWT=65K, DNWT= 59K, Pump 20 BBL hi-vis sweep. 2,247.0 2,247.0 12/23/2023 10:00 12/23/2023 11:00 1.00 SLOT, RPCOMP RURD T Cleaning rig floor and boot baskets. 0.0 0.0 12/23/2023 11:00 12/23/2023 12:00 1.00 SLOT, RPCOMP SVRG T Grease and inspect crown, blocks and drawworks. 0.0 0.0 12/23/2023 12:00 12/23/2023 16:15 4.25 SLOT, RPCOMP BHAH T Make up BHA# 47 RCJB and TIH to fish. Pump a high vis sweep. 0.0 2,248.0 12/23/2023 16:15 12/23/2023 17:45 1.50 SLOT, RPCOMP TRIP T Trip out of the hole with BHA #47 2,248.0 160.0 12/23/2023 17:45 12/23/2023 18:30 0.75 SLOT, RPCOMP BHAH T Lay down and inspect BHA 160.0 0.0 12/23/2023 18:30 12/23/2023 19:30 1.00 SLOT, RPCOMP TRIP T BHA# 48 G-plug retrieval tool // TIH to top of plug @ 2348' // Latch into G-plug and release 0.0 2,348.0 12/23/2023 19:30 12/23/2023 20:30 1.00 SLOT, RPCOMP CIRC T Plug pulling heavy, circulate sweeps sand found in returns 2,348.0 2,310.0 12/23/2023 20:30 12/23/2023 22:45 2.25 SLOT, RPCOMP TRIP T TOOH with plug // Pull out of hole slow with plug due to overpulls 2,310.0 0.0 12/23/2023 22:45 12/23/2023 23:30 0.75 SLOT, RPCOMP BHAH T Lay down G-Plug 0.0 0.0 12/23/2023 23:30 12/24/2023 00:00 0.50 SLOT, RPCOMP PRTS T Rig up and purge lines for casing test 0.0 0.0 12/24/2023 00:00 12/24/2023 01:00 1.00 SLOT, RPCOMP PRTS T Pressure test 7 in casing 2500 for 30 min good test // Rig down test equip prep for picking up BHA 0.0 0.0 12/24/2023 01:00 12/24/2023 03:00 2.00 SLOT, RPCOMP BHAH T Pick up BHA# 49 // Wavy bottom 5.75" OD 4.938" ID with 120' of wash pipe // 0.0 255.0 12/24/2023 03:00 12/24/2023 06:00 3.00 SLOT, RPCOMP TRIP T Trip in hole from 255' to 6150'. UPWT 130K/ DWT 95K 255.0 6,150.0 12/24/2023 06:00 12/24/2023 11:30 5.50 SLOT, RPCOMP MILL T Reaming and washing. Tag at 6156'. Wash down to top of cement at 6190'. Ream down to 6211'. 6,150.0 6,211.0 12/24/2023 11:30 12/24/2023 12:00 0.50 SLOT, RPCOMP SVRG T Service rig. 6,211.0 6,211.0 12/24/2023 12:00 12/24/2023 17:00 5.00 SLOT, RPCOMP TRIP T Trip out of hole with BHA #49. 6,211.0 150.0 12/24/2023 17:00 12/24/2023 17:45 0.75 SLOT, RPCOMP BHAH T Lay down BHA# 49 // Burn shoe cracked from use 150.0 0.0 12/24/2023 17:45 12/24/2023 18:30 0.75 SLOT, RPCOMP BHAH T Pick up BHA# 50 // 6" OD burn shoe 0.0 150.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 17/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/24/2023 18:30 12/24/2023 21:30 3.00 SLOT, RPCOMP TRIP T Trip in hole with burn shoe and washpipe BHA# 50 150.0 6,180.0 12/24/2023 21:30 12/25/2023 00:00 2.50 SLOT, RPCOMP MILL T Mill ahead F/ 6211 T/ 6229 // WOB 2K- 3K // Rot 40 RPM @ 6K-7K TQ //Pump 4 bbls/min @ 450 psi // 6,180.0 6,229.0 12/25/2023 00:00 12/25/2023 03:30 3.50 SLOT, RPCOMP MILL T Mill ahead F/ 6229' T/ 6242.5 // WOB 2K-3K // Rot 40 RPM @ 6K-7K TQ //Pump 4 bbls/min @ 450 psi // Progress slowed @ 03:00 attempt to get consistent ROP for 30 min unable decision made to TOOH inspect burn shoe 6,229.0 6,242.5 12/25/2023 03:30 12/25/2023 04:30 1.00 SLOT, RPCOMP CIRC T Circulate Sweep S x S ensure hole clean 6,242.5 6,242.0 12/25/2023 04:30 12/25/2023 10:30 6.00 SLOT, RPCOMP TRIP T TOOH to inspect BHA #50. Pulled 5 pieces of 3-1/2" tubing out of the wash pipe. The peices (17.5', 31.2', 17.53', 5.11' and 2.63') were a total of 73.97' long. These are not exact lengths since the pipe was shaved off on low side, twisted and stretched alittle. 6,242.0 0.0 12/25/2023 10:30 12/25/2023 11:30 1.00 SLOT, RPCOMP BHAH T PU BHA #51, burn over shoe and 188' of wash pipe. 0.0 255.0 12/25/2023 11:30 12/25/2023 12:00 0.50 SLOT, RPCOMP SVRG T Service rig. 255.0 252.0 12/25/2023 12:00 12/25/2023 15:30 3.50 SLOT, RPCOMP TRIP T TIH with BHA #51 255.0 6,242.0 12/25/2023 15:30 12/26/2023 00:00 8.50 SLOT, RPCOMP MILL T Mill ahead F/ 6242' T/ 6255.9' // WOB 8K-10K // Rot 40 RPM @ 6K-7K TQ //Pump 4 bbls/min @ 780 psi // Slow progress unable to proceed at acceptable rate 6,242.0 6,255.9 12/26/2023 00:00 12/26/2023 00:30 0.50 SLOT, RPCOMP MILL T Attempt to mill ahead no progress 6,255.9 6,255.9 12/26/2023 00:30 12/26/2023 03:30 3.00 SLOT, RPCOMP TRIP T Sweep hole pull 2 stands to 6050' to perform casing test // stop to test casing, drill pipe not bleeding off look to have plugged up or partially plugged washpipe, elected to continue out of hole ensure retain fish 6,255.9 150.0 12/26/2023 03:30 12/26/2023 04:30 1.00 SLOT, RPCOMP BHAH T Lay down BHA# 50 // Found tubing stuck in washpipe // Recovered ~18' of tubing 150.0 0.0 12/26/2023 04:30 12/26/2023 05:15 0.75 SLOT, RPCOMP PRTS T Pressure test casing 2500 15min good test // rig down test equipment 0.0 0.0 12/26/2023 05:15 12/26/2023 06:15 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 51 6" OD 4.75ID burn shoe with wash pipe 0.0 150.0 12/26/2023 06:15 12/26/2023 10:00 3.75 SLOT, RPCOMP TRIP T TIH with burn shoe and washpipe 150.0 6,255.0 12/26/2023 10:00 12/26/2023 18:00 8.00 SLOT, RPCOMP MILL T Mill ahead F/6251' T/6278' WOB 3K-5K. Rot 40 RPM @ 5K-7K TQ. Pump 4 bbls/min @ 405 psi. 6,255.0 6,278.0 12/26/2023 18:00 12/26/2023 19:00 1.00 SLOT, RPCOMP CIRC T Circulate 100 Vis. sweep at 3BPM=755PSI SxS 6,278.0 6,278.0 12/26/2023 19:00 12/26/2023 20:30 1.50 SLOT, RPCOMP TRIP T TOOH T/ 6244' Pull heavy 160K, work pipe back to 6275' to continue mill on cemtent to free fish, torque up 10K, 6,278.0 6,278.0 12/26/2023 20:30 12/26/2023 22:30 2.00 SLOT, RPCOMP MILL T Attempt to mill ahead no progress 6,278.0 6,278.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 18/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/26/2023 22:30 12/26/2023 23:00 0.50 SLOT, RPCOMP TRIP T TOOH to inspect BHA Start pulling heavy @ 6240' 160K popped free worked up to 6050' still dragging elected to pump sweep and clean hole 6,278.0 6,050.0 12/26/2023 23:00 12/27/2023 00:00 1.00 SLOT, RPCOMP CIRC T Sweep hole and ensure hole clean 6,050.0 6,050.0 12/27/2023 00:00 12/27/2023 02:30 2.50 SLOT, RPCOMP TRIP T Continue out of hole to inspect BHA no overpulls past 6240' 6,050.0 150.0 12/27/2023 02:30 12/27/2023 03:45 1.25 SLOT, RPCOMP BHAH T Lay down and inspect BHA // Found more 3.5" completion bound up in washpipe //tubing found in washpipe, unable to break off burn shoe and retrieve fish out of washpipe // lay down as one piece return to baker 150.0 0.0 12/27/2023 03:45 12/27/2023 04:30 0.75 SLOT, RPCOMP PRTS T Pressure test casing 2500 psi 15min // Good Test // bleed off blow down surface lines 0.0 0.0 12/27/2023 04:30 12/27/2023 06:00 1.50 SLOT, RPCOMP BHAH T Pick up BHA# 52 // 6.125 OD 4.625 ID w/ 3 jts washpipe 0.0 110.0 12/27/2023 06:00 12/27/2023 08:00 2.00 SLOT, RPCOMP TRIP T TIH W/BHA F/110' T/6275' Establish milling parameters PR=3BPM 400PSI Rot=30RPM Free Tq.=6K 110.0 6,275.0 12/27/2023 08:00 12/27/2023 13:30 5.50 SLOT, RPCOMP MILL T Start milling F/6278' unable to make any hole adjusted parameters unable to make shoe bite. 6,278.0 6,278.0 12/27/2023 13:30 12/27/2023 14:30 1.00 SLOT, RPCOMP TRIP T TOOH to 5900' 6,278.0 5,900.0 12/27/2023 14:30 12/27/2023 15:30 1.00 SLOT, RPCOMP SLPC T Slip and cut drilling line. 5,900.0 5,900.0 12/27/2023 15:30 12/27/2023 18:00 2.50 SLOT, RPCOMP TRIP T TOOH for junk mill 5,900.0 150.0 12/27/2023 18:00 12/27/2023 19:00 1.00 SLOT, RPCOMP BHAH T Lay down BHA // two 8' slabs recovered from washpipe 150.0 0.0 12/27/2023 19:00 12/27/2023 20:00 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 53 6-1/8" Junk mill 0.0 120.0 12/27/2023 20:00 12/27/2023 23:00 3.00 SLOT, RPCOMP TRIP T TIH with junk mill 120.0 6,280.0 12/27/2023 23:00 12/28/2023 00:00 1.00 SLOT, RPCOMP MILL Mill F/ 6277' T/ 6277' 70 spm @ 450psi DN Wt. Up Wt. Rot 31 rpm @ 6000 tq free spin Time mill due to stalling to establish pattern 6,277.0 6,277.0 12/28/2023 00:00 12/28/2023 13:00 13.00 SLOT, RPCOMP MILL T Mill F/ 6277' T/ 6311.3' 70 spm @ 450psi DN Wt. Up Wt. Rot 31 rpm @ 6000 tq free spin 6,277.0 6,311.3 12/28/2023 13:00 12/28/2023 15:00 2.00 SLOT, RPCOMP CIRC T Circulate 15 BBL sweep cleared the bit and increased rate to circulate trash OOH. PUH to clean well bore started pulling tight. Worked up hole to 6277' continue to work pipe send another sweep PR=5.5 BPM CP=675 PSI PUW=125K. Continue to work pipe to free up debris from around the BHA. F/6309' T/6266' Erratic torque and weight swings while working pipe. PUW F/110K T/125K Torque to 13K Free Tq=6K 6,311.3 6,275.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 19/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/28/2023 15:00 12/28/2023 16:00 1.00 SLOT, RPCOMP MILL T Rack back 1 stand and continue to work pipe. F/6275 T/6175' No weight changes or torque increases observed. Clean up and down shut off rotation stroked DP 100' no notable changes observed. shut off pump work pipe 100' no changes. Rot=40 RPM PR= 5.5 BPM @ 645 PSI Tq.= 6K PUW=112K SOW=95K 6,275.0 6,175.0 12/28/2023 16:00 12/29/2023 00:00 8.00 SLOT, RPCOMP MILL T Make connection work pipe F/6275' T/6309' Worked pipe back to 6311' clean up and down. Return to milling F/6311' T/6335' Rot=40 RPM, PR= 4 BPM @ 400 PSI, Free Tq.= 6K, PUW=112K, SOW=95K Perform wipers and sweeps as needed to support milling operations 6,275.0 6,335.0 12/29/2023 00:00 12/29/2023 03:30 3.50 SLOT, RPCOMP MILL T Continue milling F/6335' T/6341' Rot=40 RPM, PR= 4 BPM @ 400 PSI, Free Tq.= 6K, PUW=112K, SOW=95K Perform wipers and sweeps as needed to support milling operations Mill show signs worn out @ 6341' inconsistant torque total milled with junk mill 64' 6,335.0 6,341.0 12/29/2023 03:30 12/29/2023 04:30 1.00 SLOT, RPCOMP CIRC T Circulate sweeps clean well bore for TOOH for junk mill 6,341.0 6,177.0 12/29/2023 04:30 12/29/2023 07:30 3.00 SLOT, RPCOMP TRIP T TOOH for junk mill 6,177.0 188.0 12/29/2023 07:30 12/29/2023 09:00 1.50 SLOT, RPCOMP BHAH T LD Mill and empty boot baskets.. recovered 1.5 gallons metal debris from boot baskets. 188.0 0.0 12/29/2023 09:00 12/29/2023 10:00 1.00 SLOT, RPCOMP PRTS T RU to test, PT 7" casing to 2500 PSI for 15 minutes. Tested good. RD test equipment and blow down lines. 0.0 0.0 12/29/2023 10:00 12/29/2023 11:00 1.00 SLOT, RPCOMP SVRG T Inspect top drive and linktilt 0.0 0.0 12/29/2023 11:00 12/29/2023 12:00 1.00 SLOT, RPCOMP BHAH T PU BHA #54 0.0 188.0 12/29/2023 12:00 12/29/2023 16:15 4.25 SLOT, RPCOMP TRIP T TIH F/188 T/6325' Attempt to establish milling parmeters. Roll pump and DP psi increased to 3500 PSI. Blow down top drive and pump lines RU to Reverse circulate attempt to clear DP. 188.0 6,325.0 12/29/2023 16:15 12/29/2023 17:45 1.50 SLOT, RPCOMP CIRC T Reverse circulate DP clean .5 BPM to start. Maintain circulation 6,325.0 6,325.0 12/29/2023 17:45 12/30/2023 00:00 6.25 SLOT, RPCOMP MILL T ROT=60 RPM, PR=4 BPM @ 350 PSI, Free Tq 5800 Ft./Lbs. Start milling F/6338' T/6348' 6,325.0 6,348.0 12/30/2023 00:00 12/30/2023 00:30 0.50 SLOT, RPCOMP MILL T ROT=60 RPM, PR=4 BPM @ 350 PSI, Free Tq 5800 Ft./Lbs. Start milling F/6348' T/6350' 6,348.0 6,350.0 12/30/2023 00:30 12/30/2023 01:30 1.00 SLOT, RPCOMP DISP T Displace well with new sea water 6,350.0 6,350.0 12/30/2023 01:30 12/30/2023 06:00 4.50 SLOT, RPCOMP MILL T Rot= 70 rpm , PR= 3.5 bpm @ 299 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Mill F/6350' T/ 6359 6,350.0 6,359.0 12/30/2023 06:00 12/30/2023 07:30 1.50 SLOT, RPCOMP CIRC T Circ sweep SxS 5 BPM 550 PSI Reciprocate pipe rotating 65 RPM. 6,359.0 6,359.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 20/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/30/2023 07:30 12/31/2023 00:00 16.50 SLOT, RPCOMP MILL T Rot= 70 rpm , PR= 3.5 bpm @ 299 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Continue milling F/6350' T/6387' 6,359.0 6,387.0 12/31/2023 00:00 12/31/2023 07:00 7.00 SLOT, RPCOMP MILL T Rot= 70 rpm , PR= 3.5 bpm @ 299 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Continue milling F/6387' T/6394.8' Unable to get deeper. Changed milling parameters including PR WOB RPM worked pipe up to 6366' Pump on rot off attempt to get torque back unable to establish mill work. 6,387.0 6,394.0 12/31/2023 07:00 12/31/2023 08:30 1.50 SLOT, RPCOMP CIRC T Continued to change milling parameters including PR WOB RPM worked pipe up to 6366' Pump on rot off attempt to get torque back unable to establish mill work. Rot at 40 RPM 50 RPM 60 RPM Pump on and off unable to establish work. Sweep hole W/15 BBL 100 Vis pill imcreased PR T/6 BPM work pipe. unable to make torque. Circulate sweep out of hole. Continue to work pipe and attempt to regain milling work. 6,394.0 6,394.0 12/31/2023 08:30 12/31/2023 17:30 9.00 SLOT, RPCOMP TRIP T TOOH F/6394' PUW=120K PUH 100' started pulling 70K over. Work pipe free travel down, SOW=100-105K. Pulling heavy T/188' 6,394.0 188.0 12/31/2023 17:30 12/31/2023 19:00 1.50 SLOT, RPCOMP BHAH T LD BHA. Empty boot baskets, inspect mill. OD measured 5.75"" face showed complete wear. Carbide inserts appeared ground down with center hole cored out. 188.0 0.0 12/31/2023 19:00 12/31/2023 19:30 0.50 SLOT, RPCOMP CLEN T Clean floor prep for casing test 0.0 0.0 12/31/2023 19:30 12/31/2023 20:00 0.50 SLOT, RPCOMP PRTS T Pressure test casing 2500 for 15 min good test 0.0 0.0 12/31/2023 20:00 12/31/2023 20:30 0.50 SLOT, RPCOMP SVRG T Service wash pipe and crown 0.0 0.0 12/31/2023 20:30 12/31/2023 21:30 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 55 junk mill 0.0 194.0 12/31/2023 21:30 1/1/2024 00:00 2.50 SLOT, RPCOMP TRIP T TIH T/6100' 194.0 6,100.0 1/1/2024 00:00 1/1/2024 01:00 1.00 SLOT, RPCOMP TRIP T TIH T/ 6394' 6,100.0 6,394.0 1/1/2024 01:00 1/1/2024 17:00 16.00 SLOT, RPCOMP MILL T Rot= 60 rpm , PR= 3.5 bpm @ 338 psi, Free Tq = 5500 ft./lbs PUW=135K SOW=110K Continue milling F/6394.8' T/ 6425 Pump pressure increased to 1200 PSI at 1600. Mill appears to have plugged jet. 6,394.0 6,425.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 21/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/1/2024 17:00 1/1/2024 19:00 2.00 SLOT, RPCOMP MILL T Recieved call from CPF 2 dump truck contacted high line feeding 7ES. swapped off high line Continued milling F/6425 T/6427' ROT 60 RPM, Tq on=7000 WOB=10K PR=2.75 BPM @1000 PSI BHA plugged up pumping .8 bbls/min @ 2600 psi 6,425.0 6,427.0 1/1/2024 19:00 1/1/2024 22:30 3.50 SLOT, RPCOMP TRIP T TOOH for clean out run in prep for E- line work 6,427.0 200.0 1/1/2024 22:30 1/1/2024 23:30 1.00 SLOT, RPCOMP BHAH T Break down BHA found 8' spiral of casing cored into BHA and 5 of 6 jets plugged , boot baskets contained 1/4 of 5 gal bucket of metall chips 200.0 0.0 1/1/2024 23:30 1/2/2024 00:00 0.50 SLOT, RPCOMP CLEN T Clean floor from wet trip out of hole 0.0 1/2/2024 00:00 1/2/2024 01:00 1.00 SLOT, RPCOMP PRTS T Rig up and test casing 2500 psi 15 min good test // rig down test equipment 0.0 0.0 1/2/2024 01:00 1/2/2024 02:00 1.00 SLOT, RPCOMP BHAH T Pick up BHA# 56 // RCJB, string mills and magnets 0.0 178.0 1/2/2024 02:00 1/2/2024 05:30 3.50 SLOT, RPCOMP TRIP T TIH with clean out assembly T/6426' Pump down lastF/6358' set down. Tagged at 6426' PU off bottom. Rot=13 RPM, PR=70 SPM @ 1600 PSI Free torque=3500 Ft/Lbs PUW=135K SOW=100K. 15K over pull initial off bottom. Worked back to 6427' SO 15K WOB. Worked pipe till clean pu and slack off. 178.0 6,427.0 1/2/2024 05:30 1/2/2024 10:00 4.50 SLOT, RPCOMP CIRC T Start sweep down DP PR=160 SPM @2000 PSI RPM=15 Circ SxS till clean pumping 15 BBL 100 vis sweeps untill clean. 6,427.0 6,427.0 1/2/2024 10:00 1/2/2024 13:00 3.00 SLOT, RPCOMP TRIP T TOOH F/6427' T/1730' 6,427.0 1,730.0 1/2/2024 13:00 1/2/2024 13:30 0.50 SLOT, RPCOMP SVRG T Service top drive. 1,730.0 1,730.0 1/2/2024 13:30 1/2/2024 16:30 3.00 SLOT, RPCOMP MPSP T PU Storm packer rack back 2 Set storm packer at 67'. Test to 2500 PSI. Blow down all lines. 1,730.0 1,730.0 1/2/2024 16:30 1/2/2024 17:00 0.50 SLOT, RPCOMP RURD T Prep for BOP test. 1,730.0 1,730.0 1/2/2024 17:00 1/3/2024 00:00 7.00 SLOT, RPCOMP WAIT T Phase 3 called on 2M pulled storm packer. prepared to circulate. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/3/2024 00:00 1/4/2024 00:00 24.00 SLOT, RPCOMP WAIT T Phase 3 called on 2M pulled storm packer. prepared to circulate. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/4/2024 00:00 1/5/2024 00:00 24.00 SLOT, RPCOMP WAIT T Phase 3. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/5/2024 00:00 1/6/2024 00:00 24.00 SLOT, RPCOMP WAIT T Phase 3. Circ the top of the well SxS to 1700' every 2-3 hours to keep the well from freezing. 1,730.0 1,730.0 1/6/2024 00:00 1/6/2024 04:30 4.50 SLOT, RPCOMP WAIT T Phase 3. Circ the top of the well SxS to 1700' 1,730.0 1,730.0 1/6/2024 04:30 1/6/2024 05:30 1.00 SLOT, RPCOMP BHAH T Re-build storm packer for hanging off BHA. 1,730.0 1,730.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 22/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/6/2024 05:30 1/6/2024 06:30 1.00 SLOT, RPCOMP MPSP T PU and RIH with storm packer. Set Sorm packer W/1700' of DP hung off at 67' COEmLD running tool. PT storm packer to 2500 PSI for 15 minutes. 1,730.0 1,730.0 1/6/2024 06:30 1/6/2024 09:30 3.00 SLOT, RPCOMP RURD T Pull wear ring and clean stack with stack cleaner. grease choke manifold. mark donut joint for BOP test. flood stack and surface lines. 1,730.0 1,730.0 1/6/2024 09:30 1/6/2024 16:00 6.50 SLOT, RPCOMP BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = 115 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Brian Bixby 1,730.0 1,730.0 1/6/2024 16:00 1/6/2024 17:00 1.00 SLOT, RPCOMP RURD T R/D testing equipment, blow down choke manifold, Set up safety valve for DP. get floor ready to TOOH and R/U E- line. 1,730.0 1,730.0 1/6/2024 17:00 1/6/2024 18:00 1.00 SLOT, RPCOMP MPSP T Pull storm packer // circulate S x S prior to pulling to surface // pressure increase 1300 psi @ 1 bbl/min 1,730.0 1,730.0 1/6/2024 18:00 1/6/2024 19:00 1.00 SLOT, RPCOMP TRIP T TOOH 17 stands 1,730.0 190.0 1/6/2024 19:00 1/6/2024 20:30 1.50 SLOT, RPCOMP BHAH T Lay down BHA // Found storm valve plugged // 1/4 bucket on magnets, 1/4 bucket metal out of boot baskets 190.0 0.0 1/6/2024 20:30 1/6/2024 21:30 1.00 SLOT, RPCOMP CLEN T Clean up floor from wet trip out of hole due to plugged storm valve, remove fishing tools from rig floor 0.0 0.0 1/6/2024 21:30 1/6/2024 22:30 1.00 SLOT, RPCOMP ELNE T Rig up E-line 0.0 0.0 1/6/2024 22:30 1/7/2024 00:00 1.50 SLOT, RPCOMP ELNE T Perform CBL/CCL run 22:30- RIH with logging tools 23:30- Log CBL and CCL up to 6000' show good cement to 6290' 0.0 0.0 1/7/2024 00:00 1/7/2024 01:00 1.00 SLOT, RPCOMP ELNE P POOH with E-line for caliper run 0.0 0.0 1/7/2024 01:00 1/7/2024 02:00 1.00 SLOT, RPCOMP ELNE P Lay down CCL/CBL tools // Pick up and test READ caliper 0.0 0.0 1/7/2024 02:00 1/7/2024 04:00 2.00 SLOT, RPCOMP ELNE P Perform Caliper log of WS setting area 02:00 - RIH with caliper 03:00 - POOH with caliper 03:48 - Break down E-line and caliper tools 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 23/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/7/2024 04:00 1/7/2024 04:30 0.50 SLOT, RPCOMP ELNE P Rig down E-line 0.0 0.0 1/7/2024 04:30 1/7/2024 05:30 1.00 SLOT, RPCOMP BHAH P Pick up BHA# 59 6.151" whip stock drift run BHA. Hold PJSM to PU BHA. Pick up 6-1/8" junk mill with 6.151" smooth od string mil. l 0.0 174.0 1/7/2024 05:30 1/7/2024 07:00 1.50 SLOT, RPCOMP TRIP P TIH F/173.9' T/3476.73' Phase 3 called at 0706 AM. Stop TIH. 174.0 3,476.0 1/7/2024 07:00 1/8/2024 00:00 17.00 SLOT, RPCOMP WAIT T Waiting on weather Phase 3 called at 0706 AM. 3,476.0 1/8/2024 00:00 1/8/2024 04:00 4.00 SLOT, RPCOMP WAIT T Waiting on weather Phase 3 called at 0706 AM. 3,476.0 3,476.0 1/8/2024 04:00 1/8/2024 05:30 1.50 SLOT, RPCOMP TRIP P TIH with drillpipe T/ 6428', no obstructions 3,476.0 6,428.0 1/8/2024 05:30 1/8/2024 07:00 1.50 SLOT, RPCOMP CIRC P Circulate well ensure hole clean // Pump 100 vis sweeps 6,428.0 6,428.0 1/8/2024 07:00 1/8/2024 08:00 1.00 SLOT, RPCOMP DISP P Displace well with clean seawater 8.5# 6,428.0 6,428.0 1/8/2024 08:00 1/8/2024 08:15 0.25 SLOT, RPCOMP OWFF P OWFF no flow prep to TOOH 6,428.0 6,428.0 1/8/2024 08:15 1/8/2024 11:15 3.00 SLOT, RPCOMP TRIP P TOOH racking stands in derrick 6,428.0 150.0 1/8/2024 11:15 1/8/2024 12:45 1.50 SLOT, WHPST BHAH P Lay down BHA inspect boot baskets and magnets // boot baskets and magnets full // clean up and prep to run back in hole 150.0 0.0 1/8/2024 12:45 1/8/2024 13:45 1.00 SLOT, WHPST BHAH P Pick up clean out BHA #60 0.0 173.0 1/8/2024 13:45 1/8/2024 16:30 2.75 SLOT, WHPST TRIP P TIH to 6428', tag on depth. UPW=135K/ DNW=98K 173.0 6,428.0 1/8/2024 16:30 1/8/2024 18:00 1.50 SLOT, WHPST DISP P Displace 8.5 ppg seawater out of hole with 11.6 ppg LSND mud. 6,428.0 6,428.0 1/8/2024 18:00 1/8/2024 20:30 2.50 SLOT, WHPST TRIP P POOH standing back DP in derrick. 6,428.0 173.0 1/8/2024 20:30 1/8/2024 21:00 0.50 SLOT, WHPST BHAH P LD BHA #60. Clean magnets and junk baskets. Both magnets and boot baskets were full. 173.0 0.0 1/8/2024 21:00 1/8/2024 22:00 1.00 SLOT, WHPST BHAH P MU CO BHA #61 (same BHA as #60) 0.0 173.0 1/8/2024 22:00 1/9/2024 00:00 2.00 SLOT, WHPST TRIP P TIH to 4490' at midnight. 173.0 4,490.0 1/9/2024 00:00 1/9/2024 01:00 1.00 SLOT, WHPST TRIP P TIH from 4490' to 6351'. PUW 135K/ SOW 100K. 4,490.0 6,428.0 1/9/2024 01:00 1/9/2024 03:00 2.00 SLOT, WHPST CIRC P Pump two 22 BBL HI vis sweeps SXS at 5BPM/1000 psi. Build a dry job to POOH. 6,428.0 6,428.0 1/9/2024 03:00 1/9/2024 05:30 2.50 SLOT, WHPST TRIP P TOOH from 6428' UWT 130K to 174' UWT 36K. 6,428.0 174.0 1/9/2024 05:30 1/9/2024 07:00 1.50 SLOT, WHPST BHAH P LD BHA #61 clean magnets and boot baskets. 174.0 0.0 1/9/2024 07:00 1/9/2024 08:30 1.50 SLOT, WHPST BHAH P PU BHA #62. Same as BHA #61 plus picking up 4 more magnets and float sub with ported float. 0.0 223.0 1/9/2024 08:30 1/9/2024 09:30 1.00 SLOT, WHPST SVRG P Service rig. Greaase crown, blocks, drawworks, topdrive and roughneck. 223.0 223.0 1/9/2024 09:30 1/9/2024 14:00 4.50 SLOT, WHPST TRIP P TIH w/float in string Filling every 5 stands 223.0 6,428.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 24/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/9/2024 14:00 1/9/2024 16:30 2.50 SLOT, WHPST CIRC P Brake Circulation, TIH slowly tag bottom @ 6,425', PUW 137 k, SOW 118 k Wash down to 6,427.3', recep pipe ~30' rotating 30-80 rpm 6,425' circulate SXS w/20 bbls sweeps x 2 Nothing observed at surface on either sweep 6,428.0 6,428.0 1/9/2024 16:30 1/9/2024 17:15 0.75 SLOT, WHPST TRIP P 6,428', PUH T/6,167', Slip and cut drill line. 6,428.0 6,167.0 1/9/2024 17:15 1/9/2024 20:00 2.75 SLOT, WHPST TRIP P Pump dry job 20 bbl/13.5 ppg, TOOH F/6,167' to surface. PUW 38K. 6,167.0 223.0 1/9/2024 20:00 1/9/2024 21:30 1.50 SLOT, WHPST BHAH P L/D BHA #62, inspect magnets 223.0 0.0 1/9/2024 21:30 1/9/2024 23:00 1.50 SLOT, WHPST BHAH P MU BHA #63 clean out assembly 0.0 234.0 1/9/2024 23:00 1/10/2024 00:00 1.00 SLOT, WHPST TRIP P Trip in hole from 234' to 2780' SOW 60K 234.0 2,780.0 1/10/2024 00:00 1/10/2024 03:00 3.00 SLOT, WHPST TRIP P Trip in hole from 2780' to 6427' PUW 130 k, SOW 95 k, Tag 20 k 6,428' 2,780.0 6,427.0 1/10/2024 03:00 1/10/2024 05:30 2.50 SLOT, WHPST WASH P Wash down @ 5 bpm/900 psi, recep pipe 80 rpm, 4k torque, pump 20 bbl sweeps x 2, on second sweep pump @ 8 bpm/1,850 psi, OWFF, pump dry job 13.5 ppg 6,427.0 6,427.0 1/10/2024 05:30 1/10/2024 08:00 2.50 SLOT, WHPST TRIP P TOOH w/CO BHA #63 F/6,427' T/Surface 6,427.0 193.0 1/10/2024 08:00 1/10/2024 10:00 2.00 SLOT, WHPST BHAH P L/D and inspect BHA Minor metal hair like on magnets Lower magnet a few large pieces M/T junk baskets-minor big pieces and one rock Confer with town team, unanimous decision - Run WS L/D CO Assembly 193.0 0.0 1/10/2024 10:00 1/10/2024 13:00 3.00 SLOT, WHPST BHAH P M/U WS/Milling assembly BHA #64 0.0 198.0 1/10/2024 13:00 1/10/2024 18:30 5.50 SLOT, WHPST TRIP P TIH, stand #3 Surface test (good test), continue to trip in hole. 130K PUW/ 95K SOW 198.0 6,380.0 1/10/2024 18:30 1/10/2024 19:00 0.50 SLOT, WHPST WPST P Set whipstock per Baker rep. Set down on anchors with 12K. PU 10K over to ensure set. Set down 30K and shear out of whipstock. 6,380.0 6,409.0 1/10/2024 19:00 1/10/2024 23:30 4.50 SLOT, WHPST MILL P MIlling window per Baker rep from 6409.5' to 6411.5'. 130K PUW, 95K SOW, 110KRWT, 80 RPM, 4.5 TQ off, 5- 8K TQ on, 1K WOB, 4BPM at 975psi. 6,409.0 6,412.0 1/10/2024 23:30 1/11/2024 00:00 0.50 SLOT, WHPST SVRG P Service the rig, C/O Hyd motor on Iron Roughneck. 6,412.0 6,412.0 1/11/2024 00:00 1/11/2024 05:30 5.50 SLOT, WHPST MILL P MIlling window per Baker rep from 6412'. 130K PUW, 95K SOW, 110KRWT, 80 RPM, 4.5 TQ off, 5-8K TQ on, 1K WOB, 4BPM at 975psi. 6,412.0 6,427.0 1/11/2024 05:30 1/11/2024 09:00 3.50 SLOT, WHPST MILL P Continue milling/drilling rat hole F/6,427' T/6,440' 80 RPM / 4.6K torque / 11 k WOB 6,427.0 6,440.0 1/11/2024 09:00 1/11/2024 10:45 1.75 SLOT, WHPST MILL P Continue milling/drilling rat hole F/6,440' T/6,448' Pumping 4.0 bpm/67 spm/1,016 psi - mud pump #1 Rot=81 rpm / 4,800 ft-bls torque 6,440.0 6,448.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 25/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2024 10:45 1/11/2024 11:30 0.75 SLOT, WHPST REAM P Back ream window exit Rot=80 rpm / 4 k torq / pumping 4.0 bpm / 973 psi PUW=120 k, SOW 94 k Stop Rot, clean pass through window exit 6,448.0 6,448.0 1/11/2024 11:30 1/11/2024 13:00 1.50 SLOT, WHPST CIRC P 6,445' park and circulate 20 bbl sweep around Pull above window, circulate 20 bbls sweep BU 6,448.0 6,400.0 1/11/2024 13:00 1/11/2024 15:45 2.75 SLOT, WHPST TRIP P TOOH 6,400.0 198.0 1/11/2024 15:45 1/11/2024 18:30 2.75 SLOT, WHPST BHAH P L/D Window Miling Assembly 198.0 0.0 1/11/2024 18:30 1/11/2024 19:00 0.50 SLOT, WHPST SVRG P Service rig 0.0 0.0 1/11/2024 19:00 1/11/2024 21:30 2.50 SLOT, WHPST BHAH P MU drilling BHA. 0.0 354.0 1/11/2024 21:30 1/12/2024 00:00 2.50 SLOT, WHPST TRIP P TIH from 354 tp 5580'. At 383' SOW 38K. Perform shallow hole test at 825', 5 BPM at 1000psi, Good test. 354.0 5,580.0 1/12/2024 00:00 1/12/2024 00:30 0.50 SLOT, WHPST TRIP P TIH from 5580 to 6340'. 120K PUW/90K SOW 5,580.0 6,340.0 1/12/2024 00:30 1/12/2024 06:00 5.50 SLOT, WHPST CIRC T Circulate SXS 2BPM at 900 psi. Decision made to not drill ahead and open the time sensitive shales until after phase 3. 6,340.0 6,340.0 1/12/2024 06:00 1/13/2024 00:00 18.00 SLOT, WHPST CIRC T Continue to circulate lowering the pump rate to 60 gpm Phase 2 weather conditions. Called phase 3 at 20:30. Off highline power at 20:30. 6,340.0 6,340.0 1/13/2024 00:00 1/13/2024 16:30 16.50 SLOT, WHPST WAIT T Wait on Phase 3 weather 6,340.0 6,340.0 1/13/2024 16:30 1/13/2024 18:00 1.50 PROD1, DRILL DDRL P Kelly up at 6344' UPW 130/ DNW 95. Orientate tool face and slide through window. Stage pump to 180 GPM at 1460 psi. Start slide drilling at 6447' as per DD. 6,340.0 6,447.0 1/13/2024 18:00 1/13/2024 22:00 4.00 PROD1, DRILL DDRL P Drill F/6447' T/6498'. PUW 125K/SOW 95K, WOB10-20K, 6 BPM at 1940 psi off bottom/2100 psi on bottom. 6,447.0 6,498.0 1/13/2024 22:00 1/13/2024 23:00 1.00 PROD1, DRILL DDRL P Drill F/6498' T/6534'. PUW 125K/SOW 105K/ RWT 105K/ 40 RPM/ 4.8K TQ Off bottom/ 5.4K TQ on bottom. WOB10- 20K, 6 BPM at 1940 psi off bottom/2250 psi on bottom. Take survey @ 6515'. 6,498.0 6,534.0 1/13/2024 23:00 1/14/2024 00:00 1.00 PROD1, DRILL DDRL P Take survey, slide drill F/6534' T/6546' per DD. PUW 125K/SOW 95K/ WOB 5- 10K/ 6 BPM at 1940 off bottom and 2100 psi on botom. Mud wt 11.5+ ppg. 6,515.0 6,546.0 1/14/2024 00:00 1/14/2024 02:00 2.00 PROD1, DRILL DDRL P Slide Drill F/6,546' T/6,589' per DD. 125 k PUW, 95 k SOW, 5-10 k WOB, 112 GPM, 2050 psi off bottom, 2,170 psi on bottom, Take survey @ 6,568', Mud wt 11.5+ ppg. 6,546.0 6,568.0 1/14/2024 02:00 1/14/2024 03:00 1.00 PROD1, DRILL DDRL P Rotary Drilling F/6,589' T/6,630' as per DD, 125 k PUW, 90 k SOW, 105 RWT, 50 rpm, 5 k TQ off bottom, 5.8 k TQ on bottom, 5-8 k WOB, 112 GPM, 2,050 off bottom, 2,300 on bottom 6,568.0 6,630.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 26/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/14/2024 03:00 1/14/2024 05:00 2.00 PROD1, DRILL DDRL P Slide Drill F/6,630' T/6,710' AS per baker DD - 125 k PUW, 90 k SOW, 5-10 k WOB, 112 GPM, 2,100 psi off bottom, 2,220 psi 6,630.0 6,710.0 1/14/2024 05:00 1/14/2024 06:00 1.00 PROD1, DRILL DDRL P Rotary Drill F/6,710' T/6,724' as per baker DD, 125 k PUW, 90 k SOW, 105 k RWT, 50 RPM, 5 k TQ Off, 5.8 k TQ on, 5-8 k WOB, 112 GPM, 2,050 psi off, 2,300 psi on bottom, Take Survey @ 6,724' 6,710.0 6,724.0 1/14/2024 06:00 1/14/2024 09:30 3.50 PROD1, DRILL DDRL P Slide Drill F/6,724' T/6,816', as per Baker DD, PUW 131 k, SOW 95 k, 5 k WOB, 111 gpm, 2,050 psi off bottom, 2,240 psi on bottom, Take survey @ 6,749', 11.5+ ppg Mud Wt. Continue Slide Drill F/6,816' T/6,870' 6,724.0 6,870.0 1/14/2024 09:30 1/14/2024 11:15 1.75 PROD1, DRILL DDRL P Rotary Drill, F/6,870' T/6,912' as per Baker DD, PUW 131 k, SOW 95 k, 100 k RWT, 50 RPM, 4.8 k TQ off, TQ 5.5 k on bottom, 113 gpm, 6,870.0 6,912.0 1/14/2024 11:15 1/14/2024 12:15 1.00 PROD1, DRILL DDRL P PU stand, Rotary Drill F/6,912' T/7,000' as per Baker DD, PUW 125 k, SOW 87 k, 107 k RTW, 50 rpm, 10 k WOB, TQ on bottom 6,100 lbs, TQ off bottom 5.7 k, 11.5 ppg LSND 6,912.0 6,940.0 1/14/2024 12:15 1/14/2024 13:30 1.25 PROD1, DRILL DDRL P Rotary Drill F/6,940' T/7,005' as per Baker DD, jWOB 5-10 k WOB, GPM=270, Psi On bottom 2,300 psi, Off bottom 2,100 psi, Rot 50 rpm,TQ on bottom 6.4 k, TQ off bottom 5.2 k, PUW 125 k, SOW 87 k, RTW 107 6,940.0 7,005.0 1/14/2024 13:30 1/14/2024 17:00 3.50 PROD1, DRILL CIRC P Clean hole, recep pipe, swap hole over to 13.4 ppg LSND Mud w/40 bbl sweep 7,005.0 7,005.0 1/14/2024 17:00 1/14/2024 19:00 2.00 PROD1, DRILL DDRL P Rotary Drill F/7,005' T/7023 as per Baker DD, WOB 10-13 k, 80 RPM, TQ 4,000 lbs off bottom, TQ on bottom 5040lbs, GPM 160, PSI off bottom 1,300, PSI on bottom 1570, ECD 14.6 ppg, UPW 130K/DNW 97K/RTW 109K. Drilling break and take losses at 7022'. 7,005.0 7,023.0 1/14/2024 19:00 1/14/2024 22:30 3.50 PROD1, DRILL DISP P PU off bottom and establish loss rate of 190 BPH at 4 BPM.Shut down pumps and monitor well for flow, track and verify flow is slowing down. Circulate 2BPM at 800 psi with 1 BPM losses. Mix LCM pill and cut mud WT back from 13.55 ppg tpo 13..40 ppg. 7,023.0 7,023.0 1/14/2024 22:30 1/15/2024 00:00 1.50 PROD1, DRILL CIRC P Pump 40 bbl LCM pill followed by 13.4 ppg LSND. PUmp 2 BPM at 840 psi, spot pill on bottom. Close Annular and pump down kill line to squeeze pill into formation at 1.5 BPM not to exceed 420 psi (14.7 ppg ECD equivalnt). 7,023.0 7,023.0 1/15/2024 00:00 1/15/2024 00:30 0.50 PROD1, DRILL CIRC P Sqeeze 40 bbl LCM pill followed by 13.4 ppg LSND. PUmp 2 BPM at 840 psi, spot pill on bottom. Close Annular and pump down kill line to squeeze pill into formation at 1.5 BPM not to exceed 420 psi (14.7 ppg ECD equivalnt). 7,023.0 7,023.0 1/15/2024 00:30 1/15/2024 02:30 2.00 PROD1, DRILL OWFF P Watch for flow to decrease to zero then open Annular. 7,023.0 7,023.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 27/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2024 02:30 1/15/2024 03:45 1.25 PROD1, DRILL DDRL P On bottom drilling from 7023' to 7053' with losses at 106 bph (74.2 gpm). Pumping 145 gpm at 14.3 ECD. PUW 130K, SOW 95K, RWT 110K, 10-15K WOB, 40 RPM, 4.5K TQ Off bottom, 5.2K TQ on bottom, 1350 psi off bottom and 1450 psi on bottom. 7,023.0 7,053.0 1/15/2024 03:45 1/15/2024 06:00 2.25 PROD1, DRILL CIRC T Pick up off bottom, watch well for flow. Then circulate at minimum rate until we can get more 13.4 ppg mud wieghted up and/or the 2 trucks of 13.4 ppg mud get here. No losses while only pumping 67 gpm. 7,053.0 7,053.0 1/15/2024 06:00 1/15/2024 12:15 6.25 PROD1, DRILL CIRC T Continue circulating off bottom, 60 gpm, with minimal losses (4 bph), 749 psi, Continue weighting up 11.5 ppg to 13.4 ppg. 7,053.0 7,053.0 1/15/2024 12:15 1/15/2024 14:30 2.25 PROD1, DRILL DDRL P Rotary Drill F/7,053' T/7,104.8' as per Baker DD, WOB 10-13 k, 58 RPM, TQ 5,500 lbs off bottom, TQ on bottom 7,300 lbs, GPM 156, PSI off bottom 1,480, PSI on bottom 1830, ECD 14.3 ppg, UPW 130K/DNW 97K/RTW 109K. Short Drilling break @ 7,061' 7,053.0 7,105.0 1/15/2024 14:30 1/15/2024 17:30 3.00 PROD1, DRILL DDRL P Make connection, 7,105', Rotary Drill F/7,105' T/7,141' as per Baker DD, WOB 5-10 k, 58 RPM, TQ 5,100 lbs off bottom, TQ on bottom 6,000 lbs, GPM 135, PSI off bottom 1,580, PSI on bottom 2,042, ECD 14.7 ppg, PUW 126K/SOW 97K/RTW 60K. 7,105.0 7,141.0 1/15/2024 17:30 1/16/2024 00:00 6.50 PROD1, DRILL DDRL P Rotary Drill F/7,141' T/7,220' as per Baker DD, WOB 33-35 k,70 RPM, TQ 5,600 lbs on bottom, TQ off bottom 5,000 lbs, GPM 148, PSI off bottom 1,480, PSI on bottom 2,107 psi, ECD 14.5 ppg, UPW 130K/DNW 97K/RTW 109K. Short Drilling break @ 7,061' 7,141.0 7,220.0 1/16/2024 00:00 1/16/2024 18:00 18.00 PROD1, DRILL DDRL P Drilling ahead on losses. F/ 7220 TD 7560' Losses @ 45 bbls/hr 7,220.0 7,560.0 1/16/2024 18:00 1/16/2024 21:00 3.00 PROD1, DRILL CIRC P Circulate hole clean while recip pipe , pump 20 bbl sweeps X 2 , 100 vis with 40 lbs/bbl LCM, continue to circulate hole clean, losses down to 10 bbls/hr, 7,560.0 7,560.0 1/16/2024 21:00 1/16/2024 21:15 0.25 PROD1, DRILL OWFF P Flow check well 15 min // Flow out drop to 31% stabilized not decreasing still showing cuttings across shaker 7,560.0 7,560.0 1/16/2024 21:15 1/17/2024 00:00 2.75 PROD1, DRILL CIRC P Circulate B/U @ 3.5 bbls/min , pump away all fluid gained on flow check, mud wt at B/U 13.4 in and out still getting cuttings, lower pump rate to 1 bbl/min to relax formation while building sweeps // 1 bbls/min @ 661psi Retrun flow 29% 7,560.0 7,560.0 1/17/2024 00:00 1/17/2024 01:00 1.00 PROD1, DRILL CIRC P Continue circulating @ 1 bbl/min while building sweeps, 1 bbl/min @ 663 psi 29% return flow rate, Mud wt. 13.4 in and out 42 vis 7,560.0 7,560.0 1/17/2024 01:00 1/17/2024 02:30 1.50 PROD1, DRILL CIRC P Pump sweeps 13.4 ppg @ 90 vis // 3.5 bbls/min @ 1300 psi 32.5% 7,560.0 7,560.0 1/17/2024 02:30 1/17/2024 04:30 2.00 PROD1, DRILL OWFF P Shut down pumps OWFF, well still flowing , shut in well observe 140 psi pressure build up, blow down TD allow well to breath, continue to flow, shut in well observe 140 psi build. 7,560.0 7,560.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 28/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/17/2024 04:30 1/17/2024 10:30 6.00 PROD1, DRILL CIRC P Circulate 2 BPM down DP taking returns through choke to pits. Maintaining 13.4 ppg mud in and out. 7,560.0 7,560.0 1/17/2024 10:30 1/17/2024 18:30 8.00 PROD1, DRILL OWFF P Shut down pumps. Close annular bag for 10 minutes and write down the casing pressure. Open the supper choke, taking returns to trip tank for 15 minutes and write down the amount returned or lost. Open well to circulate clean 7,560.0 7,560.0 1/17/2024 18:30 1/17/2024 19:30 1.00 PROD1, DRILL OTHR P Work stuck pipe apperar to be packed off // Turn on pumps 3 bbls / min @ 1300 psi // Torque stalled out with 10rpm 10K torque // Work pipe down hole free up on 3rd attempt 7,560.0 7,560.0 1/17/2024 19:30 1/18/2024 00:00 4.50 PROD1, DRILL COND P Condition mud back to 13.4 in and out // 12.9 observed at shakers // excessive cuttings at shaker build sweeps to clean hole // 60 spm @ 1300 psi Up wt 120K Dn 115K 7,560.0 7,560.0 1/18/2024 00:00 1/18/2024 09:00 9.00 PROD1, DRILL COND P Condition mud to 13.7 ppg // Sweeps cleaned up hole // Pump 13.7 @ 1.5 bpm to control losses 700 psi pump pressure // Rot 10 rpm while circulating heavy mud 7,560.0 7,560.0 1/18/2024 09:00 1/18/2024 10:30 1.50 PROD1, DRILL Flow check. 7,560.0 7,560.0 1/18/2024 10:30 1/18/2024 18:00 7.50 PROD1, DRILL JAR T Work pipe 7,451.0 7,451.0 1/18/2024 18:00 1/18/2024 18:30 0.50 PROD1, DRILL SVRG T Stop jarring to inspect TD and Derrick // Total jar hits 142 // 7,451.0 7,451.0 1/18/2024 18:30 1/18/2024 21:30 3.00 PROD1, DRILL DISP T Trap 10K TQ in string, work DN to 50K on hook Work pipe up to 200-205K 10K TQ trapped in string Note @ 19:11 HRS start pumping 13.4 PPG mud down hole @ 1.4 BPM 830 PSI, 2 BPM 966 PSI Note @ 19:45 HRS 13.4 PPG mud out of the bit Continue to work pipe down with 10K TQ trapped in string 7,451.0 7,451.0 1/18/2024 21:30 1/19/2024 00:00 2.50 PROD1, DRILL JAR T Work torque into string 10K RH Torque // Jar down on string 50K down wt // 22:30- Release torque from drill string jar up // P/U 250K jars hit straight pull to 300K 15 Jar hits up no movement // Pump 30 bbl sweep 100 vis // 12:00- Swap to running down with torque in string prepping for LVT pill 7,451.0 7,451.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 29/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/19/2024 00:00 1/19/2024 02:30 2.50 PROD1, DRILL JAR T Circulate 30 bbls sweep around, 00:00 - Start jarring down with 10K RH torque in pipe 01:15 - Pump 5 bbls LVT 6.9# to bit and spot out around BHA 1BBL at a time // 5 bbls cover ~413' of open hole around BHA (Delta TVD ~ 246' Delta pressue 83 psi) 01:30 - Spot 2 bbls LVT out in open hole jar down 5 times no movement let soak 10 min Jar 5 times let soak 10 min Jar 5 times, pump 2 more bbls out in hole jar down 5 times let soak 10 min jar down 5 times pump 2 bbls out in hole all LVT in hole jar down 5 times no movement ( jars stop fireing in down direction ) 7,451.0 7,451.0 1/19/2024 02:30 1/19/2024 03:30 1.00 PROD1, DRILL CIRC T Circulate light LVT out of well, work pipe while circulating // Pump rate 3.5 bbls/min @ 1078 psi *****Jars quit firing up or down***** 7,451.0 7,451.0 1/19/2024 03:30 1/19/2024 06:00 2.50 PROD1, DRILL CIRC T Circulate S x S ensure 13.4 ppg in and out at 3BPM and 980 psi.Pump 35 bbl 13.4 ppg nutplug pill. 7,451.0 7,451.0 1/19/2024 06:00 1/19/2024 09:30 3.50 PROD1, DRILL JAR T Work stuck pipe, 2-3 BPM at 940-1050 PSI. Torque Pipe to 10K lock in and attempt to drive down, set all weight down, pulled to 250K up, chase down,jars not working. 7,451.0 7,451.0 1/19/2024 09:30 1/19/2024 10:00 0.50 PROD1, DRILL SVRG T Conduct derrick jarring inspection. 7,451.0 7,451.0 1/19/2024 10:00 1/19/2024 12:00 2.00 PROD1, DRILL JAR T Jars started working in up stoke, continue jarring. Fire at 200K up pull to 360K pumping 2-3 BPM at 950 PSI. Shut pumps off, no change, attempt to TQ in pipe drive down no change 7,451.0 7,451.0 1/19/2024 12:00 1/19/2024 17:30 5.50 PROD1, DRILL JAR T Continue jarring, fire at 200K up, pull to 360K, Pumping 2-3 BPM at 950 psi,shut pumps off, no change, attempt10K torque in pipe and drive down no change. MWT = 13.4 ppg, attempt to jar down set at 125K up jar down, All string weight 83K,with and without 9K TQ in string, without pumps. 7,451.0 7,451.0 1/19/2024 17:30 1/19/2024 18:00 0.50 PROD1, DRILL SVRG T Conduct derrick inspection 7,451.0 7,451.0 1/19/2024 18:00 1/19/2024 19:00 1.00 PROD1, DRILL CIRC T Circulate while rigging up LRS // build 30 bbl bead pill 2ppg 7,451.0 7,451.0 1/19/2024 19:00 1/19/2024 20:15 1.25 PROD1, DRILL CIRC T Pump 30 bbls sweep with 2ppg beads // follow that with 8 bbls dead crude// line up mud pump spot dead crude around BHA 1300 stks Pump rate 3 bbls/min @ 1218 psi Spot dead crude with pipe in compression // Shut annular to hold around BHA 7,451.0 7,451.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 30/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/19/2024 20:15 1/19/2024 21:45 1.50 PROD1, DRILL JAR T Spot half of crud around BHA 5 bbls let soak 20:10- Crude spotted letting soak 20:40- Open up well work pipe down 5 times work pipe up 5 time no movement spot rest of crude 21:05- Let crude soak 21:30- Work pipe no movement 7,451.0 7,451.0 1/19/2024 21:45 1/19/2024 23:45 2.00 PROD1, DRILL CIRC T Circulate out dead crude, load 15 bbls dead crude in drill pipe, displace down to BHA let soak 23:45 - Crude spotted and soaking with pipe squatted ( Hook load 30K ) 7,451.0 7,451.0 1/19/2024 23:45 1/20/2024 00:00 0.25 PROD1, DRILL OTHR T Let crude soak around BHA 7,451.0 7,451.0 1/20/2024 00:00 1/20/2024 00:30 0.50 PROD1, DRILL OTHR T Let crude soak around BHA 7,451.0 7,451.0 1/20/2024 00:30 1/20/2024 01:00 0.50 PROD1, DRILL JAR T Work stuck pipe, 5 down hits 5 pulls to 360K // 10 down hits no movement // Spot second half of crude in open hole // 7,451.0 7,451.0 1/20/2024 01:00 1/20/2024 02:00 1.00 PROD1, DRILL OTHR T Let crude soak around BHA 7,451.0 7,451.0 1/20/2024 02:00 1/20/2024 02:30 0.50 PROD1, DRILL JAR T Work stuck pipe down w/ 10K RH torque // 10 down hits // 5 pick ups jars not fireing on up stroke 7,451.0 7,451.0 1/20/2024 02:30 1/20/2024 03:30 1.00 PROD1, DRILL CIRC T Circulate dead crude out of well 7,451.0 7,451.0 1/20/2024 03:30 1/20/2024 04:00 0.50 PROD1, DRILL CIRC T Circulate black magic pill down to bit spot 7 bbls around BHA 7,451.0 7,451.0 1/20/2024 04:00 1/20/2024 05:00 1.00 PROD1, DRILL WAIT T Let 7 bbls Black Magic soak around BHA 7,451.0 7,451.0 1/20/2024 05:00 1/20/2024 12:00 7.00 PROD1, DRILL JAR T Work stuck pipe for 30 minutes then pump 1 bbl Black Magic out of bit into open hole. Work stuck pipe for 30 more minutes then pump another bb1 of Black Magic and repeat for 13 bbls. 7,451.0 7,451.0 1/20/2024 12:00 1/20/2024 19:00 7.00 PROD1, DRILL ELNE T RU Eline for a string shot back off at the IF connection right below the jars. Put 7K (70% of 10K 3-1/2"IF connection) left hand torque into the drill pipe. RIH and string shot at 7220'. 7,451.0 7,451.0 1/20/2024 19:00 1/20/2024 20:30 1.50 PROD1, DRILL ELNE T RIH with E-line log for depth control set up for spotting Black magic pill 7,451.0 7,451.0 1/20/2024 20:30 1/20/2024 21:15 0.75 PROD1, DRILL CIRC T Spot 13.7 Black Magic pill around BHA 7,451.0 7,451.0 1/20/2024 21:15 1/20/2024 22:00 0.75 PROD1, DRILL ELNE T Secure floor and equipment for shooting string shot // 7339.1 ELD XO above well commander // Fire string shot @ 22:00 7,451.0 7,451.0 1/20/2024 22:00 1/20/2024 23:00 1.00 PROD1, DRILL ELNE T Rig up lines to grease head // POOH with E-Line to inspect tools // Indicated good fire on string shot 7,451.0 7,451.0 1/20/2024 23:00 1/20/2024 23:30 0.50 PROD1, DRILL RURD T Stand back e-line equipment prep to check for free pipe 7,451.0 7,451.0 1/20/2024 23:30 1/21/2024 00:00 0.50 PROD1, DRILL OTHR T Make up TD to string // Introduce back torque into string 9K LH indicated on rig watch // work torque down to bha while counting turns indication back off successful // 150k PU wt. // Pump 62 spm @ 700 psi ( MWD not turning on ) indication BHA left down hole 7,451.0 7,339.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 31/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/21/2024 00:00 1/21/2024 04:00 4.00 PROD1, DRILL TRIP T TOOH to window // Pu Wt 150 ( 110 while rotating ) // Trip out while pumping // tool joints hard to break had to use rig tongs to break 7,339.0 6,200.0 1/21/2024 04:00 1/21/2024 05:30 1.50 PROD1, DRILL TRIP T Circulate 13.4 ppg mud 4 BPM at 660 psi. SxS 6,200.0 6,200.0 1/21/2024 05:30 1/21/2024 06:00 0.50 PROD1, DRILL OWFF T Flow check. Still has a little flow, but is dying. 6,200.0 6,200.0 1/21/2024 06:00 1/21/2024 08:00 2.00 PROD1, DRILL CIRC T Circulate 13.4 ppg mud 4 BPM at 660 psi. SxS 6,200.0 6,200.0 1/21/2024 08:00 1/21/2024 09:00 1.00 PROD1, DRILL OWFF T Flow check. Well static. Pump 15 bbl slug. 6,200.0 6,200.0 1/21/2024 09:00 1/21/2024 14:00 5.00 PROD1, DRILL TRIP T POOH from window standing back Drill Pipe. UPW=110K 6,200.0 0.0 1/21/2024 14:00 1/21/2024 16:00 2.00 PROD1, DRILL RURD T RU to test BOPE, drain stack, fill stack and set test plug. 0.0 0.0 1/21/2024 16:00 1/21/2024 22:30 6.50 PROD1, DRILL BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = 115 sec. UVBR's= 5 sec, Annular= 25 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 2 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Kam StJohn 0.0 0.0 1/21/2024 22:30 1/21/2024 23:30 1.00 PROD1, DRILL RURD T Rig down test equipment and blow down choke manifold 0.0 0.0 1/21/2024 23:30 1/22/2024 00:00 0.50 PROD1, DRILL OTHR T Install wear bushing 0.0 0.0 1/22/2024 00:00 1/22/2024 01:30 1.50 PROD1, DRILL BHAH T Pick up and make up BHA #66 // Screw in sub, side port circ sub Min ID = 2.188" in side port circ sub Max OD= 5.125" XO from BHA to DP Screw in sub 3.5" IF with cut lip for guided entry, side port circ sub 3500 psi differential burst disc 0.0 196.0 1/22/2024 01:30 1/22/2024 05:30 4.00 PROD1, DRILL TRIP T TIH with drill pipe and fishing bha #66. UWT=125K, DWT=90K. 196.0 6,855.0 1/22/2024 05:30 1/22/2024 08:30 3.00 PROD1, DRILL CIRC T Wash down from 6855 to 7110'. 1 BPM at 300 psi. Work stuck pipe and jar free. 6,855.0 7,110.0 1/22/2024 08:30 1/22/2024 09:00 0.50 PROD1, DRILL CIRC T Reciprocate from 6855' to 6982'. Pump 2x bottoms up. 13.4 ppg in and 13.4 ppg out 7,110.0 6,855.0 1/22/2024 09:00 1/22/2024 11:00 2.00 PROD1, DRILL TRIP T TOOH from 6855' to 6316' UWT=120K, DWT=90K 6,855.0 6,316.0 1/22/2024 11:00 1/22/2024 11:30 0.50 PROD1, DRILL OWFF T Flow check, no flow. 6,316.0 6,316.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 32/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/22/2024 11:30 1/22/2024 12:00 0.50 PROD1, DRILL SVRG T Service rig 6,316.0 6,316.0 1/22/2024 12:00 1/22/2024 14:30 2.50 PROD1, DRILL TRIP T TOOH with fishing BHA #65. 6,316.0 199.0 1/22/2024 14:30 1/22/2024 15:30 1.00 PROD1, DRILL BHAH T LD fishing BHA #65 199.0 0.0 1/22/2024 15:30 1/22/2024 16:00 0.50 PROD1, DRILL BHAH T MU CO BHA #66 0.0 981.0 1/22/2024 16:00 1/22/2024 20:00 4.00 PROD1, DRILL TRIP T TIH with CO BHA #66 981.0 6,400.0 1/22/2024 20:00 1/22/2024 22:00 2.00 PROD1, DRILL CIRC T Circulate ensure mud in good shape for cleanout // 13.4 in and out 42 vis // 6,400.0 6,400.0 1/22/2024 22:00 1/23/2024 00:00 2.00 PROD1, DRILL REAM T Wash through window clean to 6435' reamer outside of window // Ream down 20 rpm 63 spm @ 760 psi // RIH @ 10'/min // Ream to 6580' 6,400.0 6,580.0 1/23/2024 00:00 1/23/2024 02:00 2.00 PROD1, DRILL REAM T Ream down 20 rpm 63 spm @ 760 psi string wt 100K // RIH @ 10'/min // Ream F/ 6580' T/ 6727' Stall and heavy pick ups @ 6696', 6702', and 6727' Last pick up at 6727' 100K over string wt work rot up to 40 rpm Phase called field wide PJSM trip out to shoe 6,580.0 6,727.0 1/23/2024 02:00 1/23/2024 03:00 1.00 PROD1, DRILL TRIP T TOOH to window Pump and back ream to window // 40 rpm 65spm @ 790 psi 6,727.0 6,400.0 1/23/2024 03:00 1/23/2024 11:00 8.00 PROD1, DRILL WAIT T Phase 3 waiting on weather Pump 1.5 bpm to keep fluid moving in casing 6,400.0 6,400.0 1/23/2024 11:00 1/23/2024 13:00 2.00 PROD1, DRILL CIRC T Build and pump dry job 6,400.0 6,386.0 1/23/2024 13:00 1/23/2024 15:30 2.50 PROD1, DRILL TRIP T TOOH F/6402' T/949.25 6,386.0 949.3 1/23/2024 15:30 1/23/2024 16:30 1.00 PROD1, DRILL BHAH T LD BHA per BOT rep F/949 T surface 949.3 0.0 1/23/2024 16:30 1/23/2024 17:00 0.50 PROD1, DRILL RURD T Clear BOT tools off rig floor that aren't required. 0.0 0.0 1/23/2024 17:00 1/23/2024 18:30 1.50 PROD1, DRILL RURD T Empty stack pull wear ring. 0.0 0.0 1/23/2024 18:30 1/23/2024 22:30 4.00 COMPZN, CEMENT RURD T RU to test BOP's 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 33/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/23/2024 22:30 1/24/2024 00:00 1.50 COMPZN, CEMENT BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 4" test joint, UVBR's, LVBR's w/4-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 4" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = XXX sec. UVBR's= X sec, Annular= XX sec. Simulated blinds= X sec. LVBR’s=5 sec. HCR choke & kill= 2 sec each. 5 back up nitrogen bottles average = XXXX PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Guy Cook 0.0 0.0 1/24/2024 00:00 1/24/2024 08:30 8.50 COMPZN, CEMENT BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 4" test joint, UVBR's, LVBR's w/4-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 4" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = XXX sec. UVBR's= X sec, Annular= XX sec. Simulated blinds= X sec. LVBR’s=5 sec. HCR choke & kill= 2 sec each. 5 back up nitrogen bottles average = XXXX PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Guy Cook 0.0 0.0 1/24/2024 08:30 1/25/2024 00:00 15.50 COMPZN, CEMENT RGRP T Remove and repair internal ram seal on UPR. Bonnett removed to truck shop for proper repair. 0.0 1/25/2024 00:00 1/25/2024 11:00 11.00 COMPZN, CEMENT RGRP T Remove and repair internal ram seal on UPR. Bonnett removed to truck shop for proper repair. Repairs completed, reinstalled completed and function tested. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 34/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/25/2024 11:00 1/25/2024 15:00 4.00 COMPZN, CEMENT BOPE T Continue testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 4" test joint, UVBR's, LVBR's w/4-1/2" and 4" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 4" XT39 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =15 sec, full recovery attained = 117 sec. UVBR's= 5 sec, Annular= 31 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test witness waived by AOGCC rep Guy Cook 0.0 0.0 1/25/2024 15:00 1/25/2024 16:30 1.50 COMPZN, CEMENT RURD T RD from testing blow down choke, mud manifold and kill lines empty stack. pull test plug. Install wear ring. fill stack with 13.4# LSND 0.0 0.0 1/25/2024 16:30 1/25/2024 17:00 0.50 COMPZN, CEMENT BHAH T PU Cement retainer. 0.0 13.7 1/25/2024 17:00 1/25/2024 22:30 5.50 COMPZN, CEMENT TRIP T TIH F/13.73' T/6379' Top of retainer at 6379' 13.7 6,380.0 1/25/2024 22:30 1/25/2024 23:30 1.00 COMPZN, CEMENT CIRC T Circulate S x S even out mud @ 13.4 6,380.0 6,380.0 1/25/2024 23:30 1/26/2024 00:00 0.50 COMPZN, CEMENT PRTS T Perform injection test // Pump 1 bpm initial break over and circ @ 750psi, bump pump rate up to 2 bpm pressure initially stabilize out @ 750 psi then climb to 1500 and hold // shut down pump no blead off // Open BOPs and circulate for plan forward 6,380.0 6,380.0 1/26/2024 00:00 1/26/2024 00:30 0.50 COMPZN, CEMENT PRTS T Close BOPs and perform injection test again // Pressure up 800 psi shut down pump pressure slowly bleed to 720psi over 2 min // Pressure up 1400psi break over down to 1200 psi @ 2 bpm, continue pumping pressure up again to 1400 psi pressure break over to 1100psi @ 2 bpm 6,380.0 6,380.0 1/26/2024 00:30 1/26/2024 03:00 2.50 COMPZN, CEMENT MPSP T Set cement retainer top @ 6379' // unable to set, pump, reverse pump, rotate while RIH, pick up and slack off multiple times // Rotate while moving up slips set TOR 6377' 6,380.0 6,379.0 1/26/2024 03:00 1/26/2024 06:00 3.00 COMPZN, CEMENT HOSO T Lay down 2 jts, pick up 30.47' of pups ( 5.15', 10.17', 10.15', 5.0' ) , pick up 1 full jt space out @ floor with full jt across BOPs // PT retainer ensure good set 500 psi no communication good test 6,379.0 6,377.0 1/26/2024 06:00 1/26/2024 06:30 0.50 COMPZN, CEMENT SFTY T PJSM with Nabors/HES/CPAI for pumping cement. 6,377.0 6,377.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 35/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/26/2024 06:30 1/26/2024 10:00 3.50 COMPZN, CEMENT CMNT T Line up HES. take on water start building lead spacer. Pump 10 BBL's 80* water ahead to warm lines. PT surface lines to 250/3500 PSI. Bleed off pressure good test. Open up to well start cement ops. HES PR 2BPM 7BBL 14 PPG spacer 1.5BPM 1200 PSI 52 BBL 15.3 PPG Cement 1BPM 950 PSI 720AM 20BBLS 700 PSI 40 BBL 444PSI 45 BBL 396 52 330PSI 10 BBL 8.5 H2O spacer 1BPM 370 Shut down HES cement. 818AM shut down Online with rig pump Chase cement at 1BPM 10 BBLs contaminate pill Swap to 9.5# CI displace 49 BBL's to formation final squeeze 1550 PSI Sting out of retainer pump 1BBL PUH to 6315 Lay in 2BBLs 15.3# at .5BPM PUH at 70 FPM. Complete displacing casing and DP W/210 BBLs 9.5# CI. 6,377.0 6,315.0 1/26/2024 10:00 1/26/2024 10:30 0.50 COMPZN, CEMENT OWFF T OWFF Well Static 6,315.0 6,315.0 1/26/2024 10:30 1/26/2024 11:30 1.00 COMPZN, CEMENT RURD T Break out DP, blow down cement manifold and cementing lines RD Cement X-O's and lay down space out pups. 6,315.0 6,290.0 1/26/2024 11:30 1/26/2024 13:30 2.00 COMPZN, CEMENT TRIP T TOOH for tag assembly 6,290.0 0.0 1/26/2024 13:30 1/26/2024 14:00 0.50 COMPZN, CEMENT BHAH T Pick up tag assembly, 6-1/8" rock bit w/ 1 stand collars 0.0 120.0 1/26/2024 14:00 1/26/2024 16:00 2.00 COMPZN, CEMENT TRIP T TIH to tag cement // Stop at 6300' to wait for state rep 120.0 6,300.0 1/26/2024 16:00 1/26/2024 18:00 2.00 COMPZN, CEMENT WAIT T Wait for state rep // Prep for laying down dp 6,300.0 6,300.0 1/26/2024 18:00 1/26/2024 21:30 3.50 COMPZN, CEMENT PRTS T Tag top cement w/ 10K WOB @ 6332' ( 45' good cement ) // Pressure test 2500 psi 30min good test AOGCC Witnessed Josh Hunt 6,300.0 6,332.0 1/26/2024 21:30 1/26/2024 23:30 2.00 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 6,332.0 4,000.0 1/26/2024 23:30 1/27/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig Grease DW 4,000.0 4,000.0 1/27/2024 00:00 1/27/2024 01:30 1.50 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 4,000.0 2,800.0 1/27/2024 01:30 1/27/2024 02:30 1.00 COMPZN, RPCOMP SVRG P Replace switch on iron roughneck 2,800.0 2,800.0 1/27/2024 02:30 1/27/2024 08:00 5.50 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 2,800.0 92.0 1/27/2024 08:00 1/27/2024 08:30 0.50 COMPZN, RPCOMP BHAH P LD BHA collars and Bit 92.0 0.0 1/27/2024 08:30 1/27/2024 13:30 5.00 COMPZN, RPCOMP PUTB P RIH with 4.5" 12.6# L-80 Hyd 563 kill string to 2304.32 0.0 2,304.3 1/27/2024 13:30 1/27/2024 14:00 0.50 COMPZN, RPCOMP THGR P MU hanger to string Land hanger RILDS 2,304.3 2,304.3 1/27/2024 14:00 1/27/2024 15:00 1.00 COMPZN, RPCOMP MPSP P Set BPV. RU LRS. LRS test under BPV to 1000 PSI 2,304.3 2,304.3 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 Page 36/36 2M-24 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/27/2024 15:00 1/27/2024 21:30 6.50 COMPZN, RPCOMP NUND P ND BOPE NU tree and adapter. P/T 5000 good test 2,304.3 2,304.3 1/27/2024 21:30 1/27/2024 23:00 1.50 DEMOB, MOVE FRZP P Line up pump 80 bbls diesel freeze protect with LRS 2,304.3 2,304.0 1/27/2024 23:00 1/28/2024 00:00 1.00 DEMOB, MOVE RURD P Rig down LRS let well u-tube **** Release rig 00:00 on 1/28/24 2,304.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/28/2024 DTTMSTART JOBTYP SUMMARYOPS 10/26/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 10/28/2023 ACQUIRE DATA BRUSH W/ 3-1/2 BLB TO ROCK SCREEN @ 6961' RKB. DRIFT W/ 2.75" DMY CEMENT RETAINER TO 6961' RKB, TIGHT SPOTS 5600-5700' RKB, PRESSURE UP TBG TO 2000 PSI UNABLE TO PUMP INTO WELL, SET 1.5" DMY IN ST#7 @ 6892' RKB, READY FOR COIL. 10/29/2023 ACQUIRE DATA MIRU, BOP TEST, CUT 250' OF PIPE, 8020' OF COIL REMAINING. SET CEMENT RETAINER AT 6925' RKB, MID JOINT. PRESSURED UP TO 5100 PSI, WELL HAS ZERO INJECTIVITY. WAIT ON ENGINEER TO DISCUSS WITH AOGCC. RIG DOWN AND STAGE UNIT ON 2M PAD FOR PLAN FORWARD. 10/31/2023 REPAIR WELL PULLED 1.5'' DMY VLV ST#7 6892' RKB, READY FOR COIL. 10/31/2023 REPAIR WELL PERFORM GENERAL MAINTENANCE WHILE STANDING BY ON EOP FOR SLICKLINE TO PULL DV. MIRU CTU 6 POST SLICKLINE. DRIFT COIL. RECOVER 1/2" BRASS BALL. MAKE UP TOOLS. 11/1/2023 REPAIR WELL MIRU TO PUMP BALANCED CEMENT PLUG. CIRC WELL OUT TO 9.8 PPG BRINE. PUMP 13 BBLS OF 15.8 PPG CLASS G CEMENT. PUMP 7.7 BBLS IN IA, LAY 5.3 BBLS ON TOP OF RETAINER. CLEAN OUT EXCESS CEMENT. ESTIMATED TOC 6600' RKB. READY FOR SLICKLINE TO FREEZE PROTECT WITHIN 24 HRS. 11/2/2023 REPAIR WELL PULLED DMY @ 3214' RKB. CIRC IN 70 BBLS DIESEL FOR FREEZE PROTECT. RE-SET DV @ 3214' RKB. TAGGED TOC @ 6559' RKB. READY FOR (AOGCC WITNESS 11/5/23) 11/3/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/5/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/6/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/7/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN PROGRESS). 11/12/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/13/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/14/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/15/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR (IN-PROGRESS) 11/17/2023 ACQUIRE DATA (PRE-RWO) BLEED OA FOR BUR IN PROGRESS. 11/23/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 6559' RKB, CONDUCT AOGCC WITNESSED (JOSH HUNT) CMIT TXIA TO 2820 PSI, ATTEMPT TO PULL DMY VALVE IN STA #5 @ 6094' RKB, SHUCK OFF VALVE, RUN CHECK SET TO ENSURE VALVE IS STILL IN POCKET... READY FOR ELINE TO MAKE CUT ON TBG 11/24/2023 ACQUIRE DATA TUBING CUT AT 6565' WITH WELLTECH MECHANICAL CUTTER, TOC TAGGED AT 6570' CCL TO BLADE: 18FT CCL STOP DEPTH: 6547' 11/25/2023 ACQUIRE DATA DRIFT W/ 2.83" GAUGE RING TO SSSV @ 1808' RKB, SET HOLD-OPEN SLEEVE ACROSS SSSV. JOB COMPLETE 12/2/2023 RECOMPLETION Tested tubing and casing, freeze protected well. RDMO 2M-15. MIRU on 2M-24. Accepted rig at 1400. bring on 8.6# seawater displace well @ 1.5 bpm due to limited flow path at weltec cut, flow check dead well, install ISA BPV 12/3/2023 RECOMPLETION Test BOPs, AOGCC witness waived Austin McLeod, rig down test equipment, test MWD connection on stand pipe, re-tighten, make up landing jt attempt to pull completion, no movement circulate S x S 12/4/2023 RECOMPLETION Rig up slick line, pull sleeve and run 2.29 ID Sleeve in hole, RIH with 2" RCT cutter, cut pipe @ 6180', lay down 1000' of tubing, well u-tube up pipe circulate well to remove bad cement and mud from system, attempt to drift casing unable to pass well head with 5.25 drift, lay down tubing to get control line out of well 12/4/2023 SUPPORT OTHER OPERATIONS ( RIG JOB ON 7ES, CHARGING TO NETWORK # 10451426) PULLED 2.83'' NO-GO HOLD OPEN SLEEVE(1.58''ID). RAN FLAPPER CHECKER ON SSSV @1808' RKB, UNABLE TO CATCH. SET 2.83'' NO-GO HOLD OPEN SLEEVE (OAL 64'')(ID 2.29''). READY FOR E-LINE & TBG CUT. 12/4/2023 SUPPORT OTHER OPERATIONS CUT 3.5" TUBING @ 6180' RKB W/ 2" RCT CUTTER, CCL TO CUTTER = 10.2', CCL STOP = 6169.8', RIG HAD PIPE MOVING AND RELEASED AKE ELINE. JOB COMPLETE. NETWORK # 10451426 NOTE: ACTUAL START TIME WAS 12/4/23 @ 4:30 AM. UNABLE TO HAVE WSR'S OVER-LAP TIME WITH SL WSR. 12/5/2023 RECOMPLETION Continue L/D 3.5" completion, unable to pull through tubing spool, P/U 4" GS, TIH on 3.5" singles drop off tubing on stump, set and test IBP, N/D BOPE , strech casing, M/U tubing spool, N/U/ test BOPE break, pull test plug, set wear ring, TIH to retrieve IBP 12/6/2023 RECOMPLETION Pull IBP, L/D pulling tools, M/U grapple, TIH w/3.5" tubing out of derrick, pull/LD 3.5" completion, TIH w/DP, overshot, latch onto fish jar 56 times, and straight pull to 95%-264 k, no movement, TOOH F/6,158' T/2,780' 12/7/2023 RECOMPLETION Continue TOOH F/2,780', L/D BHA and DC, M/U overshot, TIH w/DP, rotate over stump, R/U E-line, log CBL 12/7/2023 ACQUIRE DATA PERFORM CBL. TOP OF CEMENT FOUND AT 6260'. JOB IN PROGRESS 12/8/2023 RECOMPLETION E-line, log CBL, perform RTC cut @ 6,278', POOH-R/D w/E-line, P/U fishing tools, TIH, jar on fish 86 hits, no movement, rotate off fish, TOOH, L/D fishing tools, P/U burn shoe w/4 jts of wash pipe, set down @ 255' 12/8/2023 ACQUIRE DATA CUT TUBING WITH 2" RCT AT 6278.0', CCL TO CUTTER = 13.1', CCL STOP DEPTH = 6264.9' 12/9/2023 RECOMPLETION Work wash pipe, unable to pass, stand back wash pipe, and lay down BHA, drift well w/5.95" swedge/6.10" swedge. Run CBL w/E-line F/6,170 T/350', E-line caliper failure, trouble shoot tools 12/9/2023 ACQUIRE DATA RUN 1: LOG CBL IN 7" CASING FROM 6175' - SURFACE. TOP OF CEMENT FOUND AT 2000' RUN 2: PERFORM READ 40 ARM CALIPER FROM 6175' - 350', TOOLS STOP WORKING. POOH TO TROUBLESHOOT AND SWAP TO MEMORY TOOLS, JOB IN PROGRESS 12/10/2023 RECOMPLETION M/U 40 arm caliper on memory, RIH, log 7" F/350' T/surface, R/D E-line, P/U & set G-lock, test plug T/2,500 psi, TOOH, L/D setting tools, N/D BOPE & Adaptor, remove packoff, spear 7" casing, pull into tention 185k over blocks, drift casing through damaged casing area, unable to drift 253', TOOH, L/D wash pipe, N/U BOPE/Adaptor, TIH F/surface T/2250', dump ~50' of sand on plug, 12/10/2023 ACQUIRE DATA JOB CONTINUED FROM 12/09/2023. CONTINUE RIGGING UP MEMORY CALIPER. FINISH LOG FROM 350' TO SURFACE. 2M-24 Summary of Operations 12/11/2023 RECOMPLETION TOOH, L/D Bull nose, M/U MSC, RIH T/1,786', cut casing, Space out, R/U LRS, Open well to LRS. Attempt to circulate down 7" casing up the OA. stage up to 1200 PSI no circulation. Work pipe PU WT= 215K. Stage up to 2000 PSI established circulation. Close rams and attempt to circulate work pressure up to 2000 PSI. Continue to maintain 2000 PSI. Slowly moving fluid to kill tank. Pressure locked at 2200 PSI. Pressured up and relieved the pressure cycling back and forth attempting to regain circulation. unable to make any progress. Held 2000 PSI on casing for 15 minutes no change. Bled off casing. discussed options with town engineer. Decision point to pull slips out of wellhead. 12/12/2023 RECOMPLETION Try to pull casing free, RIH with a tubing punch to regain circulation and circulate arctic pack out of the hole. Failed to circulate, RIH with MSC to cut casing at 420' circulate and pull casing out of hole. 12/12/2023 ACQUIRE DATA RUN 1: CASING PUNCH INTERVAL: 580' - 583', CCO TO TOP SHOT = 6.6', CCL STOP DEPTH = 573.4' RUN 2: CASING PUNCH INTERVAL: 830' - 833', CCL TO TOP SHOT = 6.6', CCL STOP DEPTH = 823.4' 12/13/2023 RECOMPLETION ND BOPE, pull casing slips, NU BOPE swaping lower rams to 7", Pull 7" from 428'. RIH spear 7" casing and try to jar free. 12/14/2023 RECOMPLETION MU MSC and RIH and cut 7" casing at 925', 1566' and again at 1786' and pull casing from 1566'. 12/15/2023 RECOMPLETION Finish pulling casing from 1786'. Wash and ream 9-5/8" down to 1000' 12/16/2023 RECOMPLETION Test BOPE. MU BHA with string mills to clean up 9-5/8"casing. 12/17/2023 RECOMPLETION Mill 9-5/8" casing and TOOH. MU and RIH to dress 7" tubing stub at 1786'. Would not drift. MU mills and go back to washing and reaming. 12/18/2023 RECOMPLETION Milled 9-5/8" casing F/250' T/865', drifted to tubing stump F/865' T/1,780', circulated high vis sweep, TOOH, L/D milling assembly, P/U drift/dress off BHA#35, drifted and dressed top of 7" stump F/surface T/1,787.3', TOOH, L/D drift assembly 12/19/2023 RECOMPLETION L/D dress off BHA #35, Run & cement 7" casing. 12/20/2023 RECOMPLETION Completed nipple up of BOPs, Perform full bop test 250/4000 witnessed by AOGCC Austin McLeod, pick up plug mill bha, tih mill out cement plug, unable to make progress on plug, 12/21/2023 RECOMPLETION Upon inspection of mill looked to be bolt impression, attempt fish with RCJB and Magnet, no fish, pick up rock bit TIH start milling @ 1775' 12/22/2023 RECOMPLETION Complete milling out cement plug, TOOH pick up and run RCJB 2 runs, pick up and run g-lock retrieval tool, TIH tag sand @ 2338' circulate sand off of plug 12/23/2023 RECOMPLETION Unable to get to plug with pulling assembly, complete 2 more runs with RCJB, first run lost fingers, picked up second RCJB with larger offset from end of tool to fingers, TIH able to wash to top of plug, TOOH pick up retrieval tools, latch into plug pull to surface, over pull till above cement tool in 7 in 10K - 15K , rig up to test casing 12/24/2023 RECOMPLETION Pressure test casing 2500 psi 30 min good test, pick up wavy bottom burn shoe TIH mill around casing, Top of fish 6180, top of cement 6190, mill to 6211 unable to make progress, tooh inspect mill found to be stress fractured and all of cutting material gone, pick up burn shoe with larger ID 4.75" and TIH with burn shoe and 120' wash pipe, start milling @ 6211' to 6229' 12/25/2023 RECOMPLETION Continued to mill down to 6242', progress slowed, pump hole clean with sweeps, TOOH to inspect BHA, found ~60' of 3.5" completion in wash pipe, lay down and inspect washpipe, pick up burn shoe, TIH w/ 6" OD 4.75" ID burn shoe, mill T/ 6256' progress slowed pump sweeps to clean hole 12/26/2023 RECOMPLETION Circ hole clean, TOOH T/6050', perform casing test 2500 psi for 30 min, could not get pipe to bleed off indicating partial plug of washpipe, TOOH and recovered 18' of 3.5" tubing, Test casing 2500 15min good test, pick up wash over assembly RIH and continue to mill over completion T/ 6278', torque spikes and unable to proceed, sweep hole, attempt trip out pull heavy @ 6240', work back in hole attempt to mill again no progress, tooh hang up @ 6240' wait for jars to hit, prior to jars hitting popped free, TOOH T/ 6050' circulate sweep ensure hole clean 12/27/2023 RECOMPLETION Inspect BHA, portion of fish was recovered in wash pipe. Attempt to burn over top of tubing, unable to pass 6278'. Routine slip and cut drilling line. TOOH for junk mill run, lay down washpipe bha recover two 8' slabs from washpipe, pick up junk mill BHA# 53, TIH start milling F/ 6277' 12/28/2023 RECOMPLETION Continue milling with 6.125" junk mill F/6277', perform wipers and sweeps as needed T/ 6535' 12/29/2023 RECOMPLETION Milled to 6341' 7ES RKB. TOOH for bit. gauged 6.125" OD face worn some carbide left. TIH and continue milling F/6341' T/ 6348 12/30/2023 RECOMPLETION Continued milling ahead F/6348' T/ 6387' 12/31/2023 RECOMPLETION Continued milling F/ 6387' T/ 6394' , unable to proceed, tooh pulling heavy, pump out of the hole, change BHA, RIH with 6-1/8" junk mill, TIH T/ 6100' 1/1/2024 RECOMPLETION Trip in hole tag bottom @ 6394', get perameters and mill ahead T/ 6427.35', pressure spike, TOOH to inspect BHA found 8' of spiral tubing cored into mill and up into BHA, lay down BHA clean floor 1/2/2024 RECOMPLETION Cleaned out to 6427' with cleanout BHA., trip out of hole set storm packer @ ~1730' for BOP test, phase 3 called on 2M pad, pull packer circulate well 1/3/2024 RECOMPLETION Waited on weather 1/3/2024 SUPPORT OTHER OPERATIONS 1/4/2024 RECOMPLETION Waiting on weather 1/5/2024 RECOMPLETION Waiting on weather 1/6/2024 RECOMPLETION Continue to wait on weather conditions to improve and for roads to be cleared, 04:30 phase conditions lifted, re-build storm packer and set @ 65', rig up and perform full bop test 250/4000 , retrieve storm packer circulate SxS pump pressure steady increase, blow down TD, TOOH, lay down BHA and inspect, found 1/2 bucket of metal on magnet and bootbaskets, rig up E- line tag cement 6448' ELM , log cement T/ 6290' ELM 1/6/2024 ACQUIRE DATA STANDBY FOR RIG, RIG UP CBL AND RIH. JOB IN PROGRESS 1/7/2024 ACQUIRE DATA JOB CONTINUED FROM 01/06/2024 RUN 1: PERFORM CBL FROM 6433' - 6000'. TOP OF CEMENT FOUND AT 6250' RUN 2: PERFORM 40 ARM CALIPER FROM 6440' - 6000' 1/7/2024 RECOMPLETION Complete CBL/CCL run, pick up caliper, caliper TD up to 6000', pull caliper out of hole rig down E-line, Phase 3 called wait on weather 1/8/2024 RECOMPLETION Performed a clean out run and displaced the well to mud. TOOH and lay down clean out BHA. RIH with same BHA to make a second cleanout run. 1/9/2024 RECOMPLETION Performed another clean out run. TOOH and lay down clean out BHA. RIH to make a another cleanout run. 1/10/2024 RECOMPLETION Pick up WS, TIH set on depth, shear out of WS, mill window per baker rep. 1/11/2024 RECOMPLETION Continue milling window per baker rep, then rat hole per Baker directional, TOOH for drilling assembly. MU drilling BHA and RIH to window. Shutdown and wait for weather. 1/11/2024 SUPPORT OTHER OPERATIONS 1/12/2024 RECOMPLETION Waiting on Phase 3 Weather 1/13/2024 RECOMPLETION WOW then Drill from window at 6,344' to 6,706'. 1/14/2024 RECOMPLETION Drilled 30' with 50% losses. Losses never healed up. 1/15/2024 RECOMPLETION Drilled to 7220' with 60 BPH losses. 1/16/2024 RECOMPLETION Continue drilling ahead to TD @ 7560', pump sweeps and circulate hole clean, perform flow check, return flow drop to 31% and stabilized, turn on pumps circulate B/U @ 3.5 bbls/min 1250 psi 33% return flow, Mud wt @ B/U 13.4 in and out 42 vis, still getting cuttings across shaker, lower pump to 1 bbl/min while building sweeps to "relax" formation 1/17/2024 RECOMPLETION Continue to monitor well for ballooning , open well and work stuck pipe free, circulate and condition mud to 13.4 in and out // clean well bore 1/18/2024 RECOMPLETION Continued to clean well bore, displaced well to 13.7 ppg mud, perform flow check became diff stuck, work stuck pipe while swapping mud back to 13.4 ppg mud 1/19/2024 RECOMPLETION Continue to work stuck pipe, spot dead crude around BHA let soak no movement, spot second crude sweep around BHA let soak while mixing up black magic pill 1/19/2024 SUPPORT OTHER OPERATIONS CALLED OUT TO RIG, JOB POSTPONED WHILE DECISION ON NEW PLAN FORWARD IS MADE. TRAVEL TO DEADHORSE TO OP-CHECK TOOLS 1/20/2024 RECOMPLETION Continue to work pipe with black magic, unsuccessful, call out e-line and rig up, introduce and hold 8K left torque into string, run string shot on E-line and fire @ 7339.1', POOH with e-line indication good fire, stand back e-line make up TD to stump introduce 9K LH torque and work down to BHA, count turns pick up good indication back off, pick up pipe moving @ 150K up wt 1/20/2024 SUPPORT OTHER OPERATIONS RU E-LINE W/ GREASE HEAD & PIS, RIH W/ 1-7/16" CHD (1" FN), 7' X 1-11/16" WEIGHT BAR, 1-11/16" CCL, BACK-OFF BAR (LOADED 8' W/ 3 STRANDS OF 80 GRAIN DET CORD), SHOOT BACK-OFF W/ CCL OFFSET=5.8', MID BACK- OFF=7345', CCL STOP DEPTH=7339.2', TOOLS OUT OF HOLE, STAND BY FOR RIG TO PULL ON PIPE, JOB CONTINUED TO NEXT DAY. 1/21/2024 SUPPORT OTHER OPERATIONS JOB CONTINUED FROM 20-JAN-2024, RIG ABLE TO WORK PIPE FREE. RD AFTER THEY PULL ONE JOINT OOH, LEAVE LOCATION. 1/21/2024 RECOMPLETION TOOH to shoe, circulate well clean, perform flow check, circulate B/U pump dry job, TOOH, bha recovered above jars, rig up and test BOPs 250/4000 witness waived AOGCC Kam StJohn, rig down test equipment install wear ring 1/22/2024 RECOMPLETION MU and RIH with fishing BHA #65, Hole real sticky. POOH. MU and RIH with clean out BHA #66.Stop at window and ensure mud properties good 1/23/2024 RECOMPLETION Attempted clean out to top of fish, made it to 6727' multiple stack outs and overpulls, phase 3 called, back ream to window and wait on weather, TOOH prep and start full bop test 250/4000 1/24/2024 RECOMPLETION Complete BOP ram seal replacment/repair. Continue testing BOPs, failure on top ram bonnet, remove and perform repairs 1/25/2024 RECOMPLETION Complete testing BOPE RIH with cement retainer to 6395' 1/26/2024 RECOMPLETION Suspend well with 47 BBL's cement. perform state witnessed tag and test. L/D drill pipe 1/27/2024 RECOMPLETION Continue laying down drill pipe from hole, RIH with 4.5" 12.6# Hyd 563 L-80 kill string to 2300' N/D BOP NU dry hole tree and adapter. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC corrected by E-Line) 6,570.0 2M-24 11/24/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: W/O Suspend 2M-24 2/23/2024 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS FCO'd ON 4/28/2020. 4/28/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread PRODUCTION (Original KOP@6,565') 7 6.28 6,565.0 7,436.3 6,348.5 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 6,565.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,409.0 5,492.7 34.95 WHIPSTOCK WS set on cement, 45° LOHS Baker Gen 2 Whipstoc k 10841 11048 12/28/2023 0.000 6,565.0 5,620.5 34.93 CUT WellTech Mechanical cutter made tubing cut @ 6565' RKB. Tied into GLM and corrected TOC depth. All indications of good cut. 11/24/2023 2.990 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,925.0 5,919.1 33.63 CEMENT RETAINER 10/30/2023 0.000 6,970.0 5,956.6 33.49 TUBING PUNCH 2" x 3' TBG PUNCH, 3/8" TITAN KNOCKOUT CHARGES, 7g, 6 SPF, 0 DEG PHASING 6/29/2023 2.992 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN 1 1/2 0.0 10/31/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60° phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60° phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60° phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180° phasing; Oriented 77° CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180° phasing; Oriented 81.8° CCW; SWS 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,354.0 7,582.0 5,447.6 Plug – Plug Back / Abandonment Plug 49 BBL's 15.3 # Cement below retainer 2 BBL's on top of retainer 1/26/2024 6,427.0 6,925.0 5,507.5 5,919.1 Cement Plug 10.7 bbls15.8 PPG CLASS G 11/1/2023 Cement Squeeze 1/26/2024 2M-24, 2/26/2024 5:08:33 PM Vertical schematic (actual) PRODUCTION (Original KOP@6,565'); 1,795.0-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 CUT; 6,565.0 Cement Plug; 6,427.0 ftKB WHIPSTOCK; 6,409.0 Plug – Plug Back / Abandonment Plug; 6,354.0 ftKB PRODUCTION (Moved to A); 1,795.0-6,565.0 SURFACE; 41.9-3,146.4 Tie-Back String; 39.1-1,798.0 Production String 1 Cement; 39.0 ftKB CONDUCTOR; 42.0-121.0 Hanger; 39.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: W/O Suspend 2M-24A 2/23/2024 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,789.8 47.00 L-80 BTC ABMOD Tie-Back String 7 6.28 39.1 1,798.0 1,697.7 26.00 L-80 HYD563 OPEN HOLE 7 6,565.0 7,560.0 6,217.7 PRODUCTION (Moved to A) 7 6.28 38.8 6,565.0 5,612.1 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 39.0 Set Depth … 2,304.3 Set Depth … 2,099.7 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 39.0 39.0 0.04 Hanger 7.063 4 1/2" Completion Gen 4 Tubing Hanger FMC Gen 4 3.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,399.0 5,482.2 34.96 CEMENT RETAINER 1/25/2024 0.000 7,191.0 5,994.0 53.19 FISH 4.75" Baker motor and MWD, Well commander, 4" HWDP- 4 jts, 4.75" YJ drilling Jars 1/22/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,783.8 1,686.3 36.92 Cementing Nipple 8.300 7" ES Cementer (SN#: 102463867 -A) Halliburto n HES Cementer 6.171 6,565.0 5,612.1 42.58 Open Hole 7.000 2M-24A, 2/26/2024 5:08:34 PM Vertical schematic (actual) OPEN HOLE; 6,565.0-7,560.0 FISH; 7,191.0 PRODUCTION (Moved to A); 1,795.0-6,565.0 CEMENT RETAINER; 6,399.0 PRODUCTION (Original KOP@6,565'); 1,795.0-7,436.3 SURFACE; 41.9-3,146.4 Tie-Back String; 39.1-1,798.0 Production String 1 Cement; 39.0 ftKB CONDUCTOR; 42.0-121.0 Hanger; 39.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24A ... TD Act Btm (ftKB) 7,560.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017101 Wellbore Status PROD Max Angle & MD Incl (°) 55.73 MD (ftKB) 6,844.55 WELLNAME WELLBORE2M-24 Annotation End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP 1 Conklin, Amy A From:Long, Sydney Sent:Tuesday, February 20, 2024 2:51 PM To:Conklin, Amy A Subject:Fw: [EXTERNAL]Re: 2M-24 KOP Plan Forward Thank you, Sydney Long Senior Rig Workover Engineer From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 8, 2023 11:02 AM To: Long, Sydney <Sydney.Long@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]Re: 2M-24 KOP Plan Forward 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. Sydney, Verbal approval is granted for the milling and potential change in kickoff point. This will require a change of approved program for the motherbore sundry. We will discuss location of a new kickoff point on Monday when milling results are known and discussed with the AOGCC. It is understood that a CBL , a CCL and a caliper will be run and results shared with the AOGCC. Victoria Sent from my iPhone On Dec 8, 2023, at 10:16BAM, Long, Sydney <Sydney.Long@conocophillips.com> wrote: Good morning, I would appreciate chatting with you about the current situation on 2M-24. This well is a sidetrack on 7ES. I would like to discuss our kickoff location and contingencies before we get into the weekend. The planned KOP for 2M-24 was 6550’ and the tubing was cut pre rig at 6565’. However, when we went to pull the tubing, we found ourselves unable to do so. We then went and cut the tubing at 6180’, which You don't often get email from sydney.long@conocophillips.com. Learn why this is important 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. 2 pulled successfully, and then ran a CBL as it was suspected that cement from the abandonments cement job was holding us on the outside of the tubing. We found that there was a significant amount of cement on the outside of the tubing with good bonding. We are currently in the process of attempting to gain access to the planned KOP. Our proposed plan forward is as follows: 1. Cut again at 6278’ (complete) 2. Attempt to fish tubing from 6180’ to 6278’ and break free from the poorer bonded cement (in progress) 3. Begin milling tubing and cement inside the 7” casing down to the planned KOP a. Contingency – Seeking your approval for If progress is unable to be made or we believe we are unable to proceed without causing damage to the well or adding significant risk to the project, stop milling and move KOP to the deepest depth achieved. 4. Run a CCL, CBL and Caliper of the 7” casing 5. Set whipstock and begin exit a. If the CBL shows good bonding on the outside of the 7” casing at the KOP, proceed per procedure b. If the CBL shows weak or poor bonding on the outside of the 7” casing at the KOP, mill out window and 20’ of new formation and perform FIT to 15 ppg before proceeding 6. Drill sidetrack per plan. Attached are the logs from the primary 7” cement job in 1992, the CBL of the cement on the outside of the 3-1/2” tubing, and the geologic interpretation from our geophysicist. Also attached is the APD. Thank you for your consideration of the above plan. I will be following up this email with a call. Thank you, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 <Shallower KOP Considerations 12-8-2023.pptx> <2M-24 Tubing CBL.pdf> <2M-24 CBL 7in Casing.TIF> <Permit_223-073_100423.pdf> 1 Conklin, Amy A From:Long, Sydney Sent:Tuesday, February 20, 2024 2:50 PM To:Conklin, Amy A Subject:Fw: [EXTERNAL]Re: 2M-24 Full Subsidence Plan Forward Thank you, Sydney Long Senior Rig Workover Engineer From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Sunday, December 10, 2023 1:21 PM To: Long, Sydney <Sydney.Long@conocophillips.com> SCcuebt: [EXTERNAL]Re: 2M-24 Full Subsidence Plan Forward 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. Sydney, Verbal approval is granted for the subsidence repair. Please submit a change of approved program sundry by the end of day tomorrow, Monday, December 11, 2023. Victoria Sent from my iPhone On Dec 10, 2023, at 12:57:PM, Long, Sydney <Sydney.Long@conocophillips.com> wrote: Victoria, I apologize but after further discussion with the team we would request that we test the break on the BOPE to the 3k allowed by the flange as soon as we are able to place a test plug in the stack. We would advise against exposing the full casing to the 3k test. Thank you very much for your time, Sydney You don't often get email from sydney.long@conocophillips.com. Learn why this is important 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. 2 Get Outlook for iOS From: Long, Sydney Sent: Sunday, December 10, 2023 11:59:51 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> jb: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> SCcuebt: 2M-24 Full Subsidence Plan Forward Good morning, I apologize for contacting you over the weekend. However, it has been discovered that the 7” casing on 2M-24 is compromised at approximately 270’ RKB. While still holding pressure, the casing is buckled and we have compromised drift. We will not be able to proceed with the sidetrack operations (including the recovery of the KOP we discussed on Friday) until the casing is repaired. Our current plan forward is below: 1. Perform CBL and caliper of 7” casing from Surface casing shoe up. - Complete 2. Set RBP at 2300’ and test as a barrier. Place sand on top of the RBP. – In Progress 3. Cut 7” casing at approximately 1785’ RKB and circulate. Close VBR rams or Annular as necessary while circulating 4. ND BOPE and ND tubing spool. NU BOPE to 11” 3k flange. Shell test to 3K (Note: Will not test above 3k due to flange rating. BOPE test pressure 4,000 psi) 5. Pull 7” casing and lay down 6. PU mills and bore our 9-5/8” as necessary to obtain drift for new 7” tieback. 7. Run new 7” 26# L80 Hyd563 casing and engage stub with overshot casing patch 8. Test casing to 2500 psi 9. Shift open cementing sleeve and cement the 7” x 9-5/8” annulus to surface 10. ND BOPE. Set slips and cut remaining casing. NU tubing spool and BOPE and shell test to 4k psi. 11. Cleanout casing and pull RBP 12. Return to previously discussed plan forward. Thank you very much. I will follow this email up with a call. Thank you, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 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. From:Brooks, Phoebe L (OGC) To:Cozby, Kelly Cc:Regg, James B (OGC) Subject:RE: Nabors 7ES BOP test 1-6-24 Date:Friday, February 2, 2024 3:58:17 PM Attachments:Nabors 7ES 01-06-24 Revised.xlsx Kelly, Attached is a revised report changing the sundry # to 323-659 and MASP to 3455. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Monday, January 8, 2024 4:14 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; NSK RWO CM <nskrwo.cm@conocophillips.com> Cc: White, Bradley <Bradley.White@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Yearout, Paul <Paul.Yearout@nabors.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Kneale, Michael L <michael.l.kneale@conocophillips.com> Subject: Nabors 7ES BOP test 1-6-24 Thanks, Kelly Cozby KRU 2M-24 PTD 1920500 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:27 Township:11N Range:8E Meridian:Umiat Drilling Rig:Nabors 7ES Rig Elevation:Total Depth:7450 ft MD Lease No.:ADL 025586 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 121 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 3146 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 7436 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 6990 Feet Tbg Cut@ 6180 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Retainer 6,399 ft 6,354 ft 9.5 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 2550 2520 2510 IA 2550 2520 2510 OA 0 0 0 Remarks: Attachments: I traveled to Nabors 7ES at KRU 2M-24 and met with Matt Turcott (Nabors) and Chase Erdman (CPAI). We went over the paperwork and got a plan together - tag and test of cement plug pumped after cut/retrieve casing and prior to them running a kill string, demob rig and reevaluate. Tagged top of cement at 6,354 ft MD and put 10K down, repeated this twice to verify a good solid tag. They racked a stand back and got rigged up to test the 7" to 2500 psi. They put a sensor on the 4" drillpipe and another on the cement line to the 7" casing / kill line. There was a float in the BHA so they pumped down both directions to keep the pressures the same in and outside the 4" drill pipe.The test went very well. I did speak with Mark Adams (CPAI day company man) about some better gauges for future jobs. The only calibrate guages they had on hand were on the Barton chart recorder with 50 psi increments. It worked for this for this test, but I let him know that sometimes an MIT can come down to only a few pounds for a pass or fail and better guages could be beneficial in that situation. He is going to explore the options and see what he came come up with. There was only 45 ft of cement on top of the retainer. I spoke with AOGCC's Victoria Loepp on the phone and was given a verbal agreement to proceed with the MIT. January 26, 2024 Josh Hunt Well Bore Plug & Abandonment KRU 2M-24 ConocoPhillips Alaska Inc. PTD 1920500; Sundry 323-385 none Test Data: P Casing Removal: Chase Erdman Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0126_Plug_Verification_KRU_2M-24_jh            From:Brooks, Phoebe L (OGC) To:Cozby, Kelly Cc:Regg, James B (OGC) Subject:RE: 7ES BOP Test 12/16/23 Date:Wednesday, January 31, 2024 3:04:47 PM Attachments:Nabors 7ES 12-16-23 Revised.xlsx Kelly, I’ve attached a revised report correcting the PTD # for 1920500 for KRU 2M-24 and changed the MASP to 3455 based on sundry # 323-447. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (OGC) Sent: Tuesday, January 30, 2024 2:03 PM To: Cozby, Kelly <Kelly.Cozby@nabors.com> Subject: RE: 7ES BOP Test 12/16/23 Kelly, The PTD # and well name do not match; should this be initial Drilling for KRU 2M-24A? Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Cozby, Kelly <Kelly.Cozby@nabors.com> .XSDUXN5LYHU8QLW0 37' revised report PTD # MASP 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. Sent: Monday, December 18, 2023 5:18 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: NSK RWO CM <nskrwo.cm@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Kneale, Michael L <michael.l.kneale@conocophillips.com>; White, Bradley <Bradley.White@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com>; Henson, James <James.Henson@nabors.com> Subject: 7ES BOP Test 12/16/23 Thanks, Kelly Cozby 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 12/16/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11920500 Sundry #323-447 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: Bi-Weekly: X Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:3455 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water 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" T90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 7"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0NA200 psi Attained (sec)16 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)110 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5 @ 2050 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 28 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/16/23 13:31 Waived By Test Start Date/Time:12/16/2023 12:00 (date) (time)Witness Test Finish Date/Time:12/16/2023 18:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Test with 4'' and 7'' test joints. Tested all Alarms Passed. **Note 250/2500 psi test due to BOPE NU to 11" 3k flange during subsidence repair** BOPE will be tested 250/4000 psi when repairs completed NU to 5k flange. Kelly Cozby / Johnny Medina ConocoPhillips Scott Kiser/ Ron Phillips KRU 2M-24 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2023-1216_BOP_Nabors7ES_KRU_2M-24 9 9 9 99 9 9 99 9 9 9 -5HJJ 250/2500 psi test due to BOPE NU to 11" 3k flange C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-01-07_22577_KRU_2M-24_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22577 KRU 2M-24 50-103-20171-00 Caliper Survey 07-Jan-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 1/17/2024 PTD: 192-050 T38271 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.17 08:52:35 -09'00' 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. From:Brooks, Phoebe L (OGC) To:Yearout, Paul Cc:Regg, James B (OGC) Subject:RE: Nabors 7ES 12-03-23 Date:Tuesday, January 9, 2024 4:38:55 PM Attachments:Nabors 7ES 12-03-23 Revised.xlsx Paul, Attached is a revised report changing the PTD # to 1920500 for KRU 2M-24 and MASP to 3455 per sundry # 323-447. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Yearout, Paul <Paul.Yearout@nabors.com> Sent: Monday, December 4, 2023 10:21 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Cc: White, Bradley <Bradley.White@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com>; Cozby, Kelly <Kelly.Cozby@nabors.com> Subject: Nabors 7ES 12-03-23 Thank you Paul Yearout 7ES Toolpusher Nabors Alaska Drilling Inc. <ZhϮDͲϮϰ WdϭϵϮϬϱϬϬ revised report Office 907-670- 6132 Cell 907-244-6322 paul.yearout@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 12/3/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1920500 Sundry #323-447 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/4000 Annular:250/3500 Valves:250/4000 MASP:3455 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water 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" T90 FP Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate FP System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1550 P Check Valve 0NA200 psi Attained (sec)20 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)108 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5 @ 2100 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 29 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:8.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/01/23 18:58 Waived By Test Start Date/Time:12/3/2023 10:30 (date) (time)Witness Test Finish Date/Time:12/3/2023 18:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Test with 3-1/2" and 4" test joints. Choke HCR valve failed regreased test good. Annular failed initial test - retest good. Tony Morales / Paul Yearout ConocoPhillips Mark Adams/Chase Eardman KRU 2M-24 Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2023-1203_BOP_Nabors7ES_KRU_2M-24 9 9 9 9 9 9999 9 9 9 9 - 5HJJ Choke HCR valve failed Annular failed FP FP 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 Rig Owner:Rig No.:7ES DATE:1/6/24 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1920500 Sundry #323-659 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:Bi-Weekly:X Other: Rams:250/4000 Annular:250/3500 Valves:250/4000 MASP:3455 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)16 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)115 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5 @ 2100 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/1/24 22:30 Waived By Test Start Date/Time:1/6/2024 9:30 (date)(time)Witness Test Finish Date/Time:1/6/2024 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nabors Test BOPE with 3.5'' & 4" test joints 250/4000. Annular tested on 3.5" test jnt. 250/3500. Alarms tested. Bottle Precharge - 1000 psi. *** Testing was delayed due to suspended operations from weather conditions *** Kelly Cozby/Johnny Medina ConocoPhillips Mark Adams/Chase Erdman KRU 2M-24 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2024-0106_BOP_Nabors7ES_KRU_2M-24         J. Regg; 4/5/2024 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: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 105' 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: N/A 23. BOTTOM 16" H-40 121' 9-5/8" L-80/ J-55 2792' 7" J-55 6348' 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 Sr Res EngSr Pet GeoSr Pet Eng Kuparuk River Field/ N/A -Suspended 1808' MD/ 1708' TVD Oil-Bbl: Water-Bbl: 6570-6925' 10.7 bbls 15.8 ppg Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 7070-7079' MD and 6040-6048' TVD (cemented) 7103-7112' MD and 6068-6075' TVD (cemented) 7122-7137' MD and 6084-6096' TVD (cemented) 7156-7182' MD and 6112-6134' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 26# 39' 62.5# 47#/ 36# 121' 39' 7436' SIZE DEPTH SET (MD) 6961' MD/ 5949' TVD PACKER SET (MD/TVD) 24" CASING WT. PER FT.GRADE 6/18/1992 CEMENTING RECORD 5947749 1400' MD/ 1361' TVD SETTING DEPTH TVD 5942402 TOP HOLE SIZE AMOUNT PULLED 491612 53206 TOP SETTING DEPTH MD 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 50-103-20171-00-00 KRU 2M-24 ADL0025586 114' FSL, 554' FWL, Sec. 27, T11N, R8E, UM 1182' FNL, 1313' FEL, Sec. 37, T11N, R8E, UM 92-50, ALK2672 6/14/1992 7450' MD/ 6360' TVD 6570' MD/ 5625' TVD 146' P.O. Box 100360, Anchorage, AK 99510-0360 488394 5948985 1118' FNL, 1509' FEL, Sec. 34, T11N, R8E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 11/23/2023 192-050/ 323-302/ 323-385 BOTTOM 12-1/4" 220 sx AS I 42'613 sx PF E, 483 sx Class G 42' 3146'42' 42' 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. 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, TUBING RECORD 206 sx Class G8-1/2" 6990'3-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 10:52 am, Dec 21, 2023 Suspended 11/23/2023 JSB RBDMS JSB 122123 xG DSR-1/29/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD surface surface 1400' 1361' Top of Productive Interval 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Intervention Engineer 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: N/A suspended N/A suspended INSTRUCTIONS 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. Authorized Title: 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 Formation Name at TD: 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. 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 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.12.20 12:00:11-09'00'Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC corrected by E-Line) 6,570.0 2M-24 11/24/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 6180' RKB 2M-24 12/4/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS FCO'd ON 4/28/2020. 4/28/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,791.9 47.00 L-80 BTC ABMOD PRODUCTION 7 6.28 38.8 7,436.3 6,348.5 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.0 38.0 0.09 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV 5.250 CAMCO TRDP-4A-RO SAFETY VALVE CAMCO TRDP- 4A RO 2.812 3,214.2 2,848.8 32.90 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,714.2 4,098.4 34.15 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,244.5 4,535.3 34.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,652.6 4,870.7 35.06 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,094.8 5,235.2 34.75 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,535.0 5,595.9 35.05 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,808.0 1,708.3 36.94 OTHER Set 2.83" NO-GO sub with hold open sleeve across SSSV (OAL = 67") 12/4/2023 2.290 1,814.0 1,713.0 36.96 TUBING LEAK IDENTIFIED TUBING LEAK WITH SPINNER @ 1814' 9/23/2020 2.990 6,180.0 5,305.1 34.91 CUT TUBING CUT W/ 2" RCT (PERFORMED ON RIG - 7es) 12/4/2023 2.992 6,278.0 5,385.4 35.10 CUT TUBING CUT W/ 2" RCT (PERFORMED ON RIG - 7es) 12/8/2023 2.992 6,565.0 5,620.5 34.93 CUT WellTech Mechanical cutter made tubing cut @ 6565' RKB. Tied into GLM and corrected TOC depth. All indications of good cut. 11/24/2023 2.990 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,925.0 5,919.1 33.63 CEMENT RETAINER 10/30/2023 0.000 6,970.0 5,956.6 33.49 TUBING PUNCH 2" x 3' TBG PUNCH, 3/8" TITAN KNOCKOUT CHARGES, 7g, 6 SPF, 0 DEG PHASING 6/29/2023 2.992 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,214.2 2,848.8 32.90 1 GAS LIFT DMY BK 1 8/16/2023 4,714.2 4,098.4 34.15 2 GAS LIFT DMY BK 1 0.0 7/27/2023 0.000 5,244.5 4,535.3 34.62 3 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 5,652.6 4,870.7 35.06 4 GAS LIFT DMY BK 1 0.0 7/27/2023 0.000 6,094.8 5,235.2 34.75 5 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 6,535.0 5,595.9 35.05 6 GAS LIFT DMY BTM 1 0.0 5/26/2017 0.000 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN 1 1/2 0.0 10/31/2023 0.000 2M-24, 12/19/2023 4:13:59 PM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 Cement Plug; 6,570.0 ftKB CUT; 6,565.0 GAS LIFT; 6,535.0 CUT; 6,278.0 CUT; 6,180.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 OTHER; 1,808.0 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,570.0 6,925.0 5,624.6 5,919.1 Cement Plug 10.7 bbls15.8 PPG CLASS G 11/1/2023 2M-24, 12/19/2023 4:14:00 PM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 Cement Plug; 6,570.0 ftKB CUT; 6,565.0 GAS LIFT; 6,535.0 CUT; 6,278.0 CUT; 6,180.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 OTHER; 1,808.0 CONDUCTOR; 42.0-121.0 KUP PROD 2M-24 ... WELLNAME WELLBORE2M-24 DTTMSTART JOBTYP SUMMARYOPS 2/11/2023 REPAIR WELL DRIFT TBG W/ 1.5" PUMP BAILER DOWN TO TOP OF ROCK SCREEN @ 6977' RKB (NO RETURNS); REPEAT BAILER RUN W/ SAME RESULT (NO SAMPLE OBTAINED) 3/12/2023 REPAIR WELL SET BAITED 3 1/2" TTS PULLING TOOL IN UPPER 2.725" P2P PATCH ASSEMBLY @ 1789' RKB & JARRED FOR 2 HOURS W/ NO MOVEMENT. IN PROGRESS. 3/13/2023 REPAIR WELL JARRED ON 2.725" UPPER PATCH ASSEMBLY FOR 2.5 HOURS BEFORE PARTING WIRE @ SURFACE (ABLE TO CLOSE IN WLV'S ON WIRE WITH WIRE TOP INSIDE LUBRICATOR); TIE BACK WIRE TO UNIT AND RECOVER ALL WIRE & TOOLS. (TTS PULLING TOOL REMAINS IN HOLE IN TOP OF PATCH). RIGGED DOWN FOR HIGHER PRIORITY WORK. 3/19/2023 REPAIR WELL WITH .160" WIRE: ATTEMPT TO PULL 2.72 UPPER PATCH ASSEMBLY (UNSUCCESSFUL) @ 1789'RKB,3.5''TTS PULLING TOOL REMAINS IN UPPER PATCH ASSEMBLY, READY FOR COIL. 6/25/2023 REPAIR WELL PULLED UPPER PATCH FROM 1789' RKB. RBIH AND PUMPED OFF FISH. POOH TO SHORTEN UP TOOLSTRING. JOB IN PROGRESS. 6/26/2023 REPAIR WELL PULL LOWER PACKER @ 1818', PULL UPPER PACKER @ 6876' WITH SPACER PIPE. PULL LOWER PACKER @ 6904'. FREEZE PROTECT WELL WITH 30 BBLS DIESEL. ATTEMPT TO INJECT INTO WELL. NOT ABLE TO INJECT INTO WELL. WHP CAME UP TO 2000 PSI. 6/29/2023 REPAIR WELL PERFORM TUBING PUNCH OVER INTERVAL: 6970' - 6973', LRS PERFORM INJECTIVITY TEST. PUMPED 5.3 BBLS AND PRESSURED T & IA TO 2500 PSI. HOLD FOR 30 MIN. 0 = 2500/2500/850 15 = 2275/2400/850 30 = 2200/2400/850 BLEED BACK TO STARTING PRESSURES. JOB COMPLETE, READY FOR PLAN FORWARD 7/27/2023 ACQUIRE DATA SET SLIPSTOP-CATCHER @ 5734' RKB, PULL / SET DMY IN ST#4 @ 5652' RKB, PULL GLV / SET DMY IN ST#2 @ 4714' RKB, PULL GLV FROM ST#1 @ 3214' RKB, JOB IN PROGRESS 7/28/2023 ACQUIRE DATA RATTLE MANDRELS 1-4 W/ 3-1/2 BRUSH, SET DMY IN ST#1 @ 3214' RKB, PULL SLIPSTOP- CATCHER @ 5734' RKB. READY FOR COIL 8/14/2023 REPAIR WELL CIRCULATE 240 BBLS OF SEAWATER DOWN THE TBG AND UP THE IA, LAY IN 3.5 BBLS OF 15.8# CLASS G CEMENT FROM 6942' CTMD TO 6540' CTMD IN 3 1/2" TBG, SQUEEZE 9.5 BBLS CEMENT INTO THE IA, MAINTAIN 1:1 RETURNS UP THE TBG WHILE POOH, TRAP 1160 WHP AT SURFACE, DID NOT LEAVE THE TBG OR IA FREEZE PROTECTED AS PER TOWN ENGINEER, READY FOR TAG & TEST IN 24 HOURS, JOB IN PROGRESS. 8/16/2023 ACQUIRE DATA TAG TOC @ 5241' RKB W/ 10'X2.5" BAILER, SET 3.5" SLIP STOP CATCHER @ 3392' RKB, PULL DUMMY VALVE FROM STA 1 @ 3214' RKB, CIRCULATE 115 BBLS DIESEL TO FREEZE PROTECT TBG & IA, PERFORM CMIT TO 2000 PSI (PASSED), SET DMY VALVE IN STA 1 @ 3214' RKB, PULL 3.5" SLIP STOP CATCHER FROM 3392' RKB 8/19/2023 REPAIR WELL RIH W/ 2.80" CONCAVE MILL. DRY TAG AT 5,241' RKB. MILL CONTAMINATED CEMENT DOWN TO 5,660'. JOB IN PROGRESS. 8/20/2023 REPAIR WELL CONTINUE MILLING CONTAMINATED CEMENT FROM 5,660' TO 6,970' RKB. WELL WAS FLOWING ON US DURING CEMENT MILL OUT. HAD TO CHOKE IT IN TO MAINTAIN 1:1 RETURNS. HEAVY PICKUP WEIGHTS BELOW 5,200'. FREEZE PROTECT WELL WITH DIESEL. PERFORM INJECTIVITY TEST AT SURFACE ABLE TO PUMP 0.4 BPM AT 2575 PSI WHP. READY FOR REMEDIAL CEMENT JOB. 8/26/2023 PUMPING TRACKING ONLY CIRCULATION TEST PUMP 20 BBLS DSL DOWN TBG @ 3.75 BPM SEE BELOW FOR DETAILS 10/29/2023 ACQUIRE DATA MIRU, BOP TEST, CUT 250' OF PIPE, 8020' OF COIL REMAINING. SET CEMENT RETAINER AT 6925' RKB, MID JOINT. PRESSURED UP TO 5100 PSI, WELL HAS ZERO INJECTIVITY. WAIT ON ENGINEER TO DISCUSS WITH AOGCC. RIG DOWN AND STAGE UNIT ON 2M PAD FOR PLAN FORWARD. 10/31/2023 REPAIR WELL PULLED 1.5'' DMY VLV ST#7 6892' RKB, READY FOR COIL. 10/31/2023 REPAIR WELL PERFORM GENERAL MAINTENANCE WHILE STANDING BY ON EOP FOR SLICKLINE TO PULL DV. MIRU CTU 6 POST SLICKLINE. DRIFT COIL. RECOVER 1/2" BRASS BALL. MAKE UP TOOLS. 2M-24 Plug for Redrill Summary of Operations 11/1/2023 REPAIR WELL MIRU TO PUMP BALANCED CEMENT PLUG. CIRC WELL OUT TO 9.8 PPG BRINE. PUMP 13 BBLS OF 15.8 PPG CLASS G CEMENT. PUMP 7.7 BBLS IN IA, LAY 5.3 BBLS ON TOP OF RETAINER. CLEAN OUT EXCESS CEMENT. ESTIMATED TOC 6600' RKB. READY FOR SLICKLINE TO FREEZE PROTECT WITHIN 24 HRS. 11/2/2023 REPAIR WELL PULLED DMY @ 3214' RKB. CIRC IN 70 BBLS DIESEL FOR FREEZE PROTECT. RE-SET DV @ 3214' RKB. TAGGED TOC @ 6559' RKB. READY FOR (AOGCC WITNESS 11/5/23) 11/23/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 6559' RKB, CONDUCT AOGCC WITNESSED (JOSH HUNT) CMIT TXIA TO 2820 PSI, ATTEMPT TO PULL DMY VALVE IN STA #5 @ 6094' RKB, SHUCK OFF VALVE, RUN CHECK SET TO ENSURE VALVE IS STILL IN POCKET... READY FOR ELINE TO MAKE CUT ON TBG STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2M-24 JBR 03/01/2024 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:1 3-1/2" & 4" joints. Cellar H2S-calibrated for a pass. Due 12/17. With a 3k spool on wellhead AOGCC approved 2500psi test for that test. This was the subsequent test after it was removed. Test Results TEST DATA Rig Rep:Morales/YearoutOperator:ConocoPhillips Alaska, Inc.Operator Rep:Phillips/Erdman Rig Owner/Rig No.:Nabors 7ES PTD#:1920500 DATE:12/20/2023 Type Operation:WRKOV Annular: 250/4000Type Test:BIWKLY Valves: 250/4000 Rams: 250/4000 Test Pressures:Inspection No:bopSAM231221155741 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 3455 Sundry No: 323-447 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 W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 3-1/2"x5"P #2 Rams 1 Blinds P #3 Rams 1 3-1/2"x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 2 3-1/8"/2"P Check Valve 0 NA BOP Misc 2 2-1/16"P System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P19 Full Pressure Attained P116 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P FPH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1       jbr C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-23_20286_KRU_2M-24_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20286 KRU 2M-24 50-103-20171-00 Caliper Survey w/ Log Data 09-Dec-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 192-050 T38246 12/29/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.29 12:34:59 -09'00' 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7450'7130' Casing Collapse Structural Conductor Surface 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: 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-6312 Senior Workover Engineer KRU 2M-24 6360' 7130' 6090' 3455 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 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: Tubing Size: sydney.long@conocophillips.com AOGCC USE ONLY Victoria Loepp 12/10/2023 Tubing Grade: Tubing MD (ft): 6961' MD and 5949' TVD 1808' MD and 1708' TVD Sydney Long STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025586 192-050 P.O. Box 100360, Anchorage, AK 99510 50-103-20171-00-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Suspended TVD Burst 6990' MD 121' 2792' 121' 3146' 6348'7436' 16" 9-5/8" 79' 3104' 7070-7079', 7103-7112', 7122- 7137', 7156-7182' 7397' 6040-6048', 6068-6075', 6084- 6096', 6112-6134' 7" Perforation Depth TVD (ft): 12/10/2023 3-1/2" Packer: Baker HB Rtrvbl Packer SSSV: Camco TRDP-4A-RO Sfty Vlv Perforation Depth MD (ft): J-55 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Plugs (MD): 6570' By Grace Christianson at 4:03 pm, Dec 11, 2023 323-659 X X DSR-12/14/23VTL 01/03/2024 SFD 12/13/2023 BOP test to 3500 psig Annular preventer test to 2500 psig 10-407 *&:JLC 1/3/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.03 15:22:19 -09'00'01/03/24 RBDMS JSB 010424 2M-24 RWO Procedure Kuparuk Producer Sidetrack Setup PTD #192-050 Page 1 of 2 Application for Change of Approved Sundry #323-447 Completed Rig Work MIRU 1. MIRU Nabors 7ES on 2M-24. Circulate well over to 8.5ppg seawater. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing, Grow PC, Set whipstock 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to cut. Unable to pull from prerig cut at 6565’. Cut again at 6278’ RKB. a. Grow and stretch of 7” production casing: set plug/ storm packer near surface, pressure test plug. ND to casing head and let grow, pull 7” casing and re-land slips and PO, nipple up new tubing spool and BOP’s, test flange break and IC packoffs. b. Continue to lay down tubing. New Scope for Rig Work Perform Subsidence Repair – Verbal Approval Received 12/10/2023 6. Perform CBL and caliper of 7” casing from Surface casing shoe up. 7. Set RBP at 2300’ and test as a barrier. Place sand on top of the RBP. 8. Cut 7” casing at approximately 1785’ RKB and circulate. Close VBR rams or Annular as necessary while circulating 9. ND BOPE and ND tubing spool. NU BOPE to 11” 3k flange. Do not test until able to set test plug as it is not recommended to expose the entire system to the full test pressure. 10. Pull 7” casing and lay down 11. PU mills and bore our 9-5/8” as necessary to obtain drift for new 7” tieback. 12. Run new 7” 26# L80 Hyd563 casing and engage stub with overshot casing patch 13. Test casing to 2500 psi 14. Shift open cementing sleeve and cement the 7” x 9-5/8” annulus to surface 15. ND BOPE. Set slips and cut the remaining casing. NU tubing spool and BOPE and shell test to 4,000 psi. 16. Cleanout casing and pull RBP Recover KOP and Set Whipstock 17. Begin milling tubing and cement inside the 7” casing down to the planned KOP a. Contingency: i. If progress is unable to be made or we believe we are unable to proceed without causing damage to the well or adding significant risk to the project, stop milling and move KOP to the deepest depth achieved. 18. Run a CCL, CBL and Caliper of the 7” casing. Provide logs and new KOP to AOGCC as requested on 12/8/2023. 19. Set Whipstock at 6550’ TOWS (or contingency depth as outlined above) oriented high side. Exit casing. a. If the CBL shows good bonding on the outside of the 7” casing at the KOP, proceed per Permit to Drill b. If the CBL shows weak or poor bonding on the outside of the 7” casing at the KOP, mill out window and 20’ of new formation and perform FIT to 15 ppg before proceeding Subsequent work to mill window and drill the 2M-24A sidetrack is covered in the Permit to Drill that will be submitted in parallel. 2M-24 RWO Procedure Kuparuk Producer Sidetrack Setup PTD #192-050 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen IV Tree, 3K rated casing flange Production Engineer: Natalie Berryman Dye Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 9/15/23 Workover Engineer: Elliott Tuttle (907 252-3347/ Elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre rig cut, perform grow and stretch of 7” production casing, set whipstock in preparation to drill 2M-24A lateral BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T failed CMIT-TxIA – While attempting to obtain injectivity through rock screen, pressure up to 2500psi TxIA, hold for 30 minutes. Starting PSI 2500/2500/850, 30 min PSI 2200/2400/850 MIT-OA Passed to 1800psi 7/17/2023 IC POT &PPPOT Failed – 7/18/23 TBG POT &PPPOT PASSED – 7/18/23 MPSP: 3455 psi using 0.1 psi/ft gradient Static BHP: 4048 psi/ 5926’ TVD (measured 7/7/22) 1 Long, Sydney From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Friday, December 8, 2023 11:02 AM To:Long, Sydney Cc:Hobbs, Greg S; Tuttle, Elliott; Coberly, Jonathan Subject:[EXTERNAL]Re: 2M-24 KOP Plan Forward 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. Sydney, Verbal approval is granted for the milling and potential change in kickoff point. This will require a change of approved program for the motherbore sundry. We will discuss location of a new kickoff point on Monday when milling results are known and discussed with the AOGCC. It is understood that a CBL , a CCL and a caliper will be run and results shared with the AOGCC. Victoria Sent from my iPhone On Dec 8, 2023, at 10:16ථAM, Long, Sydney <Sydney.Long@conocophillips.com> wrote: Good morning, I would appreciate chatting with you about the current situation on 2M-24. This well is a sidetrack on 7ES. I would like to discuss our kickoff location and contingencies before we get into the weekend. The planned KOP for 2M-24 was 6550’ and the tubing was cut pre rig at 6565’. However, when we went to pull the tubing, we found ourselves unable to do so. We then went and cut the tubing at 6180’, which pulled successfully, and then ran a CBL as it was suspected that cement from the abandonments cement job was holding us on the outside of the tubing. We found that there was a significant amount of cement on the outside of the tubing with good bonding. We are currently in the process of attempting to gain access to the planned KOP. Our proposed plan forward is as follows: 1. Cut again at 6278’ (complete) 2. Attempt to fish tubing from 6180’ to 6278’ and break free from the poorer bonded cement (in progress) 3. Begin milling tubing and cement inside the 7” casing down to the planned KOP 1. Contingency – Seeking your approval for You don't often get email from sydney.long@conocophillips.com. Learn why this is important 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. 2 1. If progress is unable to be made or we believe we are unable to proceed without causing damage to the well or adding significant risk to the project, stop milling and move KOP to the deepest depth achieved. 4. Run a CCL, CBL and Caliper of the 7” casing 5. Set whipstock and begin exit 1. If the CBL shows good bonding on the outside of the 7” casing at the KOP, proceed per procedure 2. If the CBL shows weak or poor bonding on the outside of the 7” casing at the KOP, mill out window and 20’ of new formation and perform FIT to 15 ppg before proceeding 6. Drill sidetrack per plan. Attached are the logs from the primary 7” cement job in 1992, the CBL of the cement on the outside of the 3-1/2” tubing, and the geologic interpretation from our geophysicist. Also attached is the APD. Thank you for your consideration of the above plan. I will be following up this email with a call. Thank you, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 <Shallower KOP Considerations 12-8-2023.pptx> <2M-24 Tubing CBL.pdf> <2M-24 CBL 7in Casing.TIF> <Permit_223-073_100423.pdf> 1 Long, Sydney From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Sunday, December 10, 2023 1:21 PM To:Long, Sydney Subject:[EXTERNAL]Re: 2M-24 Full Subsidence Plan Forward 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. Sydney, Verbal approval is granted for the subsidence repair. Please submit a change of approved program sundry by the end of day tomorrow, Monday, December 11, 2023. Victoria Sent from my iPhone On Dec 10, 2023, at 12:57ථPM, Long, Sydney <Sydney.Long@conocophillips.com> wrote: Victoria, I apologize but after further discussion with the team we would request that we test the break on the BOPE to the 3k allowed by the flange as soon as we are able to place a test plug in the stack. We would advise against exposing the full casing to the 3k test. Thank you very much for your time, Sydney Get Outlook for iOS From: Long, Sydney Sent: Sunday, December 10, 2023 11:59:51 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Subject: 2M-24 Full Subsidence Plan Forward Good morning, You don't often get email from sydney.long@conocophillips.com. Learn why this is important 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. 2 I apologize for contacting you over the weekend. However, it has been discovered that the 7” casing on 2M-24 is compromised at approximately 270’ RKB. While still holding pressure, the casing is buckled and we have compromised drift. We will not be able to proceed with the sidetrack operations (including the recovery of the KOP we discussed on Friday) until the casing is repaired. Our current plan forward is below: 1. Perform CBL and caliper of 7” casing from Surface casing shoe up. - Complete 2. Set RBP at 2300’ and test as a barrier. Place sand on top of the RBP. – In Progress 3. Cut 7” casing at approximately 1785’ RKB and circulate. Close VBR rams or Annular as necessary while circulating 4. ND BOPE and ND tubing spool. NU BOPE to 11” 3k flange. Shell test to 3K (Note: Will not test above 3k due to flange rating. BOPE test pressure 4,000 psi) 5. Pull 7” casing and lay down 6. PU mills and bore our 9-5/8” as necessary to obtain drift for new 7” tieback. 7. Run new 7” 26# L80 Hyd563 casing and engage stub with overshot casing patch 8. Test casing to 2500 psi 9. Shift open cementing sleeve and cement the 7” x 9-5/8” annulus to surface 10. ND BOPE. Set slips and cut remaining casing. NU tubing spool and BOPE and shell test to 4k psi. 11. Cleanout casing and pull RBP 12. Return to previously discussed plan forward. Thank you very much. I will follow this email up with a call. Thank you, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC corrected by E-Line) 6,570.0 2M-24 11/24/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 6180' RKB 2M-24 12/4/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS FCO'd ON 4/28/2020. 4/28/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,791.9 47.00 L-80 BTC ABMOD PRODUCTION 7 6.28 38.8 7,436.3 6,348.5 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.0 38.0 0.09 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV 5.250 CAMCO TRDP-4A-RO SAFETY VALVE CAMCO TRDP- 4A RO 2.812 3,214.2 2,848.8 32.90 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,714.2 4,098.4 34.15 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,244.5 4,535.3 34.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,652.6 4,870.7 35.06 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,094.8 5,235.2 34.75 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,535.0 5,595.9 35.05 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,808.0 1,708.3 36.94 OTHER Set 2.83" NO-GO sub with hold open sleeve across SSSV (OAL = 67") 12/4/2023 2.290 1,814.0 1,713.0 36.96 TUBING LEAK IDENTIFIED TUBING LEAK WITH SPINNER @ 1814' 9/23/2020 2.990 6,180.0 5,305.1 34.91 CUT TUBING CUT W/ 2" RCT (PERFORMED ON RIG - 7es) 12/4/2023 2.992 6,278.0 5,385.4 35.10 CUT TUBING CUT W/ 2" RCT (PERFORMED ON RIG - 7es) 12/8/2023 2.992 6,565.0 5,620.5 34.93 CUT WellTech Mechanical cutter made tubing cut @ 6565' RKB. Tied into GLM and corrected TOC depth. All indications of good cut. 11/24/2023 2.990 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,925.0 5,919.1 33.63 CEMENT RETAINER 10/30/2023 0.000 6,970.0 5,956.6 33.49 TUBING PUNCH 2" x 3' TBG PUNCH, 3/8" TITAN KNOCKOUT CHARGES, 7g, 6 SPF, 0 DEG PHASING 6/29/2023 2.992 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,214.2 2,848.8 32.90 1 GAS LIFT DMY BK 1 8/16/2023 4,714.2 4,098.4 34.15 2 GAS LIFT DMY BK 1 0.0 7/27/2023 0.000 5,244.5 4,535.3 34.62 3 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 5,652.6 4,870.7 35.06 4 GAS LIFT DMY BK 1 0.0 7/27/2023 0.000 6,094.8 5,235.2 34.75 5 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 6,535.0 5,595.9 35.05 6 GAS LIFT DMY BTM 1 0.0 5/26/2017 0.000 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN 1 1/2 0.0 10/31/2023 0.000 2M-24, 12/11/2023 12:37:28 PM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 Cement Plug; 6,570.0 ftKB CUT; 6,565.0 GAS LIFT; 6,535.0 CUT; 6,278.0 CUT; 6,180.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 OTHER; 1,808.0 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,570.0 6,925.0 5,624.6 5,919.1 Cement Plug 10.7 bbls15.8 PPG CLASS G 11/1/2023 2M-24, 12/11/2023 12:37:29 PM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 Cement Plug; 6,570.0 ftKB CUT; 6,565.0 GAS LIFT; 6,535.0 CUT; 6,278.0 CUT; 6,180.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 OTHER; 1,808.0 CONDUCTOR; 42.0-121.0 KUP PROD 2M-24 ... WELLNAME WELLBORE2M-24 Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:27 Township:11N Range:8E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:7450 ft MD Lease No.:ADL 0025586 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 121 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 3146 Feet Csg Cut@ Feet Intermediate:7"O.D. Shoe@ 7436 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 6990 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 6925 ft 6559 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2860 2820 2820 IA 2890 2880 2880 OA 10 10 10 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Brent Rogers/John Hansen Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Plug back for redrill. They ran 11 feet of 1-7/8" weight pipe and an 8 feet x 2-1/2" bailer and mule shoe with a weight of 180 lbs. Tagged up several times at 6529 ft MD. Thick cement came back in the bailer. All tags stopped solid in the same location. They added a 30 feet RKB correcttion factor. November 23, 2023 Josh Hunt Well Bore Plug & Abandonment KRU 2M-24 ConocoPhillips Alaska Inc. PTD 1920500; Sundry 323-302 none Test Data: P Casing Removal: rev. 11-28-18 2023-1123_Plug_Verification_KRU_2M-24_jh                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 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?KRU 2M-24 Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool None/Suspended 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7450'6360' 7130' 6090' 3455 None 7130' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell 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:Elliott Tuttle Contact Email: Contact Phone: 907-263-4742 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Replace Tubing N/A Kuparuk River Field elliott.tuttle@conocophillips.com CTD/RWO Drilling Engineer Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 6962'MD/5950'TVD SSSV: 1808'MD/1708'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025586 192-050 P.O. Box 100360, Anchorage, AK 99510 50-103-20171-00-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: J-55 TVD Burst 6990' MD 121' 2792' 121' 3146' 6348'7" 16" 9-5/8" 79' 3104' 7436' Perforation Depth MD (ft): 7070-7079' 7103-7112' 7122-7137' 7156-7182' 7397' 6040-6048' 6068-6075' 6084-6096' 6112-6134' 9/15/2023 3-1/2" Packer: Baker HB SSSV: CAMCO TRDP Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:49 pm, Aug 07, 2023 323-447 X DSR-8/7/23 X BOP test to 3500 psig Annular preventer test to 2500 psig VTL 9/15/2023 MDG 8/23/2023*&: 09/15/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.15 12:06:52 -08'00' 404 RBDMS JSB 091823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2M-24 (PTD# 192-050). Well 2M-24 was drilled and completed in June of 1992 by Parker 245 as a Kuparuk producer and frac'd soon after. It was re-frac'd in 1998. Fill from solids production was tagged high as early as 2006 but could be resolved with a cleanout. Three total fill cleanouts were performed until in 2020, CTU stuck a BHA due to rock production. A rock screen was installed and allowed production until 2021 when the screen failed.A rock screen was attempted one more time late 2022 but the well failed to flow after install. Due to rock production and multiple leaks in the tubing, the well has been chosen as a canidate for redrill to access the same pool but only target the Kuparuk A sand. A Frac Sundry will then be submitted, to support a fracture stimulation into the Kuparuk A-sand. If you have any questions or require any further information, please contact me at +1-907-252-3347. After a suspension of 2M-24 on a previously approved form 10-403 (sundry # 323-385), the tubing will be pulled, whipstock set. A permit to drill will be submitted seperatly to drill a short slant well to reacquire the Kuparuk A-sand. A cemented liner will be landed and lastly a 3 1/2" gas lifted upper completion will be installed. 2M-24 RWO Procedure Kuparuk Producer Sidetrack Setup PTD #192-050 Page 1 of 2 Completed Pre-Rig Work 1. Pull 2 ea. Patches straddling tubing leaks (1,789’- 1818’ and 6876’-6904’) – Completed 6/26/23 2. Tubing punch below packer for injectivity test, Injectivity Failed – 6/29/23 3. T-PPPOT (Passed) and T-POT tests (passed). IC-POT failed 7/18/2023 Remaining Pre-Rig Work 4. Suspend well based on separate state approved sundry (323-385) a. Tag top of cement @ ~6600’ MD 5. Dummy off GLMs 1,2,4 and leave station 7 open 6. Perform tubing cut at 6565’ MD Rig Work MIRU 1. MIRU Nabors 7ES on 2M-24. Circulate well over to 8.5ppg seawater. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing, Grow PC, Set whipstock 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to cut (~6565’ RKB). a. Grow and stretch of 7” production casing: set plug/ storm packer near surface, pressure test plug. ND to casing head and let grow, pull 7” casing and re-land slips and PO, nipple up new tubing spool and BOP’s, test flange break and IC packoffs. b. Continue to lay down tubing. 6. Set Whipstock at 6550’ TOWS oriented high side. Subsequent work to mill window and drill the 2M-24A sidetrack is covered in the Permit to Drill that will be submitted in parallel. 2M-24 RWO Procedure Kuparuk Producer Sidetrack Setup PTD #192-050 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen IV Tree, 3K rated casing flange Production Engineer: Natalie Berryman Dye Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 9/15/23 Workover Engineer: Elliott Tuttle (907 252-3347/ Elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre rig cut, perform grow and stretch of 7” production casing, set whipstock in preparation to drill 2M-24A lateral BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T failed CMIT-TxIA – While attempting to obtain injectivity through rock screen, pressure up to 2500psi TxIA, hold for 30 minutes. Starting PSI 2500/2500/850, 30 min PSI 2200/2400/850 MIT-OA Passed to 1800psi 7/17/2023 IC POT &PPPOT Failed – 7/18/23 TBG POT &PPPOT PASSED – 7/18/23 MPSP: 3455 psi using 0.1 psi/ft gradient Static BHP: 4048 psi/ 5926’ TVD (measured 7/7/22) 2M-24 Proposed RWO-ST Completion Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121' 121' 16" 15.06" 62.58# H-40 Welded Welded Surface 3146.4' 2791.9' 9 5/8" 8.681" 47# L-80 BTC ABMOD BTC ABMOD Production 7436.3' 6348.5' 7" 6.276" 26# J-55 BTC MOD BTC MOD Tubing 6550' 5482' 3 1/2" 2.992" 9.3# L-80 EUE 8rd EUE 8rd Liner 7645' 6173' 3 1/2" 2.992" 9.3# L-80 HYD563 HYD563 MD +/- 5' TVDSS 7245 5926 7,265 5,937 7,296 5,954 7,331 5,976 A3 Top Perf A3 Btm Perf Planned Perf Details: Reference Point A4 Top Perf A4 Btm Perf PROPOSED UPPER COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3 1/2" X Nipple @ ~500' RKB (2.813" ID) 3-1/2" x 1 1/2" MMG @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 80-40 Locator and Seal assembly PROPOSED LOWER COMPLETION 5" x 7" Baker ZXP Packer and FL5 Hanger @ ~6500' RKB (3.875" ID) 4" Sealbore Extension 3-1/2" 9.3# H563 Liner to a TD of ~7545' RKB Landing Collar Float Collar Float Shoe Planned TD of: 7645' RKB (250' past Target) Tubing cut planned Pre-Rig @ 6565' MD Surface Casing @ 3146.4' RKB Conductor @ 121' RKB KOP: 6550' RKB 5462' TVDSS Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,130.0 2M-24 2/5/2022 famaj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set upper on patch #1. set complete #2 patch 2M-24 12/23/2022 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS CLEANED OUT ON 4/28/2020. TAG AT 7,100'. 4/28/2020 rwocoman General Notes: Last 3 entries Com Date Last Mod By Bottom Latch GLV @ 6535''RKB 4/10/1998 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,791.9 47.00 L-80 BTC ABMOD PRODUCTION 7 6.28 38.8 7,436.3 6,348.5 26.00 J-55 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 38.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.0 38.0 0.09 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV 5.250 CAMCO TRDP-4A-RO SAFETY VALVE CAMCO TRDP- 4A RO 2.812 3,214.2 2,848.8 32.90 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,714.2 4,098.4 34.15 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,244.5 4,535.3 34.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,652.6 4,870.7 35.06 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,094.8 5,235.2 34.75 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,535.0 5,595.9 35.05 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,789.0 1,693.1 36.89 PACKER - PATCH - UPR Upper patch assembly 2.72" P2P, XO, spacer pipe &anchor latch.(OAL 30') 12/23/2022 1.625 1,792.0 1,695.5 36.90 SPACER PIPE Spacer Pipe CPAI 12/23/2022 1.600 1,814.0 1,713.0 36.96 TUBING LEAK IDENTIFIED TUBING LEAK WITH SPINNER @ 1814' 9/23/2020 2.990 1,818.0 1,716.2 36.97 PACKER - PATCH - LWR Set Lower packer CPP3 5225 12/22/2022 1.625 6,876.0 5,878.3 33.66 PACKER - PATCH - UPR Upper patch assembly 2.72 P2P, xo, spacer pipe, & anchor latch (31.71 OAL) CPP3 5003 12/19/2022 1.625 6,879.0 5,880.8 33.66 SPACER PIPE Spacer pipe & anchor latch CPAL 35194 12/19/2022 1.600 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,904.6 5,902.1 33.65 PACKER - PATCH - LWR 2.725" (3.5") P2P LOWER PACKER W/ WLRG, OAL = 3.98', MOE = 6907' RKB CPP3 5326 11/29/2022 1.625 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,214.2 2,848.8 32.90 1 GAS LIFT GLV BK 1 1,281.0 5/16/2020 0.016 4,714.2 4,098.4 34.15 2 GAS LIFT GLV BK 1 1,316.0 5/16/2020 0.188 5,244.5 4,535.3 34.62 3 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 5,652.6 4,870.7 35.06 4 GAS LIFT OV BK 1 0.0 5/17/2020 0.250 6,094.8 5,235.2 34.75 5 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 6,535.0 5,595.9 35.05 6 GAS LIFT DMY BTM 1 0.0 5/26/2017 0.000 2M-24, 12/24/2022 12:41:34 PM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 FLOAT SHOE; 7,434.4-7,436.3 FLOAT COLLAR; 7,348.7- 7,350.4 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SOS; 6,989.4 SCREEN; 6,977.0 NIPPLE; 6,977.8 PACKER; 6,961.5 PBR; 6,947.8 PACKER - PATCH - LWR; 6,904.5 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 SPACER PIPE; 6,879.0 PACKER - PATCH - UPR; 6,876.0 GAS LIFT; 6,535.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 FLOAT SHOE; 3,144.4-3,146.4 FLOAT COLLAR; 3,059.8- 3,061.5 PACKER - PATCH - LWR; 1,818.0 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 SPACER PIPE; 1,792.0 PACKER - PATCH - UPR; 1,789.0 CONDUCTOR; 42.0-121.0 HANGER; 41.9-45.1 HANGER; 38.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN OPEN 1 1/2 0.0 7/30/2020 OPEN 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun 2M-24, 12/24/2022 12:41:35 PM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 FLOAT SHOE; 7,434.4-7,436.3 FLOAT COLLAR; 7,348.7- 7,350.4 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SOS; 6,989.4 SCREEN; 6,977.0 NIPPLE; 6,977.8 PACKER; 6,961.5 PBR; 6,947.8 PACKER - PATCH - LWR; 6,904.5 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 SPACER PIPE; 6,879.0 PACKER - PATCH - UPR; 6,876.0 GAS LIFT; 6,535.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 FLOAT SHOE; 3,144.4-3,146.4 FLOAT COLLAR; 3,059.8- 3,061.5 PACKER - PATCH - LWR; 1,818.0 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 SPACER PIPE; 1,792.0 PACKER - PATCH - UPR; 1,789.0 CONDUCTOR; 42.0-121.0 HANGER; 41.9-45.1 HANGER; 38.0 KUP PROD 2M-24 ... WELLNAME WELLBORE2M-24 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7450'7130' Casing Collapse Structural Conductor Surface 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: 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/24/2023 3-1/2" Packer: Baker HB Rtrvbl Packer SSSV: Camco TRDP-4A-RO Sfty Vlv Perforation Depth MD (ft): J-55 3104' 7070-7079', 7103-7112', 7122- 7137', 7156-7182' 7397' 6040-6048', 6068-6075', 6084- 6096', 6112-6134' 7" Perforation Depth TVD (ft): 121' 3146' 6348'7436' 16" 9-5/8" 79' 6990' MD 121' 2792' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025586 192-050 P.O. Box 100360, Anchorage, AK 99510 50-103-20171-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6961' MD and 5949' TVD 1808' MD and 1708' TVD Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Intervention Engineer KRU 2M-24 6360' 7130' 6090' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:29 pm, Jul 11, 2023 323-385 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips , OU=Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.07.11 13:21:53-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor X X MDG 7/17/2023 DSR-7/12/23VTL 7/17/2023 X 10-404 JLC 7/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:12:09 -05'00'07/18/23 RBDMS JSB 071823 Date: 5-16-23 Date of Work: 24 July 2023 Subject: 2M-24 Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Updated 7-10-23 Well History 2M-24 is a gas li2ed producer that has TxIA communica6on. It has two patches installed from 1792’ – 1818’ RKB and 6876’ – 6904’ RKB to cover holes at 1814’ and 6893’ RKB. This well began producing <ll and rocks to surface, so a rock screen was installed. Pre>y soon a2er the rock screen was installed, the well stopped surfacing ?uid. This well will be sidetracked and redrilled. The objec6ve of this program is to abandon the reservoir in prepara6on for the sidetrack, which is scheduled for September 2023. The patches were pulled on this well, and an injec6vity test was performed, but 2M-24 does not have any injec6vity. The next step was to punch the tubing tail below the packer to a>empt to gain injec6vity that way, but no access to reservoir was gained a2er pressuring up the tubing to 2500 psi. During the injec6vity test, the well nearly passed a CMIT-TxIA against the <ll/rock screen (pressure readings over 30 minutes were 2500/2275/2200 psi) The updated procedure will abandon the well from top of <ll/rock screen (6977’ RKB), placing cement into the tubing and IA from the rock screen up. This is within 100’ of the perfora6ons, and ~300’ of cement will be placed into the tubing and IA. Notes: Current TIO pressure= 200/1300/650. Two tubing leaks @ 1814’ and 6893’ RKB Inclina6on Max: 39 deg @ 2114’ RKB Min ID: 2.812” TRSV @ 1808’ RKB Last SBHP 07/7/22 || 4299 psi || 6908’ RKB Planned KOP for sidetrack 6550’ RKB Calculaons Procedure: Coil 1. Pull patches from 1789’ RKB and 6876’ RKB 2. Perform injec6vity test into the perfs (if injec6vity is not at least 2 bpm at < 2000 psi contact interven6ons engineer to discuss plan forward) a. 6/29/23 an injec6vity test was performed a2er punching tubing tail just above the rock screen and no communica6on with the reservoir was established 3. RU coil and cementers and RIH to rock screen at 6977’ RKB String Top Bottom Size ID bbls/ft volume ft/bbl notes 3.5" tubing 0 6990 3.5" 9.3# 2.992" 0.0087 60.8 115.0 3.5" x 7" annulus (IA) 0 6962 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 183.9 37.9 calc'd from packer 7" casing 6990 7282 7" 26# 6.28" 0.0383 11.2 26.1 100' below perfs 4. Pull up hole to 6600’ RKB laying in 13 bbls of cement (3.5 bbls into tubing and 9.5 bbls into IA) 5. Squeeze cement into IA through tubing hole at 6893’ RKB, max pressure 2500 psi 6. A2er cement is pumped away, POOH and circulate clean from 6600’ to surface 7. RDMO Slickline & Fullbore 1. WOC for minimum 24 hours. No6fy AOGCC inspector of cement 6ming and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 6600’ RKB, record results 4. CMIT-TxIA to 1500 psi (AOGCC witness), record results Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,130.0 2M-24 2/5/2022 famaj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Punch Tbg 2M-24 6/29/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS FCO'd ON 4/28/2020. 4/28/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,791.9 47.00 L-80 BTC ABMOD PRODUCTION 7 6.28 38.8 7,436.3 6,348.5 26.00 J-55 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 38.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.0 38.0 0.09 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV 5.250 CAMCO TRDP-4A-RO SAFETY VALVE CAMCO TRDP- 4A RO 2.812 3,214.2 2,848.8 32.90 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,714.2 4,098.4 34.15 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,244.5 4,535.3 34.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,652.6 4,870.7 35.06 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,094.8 5,235.2 34.75 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,535.0 5,595.9 35.05 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,814.0 1,713.0 36.96 TUBING LEAK IDENTIFIED TUBING LEAK WITH SPINNER @ 1814' 9/23/2020 2.990 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,970.0 5,956.6 33.49 TUBING PUNCH 2" x 3' TBG PUNCH, 3/8" TITAN KNOCKOUT CHARGES, 7g, 6 SPF, 0 DEG PHASING 6/29/2023 2.992 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,214.2 2,848.8 32.90 1 GAS LIFT GLV BK 1 1,281.0 5/16/2020 0.016 4,714.2 4,098.4 34.15 2 GAS LIFT GLV BK 1 1,316.0 5/16/2020 0.188 5,244.5 4,535.3 34.62 3 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 5,652.6 4,870.7 35.06 4 GAS LIFT OV BK 1 0.0 5/17/2020 0.250 6,094.8 5,235.2 34.75 5 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 6,535.0 5,595.9 35.05 6 GAS LIFT DMY BTM 1 0.0 5/26/2017 0.000 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN OPEN 1 1/2 0.0 7/30/2020 OPEN 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun 2M-24, 7/11/2023 11:43:15 AM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 GAS LIFT; 6,535.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP 1 Conklin, Amy A From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Tuesday, June 27, 2023 11:14 AM To:O'Connor, Katherine Subject:[EXTERNAL]Re: 2M-24 Procedure Update 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. Katherine, Tubing punch approved. If injection unsuccessful then submit 10-403 change of approved program. Victoria Sent from my iPhone On Jun 27, 2023, at 10:53 AM, O'Connor, Katherine <Katherine.OConnor@conocophillips.com> wrote: Hi Victoria As I mentioned on the phone, the patches were pulled on 2M-24, and they attempted an injectivity test but were not able to inject any fluid into the well. It immediately pressured up to 2000 psi. I request approval to tubing punch the tubing tail at ~6970’ RKB (below the packer but above the rock screen) as an attempt to bypass the rock screen and get injectivity into the perforations. Then continue with the approved sundry as planned from step 4 on. If we are still unable to inject into the well, I would request to perform the coil abandonment from top of rock screen leaving ~400’ of cement in the tubing. Thank you! Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) <Sundry_323-302_062623.pdf> 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. 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: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7450'7130' Casing Collapse Conductor Surface 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: 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 writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Katherine O'Conner katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Intervention Engineer Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: J-55 6990' 6/12/2023 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 192-050 P.O. Box 100360, Anchorage, AK 99510 50-103-20171-00-00 ConocoPhillips Alaska, Inc. KRU 2M-24 N/A-SuspendedKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6360' 7130' 6090' None MD 121' 2792' 121' 3146' 6348'7436' 16" 9-5/8" 79' 3104' Perforation Depth MD (ft): 7070-7079', 7103-7112', 7122- 7137', 7156-7182' 7397' 6040-6048', 6068-6075', 6084- 6096', 6112-6134'3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Packer: Baker HB Rtrvbl Packer SSSV: Camco TRDP-4A-RO Sfty Vlv 6961' MD and 5949' TVD 1808' MD and 1708' TVD 323-302 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.05.23 14:31:28-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor Suspension expires 12/31/2023 10-407 VTL 6/26/2023 Suspended DSR-5/24/23 X SFD 5/30/2023 X X NOVTL 6/26/23Suspend BWH 6/26/23 06/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 14:11:42 -08'00' RBDMS JSB 062723 Date: 5-16-23 Date of Work: 6-12-23 Subject: 2M-24 Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Well History 2M-24 is a gas liŌed producer that has TxIA communicaƟon. It has two patches installed from 1792’ – 1818’ RKB and 6876’ – 6904’ RKB to cover holes at 1814’ and 6893’ RKB. This well began producing Įll and rocks to surface, so a rock screen was installed. PreƩy soon aŌer the rock screen was installed, the well stopped surfacing Ňuid. This well will be sidetracked and redrilled. The objecƟve of this program is to abandon the reservoir in preparaƟon for the sidetrack, which is scheduled for 1 August 2023. Notes: x Current TIO pressure= 200/1300/650. x Two tubing leaks @ 1814’ and 6893’ RKB x InclinaƟon Max: 39 deg @ 2114’ RKB x Min ID: 2.812” TRSV @ 1808’ RKB x Last SBHP 07/7/22 || 4299 psi || 6908’ RKB x Planned KOP for sidetrack 6550’ RKB CalculaƟons Procedure: Coil 1. Pull patches from 1789’ RKB and 6876’ RKB 2. Perform injecƟvity test into the perfs (if injecƟvity is not at least 2 bpm at < 2000 psi contact intervenƟons engineer to discuss plan forward) 3. DriŌ to TD 4. RIH with one trip cement retainer, set retainer @ ±6930’ RKB (middle jt of tubing) 5. The total cement pumped is 16 bbls (12 below retainer and 3 above retainer) for planned TOC at 6600’ RKB. Recalculate cement volumes as necessary depending on retainer depth. 6. RU Cementers and pump the following cement schedule: a. ±10 bbl diesel to establish injecƟvity b. ±15 bbl freshwater spacer c. ±15 bbls 15.8ppg Class G cement 7. AŌer 12 bbls pumped, unsƟng from retainer and lay in remaining cement (TOC should be approx. 6600’ RKB 8. POOH above TOC and circulate clean String Top Bottom Size ID bbls/ft volume ft/bbl notes 3.5" tubing 0 6990 3.5" 9.3# 2.992" 0.0087 60.8 115.0 3.5" x 7" annulus (IA) 0 6962 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 183.9 37.9 calc'd from packer 7" casing 6990 7282 7" 26# 6.28" 0.0383 11.2 26.1 100' below perfs The objecƟve of this program is to abandon the reservoir in preparaƟon for the sidetrack, which is scheduled for 1 August 2023. 9. RDMO Slickline & Fullbore 1. WOC for minimum 24 hours. NoƟfy AOGCC inspector of cement Ɵming and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 6600’ RKB, record results 4. CMIT-TxIA to 2500 psi (AOGCC witness), record results 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch /Screen Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7450' feet None feet true vertical 6360' feet 7130'feet Effective Depth measured 7130'feet 1789', 1818', 6876', 6905', 6961' feet true vertical 6090'feet 1693', 1716', 5878', 5902', 5949' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 6990' MD 5973' TVD Packers and SSSV (type, measured and true vertical depth) 1789' MD 1818' MD 6876' MD 6905' MD 6961' MD 1808' MD 1693' TVD 1716' TVD 5878' TVD 5902' TVD 5949' TVD 1708' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3146' 2792' Burst Collapse Production Liner 7397' Casing 6348'7436' 3104' 121'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-050 50-103-20171-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025586 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2M-24 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~ ~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker HB Rtrvbl Packer SSSV: Camco TRDP-4A-RO Sfty Vlv Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 7070-7079', 7103-7112', 7122-7137', 7156-7182', 6040-6048', 6068-6075', 6084-6096', 6112-6134' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 7:07 am, Jan 26, 2023 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.01.25 16:26:20-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 25, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for two retrievable tubing patches and a down hole rock screen set in producer KRU 2M-24 (PTD #192-050). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.01.25 16:25:47-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 11/19/2022 REPAIR WELL BRUSH n' FLUSH PATCH INTERVALS & D-NIPPLE @ 6978' RKB (VERY TIGHT PUMPING INTO WELL); SET 2.75" CA-2 PLUG @ 6978' RKB; CMIT TBG X IA TO 2500 PSI (PASS); ATTEMPT TO PULL PRONG FROM CA-2 PLUG @ 6978' RKB. IN PROGRESS. 11/20/2022 REPAIR WELL PULLED 2.75" CA-2 PLUG @ 6978' RKB. JOB SUSPENDED DUE TO LACK OF PUMP SUPPORT. IN PROGRESS. 11/21/2022 REPAIR WELL MAKE MULTIPLE DRIFTS & SET 2.75" C -LOCK W/ ROCK SCREEN IN (18' OAL) D-NIPPLE @ 6978' RKB. READY FOR PATCH 11/29/2022 REPAIR WELL SET 2.725" P2P LOWER PACKER W/ ME @ 6907'. CCL STOP DEPTH = 6896.7'. CCL TO ME=10.3'. JOB IS READY FOR SL 12/19/2022 REPAIR WELL RAN 3 1/2" TTS TEST TOOL TO LOWER P2P @ 6904' RKB & CMIT TBG X IA TO 2500 PSI (PASS); ((UTILIZING 1.69" DPU))SET UPPER 2.725" P2P (CPP35003), SPACER PIPE, & ANCHOR LATCH (CPAL35194) @ 6873' RKB (MID ELEMENT @ 6876' RKB). DPU BOUND UP ON PACKER AND HAD TO LIGHTLY TAP UP TO GET RELEASED (DPU SHOWED IT STROKED 3" & ONLY NEEDS 2.5" TO FULLY SET INDICATING PACKER SET). IN PROGRESS. 12/20/2022 REPAIR WELL RAN 3 1/2 TTS TEST TOOL TO UPPER PATCH 6873' RKB. CMIT PASSED TO 2500 PSI. PULLED OV @ 5652' RKB & GLV @ 4714' RKB, SET DV @ 5652' RKB, IN PROGRESS. 12/21/2022 REPAIR WELL SET OV @ 4714' RKB. REPLACED GLV @ 3214' RKB w/ IN KIND. PULLED TTS TEST TOOL @ 6873' RKB, LDFN, SWAP TO RELAY, IN PROGRESS. 12/22/2022 REPAIR WELL SET 3 1/2 LOWER P2P PKR @ 1818' RKB ( COE), IN PROGRESS. P2P # (CPP35225) 12/23/2022 REPAIR WELL SET 3 1/2 29' P2P UPPER PATCH ASSY' @ 1786' RKB, BLEED IA FROM 1650 TO 500 PSI, HELD SOLID, JOB COMPLETE. P2P # CPP35141 ANCHOR LATCH: CPAL35036 12/28/2022 ACQUIRE DATA (AC EVAL) : TIFL PASSED. 2M-24 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,130.0 2M-24 2/5/2022 famaj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set upper on patch #1. set complete #2 patch 2M-24 12/23/2022 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS CLEANED OUT ON 4/28/2020. TAG AT 7,100'. 4/28/2020 rwocoman General Notes: Last 3 entries Com Date Last Mod By Bottom Latch GLV @ 6535''RKB 4/10/1998 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,791.9 47.00 L-80 BTC ABMOD PRODUCTION 7 6.28 38.8 7,436.3 6,348.5 26.00 J-55 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 38.0 Set Depth 6,990.3 Set Depth 5,973.5 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.0 38.0 0.09 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV 5.250 CAMCO TRDP-4A-RO SAFETY VALVE CAMCO TRDP- 4A RO 2.812 3,214.2 2,848.8 32.90 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,714.2 4,098.4 34.15 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,244.5 4,535.3 34.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,652.6 4,870.7 35.06 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,094.8 5,235.2 34.75 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,535.0 5,595.9 35.05 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,789.0 1,693.1 36.89 PACKER - PATCH - UPR Upper patch assembly 2.72" P2P, XO, spacer pipe &anchor latch.(OAL 30') 12/23/2022 1.625 1,792.0 1,695.5 36.90 SPACER PIPE Spacer Pipe CPAI 12/23/2022 1.600 1,814.0 1,713.0 36.96 TUBING LEAK IDENTIFIED TUBING LEAK WITH SPINNER @ 1814' 9/23/2020 2.990 1,818.0 1,716.2 36.97 PACKER - PATCH - LWR Set Lower packer CPP3 5225 12/22/2022 1.625 6,876.0 5,878.3 33.66 PACKER - PATCH - UPR Upper patch assembly 2.72 P2P, xo, spacer pipe, & anchor latch (31.71 OAL) CPP3 5003 12/19/2022 1.625 6,879.0 5,880.8 33.66 SPACER PIPE Spacer pipe & anchor latch CPAL 35194 12/19/2022 1.600 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,904.6 5,902.1 33.65 PACKER - PATCH - LWR 2.725" (3.5") P2P LOWER PACKER W/ WLRG, OAL = 3.98', MOE = 6907' RKB CPP3 5326 11/29/2022 1.625 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,214.2 2,848.8 32.90 1 GAS LIFT GLV BK 1 1,281.0 5/16/2020 0.016 4,714.2 4,098.4 34.15 2 GAS LIFT GLV BK 1 1,316.0 5/16/2020 0.188 5,244.5 4,535.3 34.62 3 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 5,652.6 4,870.7 35.06 4 GAS LIFT OV BK 1 0.0 5/17/2020 0.250 6,094.8 5,235.2 34.75 5 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 6,535.0 5,595.9 35.05 6 GAS LIFT DMY BTM 1 0.0 5/26/2017 0.000 2M-24, 1/24/2023 9:48:41 AM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 PACKER; 6,961.5 PACKER - PATCH - LWR; 6,904.5 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 SPACER PIPE; 6,879.0 PACKER - PATCH - UPR; 6,876.0 GAS LIFT; 6,535.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 PACKER - PATCH - LWR; 1,818.0 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 SPACER PIPE; 1,792.0 PACKER - PATCH - UPR; 1,789.0 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN OPEN 1 1/2 0.0 7/30/2020 OPEN 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun 2M-24, 1/24/2023 9:48:42 AM Vertical schematic (actual) PRODUCTION; 38.8-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 PACKER; 6,961.5 PACKER - PATCH - LWR; 6,904.5 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 SPACER PIPE; 6,879.0 PACKER - PATCH - UPR; 6,876.0 GAS LIFT; 6,535.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 PACKER - PATCH - LWR; 1,818.0 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 SPACER PIPE; 1,792.0 PACKER - PATCH - UPR; 1,789.0 CONDUCTOR; 42.0-121.0 KUP PROD 2M-24 ... WELLNAME WELLBORE2M-24 Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1Y-27 50-029-22379-00 n/a Kuparuk River Packer Setting Record Field- Final 8-Sep-20 0 1 2 2B-02 50-029-21154-00 906718091 Kuparuk River Packer Setting Record Field- Final 20-Sep-20 0 1 3 2F-05X 50-029-22730-00 906726469 Kuparuk River Packer Setting Record Field- Final 28-Sep-20 0 1 4 2H-09 50-103-20050-00 n/a Kuparuk River Plug Setting Record Field- Final 6-Sep-20 0 1 5 2M-03 50-103-20160-00 906439276 Kuparuk River Packer Setting Record Field- Final 21-Sep-20 0 1 6 2M-24 50-103-20171-00 906726590 Kuparuk River Leak Detect Log Field- Final 23-Sep-20 0 1 7 2M-24 50-103-20171-00 906726590 Kuparuk River Packer Setting Record Field- Final 23-Sep-20 0 1 8 2T-209 50-103-20281-00 906722868 Kuparuk River Water Flow Log Field & Processed 28-Sep-20 0 1 9 3B-03 50-029-21322-00 906711627 Kuparuk River Leak Detect Log Field- Final 15-Sep-20 0 1 10 3B-03 50-029-21322-00 906711627 Kuparuk River Packer Setting Record Field- Final 16-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1920500 E-Set: 34336 12/07/2020 Abby Bell Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1Y-27 50-029-22379-00 n/a Kuparuk River Packer Setting Record Field- Final 8-Sep-20 0 1 2 2B-02 50-029-21154-00 906718091 Kuparuk River Packer Setting Record Field- Final 20-Sep-20 0 1 3 2F-05X 50-029-22730-00 906726469 Kuparuk River Packer Setting Record Field- Final 28-Sep-20 0 1 4 2H-09 50-103-20050-00 n/a Kuparuk River Plug Setting Record Field- Final 6-Sep-20 0 1 5 2M-03 50-103-20160-00 906439276 Kuparuk River Packer Setting Record Field- Final 21-Sep-20 0 1 6 2M-24 50-103-20171-00 906726590 Kuparuk River Leak Detect Log Field- Final 23-Sep-20 0 1 7 2M-24 50-103-20171-00 906726590 Kuparuk River Packer Setting Record Field- Final 23-Sep-20 0 1 8 2T-209 50-103-20281-00 906722868 Kuparuk River Water Flow Log Field & Processed 28-Sep-20 0 1 9 3B-03 50-029-21322-00 906711627 Kuparuk River Leak Detect Log Field- Final 15-Sep-20 0 1 10 3B-03 50-029-21322-00 906711627 Kuparuk River Packer Setting Record Field- Final 16-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1920500 E-Set: 34335 12/07/2020 Abby Bell Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 2N-345A 50-103-20264-01 906623204 Tarn Perforation Record Field- Final 25-Jul-20 0 1 2 2U-02 50-029-21268-00 906648446 Kuparuk River Packer Setting Record Field- Final 11-Aug-20 0 1 3 CPF-1A 50-029-21243-00 n/a Shallow Sands Leak Detect Log Field- Final 26-Aug-20 0 1 4 2G-08 50-029-21125-00 906640095 Kuparuk River Leak Detect Log and Plug Setting RecordField- Final 4-Aug-20 0 1 5 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 7-Aug-20 6 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 8-Aug-20 7 2M-33 50-103-20240-00 906598622 Kuparuk River Multi Finger Caliper Field- Processed 9-Aug-20 0 1 8 1A-23 50-029-22131-00 n/a Kuparuk River Leak Detect Log Field- Final 11-Aug-20 0 1 9 2B-02A 50-029-21154-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Aug-20 0 1 10 2M-10 50-103-20157-00 906659029 Kuparuk River Multi Finger Caliper Field- Processed 15-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 1920500 E-Set: 34231 Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 2N-345A 50-103-20264-01 906623204 Tarn Perforation Record Field- Final 25-Jul-20 0 1 2 2U-02 50-029-21268-00 906648446 Kuparuk River Packer Setting Record Field- Final 11-Aug-20 0 1 3 CPF-1A 50-029-21243-00 n/a Shallow Sands Leak Detect Log Field- Final 26-Aug-20 0 1 4 2G-08 50-029-21125-00 906640095 Kuparuk River Leak Detect Log and Plug Setting RecordField- Final 4-Aug-20 0 1 5 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 7-Aug-20 6 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 8-Aug-20 7 2M-33 50-103-20240-00 906598622 Kuparuk River Multi Finger Caliper Field- Processed 9-Aug-20 0 1 8 1A-23 50-029-22131-00 n/a Kuparuk River Leak Detect Log Field- Final 11-Aug-20 0 1 9 2B-02A 50-029-21154-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Aug-20 0 1 10 2M-10 50-103-20157-00 906659029 Kuparuk River Multi Finger Caliper Field- Processed 15-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 1920500 E-Set: 34232 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing patches ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7450 feet None feet true vertical 6360 feet None feet Effective Depth measured 6978 feet 6962 feet true vertical 5963 feet 5950 feet Perforation depth Measured depth 7070 - 7182 feet True Vertical depth 6040 - 6134 feet Tubing (size, grade, measured and true vertical depth)3.5 J-55 6990 5974 Packers and SSSV (type, measured and true vertical depth)Baker HB packer 6962 / 5950 Camco TRDP-4A-RO 1808 / 1708 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 10/2/2020 Contact Phone: Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist ----- ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Conductor 79 16 121 121 N/A N/A N/A Production 7397 7 7436 6349 N/A N/A Surface 3104 9.625 3146 2792 N/A Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/ Kuparuk River Oil Plugs measured Junk measured Burst Collapse 192-050 50103201710000 ADL0025586 KRU 2M-24 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: t Fra O 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:04 am, Oct 05, 2020 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季安季宺宬宱宪孯季宎宒宆孯季宎宸害室宵宸宮宇室宷宨孽季孵孳孵孳孰孴孳孰孳孵季孴學孽孵孴孽學孺安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne DSR-10/12/2020 X VTL 11/03/20 RBDMS HEW 10/27/2020 SFD 10/6/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 2, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the two retrievable tubing patches set across a known tubing leaks in producer KRU 2M-24 (192-050). Please contact Dusty Freeborn or me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季安季宺宬宱宪孯季宎宒宆孯季宎宸害室宵宸宮宇室宷宨孽季孵孳孵孳孰孴孳孰孳孵季孴學孽孵孴孽孶孵安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne Date Event Summary Executive Summary 2M-24 was identified to have high IA pressure while shut in. Diagnostics culminated in an LDL locating a tubing leak at 6893'. After setting a rock screen at 6978' a 2.72" OD, 32' OAL, Paragon 2 Packer retrievable patch was set across the tubing leak at 6893'. During testing of the patch an additional leak was identified at ~1800'. A 2.72" OD, 14' OAL, Paragon 2 Packer retrievable patch was set across the leak at ~1800'. The well was brought online for approximately 2 days, but failed to surface fluids and when the well was shut in IA-FL shots showed inflow into the IA indicating TxIA. A 96 hour flow test with TxIA was granted by the AOGCC to determined if the well would flow and what diagnostics were necessary. After a passing flow test diagnostics culminated in an LDL locating an additional leak in the tubing at 1814' (after the upper patch had been pulled). A new 2.72" OD, 27' OAL, Paragon 2 Packer retrievable patch was set over the tubing leaks. A passing MITT above the upper packer was acquired and a passing TIFL was completed after the well was brought online. Pertinent well work is copied below. 06/08/20 LOG SPINNER TEMP. LOG FROM 6978' RKB TO SURFACE, FOUND LEAK @ 6893' RKB, NO OTHER LEAKS OBSERVED. IN PROGRESS. 07/30/20 SET EXT PKG DV @ 6893' RKB (MITT FAILED W/ COMM TO IA & ESTABLISHED 2BPM LLR @ 1300 PSI); PULLED EXT PKG DV @ SAME; DRIFT W/ 31' X 2.74" DMY PATCH DOWN TO CATCHER @ 6973' RKB; READY FOR RELAY ONCE ROCKSCREEN ARRIVES TO KUPARUK. IN PROGRESS. 08/07/20 SET 2.75" C-LOCK W/ 250 MICRON SCREEN @ 6978' RKB (OAL 218"), BRUSH n' FLUSH PATCH AREA FROM 6925' TO 6850', SET LOWER 2.72" P2P @ 6905' RKB (ME), RAN 3 1/2 TTS TEST TOOL TO LOWER P2P @ SAME CMIT TBG x IA 2500 PSI PASSED, SET UPPER 2.72" P2P SPACER ANCHOR LATCH @ 6877' RKB (ME) (OAL 28.87' / SN:CPP35241 / CPAL35022), SET 3 1/2 TTS TEST TOOL IN UPPER PACKER @ 6877' RKB, MIT TBG FAILED WITH COMMUNICATION TO IA, CMIT TBG x IA 2500 PASS. IN PROGRESS. PRE CMIT T/I/O= 1700/1700/760, PRESSURE UP (.7 BBLS) T/I/O= 2550/2500/760, 15 MIN T/I/O= 2500/2500/760, 30 MIN T/I/O= 2500/2500/760 08/08/20 ESTABLISH .1 BPM LLR @ 3000 PSI, RAN SMART SLIP STOP HOLE FINDER FROM 3 1/2 TTS TEST TOOL @ 6870' RKB NARROW LEAK DOWN BETWEEN 1801' RKB TO 1796' RKB, PULLED 3 1/2 TTS TEST TOOL @ 6877' RKB, SET 2.72" P2P @ 1803' RKB (ME) (OAL 4.01' / SN:CPP35247), SET UPPER 2.72" P2P PATCH ASSEMBLY @ 1792' RKB (ME) (OAL 11.88' / SN: CPP35150 / CPAL35145) DRAW DOWN TEST FAILED, MIT TBG 2500 WITH TEST TOOL IN UPPER PACKER @ 1792' RKB PASS. COMPLETE. PRE MITT T/I/O= 1425/1400/760, PRESSURE UP (.1 BBLS) T/I/O= 2550/1400/760, 15 MIN T/I/O= 2450/1400/760, 30 MIN T/I/O= 2450/1400/760 08/17/20 Jan, Approval is granted for the 96 hour flow test as outlined below. Thanx, Victoria Victoria, KRU 2M-24 (PTD 192-050) recently had a rock screen and two anncomm tubing patches installed (10-404 pending post successful testing). The well was BOL for approximately 2 days, but failed to produce fluids and was shut back in. Post shut in IA-FL shots showed fluid inflow into the IA indicating TxIA communication. CPAI intends to pump into the rock screen and then attempt to flow the well prior to completing AnnComm diagnostics to determine if the well will flow or the rock screen needs to be pulled. CPAI requests a 96 hour flow test period with known TxIA communication to determine if the well will flow with the rock screen. The path forward will be based upon the results of the flow test. 09/23/20 LEAK DETECT LOGGING FROM 6877' RKB TO SURFACE (TIED INTO TBG TALLY & DETERMINE LEAK @ 1814' RKB W/NO ADDITIONAL LEAKS OBSERVED); PULLED TTS TEST TOOL @ 6877' RKB; BRUSH n' FLUSH TBG FROM 1850'- 1750' RKB; SET LOWER 2.72" P2P (4.01' OAL / SN: CPP35265) W/ ME @ 1816' RKB; SET UPPER 2.72" P2P (SN: CPP35099), SPACER, & ANCHOR LATCH (CPAL35064) 25.88' OAL W/ ME @ 1790.5' RKB; OBTAIN GOOD IA DDT & MITT TO 3000 PSI W/ TTS TEST TOOL IN UPPER P2P @ 1791' RKB. JOB COMPLETE. BLEED IA FROM 1400 TO 200 PSI PRE MITT T/I/O= 1375/275/700 INITIAL T/I/O= 3025/275/700, 15 MIN T/I/O = 2875/275/700, 30 MIN T/I/O = 2850/275/700 ****PASS**** 09/30/20 (AC EVAL) Re-TIFL Passed. Initial T/I/O = 200/1275/720, IA FL @ 5653' ST#4 OV, OA FL @ 66' (600 fps, decimeter), 2 bbl FUV. SI WV, let tubing stack naturally for 80 min due to rock screen to T/I/O = 800/1250/680. SI and bled AL line, bled IA for 60 min to T/I/O = 800/480/640, IA FL @ same location. Bled IA for additional 20 min to T/I/O = 800/300/625, IA FL @ same location. 15 min: 800/300/625 30 min: 800/300/620, IA FL @ same location. 45 min: 800/300/620 60 min: 800/300/620, IA FL @ same location. Final T/I/O = SI 800/300/620 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled upper patch, Identified Tubing Leak, & Installed New Upper Patch 9/23/2020 2M-24 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.9 Set Depth (ftKB) 3,146.4 Set Depth (TVD) … 2,791.9 Wt/Len (l… 47.00 Grade L-80 Top Thread BTC ABMOD Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.8 Set Depth (ftKB) 7,436.3 Set Depth (TVD) … 6,348.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 38.0 Set Depth (ft… 6,990.3 Set Depth (TVD) (… 5,973.5 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 38.0 38.0 0.09 HANGER FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 6,947.8 5,938.1 33.58 PBR BAKER PBR w/ 10' STROKE, 4" SEAL BORE 3.000 6,961.5 5,949.5 33.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 6,977.8 5,963.1 33.45 NIPPLE CAMCO D NIPPLE 2.750 6,989.4 5,972.8 33.42 SOS BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 1,790.5 1,694.3 36.89 P2P PATCH- PACKER 2.72" P2P WITH SPACER PIPE, ANCHOR LATCH (25.88' OAL) 9/23/2020 1.625 CPP35099 1,794.5 1,697.5 36.91 SPACER PIPE 2-1/16" P110 SPACER PIPE W/ ANCHOR LATCH 9/23/2020 1.600 CPAL35064 1,814.0 1,713.0 36.96 TUBING LEAK IDENTIFIED TUBING LEAK WITH SPINNER @ 1814' 9/23/2020 2.990 1,815.0 1,713.8 36.96 P2P PATCH- PACKER 2.72" P2P PACKER (4.01' OAL) 9/23/2020 1.625 CPP35265 6,877.0 5,879.1 33.66 PATCH - PACKER 2.72" P2P WITH SPACER PIPE, ANCHOR LATCH, OAL 28.87 FT 8/7/2020 1.625 CPP35241 6,881.1 5,882.6 33.66 SPACER PIPE 2-1/16", P110 SPACER PIPE 8/7/2020 1.600 CPAL35022 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,905.0 5,902.5 33.65 PATCH - PACKER 2.72" P2P PACKER, 4.01' OAL 8/7/2020 1.625 CPP35256 6,978.0 5,963.3 33.45 SCREEN ROCK SCREEN ON 2.75" C-LOCK, 250 MICRON SCREEN, BN BOTTOM (OAL 218") 8/7/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,214.2 2,848.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.016 1,281.0 5/16/2020 2 4,714.2 4,098.4 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,316.0 5/16/2020 3 5,244.5 4,535.3 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 9/4/1992 4 5,652.6 4,870.7 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 5/17/2020 5 6,094.8 5,235.2 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 9/4/1992 6 6,535.0 5,595.9 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 5/26/2017 7 6,892.4 5,892.0 CAMCO MMG-2 1 1/2 GAS LIFT OPEN OPEN 0.000 0.0 7/30/2020 OPEN Notes: General & Safety End Date Annotation 4/28/2020 NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS CLEANED OUT ON 4/28/2020. TAG AT 7,100'. IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 SOS; 6,989.4 SCREEN; 6,978.0 NIPPLE; 6,977.8 PACKER; 6,961.5 PBR; 6,947.8 PATCH - PACKER; 6,905.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 SPACER PIPE; 6,881.1 PATCH - PACKER; 6,877.0 GAS LIFT; 6,535.0 GAS LIFT; 6,094.7 GAS LIFT; 5,652.6 GAS LIFT; 5,244.5 GAS LIFT; 4,714.2 GAS LIFT; 3,214.2 SURFACE; 41.9-3,146.4 P2P PATCH-PACKER; 1,815.0 TUBING LEAK; 1,814.0 SAFETY VLV; 1,808.0 SPACER PIPE; 1,794.5 P2P PATCH-PACKER; 1,790.5 CONDUCTOR; 42.0-121.0 HANGER; 38.0 eV 24— z4 Regg, James B (DOA) From: Bixby, Brian D (DOA) -7 Sent: Wednesday, December 28, 2016 4:07 PM (\II /7 To: Regg, James B (DOA) Subject: Emailing: 161228 Kuparuk 2M-Pad Deficiency Report.pdf, 161228 Kuparuk 2M Pad Deficiency Report.xlsx Attachments: 161228 Kuparuk 2M-Pad Deficiency Report.pdf; 161228 Kuparuk 2M Pad Deficiency Report.xlsx Jim, Just FYI 2M-24 and 2M-32 are temp well houses or hootches while the rig is on the next to them. I told Larry they still needed Well Identification sing and he agreed. Should you need anything else from me please let me know. Thanks, Brian Brian Bixby Petroleum Inspector N� M�� 111 Cell 509-998-3683 S �1 brian.bixby@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 Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. • State of Alaska Oil and Gas Conservation Commission I 5(i7 Deficiency Report Location: kv PAR vv.- wt Date: t Zt G g 1� PTD: 6A-JescorRotot4Ak3 6VL 050 Operator: AtAsitetk, Type Inspection:CJ, i 1.( Operator Rep: A t2.lZ1 12). KGS InspectorEgmZE lixsy Position: V � - ,�c(wc �2. a� Suer Op.Phone: , j - 7 b q2_ Correct by(date): ZJZgI'' , Op.Email: n 2...o 72 e (0116(0 c Follow Up Req'd: x.4240 Detailed Description of Deficiencies Date Corrected \itej 144 eZr4 13, Zw%-Z'i 4d4 ZA4.3z Aka, `"To h�r6�v t/t)Et. .. NT , 1CATto».1 Sii6;f4s 160.1 !tti6404o0 tS Attachments: , L � rZ L� 0Operator Rep Signatures: } g bog ®ziir/j , AOGCC Inspector *After signing,a copy of this form is to be left woperator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 � . 0 a r RE: Production Profile: 2M -24 Run Date: 6/7/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -24 7 r3 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom V 50 -103- 20171 -00 Production Profile Log 1 Color Log 50 -103- 20171 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: � SA/1 � Signed: 1ZZ_ Oki I .2 -n56 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2M -24 * ** Corrected Report and LAS - Replace previous distribution * ** Run Date: 6/7/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -24 * ** Corrected Report and LAS - Replace previous distribution * ** Digital Data in LAS format, Interpretation Report 1 CD Rom 50- 103 - 20171 -00 LI @ 5-r PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com 4 16 6 /a Date: { Signed: 1 � •-• oso ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 ~~ ~A~i ~ ~ ~~ Dear Mr. Maunder: • RECEIVED JAN ~ 8 100 Atka Oil & Gea Conan. Go~ir~l~vn AnchoraDe ~ ~-~°~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. Asper previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, Perry ConocoPhillips Weil Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Initial top Well Name PTD # cement ft 2M-01 192-103 21' 7" 2M-10 191-131 4" 2M-11 191-137 13" 2M-12 192-090 6" 2M-15 191-033 24" 2M-21 2M-24 191-129 192-050 8' 6" 2M-25 191-021 30" 2M-31 2M-32 196-077 192-104 SF 10' 4" 2M-33 2M-34 196-072 196-n79 SF cG Vol. of cement Final top of Cement top o um ed cement date bbis ft na 3.0 12" 12/25/2007 na 4" na na na na na 1.1 na na na 1.5 na 13" 6.. na 12" 6" 12/25p na 30" na 6" na 12" 12/2512 6" na 6" na 6" na sn/2nn7 f Corrosion inhibitor Corrosion inhibitor/ sealant date al 6 1/6/2008 8 1/6/2008 5.5 1/6/2008 3 1 /6/2008 5.5 1/6/2008 6 1 /6/2008 4 1/6/2008 5.5 1/6/2008 11 1/6/2008 1 1/6/2008 3 1/6/2008 2 1/6/2008 2 1/6/2008 3 1/6/2008 Scblllllbepg8P NO. 4468 Schlumberger -DCS 2525 Gambell Street. Suite 400 Anchorage. AK 99503·2838 ATTN: Beth 5~~NED CCT :; 1 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Kuparuk Well Job # ,,-". Date BL Color CD Log Description 2N-327 11839673 PERF/SBHP ~)tJ~ ~ {){~q 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE l ) -¡:C- I q ~- /:J::J 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE IO¡ ( -oc::l\ 10/04/07 1 2M-09A 11846446 WFL ():t..~ ¡qf. -(-¡qò 10/04/07 1 31-08 11837517 LDL I~t... - (")iff') 10/02/07 1 2M-24 11839670 PRODUCTION PROFILE ¡t:ì Q -D5() 10/03/07 1 1J-102 11846451 INJECTION PROFILE lJ-:tC- .9CXD -/t,O 10/10/07 1 1Y-02 11837516 INJECTION PROFILE í JTC' J èk~ - ~ 10/01/07 1 1E-112 11846450 INJECTION PROFILE l 1'"1"(\ . ::JI"\<J -cPr ( 1 0/1 0/07 1 2T-12A 11839669 LDL 1«.& - I :::l $( 10/02/07 1 2B-07 11837522 INJECTION PROFILE UT Œ I "if£.l-r-;:¡<-f 10/05/07 1 1E-12 11846447 DDL I "1C:l - 1"'\(,.. () 10/08/07 1 2N-327 11839671 SCMT ,::}-o'1--oCo'9 10/23/07 1 . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. i3 10/25/07 . . 06/08/07 Schlullbel'gep NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ], ]. 20m "nq¡,VZ¡1jI j"')¡~ fI, (¡':;f.""', t',"!¡'~' Gömm!S\I!!O:iìì " ,', ',',' Uì.t, 1 4 '>007 ,."",'","~I'iln.,""""" ~NW J 11 ' /Lic9 -D'Sb Field: Kuparuk f0V Well Job # Log Description BL Color CD Date 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1 Q-1 0 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V -08A 11629013 PMIT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY OS/20/07 1 2F -11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 , 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1 Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 1D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E PL E W M A TE R IA L U N D ER TH IS M A R K ER' C:LORI~MFILM. IX)C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate X Puli tubing _ Alter casing _ 2. Name of Operator: 15. Type of Well: ARCO Alaska, Inc. I Development X 3. Address: Exploratory ~. 7. P.O. Box 100360 Stratagrapic ~. Anchorage, AK 99510-0360 Service 4. Location of well at surface: 8. Plugging _ Perforate _ Repair well_ Other _ 6. Datum of elavation (DF or KB feet): 146' RKE Unit or Property: Kuparuk River Unit Well number: 114' FSU 554' F-WL, Sec 27, T11 N, R8E, UM At top of productive interval: 1118' FNL 1509' FEL, Sec 34, T11 N, R8E, UM At effective depth: 1164' FNL, 1366' FEL, Sec 34, T11 N, R8E, UM At total depth: 1182' FNL, 1313' FEL Sec 34, T11N, R8E, UM 2M-24 9. Permit number/approval number: 92-50 10. APl number: 50-103-20171-00 11. Field/Pool: Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured true vertical 7450 feet Plugs (measured) None 6360 feet Effective Deptl measured true vertical 7346 feet Junk (measured) None 6272 feet Casing Length Conductor 80' Surface 3100' Production 7391' Size Cemented 16" 220 Sx AS I 9-5/8" 613 Sx PF E & 483 Sx Class G 7" 206 Sx Class G Measured depth 121' 3146' 7434' True vertical depth 121' 1141' 6201' Liner Perforation Depth measured 7156' - 7182 true vertical 6112' - 6134 Tubing (size, grade, and measured depth) 3.5", 9.3 Cf/ft., J-55 EUE @ 6990' Packers and SSSV (type and measured depth) Pkr: Baker 'HE' @ 6961" SSSV: Camco TRDP-4A-RO @ 180E 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 3/31/98. Intervals treated (measured) 7156' - 7182' Treatment description including volumes used and final pressure Pumped 218116 lbs of 16/20, 12/18, and 10/14 ceramic proppant into the formation, final pressure = 5900 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 653 621 312 1270 250 Subsequent to operation 800 384 456 1277 249 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ~X 16. Status of well classification as: Oil X Gas_ Suspended _ Service _ 17. I hereby certify th.at the for,qgoing is. tr_ue and correct to the best of my knowledge. Signed~//~ Title: Wells Superintendent Form 10-404 R~v 06/15/8 / Date ~//~ ¢/¢~ ~ / /SUBMIT IN DUPLICATE,,~ Alaska, Inc. -~-'~UPARUK RIVER UNIT ',,,,ELL SERVICE REPORT K1 (2M-24(W4-6)) WELL JOB SCOPE JOB NUMBER 2M-24 FRAC, FRAC SUPPORT 0327981437.2 DATE DAILY WORK UNIT NUMBER 03/31/98 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O NoI (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE KD1940 230DS28M L $133,592 $140,369 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 325 PSI 700 PSI 148 PSI 500 PSII 400 PSII 600 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 218116 LBS OF PROP IN THE FORM W/14# PPA OF #10/14 @ THE PERF'S. MAXIMUM PRESSURE 5900 PSI & F.G. (.68). FREEZE PROTECTED TBG DOWN TO 2300' W/20 BBLS OF DIESEL. TIME LOG ENTRY 06:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). 09:00 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS NEEDED. SET TREESAVER AND PT'D THE HIGH PRESSURE LINES TO 9600 PSI. 09:30 10:20 12:10 PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. SLURRY VOLUME PUMPED 405 BBLS. USED 6201 LBS OF #16/20 PROP FOR SCOURING. MAXIMUM PRESSURE 5700 PSI AND ENDING PRESSURE 2500 PSI. STEPPED DOWN RATE AT THE END OF STAGE. S/D AND OBTAINED ISIP OF 1464 PSI W/F.G. @ (.68). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 8.9 MINS @ 1061 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 179 BBLS. MAXIMUM PRESSURE 4300 PSI AND ENDING PRESSURE 2650 PSI. S/D AND OBTAINED ISIP OF 1647 PSI W/F.G. @ (.71). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 13 MINS @ 1203 PSI. PAD VOLUME = 450 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. PUMPED 218481 LBS OF PROP (18200 LBS OF #16/20, 170617 LBS OF #12/18, & 29664 LBS OF #10/14). INJECTED 218116 LBS OF PROP IN THE FORMATION W/14# PPA OF #10/14 @ THE PERF'S. LEFT 365 LBS OF PROP IN THE WELLBORE AND EST FILL LEVEL TO BE @ 7300'. EST BHP OF 2500 PSI. FREEZE PROTECTED TBG DOWN TO 2300' W/20 BBLS OF DIESEL. 14:15 STARTED P,/D AND DEPRESSURED THE INNER CSG BACK TO 500 PSI. 15:00 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. 16:00 R/D COMPLETED AND ALL WELL SERVICE PERSONNEL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $350.00 APO $5,650.00 $5,650.00 DIES EL $400.00 $400.00 DOWELL $125,342.10 $125,342.10 HALLIBURTON $0.00 $3,427.71 LITTLE RED $2,200.00 $5,200.00 TOTAL FIELD ESTIMATE $133,592.10 $140,369.81 CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman KUPARUK FLUID LEVEL REPORT Well Date ~ Fluid Level Shot Down: sssv GLM OV or GLV Casing Tubing CSG Press During Shot =~ # TBG Press During Shot =/.,~ c~O # Reason For Shooting FL: To Determine Operating Valve Well Status: On Continuous GL Operating CSG Press = GL Rate (If Available) MCFD On Intermittent GL On Time = Min. Off Time = Hr. Min. Fluid Level Delta Time From End Of O~ Cycle No GL Min. Comments: 7;3o PERMIT DATA 92-050 CBT 92-050 CDN 92-050 CDR 92-050 CET 92-050 407 92-050 DAILY WELL OP OGCC Individual Well Geological Materials Inventory T DATA_PLUS 92-050 SURVEY L 5900-7305 L 3146-7450 L 3146-7450 L 5900-7305 R COMP DATE: 09/15/92 R 06/14-09/05/92 R 0.00-7450 92-050 5329 T 2968-7450 Page: 1 Date: 09/23/94 RUN DATE_RECVD 1 07/27/92 1 06/29/92 1 06/29/92 1 07/27/92 10/20/92 07/27/92 07/27/92 ALL 07/20/92 Are dry ditch samples required? yes_~And received? yes c°red?~~st~d Was the well escription received? Are well tests req~~~s nb ReOeived? yes no Well is in compliance 1~~-' Initial COMMENTS no yes no ARCO Alaska, Inc. Post Office E 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION Stimulate ?~-??. 2M-18 Stimulate Stimulate ~-iF ~:,'~ 2M-19 Stimulate Stimulate .~::.~._ ,~; ~ 2M-20 Stimulate Stimulate ~_~; ~-~z~¢~ 2M-21 Stimulate Stimulate q~_qct 2M-22 Stimulate Stimulate ti-~_ 5o 2M-24 Stimulate Stimulate o~,- ~t 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051696 (w/o atch) AR3B-6003-93 242-2603 STATE OF ALASKA AL....,KA OIL AND GAS CONSERVATION COMM.....~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 114' FSL, 554' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1118' FSL, 1509' FEL, SEC 34, T11N, R8E, UM At effective depth At total depth 1182' FNL, 1313' FEL, SEC 34, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7450' 6360' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 146' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-24 9. ~Permit number/approval number 10. APl number 5o-103-20171 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7346' true vertical 6272' feet feet Junk (measured) 13. Casing Length Size Structural Conductor 1 21 ' 1 6' Surface 3146' 9 5/8" Intermediate Production 7434' 7" Liner Perforation depth: measured 7156' - 7182' true vertical 6112' - 6134' Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 220 SX AS I 613 SX PF E ~ sx CLA 206 SX CLASS RECEIVED 2 0 3.5", 9.3# J-55 EUE, @ 6990' ~ A!asJ(a 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage CAMCO TRDP-4A-RO SSSV @ 1808', BAKER PBR @ 6948'~ BAKER HB RETR PKR @ 6961 Stimulation or cement squeeze summary Intervals treated (measured) 7156' - 7182' Treatmer~t description including volumes used and final pressure See Attached Summary 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 11/18/92 221 7 321 4 0 950 470 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby _certify that the foregoing is true and correct to the best of my knowledge. Signed '~~dJ ~//~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 10/24/92 GSW PI/SI W/DOWELL. PUMP GSW PI/SI'S @ 25 BPM. DATA AS FOLLOWS: STEP VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC PI/SI~i 150 3845 1547 3928 .69 0 FE=32% (SMART CLOS TIME), 28% (DOWELL), NO CHANGE TO PAD SIZE. GSW REFRAC W/DOWELL YF140D. PUMP 503 BBL PAD @ 25.5 BPM, LAST WHTP=4179 PSI. PUMPED 18.6 MLBS 16/20 CL IN 2 PPA STAGE, 178.4 MLBS 12/18 CL IN 4-12 PPA STAGES & 29.7 MLBS 10/14 CL IN 12 PPA STAGE @ 25.5 BPM, LAST WHTP=5740 PSI. WELL SCREENED OUR 27.4 BBLS INTO FLUSH, LAST WHTP=8000 PSI. TOT PROP: DESIGN=228.6 MLBS, IN FORM=213.8 MLBS W/12.0 PPA @ PERFS. TOT FLUIDS: WATER=1410 BBL, DSL(FLA + FLUSH)=31BBL, ADD'S=79 BBL. ALL FLUIDS LOOKED GOOD. SMART COMPUTER WORKED GOOD, NO TROUBLE W/STAGE ADVANCES. (ANGLEN) RECEIVED ~'IAY 2 0 i994 Oil & Gas Oons. Commission Anchorage STATE OF ALASKA ' ,~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Ciassirmation of Sewice Well OIL ~] GAS ['~ SUSPENDED [~] ABANDONED [~] SERVICE [---] 2 Name of Operator 7 Peff~ti{ Numb~ ARCO Alaska, Inc 92-50 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-103-20171 4 Location of well at surface 9 Unit or Lease Name 114' FSL, 554' FWL, SEC 27, T11N, R8E, UM ~ ~C:~,~,~[~, ~':~:~:;~'~ ~' , ._,.,-,--,- ~ KUPARUK RIVER i At Top Producing Interval 10 Well Nurd3er 1118' FSL, 1509' FEL, SEC34, T11N, RSE, UM i .......... ~! ,.~urf 2M-24 AtTolalDefXh i'~'~--~- ~/<,/>./, _.-~_~. . 11 Field and Pool 118Z FNL, 1313' FEL SEC 34, T11 N, R8E, UM ....................... ..~.~¢ KUPARUK RIVER FIELD 5 Elevation in fee{ (indicate KB, DF, ate..) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 146', PAD 105' GLI ADL 25586, ALK 2672 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, il offshore 116 No. of Completions 06/14/92. 06/18/92. 09/05/92. NA feet MSLI 1 17TotalDepth(MO+'rVD) 18 Plug Back Dep~h (MD+'rVD) 19 D~Survey 20 DeplhwhereSSSVsat 21 Thickness of pe~wafrost 7450'MD, 6360'TVD 7346'MD, 6272'TVD YES X~ NO bJ 1808' fee~MD 1400' APPROX 22 Type Electric or Other Logs Run CDR,CDN,GR,CET,CBT, GYRO, 23 CASING, UNER AND CEMENTING RECOFI~ I SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'i-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 121' 24' 220 SX ASI 9-5/8' 47#/36~ L-80/J-55 SURF 3146' 12-1/4' 613 SX PF E, 483 SX CLASS G 7' 26# J-55 SURF 7434' 8-1/2' 206 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Boitom and 25 TUBING RECORD interval, size and number) SIZE !DEPTH SET {MD) PACKER SET 3-1/2', 9.3#, J-55 6990' 6961' 7156'-7182' W/4-1/2' CSG GUN ~ 4 SPF MD 611Z-6134' TVD .26 ACID, FRACTURE, CEMENT ,SQUEEZE, ETC DEPTH INTERVAL ~ID) AMOiJNT & K]ND Ch= MATERIAL USED 27 PRODUCTION TEST ~-~ Date First Produclion JMethod of Operation (Flowing, gas Iii1, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,e Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (con') Press. 24-HO~R RATE ,~ Brief desc~'iplion of lithok>gy, porosily, fraclures, apparent dills and presence of oil, gas or water. Submit corn chips. ~"~ ~.~ Form 10-407 Subrr~ in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SDE N.NVE Include interval tested, pressure data, all fluids recoverd and gravity, I',~_.AS. DEPTH TRUE VERT. DEPTH GOR, and time o-f each phase. KUPARUK C TOP 7068' 60,.'.'~' NA KUPARUK C BO'I~'OM 7080' 6049' KUPARUK A TOP 7080' 6049' KUPARUK A Bo'FrOM 7258' 61 31. LIST OF A'I-I'ACI-WIENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the t°regoing is true and c°rrect to the best o~ my kn°Wledge Signed ~__ Title AREA~~I:1 Date ~--- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion, Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-24 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-103-20171 DAILY OPERATION~ PAGE: 1 ACCEPT: 06/13/92 08:06 SPUD: 06/14/92 01:06 RELEASE: 06/20/92 12:06 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 06/14/92 ( 1) TD: 756'( 0) 06/15/92 ( 2) TD: 3146' (2390) 06/16/92 ( 3) TD: 3146' ( 0) 06/17/92 ( 4) TD: 3408' ( 262) 06/18/92 ( 5) TD' 7105' ( 3697) DRILLING SURF HOLE MW: 8.9 VIS: 88 MOVE RIG F/2M-22 T/2M-24. RIG ACCEPT 20:00 6/13/92. N/U & TEST DIVERTER. SERVICE TOP DRIVE. P/U BHA, ORIENT TOOLS, DRILL ICE F/45 T/121. SPUD 01:00 6/14/92. DRILL F/121' T/756'. WIPING HOLE MW: 9.6 VIS: 84 DRILL F/756' T/1671'. BOTH MOYNO PUMPS WENT DOWN, MOYNO ROOM WAS FLOODED. REPAIRED PUMPS, RING GEAR ASSEMBLY WAS STRIPPED OUT ON ONE PUMP. RIG DOWN TIME. DRILL F/1671' T/3146' TD SURF HOLE. CIRC FOR WIPER TRIP. CEMENTING SURF CASING MW: 9.6 VIS: 68 SHORT TRIP TO HWDP. NO FILL. CIRC AND COND HOLE FOR 9 5/8" CSG. DROP SURVEY, TOH NO TIGHT SPOTS. RETRIEVE SURVEY, 1 IS 30 DEG OFF. RIH WITH NEW MWD, SURVEY EVERY 500'. CIRC AND COND MUD. WL SURVEY - MATCHES MWD. POOH. R/U AND RUN 9 5/8" CSG. WASH THROUGH BRIDGE F/1520-1560. FINISH RUNNING CSG. CIRC AND COND FOR CMT JOB. RUN LEAD SLURRY. DRILLING MW: 8.8 VIS: 31 CEMENT 9 5/8" CSG, LAND CSG. ND DIVERTER, INSTALL PACKOFF AND MU WELLHEAD. NU BOP, TEST. PULL TEST PLUG, RUN WEAR RING. CHANGE OUT NEYRFOR TURBINE, RIH W/ HWDP. TEST MWD TOOL, UNABLE TO GET TOOL TO TURN ON. POOH, CHANGEOUT ELECTRONICS IN MWD TOOL, RIH. CHECK MWD, OK. SLIP AND'CUT DRLG LINE CUT 105'. RIH, TAG WIPER PLUGS AT 3058', CLOSE RAMS AND TEST CSG TO 2000 PSI, LOST 75 PSI IN 30 MIN. DRILL PLUGS AND FLOAT COLLAR AT 3060, DRILL CEMENT AND FLOAT SHOE AT 3146'. CLEANOUT OLD HOLE AND DRILL 10' NEW HOLE TO 3172. CIRC HOLE CLEAN. WITH 8.8 PPG MUD PRESS. FORM AT 2814 AT EMW 12.5 PPG, OK. DRILL TO 3406 AT RPT TIME. DRILLING MW:10.3 VIS: 43 DRILL, LOG, & SURVEY F/3408' TO 4802'. ADT 5.0 HRS. SERVICE TOP DRIVE AND RIG. DRILL, LOG, & SURVEY F/4802' TO 7105'. ADT 13.75 HRS. WELL : 2M-24 OPERATION: RIG : PARKER 245 PAGE: 2 06/19/92 ( 6) TD: 7450' ( 345) 06/20/92 ( 7) TD: 7450' ( 0) 09/05/92 ( 8) TD: 7450 PB: 7346 RUNNING 7 CSG 7"@ 7433' MW:10.3 VIS: 43 DRILL, LOG, AND SURVEY FROM 7105 TO 7450. ADT 5.25 HRS. CIRC BTMS UP, PUMP SLUG. POH TO 9 5/8" SHOE, NO TIGHT SPOTS. SERVICE RIG AND TOP DRIVE. RIH, WASH THRU BRIDGE 6364-6384. RIH WASH 30' TO BTM, 3' FILL. CIRC HOLE CLEAN, PUMP SLUG. POH, NO TIGHT SPOTS. LAY DOWN BHA. PULL WEAR RING, RIG TO RUN 7" CSG. HOLD SAFETY MTG. RUNNING 7" CASING AT REPORT TIME. RIG RELEASED 7"@ 7433' MW:10.3 VIS: 78 CONT. RIH WITH 7" CASG. FILL PIPE EVERY JOINT. LOSE PARTIAL RETURNS FROM 6800-7410. WASH THRU BRIDGE F/7410-7433. LOST 67 BBLS WHILE CIRC AND WORKING PIPE DOWN. CIRC AND COND HOLE FOR CMT. CIRC AT 1-2 BPM - HOLE PACKING OFF. FREED UP, INCREASED RATE TO 5.5 BPM W/GOOD RETURNS, NO PACKING OFF. CIRC TOTAL OF 968 BBLS. RU HOWCO. PUMP 5 BBLS ARCO PREFLUSH, PT LINES TO 4000 PSI. PUMP 15 BBLS ARCO PREFLUSH (5 BPM @450 PSI), FIRST PLUG, PUMP 50 BBLS ARCO SPACER (7 BPM @900 PSI), SECOND PLUG, PUMP 206 SX (45 BBLS) PREM. CLASS G CMT AT 15.6 PPG (7 BPM @1200 PSI), TOP PLUG. DISPLACE W/280.5 BBLS 10.3 PPG BRINE. BUMPED PLUG TO 3500 PSI, OK. RD HOWCO. WELL FLOWING THRU 7"X9-5/8" ANNULUS (15 BBLS/HR) . MONITORED WELL - FLOW STOPPED. SET CSG SLIPS, MAKE ROUGH CUT ON 7". ND BOPE, MAKE FINAL CUT ON 7" CSG, NU TREE AND TEST - OK. INJECT 50 BBLS WATER FOLLOWED BY 70 BBLS DIESEL DOWN 7"X9-5/8" ANNULUS. RIG RELEASE AT 2400 HRS ON 6/19/92. RIG RELEASED 7"@ 7433" MW:10.3 NaC1/Br MVE RIG F/ 2M-17 TO 2M-24. ACCEPT RIG @ 0700 HRS 09/04/92. ND TREE. NU BOPE. TEST ALL TO 3000 PSI. TEST 7" CSG TO 3500 PSI-OK. RU SWS. MU PERF GUN. PERF A SAND F/7156'-7182' USED 4-1/2" CSG GUNS, 4 SPF, 180 DEGREES PHASING ALTERNATING 24 GM & 21 GM BH CHARGES. RD SWS. NU FLOW NIPPLE. RU FOSTER TONGS. RUN 3-1/2" SINGLE COMPLETION STRING. TBG TAIL @ 6990', BAKER HB RETRY PKR 6961', CAMCO TRDP-4A-RO SSSV @ 1808'. PRESS TEST ANN & TBG-OK. SET BPV. ND BOPE. NU TREE. TEST PACKOFF & TREE-OK. DISPLACE ANN & TBG W/DIESEL CAP. MONITOR WELL. SECURE WELL. CLEAN AROUND LOCATION. RELEASE RIG @ 03:30 HRS 09/05/92. SIGNATURE: (drillin~~g p~nt DATE: ORIGINAL I ICltOFILME ~t~//.3/c~c~ SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ ONTINUOUS r~ OOL RECEIVED JUL 2 7 1992 Alaska 0il & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 2M-24 (114'FSL,554'FWL,SEC 27,T11N,R8E,UM) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92425 Loc;ged By: SCHWARTZ Date 13-JUL-1992 Computed By: R. KRUNELL ~ SCHLIJ~IBF_RGER · GCT DIRECTTONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2M-24 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 13-JUL-1992 ENGINEER' SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION- LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 68 DEG 31MIN EAST COMPUTATION DATE' 1g-JUL-92 PAGE I ARCO ALASKA INC. 2M-24 KUPARLJK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 13-JUL-1992 KELLY BUSHING ELEVATION' 146.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION ~ZIMUTH DEPTH DEPTH DEPTH DEG MTN DEG MIN 0 0 -46.00 0 21 54.00 0 26 153 99 0 32 253 96 3 9 353 54 6 23 452 55 9 49 550 74 11 37 648 48 13 4 745 43 15 6 N 0 .OE S41 30 W $ 31 55 W $ 721W S43 11 E S50 4 E S53 9 E $54 19 E S55 OE S 56 56 E ENGINEER' SCHWARTZ 0 O0 100 O0 200 O0 300 O0 4O0 O0 500 O0 600 O0 700 O0 800 O0 900 O0 1000 O0 0 O0 -146.00 100 O0 200 O0 299 99 399 96 499 54 598 55 696 74 794 48 891 43 O0 1082 O0 1176 O0 1270 O0 1361 O0 1451 O0 1538 O0 1621 O0 1701 987 47 841.47 17 15 54 936.54 18 42 89 1030.89 20 7 07 1124.07 22 37 54 1215.54 24 58 25 1305.25 27 30 45 1392.45 31 24 51 1475.51 35 51 86 1555.86 36 55 69 1635.69 37 7 S 57 56 E S 58 27 E S 59 38 E S 62 10 E S 6351 E S 62 18 E S 61 39 E S 63 7 E S 63 9 E S 62 28 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 1100 1200 1300 1400 1500 1600 1700 1800 1900.00 1781 2000 O0 1861 12 1715 12 37 50 74 38 26 59 37 4 76 36 40 77 37 58 36 26 44 34 15 97 34 33 22 34 44 33 34 54 0. O0 -0.08 -0.24 -0.27 I. 56 10.02 23.32 41.62 62.13 86.03 113 36 143 85 176 53 212 46 252 68 296 64 345 19 400 51 459 78 519 70 2100 O0 1939 2200 O0 2018 2300 O0 2098 2400 O0 2178 2500 O0 2258 2600 O0 2340 2700.00 2422 2800.00 2505 2900.00 2587 74 1793 59 1872 76 1952 77 2032 58 2112 44 2194 97 2276 22 2359 33 2441 3000 O0 2669.45 2523.45 34 14 S 64 27 E S 65 14 E S 69 16 E S 70 51E S 70 41E S 71 28 E S 74 20 E S 74 13 E S 73 50 E 1053 S 73 29 E 1110 3100 3200 3300 3400 3500 3600 3700 3800 3900 580 19 641 87 703 32 763 05 822 99 883 20 940 42 996 60 22 06 O0 2752.96 2606.96 33 1 O0 2836.91 2690.91 32 52 O0 2920.77 2774.77 33 11 O0 3004.38 2858.38 33 20 O0 3087.89 2941.89 33 25 O0 3171.41 3025.41 33 19 O0 3255.00 3109.00 33 18 O0 3338.56 3192.56 33 17 O0 3422.22 3276.22 33 11 S 72 20 E 1166.95 S 70 40 E 1221.89 S 70 45 E 1276.18 S 70 57 E 1330,62 S 71 0 E 1385.42 S 70 50 E 1440.38 S 70 35 E 1495.34 S 70 26 E 1550.20 S 70 24 E 1605.09 S 70 15 E 1659.86 0 O0 0 29 0 O0 0 53 5 64 I 86 3 45 0 97 2 62 2.05 O00N 0 19 S 0 775 I 535 3 54 S 9 50S 18 13 S 29 24 S 41 53 S 55 14 S 0 O0 E 0 16W 0 56W 089W 0 29 E 7 03 E 17 92 E 33 22 E 50 43 E 70 76 E 0.00 N 0 0 E 0,25 S 40 17 W 0.96 S 36 8 W ,1 77 S 30 18 W 3 55 S 4 40 E 11 82 S 36 31E 25 49 S 44 41E 44 25 S 48 39 E 65 33 S 50 32 E 89 70 S 52 4 E I 90 I 04 I 92 3 24 2 29 2 97 5 29 2 69 0 47 0 24 70 10 S 86 103 121 139 159 182 208 235 262 94.23 E 117 44 S 53 21E 47 S 120.56 E 148 51 S 148.97 E 181 22 S 180.62 E 217 39 S 216.69 E 257 34 S 256.08 E 301 49 S 299.15 E 350 26 S 348.45 E 405 06 S' 401.60 E 465 60 S 455.16 E 525 36 S 54 21E 40 S 55 12 E 52 S 56 8 E 65 S 57 15 E 60 S 58 7 E 42 S 58 37 E 94 S 59 8 E 34 S 59 40 E 47 S 60 I E 1 82 0 63 3 61 0 39 0 57 3 78 0 49 0 42 0 15 0 35 289 98 S 509 39 E 586.14 S 60 21 E 316 11S 565 340 27 S 621 360 32 S 678 380 07 S 734 399 84 S 791 416 53 S 846 431.77 S 901 447.45 S 955 463.49 S 1010 38 E 647.75 S 60 47 E 92 E 708.92 S 61 19 E 22 E 767.99 S 62 I E 86 E 827.33 S 62 39 E 78 E 887.01 S 63 12 E 71 E 943.62 S 63 48 E 08 E 999.18 S 64 24 E 76 E 1055.31 S 64 55 E 53 E 1111.75 S 65 22 E 3 26 0 20 0 30 0 32 0 14 0 18 0 10 0 03 0 13 0 17 480 10 S 1065 12 E 1168 32 S 65 44 E 497 515 533 551 569 587 606 624 642 79 S 1117 73 S 1168 62 S 1219 50 S 1271 48 S 1323 68 S 1375 O0 S 1427 39 S 1479 88 S 1530 20 E 1223 49 E 1277 95 E 1331 81E 1386 80 E 1441 69 E 1495 44 E 1550 19 E 1605 77 E 1660 08 S 65 59 E 24 S 66 11E 56 S 66 22 E 23 S 66 33 E 09 S 66 43 E 96 S 66 52 E 75 S 67 0 E 58 S 67 7 E 29 S 67 13 E ARCO ALASKA INC. 2D-24 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE' 19-JUL-g2 PAGE 2 DATE OF SURVEY: 13-JUL-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASL~ED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MTN DEG MIN 4000 O0 3505 94 3359 94 33 8 4100 4200 4300 44O0 4500 4600 4700 4800 4900 O0 3589 O0 3673 O0 3755 O0 3838 O0 3921 O0 4003 O0 4086 O0 4169 O0 4251 68 3443 06 3527 83 3609 48 3692 10 3775 87 3857 65 3940 37 4023 98 4105 68 33 11 06 33 57 83 34 13 48 34 18 10 34 14 87 34 5 65 34 9 37 34 13 98 34 28 VERTICAL DOGLEG RECTANGUL.~R COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOL~-H EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG MIN S 70 6 E 1714 53 S 70 1E 1769 S 70 16 E 1824 S 70 9 E 1880 S 69 51E 1936 S 69 38 E 1993 S 69 35 E 2049 S 69 33 E 2105 S 69 36 E 2161 S 69 54 E 2217 16 34 44 70 04 15 23 41 75 0.08 0.24 0.86 0.16 0.13 0.24 0.13 0.10 0.16 0.79 661 44 S 1582 22 E 1714 91 S 67 19 E 680 698 717 737 756 776 795 815 834 10 $ 1633 87 $ 1685 85 S 1738 10 S 1791 59 S 1844 18 S 1896 76 S 1949 38 $ 2001 99 S 2054 58 E 1769 50 E 1824 31E 1880 20 E 1936 07 E 1993 66 E 2049 23 E 2105 88 E 2161 71E 2217 50 S 67 24 E 65 S 67 29 E 70 $ 67 34 E 94 S 67 38 E 24 S 67 42 E 34 S 67 45 E 40 S 67 48 E 57 S 67 50 E 89 S 67 53 E 5000 O0 4334 29 4188 29 34 39 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4416 O0 4498 O0 4580 O0 4663 O0 4745 O0 4827 O0 4909 O0 4991 O0 5074 53 4270 73 4352 99 4434 31 4517 62 4599 70 4681 60 4763 89 4845 45 4928 53 34 42 73 34 41 99 34 41 31 34 30 62 34 44 70 34 58 60 34 52 89 34 28 45 34 16 6000 O0 5157 08 5011 08 34 19 6100 6200 6300 640O 6500 66O0 6700 6800 690O O0 5239 O0 5321 O0 5403 O0 5485 O0 5567 O0 5649 O0 5732 O0 5815 O0 5898 49 5093 54 5175 41 5257 34 5339 26 5421 28 5503 10 5586 09 5669 30 5752 49 34 47 54 34 58 41 35 4 34 34 57 26 35 1 28 34 29 10 33 58 09 33 45 30 33 39 7000 O0 5981 64 5835 64 33 24 7100 ,00 6065 28 5919 28 33 2 7200 O0 6149 26 6003 26 32 46 7300 O0 6233 49 6087 49 32 24 7400 O0 6317 91 6171 91 32 24 7450 O0 6360 12 6214 12 32 24 S 70 27 E 2274 53 S 70 25 E 2331 S 70 15 E 2388 S 70 13 E 2445 S 70 10 E 2501 S 71 10 E 2558 S 71 16 E 2615 S 71 7 E 2673 S 71 17 E 2729 S 71 38 E 2786 38 3,0 14 89 64 70 01 77 13 S 72 7 E 2842.35 S 70 46 E 2898.91 $ 70 27 E 2956.04 S 70 34 E 3013.43 S 70 43 E 3070 72 S 70 51 E 3128 03 $ 71 27 E 3185 19 S 72 13 E 3241 13 S 72 38 E 3296 80 S 72 46 E 3352 10 S 72 28 E 3407.22 S 71 58 E 3461.93 S 72 4 E 3516.12 S 72 0 E 3569.92 S 72 0 E 3623.43 S 72 0 E 3650.19 0.10 0.21 0.15 0 60 0 13 0 52 0 48 0 85 0 20 0 39 0 20 0 89 0 19 0 23 0 29 0 33 1 82 0 14 0 41 0 25 0 43 0 44 0 30 0 O0 0 O0 0 O0 854 13 $ 2108 18 E 2274 64 S 67 57 E 873 892 911 930 949 968 986 1004 1022 19 S 2161 38 S 2215 63 S 2268 86 $ 2322 77 S 2375 14 S 2429 65 S 2484 94 S 2538 93 $ 2591 79 E 2331 40 E 2388 91E 2445 32 E 2501 87 E 2558 97 E 2615 27 E 2673 06 E 2729 55 E 2786 48 S 68 0 E 38 S 68 4 E 20 S 68 7 E 94 S 68 9 E 68 S 68 13 E 73 S 68 17 E 03 S 68 20 E 77 S 68 24 E 13 S 68 28 E 1040.43 S 2645.09 E 2842 35 S 68 32 E 1058 30 S 2698.83 E 2898 1077 1096 1115 1134 1153 1170 1187 1203 39 S 2752.71 E 2956 58 S 2806 84 E 3013 57 S 2860 93 E 3070 48 S 2915 08 E 3128 02 S 2969 21 E 3185 43 S 3022 48 E 3241 27 $ 3075 66 E 3296 73 S 3128 62 E 3352 92 S 68 35 E 05 S 68 37 E 44 S 68 40 E 74 $ 68 42 E 05 $ 68 44 E 22 S 68 47 E 18 S 68 50 E 87 S 68 54 E 20 S 68 57 E 1220 23 $ 3181 36 E 3407 35 S 69 1 E 1237 02 S 3233 55 E 3462 09 $ 69 4 E 1253 81 $ 3285 17 E 3516 30 S 69 7 E 1270 50 S 3336 42 E 3570 14 S 69 9 E 1287 20 S 3387 36 E 3623 68 $ 69 12 E 1295 56 S 3412 83 E 3650 46 S 69 13 E COMPUTATION DATE: 19-JUL-92 PAGE 3 ARCO ALASKA INC. 2M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 13-JUL-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ INTERPDLATE~ VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIUUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 7450 0 O0 -146 O0 0 0 N 0 0 E O0 987 47 841 O0 1861 12 1715 O0 2669 45 2523 O0 3505 94 3359 O0 4334 29 4[88 O0 5157 08 SOil O0 5981 64 5835 O0 6360 12 6214 0.00 47 17 15 S 57 56 E 113.36 12 37 50 S 64 27 E 580.19 45 34 14 S 72 20 E 1166 95 94 33 8 S 70 6 E 1714 53 29 34 39 S 70 27 E 2274 53 08 34 19 S 72 7 E 2842 35 64 33 24 S 72 28 E 3407 22 12 32 24 S 72 0 E 3650 19 0 O0 1 90 70.10 S 94.23 E 117 1 82 289.98 S 509.39 E 586 3 26 480,10 S 1065.12 E 1168 0 08 661.44 S 1582.22 E 1714 0 10 854.13 S 2108.18 E 2274 0.20 1040.43 S 2645.09 E 2842 0.43 1220.23 S 3181,36 E 3407 0.00 1295.56 S 3412.83 E 3650 0.00 N 0.00 E 0 O0 N 0 0 E 44 S 53 21E 14 S 60 21E 32 S 65 44 E 91 S 67 19 E 64 S 67 57 E 35 S 68 32 E 35 S 69 I E 46 S 69 13 E COMPUTATION DATE' 1g-JUL-g2 PAGE 4 ARCO ALASKA INC. 2M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 13-JUL-lgg2 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER- SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SLS-SEA DEPTH -F~E .S19B-S~ COL~SE MF_~ED VERTICAL VERTICAl._ DEVIATION AZIMLFFH DEPTH DEPTH DEPTH ,DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 146 O0 246 O0 346 01 446 18 546 82 648 25 750 34 853 03 956 68 0.00 -146 O0 146.00 0 246.00 100 346 O0 200 446 O0 300 546 O0 400 646 O0 500 746 O0 600 846 O0 700 946 O0 800 0 0 N 0 0 E O0 0 24 S 34 47 W O0 0 29 $ 27 29 W O0 I 3 S 22 36 E O0 5 18 S 48 49 E O0 7 50 S 51 21E O0 10 58 S 54 5 E O0 12 8 $ 54 25 E O0 14 13 S 56 21 E O0 16 21 S 57 38 E 15 31 51 74 101 0 O0 -0 16 -0 29 0 O2 4 80 47 77 65 37 06 0 O0 0 25 0 O0 2 46 2 67 4 08 I 88 I 29 I 78 2 26 0 O0 N 0 43 S I 09 S 2 O9 S 5 92 S 13 13 $ 23 29 S 35 27 S 48 59 S 63 42 S 000 E 0 34 W 0 74 W 0 80W 2 83 E 11 46 E 24 97 E 41 63 E 60 80 E 83 0.00 N 0 0 E 0.55 S 38 17 W 1.32 $ 34 24 W 2.24 $ 20 57 W 6.56 $ 25 33 E 17.43 S 41 7 E 34.15 S 46 59 E 54.56 S 49 44 E 77.83 S 51 22 E 65 E 104.97 S 52 50 E 1061 47 1046 O0 1167 1274 1382 1494 1608 1730 1855 1980 2107 16 1146 O0 1246 91 1346 09 1446 84 1546 32 1646 26 1746 89 1846 99 1946 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 18 16 O0 19 33 O0 21 52 O0 24 36 O0 27 20 O0 31 52 O0 36 27 O0 37 3 O0 37 39 O0 38 28 S 58 8 E $ 59 13 E S 61 21E S 63 46 E $ 62 25 E S 61 45 E S 63 19 E S 62 44 E $ 63 53 E S 65 16 E 131 84 165 52 202 71 245 59 293 95 349 76 418 30 492 87 568 53 646 82 1 28 1 59 3 16 2 16 2 99 5 51 1 12 0 54 2 27 0 65 80.05 S 110 18 E 136 19 S 54 0 E 97.84 S 139 116.57 S 171 136.25 S 210 158.08 S 253 184.67 $ 303 216.32 S 364 250.19 S 431 284.87 S 498 318.19 S 569 38 E 170 97 E 207 31E 250 68 E 298 19 E 355 39 E 423 21E 498 87 E 574 89 E 652 29 S 54 56 E 75 S 55 52 E 59 S 57 4 E 90 S 58 4 E O1 S 58 39 E 77 S 59 18 E 53 S 59 53 E 47 S 60 16 E 70 $ 60 49 E 2234 26 2046 O0 1900 OO 36 39 2358 2419.4 2606 2727 2849 2971 3091 3210 3330 98 2146 32 2246 73 2346 97 2446 64 2546 53 2646 69 2746 82 2846 16 2946 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 36 54 O0 36 50 O0 34 14 O0 34 39 O0 34 47 O0 34 45 O0 33 2 O0 32 53 OO 33 15 S 70 26 E S 7O 47 E 798 S 71 6 E 873 S 74 23 E 944 S 74 6 E 1012 S 73 42 E 1081 $ 72 54 E 1150 S 70 42 E 1217 S 70 45 E 1282 S 71 0 E 1347 723 87 33 84 19 4O 41 84 36 05 13 1 13 0 42 2 36 0 34 0 43 0 29 1 53 0 26 0 37 0 09 347.36 S 641 20 E 729 25 S 61 33 E 371 92 S 711 396 417 436 455 475 496 517 539 82 S 782 55 $ 850 10 S 916 36 S 982 29 S 1049 29 S 1112 67 S 1174 01S 1235 56 E 802 91E 877 35 E 947 36 E 1014 93 E 1083 71E 1152 93 E 1218 03 E 1283 57 E 1348 90 S 62 24 E 73 S 63 7 E 34 S 63 51E 84 S 64 33 E 29 S 65 9 E 3O S 65 38 E 57 $ 65 58 E 09 S 66 12 E 02 S 66 26 E 3449 82 3046.00 29D0 O0 33 23 3569 3689 3808 3928 4047 4167 4288 4409 4530 59 3146.00 3000 O0 33 20 24 3246.00 3100 O0 33 17 89 3346.00 3200 O0 33 16 41 3446.00 3300 O0 33 10 83 3546.00 3400 O0 33 6 44 3646.00 3500.00 33 38 11 3746.00 3600.00 34 13 10 3846.00 3700.00 34 18 10 3946.00 3800.00 34 10 S 70 57 E 1412 79 S 7O 37 E 1478 S 70 27 E 1544 S 70 22 E 1609 S 70 13 E 1675 S 70 2 E 1740 S 70 11E 1806 S 70 11E 1873 S 69 51E 1941 S 69 35 E 2009 64 30 97 4O 65 25 76 83 95 0 13 0 17 0 04 0 2O 0 04 0 16 1 10 0 18 0 14 0 27 560 43 S 1297 70 E 1413 55 S 66 39 E 582 604 626 648 670 692 715 738 13 S 1359 02 $ 1421 03 S 1483 14 S 1545 35 $ 1606 74 S 1668 58 S 1732 86 S 1796 762.49 S 1859 94 E 1479 87 E 1544 79 E 1610 40 E 1675 79 E 1741 46 E 1806 03 E 1874 02 E 1942 93 E 2010 29 $ 66 50 E 85 S 66 59 E 45 $ 67 7 E 81 S 67 15 E O1 S 67 21E 56 $ 67 27 E 02 S 67 33 E 06 S 67 38 E 15 S 67 43 E COMPUTATION DATE: 19-JUL-92 PAGE 5 ARCO ALASKA INC. 2M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: i3-JUL-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIUUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4650.88 4046.00 3900.00 34 7 4771.73 4146,00 4000.00 34 13 4892.74 4246.00 4100.00 34 26 5014.24 4346.00 4200.00 34 39 5135.85 4446.00 4300.00 34 43 5257.46 4546.00 4400.00 34 37 5378.99 4646.00 4500.00 34 31 5500.46 4746.00 4600.00 34 44 5622.35 4846.00 4700.00 35 2 5744.30 4946.00 4800.00 34 36 S 69 36 E 2077 67 S 69 35 E 2145 52 S 69 49 E 2213 65 S 70 26 E 2282 62 S 70 20 E 2351 79 S 70 13 E 2420 96 S 70 10 E 2489 98 S 71 10 E 2558 90 S 71 15 E 2628 51 S 71 16 E 2698.23 0 27 0 24 0 75 0 10 0 16 0 31 0 12 0 51 0 37 0 32 786 13 S 1923 40 E 2077 85 S 67 46 E 809 833 856 880 903 926 949 972 994 84 S 1986 99 E 2145 57 S 2050 86 E 2213 85 S 2115 81 E 2282 05 S 2181 02 E 2351 43 S 2246 14 E 2421 82 S 2311 12 E 2490 85 S 2376.12 E 2558 26 S 2442.11 E 2628 80 S 2508.17 E 2698 68 S 67 50 E 79 S 67 53 E 73 S 67 57 E 87 S 68 2 E 02 S 68 5 E O4 S 68 9 E 94 S 68 13 E 53 S 68 17 E 24 S 68 22 E 5865 57 5046.00 4900 O0 34 19 5986 59 5146.00 5000 O0 34 18 6107 93 5246.00 5100 O0 34 47 6229 86 5346.00 5200 6352 01 5446.00 5300 6474 045546.00 5400 6596 03 5646.00 S500 6716 77 5746.00 5600 6837 16 5846.00 5700 6957.27 5946.00 5800.00 33 33 O0 35 2 O0 34 58 O0 35 0 O0 34 32 O0 33 59 O0 33 40 S 71 27 E 2766 76 S 72 6 E 2834 81 S 70 42 E 2903 44 S 70 27 E 2973 16 S 70 41 E 3043 25 S 70 47 E 3113 15 S 71 24 E 3182 96 S 72 17 E 3250.48 S 72 44 E 3317.37 S 72 38 E 3383.72 0 35 0 21 0 77 0 22 0 23 0 19 I 91 0.27 O. 10 0.43 1016.79 S 2573.15 E 2766 76 S 68 26 E 1038.10 S 2637.89 E 2834 1059.81 S 2703.10 E 2903 1083.13 S 2768.85 E 2973 1106.48 S 2834.99 E 3043 1129.58 S 2901.01 E 3113 1152.31 S 2967.08 E 3182 1173.28 S 3031.40 E 3250 1193.42 S 3095.36 E 3317 1213.16 S 3158.89 E 3383 81 S 68 31E 44 S 68 35 E 16 S 68 38 E 27 S 68 41E 17 S 68 44 E 99 S 68 47 E 54 S 68 50 E 45 S 68 55 E 83 S 68 59 E 7077.00 6046.00 5900.00 33 8 7196.12 6146.00 6000.00 32 47 7314.82 6246.00 6100.00 32 24 7433.28 6346.00 6200.00 32 24 7450.00 6360.12 6214.12 32 24 S 72 I E 3449.40 S 72 4 E 3514.02 S 72 0 E 3577.85 S 72 0 E 3641.24 S 72 0 E 3650.19 O. 65 0.29 0. O0 0. O0 0. O0 1233.14 S 3221.62 E 3449.55 S 69 3 E 1253.16 S 3283.18 E 3514.21 S 69 7 E 1272.97 S 3343.97 E 3578.07 S 69 10 E 1292,76 S 3404.31E 3641.51 S 69 12 E 1295.56 S 3412.83 E 3650.46 S 69 13 E COMPUTATION DATE: 1g-JUL-g2 PAGE 6 ARCO ALASKA INC. 2M-24 KUPARU~ RIVER NORTH SLOPE, ALASKA MA~KER 9 5/8" CASING TOP KIJPARUK C BASE KLJPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING DATE OF SURVEY: 13-JUL-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ IN1-ERPO~TED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114' FSL ~ 554' F-'WL, SEC27 T11N R8E UM MEASURED DEPTH BELOW KB TVD FRO~ KB Sl~-SEA RECTANGU~R COORDINATES NOR1-H/$OUFFH EAST/WEST 3146 O0 7068 O0 7080 O0 7080 O0 7258 O0 7300 34 7346 O0 7434 O0 7450 O0 2791.56 2645.56 6038.47 5892.47 6048.51 5902.51 6048.51 5902.51 6198.06 6052.06 6233.78 6087.78 6272.32 6126.32 6346.61 6200.61 6360.12 6214.12 506.07 $ 1231.62 S 1233.64 S 1233.64 $ 1263.48 S 1270.55 S 1278.18 S 1292.88 S 1295.56 S 1140 82 E 3216 93 E 3223 18 E 3223 18 E 3314 99 E 3336 59 E 3359 85 E 3404 68 E 3412 83 E COMPUTATION DATE: 19-JUL-92 PAGE 7 ARCO ALASKA INC. 2M-24 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PB'TD 7" CASING DATE OF SURVEY: 13-JUL-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 114' FSL & 554' FWL, SEC27 TI1N R8E UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3146 O0 7068 O0 7080 O0 7080 O0 7258 O0 7300 34 7346 O0 7434 O0 7450 O0 2791.56 2645.56 6038.47 5892.47 6048.51 5902.51 6048.51 5902.51 6198.06 6052.06 6233.78 6087.78 6272.32 6126.32 6346.61 6200.61 6360.12 6214.12 506 07 S 1231 62 S 1233 64 S 1233 64 S 1263 48 S 1270 55 S 1278 18 S 1292 88 S 1295 56 S 1140 82 E 3216 93 E 3223 18 E 3223 18 E 3314 99 E 3336 59 E 3359 85 E 3404 68 E 3412 83 E FINAL w~mm LOCATION AT TD: TRUE SUB-SEA MEA~UEE~ VERTICAL VERTIC~J_ DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7450.00 6360.12 6214.12 3650.46 S 69 13 E DIRECTIONAL SURVEY COMPANY FIELD WELL COUNTRY RUN I:~TE LC)(:~ED D4'PTH UNIT ARCO ALASKA INC. 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FT"Fi ..... !"F'F'F'I"i~'"~'["i-' '~',i~ ~" ~ ~"~ AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST c~ck off or i'ist data as it is received.'list re~ived date for 407. if 407 ! *F~o/~~ drillin~ histo~' ~ ~ su~-e~! / ! Well'~eSts cored inte~als core analysis ! I d~ ditch inte~als ' ' i ' .... not required list as dig!i, al data i rll"lkl i i~'~'~ ] ~0. i/ i ! / , 7) 9) 111 1-"'! 131 1']4) 18.1 I ARCO Alaska, Inc. Date: July 24, .1992 Transmittal #: 8492 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~'3' '~ ~//4j) 2M-20 Sub-Surface Directional 7 - 1 2 - 9 2 92423 Survey Sub-Surface Directional 7 - 1 3 - 9 2 92425 Survey Receipt Acknowledged: D&M Date: copies) RECEIVED JUL 2 7 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: July 24, 1992 Transmittal Ct: 8488 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-24 Cement Evaluation Log 7- 1 3-92 5900-7305 i2M 24 Cement Bond Log 7-13-92 5900-7346 Receipt Drilling Acknowledge' -,-~,~ ..... Date' State of Alaska(+sepia) NSK RECEIVED JUl_ 2 7 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: July 17, 1992 Transmittal #: 8478 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 M- 24 ~.~"'- LIS Tape and Listing 6-18-92 92378 2M 20~,,p._~'~ LIS Tape and Listing,~ .~.~ o 6-25-92 92388 Receipt Acknowledged' ~ ~~Date · - ......... DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED JUL. 2 0 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: June 26, 1992 Transmittal #: 8471 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-24 ~ / 6/16-18/92 3146-7450 2M-24 CDR ' 6/16-18/92 3146-7450 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Date: ~-~--C- --F- l-V E D JUN 2 9 1992 Alaska Oil 8, Gas Cons. commission Anchorage Vendor Package(Johnston) NSK State of Alaska(+Sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 19, 1992 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River 2M-24 ARCO Alaska, Inc. Permit No: 92-50 Sur. Loc. ll4'FSL, 554'FWL, Sec. 27. TllN, R8E, UM' Btmhole Loc. 1223'FNL, 1329'FEL, Sec. 34, TllN, R8E, %TM Dear Mr. MCBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and dOes not authorize conducting drilling operations until all other required permitting determinations are made. . Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035'. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W.~ohnsto~_~ Chairman BY ORDER OF THE COMMISSION dlf/En¢losures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AI_A,~r,,A OIL AND C-.-.-.-.-.-.-.-.-~ CONSERVATION COMMISS~,,I PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D 1 b Type of Well Exploratory D Stratigraphic Test D Development Oil X Re-Entry D Deel:)en D Service C] Development Gas D Single Zone X Multiple Zone r'~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 146', Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586, ALK 2672 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 114' FSL, 554' FWL, Sec. 27, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (~ TARGET ) 8. Well number Number 1140' FNL, 1540' FEL, Sec. 34, T11N, R8E, UM 2M-24 #UG630610 At total depth 9. Approximate spud date Amount 1223' FNL, 1329' FEL, Sec. 34, T11N, R8E, UM 5/25/92 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2M-23 7,449' MD 1329 ~ TD feet 25' @ 425' MD feet 2560 6,361' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400 feet Maximum hole angle 34° Maximumsu~face 1660 Dsia At total depth ~TVD) 3125 osio 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'rVD MD TVD linclude sta(~e dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25" 9.625" 36.0# J-55 BTC 3,104' 41' 41' 3,145' 2,801' 313 Sx Permafrost E & HF-ERW 483 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 3,676' 41' 41' 3,717' 3,275' HF-ERW 8.5" 7" 26.0# J-55 BTC 3,732' 3,71 7' 3,275' 7,449' 6,361' 163SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth R E¢ E IV E D Surface Intermediate . oduc,io. MAY - ? 1992: Liner Perforation depth: measured AlasJa .0il & Gas Cons. C0mmissi0~ true verticalNlch0rage 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot I--I Refraction analysis D Seabed report ~] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed/~'~"~'~,_~'"~'~-j~,..~,..~,~~.a.~J,),~,C~::3(";a~_, Title Area Drilling Engineer Date Permit Number I APl number Approval date See cover letter for ~'-~.- -.~0 50-~//~,~'- -2_, ~ ,/7 / other rec]uirements Conditions of approval Samples required [~ Yes ~ No Mud log required D Yes ,,~ No Hydrogen sub,de measures r"l Yes ,o Dire tiona survey re,u red Yes D No ReQuired workin.q pressure for BOPE r"'i 2M ~ 3M r-I 5M I-'1 1OM I-'! 15M Other: ~~'-'---- by order of ~_ Commissioner the commission Date Form 10-401 Rev. 7-24-8 Submit in triolicate DRILLING FLUID PROGRAM Well 2M-24 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-120' 5-15 15-40 10-12 9-10 10% + Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 1660 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-24 is 2M-23. As designed, the minimum distance between the two wells would be 25' @ 425' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. Adjust FV to 50-80 sec/qt below gravel beds. RECEIVED MAY - 7 ~99~ Alasl{a Oil & Gas Cons. 6omm'tss'to~ ;Anchorage iCREATED BT : JONES iDATE PLOWED : 27--APR--g2 iPLOT REFERENCE IS 24- VERSION #2. iCOORDINATES ARE IN FEET REFERENCE SLOT #24. iTRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. A ~aker Hughes company ARCO ALASKA, Inc. Structure : Pod 2M Well : 24 Field : Kuporuk River Unit Location : North Slope, Alaska SURFACE LOCATION: I 114' FSL, 554-' FWL SEC. 27, Tl lN, RBE 0 0 0 300 .. 600 <r - 900_ 1200_ 1500_ - .~ 18oo_ G_ - 21 oo_ - 2?00_ 3ooe _ 36oo_ 3~oo_ 42oo I 4500 V 5100_ 5400_ - 5700_ SCALE 1 : 100.00 Eo st -- > 200 0 200 400 500 800 1000 1200 1400 1600 1800 2000 2200 24O0 2600 2800 3000 3200 34-00 3600 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 200 RKB ELEVATION: 1461 0 [ KOP TVO=4oo ~ 3424' (TO TARGET) 2oo t :3 O0 TMS:~00 ~ - I ' DEP=O ~ ,oo O ~ 9.oo ~ - ~ 1500 BUILD 3 DEG / 100' ~ ~00 ~ ~ 2~.oo~ - ~ ..... TVD~ ~MD~1525 DE~2 ~ ~ Jooo I 1/ W SAK S~OS TVO:2031 TM~=22~4 -,~ 9 5/8"CS~ PT TVD:2801 TMD:3145 DEP=1232 I~c 3~ TI'N ~8E I K-10 TVD=2876 TMD:3235 DEP:I 283 ' ' ' I I ~ TARGET ~ TVD=6028 ~ TMD=70~6 DEP=3424 I SEC. 34, Tl lN, RSE I K-5 TVD=~371 TMD=50~3 DEP=2298 RECEIVED AVERAGE ANGLE 34.19 DEG ' ~ AY 1 199 ~ Alaska 0il & Gas uons. uom _ ~ Anchorage eooo_ TARGET - T/ ZONE C _ ~ ~ kT/ ZONE A TVD=6051 TMD=707& DEP=34&O x --B/ KUP SNDS TVD=6196 TMD=7249 DEP=3538 6300_ 660o ' ' ' ' ..... ;o' 'o' ~' 'o''' ~' ~ 30O 0 300 600 gO0 1 0 15 0 1 O0 21 0 2~0 27 0 3 O0 3 0 3600 SCALE 1 : 150.00 VeHicol Section on 111.48 ozimulh wifh reference 0.00 N, 0,00 E from slof SCALE 1 ; 50,00 35O 400 i I I East 450 500 I 1900 O0 :500 1700 ~0 ;00 )0 900 O0 900 ARCO ALASKA, Inc. ~StruahJre J: Pad 2¥ Iqeid t Kuparuk I~rer UnB I.moatbn ~ #~,'th Sio1:,4, Naeica 550 600 650 I I I I I 00 100 1500 1300 100 tO0 ~'00 1100 300 900 7OO I 1100 5O0 750 450 _400 _35O O0 ~50 ~oo 150 00 50 7 O O GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2M-24 I , . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3,145')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7,449') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEiVeD MAY - 7' 1992 Alas~ Oil & Gas Cons. Comm'tssto~ Anchorage I 13 5/8" 5000 F 41 BOP STACK 7 4 I I 3 2 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 154:30 PSI DOWNSTREAM OF THE REGULATOR. · OI~SERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TES~ 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL CHECK THAT ALL HOLD-DOm SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 31:XX] PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. & OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KJLLAND CHOKE UNES. 7. TEST TO 250 PSI AND 301:X) PSt AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 30(X) PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BoTrOM RAMS TO 250 PSI AND 30(X3 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVlSOI~ 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PS! STARTING HEAD 11' - 3000 PSI CASING HEAD 11" - 3000 PSI X 13~B* - ~ PSI SPACER SPCX:X. 4. 1953' - 5(XX:) PSI PIPE RAMS 5. 13-5/8' - 5(X)0 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSi DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5~8' - 50(X) PSI ANNULAR R £1VJ D Alaska Oil & Gas Oons. OommisS~,o~ Anchorage h,.JPARUK RIVER UNI't 20" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREV~ IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. ~IAY - ? 1992 Alaska, 0il & Gas Cons, CommissiOn Anchorage 10' HCR BALL VALVES WITH 10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20- - 2000 PSI ANNULAR PREVENTER EDF 3/1 (3/92 ITEM (1) Fee (2) Loc (3) Admin CHECK LIST FOR NEW WELL PERMITS APPROVE DATE [2 f. hru ~ ~[9'thru 13]' [10 & 13] (4) Casg ~Z'.,,~.'. [14 thru 22] (5) BOPE [23 thru 28] Ii 2. 3. 4, e 6. 7. 8. 9. 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is permit fee attached ............................................... ~_ Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... '/~ Is well located proper distance from other wells ..................... ~ Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... . Is operator the only affected party .................................. ~ Can permit be approved before 15-day wait ............................ NO REI~RKS Is administrative approval needed .................................... Is lease nt~ber appropriate ......................................... Does well have a unique name ~ nLrnber Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface g intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams $ descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~o~O psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... / ! (6) Other Z/'~'~ ,~'/~//92~. 1-29 thrG 31] 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. c~m m z .geology' engineering: . D;;~,,~-----~- MTM/~ LCS .~.~ RPC~/~ BEW ,,--'-- RAD'b' ~-, ~ · ' ' JH---~ ~ rev 04/92 jo/6.011 INITIAL GEOL uNIT ' ON/OFF POOL CLASS STATUS AREA ~ SHORE , , , , , Add i t ional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically organize this category of information. * ~h~$~ COmPUTInG CE~TE~ ******************************* C[]~PAN¥' NAME : ARC© Ab.ASKA. INC, FIESD NAME : KUPARUK RIVER ADI NUMBER : 50-103-2017~ R, EF~RENCE N~] : 92378 RECEIVED JUL 2. 0 199~ Alaska Oil & Gas Co~s. CommissioD A~chorage Tame Vertiicat,!on Listl, nq ;hlUm. ber'ger alaska Comput~tn¢~ Center 26-JU~1-1992 08:43 **** REEL HEAD,IR **** SERVICE NAME : '~;DIT DATE : 92106/26 ORIGIN ; FLIC RF, Eb ~A~[,i,,r, : 92378 COg~ENT : ARCO aLASKg, I~)C., 2M-24, KUPARU[ RIVER, **** T AP~'; HEADER **** ~RVICE NA,t~ : E,DII, A"r ~ : 92/(i)6/26 ORIGIN : FLIC TAP~ NAI'vtE : 02378 CPNTIMUATION ~ : 1, CO~b~E'NT : ARCO ALASK[ IMC., 1R~2!, K.,.,I.[,ARUK RIV~.R, 50-103-20171-00 P.AGE~ **'** FILE HEADER **** FILE NAgE : EDIT ,001 SER.ICE : FL' C ~ERSION : 001A06 DaTF, MAX REC SIZE : 102<% FILE TYPE : LO L~ST FILE ********************************************************************************* ******************************************************************************** ** ** ** SCRLUMBERGER wELL SERVICES ** ** ** COMPANY NAME: ARCO gLASKA, INC. WELL: 2~-24 FIELD: KUPARUK R!VE:~ BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-103=20171 LOCATION: 114' FSL g 554' FWL SECTIOt'i: 27 TOWNSHIP: ll, N RANGE: PERMANENT DAT[J~: MS[., EbE'I/ATIOb~: 0 LOG MEASURED FRO}~[ RKB 1.468 ABOVE PERI'q.ANENT [)AT.U?! [$ Ta~e V'erlflcatlon L.istInq ~h. lumber,s'er Alask;a Computin~ Center 26",JUN-, 199~ 0B:43 ELEVATIONS K.B; 146 DF: 146 GL: 105 D~,TE bOGGED: ~,8-JUN-92 RUN NUM:BER: ON~ T:~ DRIL[,,ER: 7450 TD LOGGER: 7450 CASING 1: 9 5/8" 36 bB ~ DRIiLS'ER DEPTH OF -- TO 3146 ,BIT SIZE 1: 8 ~,/2" TYPE FLUID IN HOBS;: GEL LIGNITE DENSITY: 10.3 MUD R ~" ~ [.'..p~STIV I T¥ 2,36 FILTRA ~ ..... RESISTIVITY: , ~.,~.XNG DISTRICT: bOGGING ENGINEER: TOOL NUMBERS: RGS022 VISCOSITY: 42 FLUID bOSS: 3.8 0 68 ST, ~.~D6055 RES TO ~ir 65.3 ~._G TO ..... i 75 7' DENS TO ~I~.. !32..3 , . . . HOLE CORRE(.,TIO~ : 8I SIZE q..tRIX D~NS : 2 65 (G/CC) 6~.,D~ braid ~ENS : 1. (~/OC) RI i. ATIO~AL B[JLK DENSITY PROC~SSI '~ SLIDII',i'G iNDICATOR SHOWN IN DEPTH TRACK. DATE JOB STARTED: 26-JUN-g2 JOB REFERENCE NO: 92378 hOP/AMA: I)EES ****************************************************************************** FILE - EDIT,001 .ARCO ALASKA INC, KUPARUK RIVER 2~-24 50-103-2017~ MAiN P,ASS bWD LOG DATA Verification Listinq .-blumberger A.las~a Comp~ltiDO Center T~4E DE.~.$ITY OATA PRESE?~TED ON THiS LIBRARY TAPE iS DATA SAMPLED EVERY -,5000 FEET D~Ta INCLUDED - TOOL EXTE;NS TYPE USED RGS . Li~'D ND$ ,LWD !..,OGGING WHILE t) RI!..,.bI. NG RESISTIVITY/GR 3146' TO 7385' bOGGiNG ~'~ILE DRILLING NEUTRON/DENSITY 3146' TO 7318' , ******************************************************************************** PAGE: TABLE TYPE : CONS TUNI VAI, U DEFI TYPE CN APIN FL SECT TOWN R~NG COUN STAT NAT! .bATI LONG PDAT EPD LMF APD EKB EDF EGL TOD TDL BI.,I TL I DFD DFP~ ~ST R~FS R~CS FT FT MT FT FT FT FT FT G/C3 C? DEGF DEGF ARCO AbA6KA, IS~C. KUPARUK RIVER 2~-24 ll. 4' FSL & 554' FWL 27 Ifa NORTH SLOPE ALASKA USA 548955 0 1468. 146, 146, .1..05. 745O, 7450. 7450. 3146, GEl.., b. IGNITE 10,3 10, 42, 3,8 2,42 68. r! e ~ompa me ield ~aNam Well Name API Serial NUmber Field Location Sectlom Township Ran e CoUnty State~ or Province Nation Latitude Longitude witness' Name Service order Number Permanent datum Elevation of Perm, Da I.~o~ Measured From ABOVE PERMANENT DATI]~ Elevation of Kelly Bu Elevation of Derric~ Elevation of Ground L Total DePth - Driller Total Dept~ - Logger Bottom Log Interval TOD bog Interval Drillin~ Fluid Type Drillin~ Fluid DeDsit Drilling Fluid Ph Drilling Fluid Vlscos Drillin~ Fluid boss Resist! ity of Mud Sa MUd Sample Te[nperatur Resistivity of mud fi ~ud Filtrate Sample T Resistivity of ~Ud Ca ZONE S Tape verification bist.inq 26-jUM-!992 08:43 PAGE: 4 ~hlumberger Al, aska Computing Cer~ter T U ~,I I V A I',,, U D g t:' I T ¥ P MCST [)EGF Mud, Cake SamPle ~e pe ZONE STE~,~ DEGF 30. Surface Temperat,~re BHT DEGF 144. Bottom Hole Temperatll TABLE TYPE TYPE: CURV DEPT RHOB DR,am PEF DC;If, DPHI T:MPH ATR p,SI~ ROPE GR D'EFI Depth Channel Ma~e BU. lk Density Delta RHO Photoelectric Factor Differential Ca!t.~ier Density Poroslt¥~ r Thermal Neutron =o osi, ty Gamma Ray . ** DATA FOR~A,T SPECIFI.~AIluN RECGR. D ** SET TYPE - 64E,3 ** .. TYP~,] R~ .... R CODE vAbUE i 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 9 65 11 6b 23 12 6~ IS Ta~e Verificotlon chlUmberger AlaSKa CO~pUt, ing Center 26-jUN-1992 t[)8:43 PAGE: , 1,~ 14 65 15 66 68 16 66 0 66 SE:,r TY'PE - CHAN ., ORDER ~ LOG TYPE CLASS MOD NUMB SA~P gLEM CODE (HEX) , 54 ~ 955 00 000 00 0 1 1 I 4 68 000 () 000000 RHOB I.,WD G/C3 548955 O0 000 DRHO L~D G/C3 548955 O0 000 PEF LWD 548955 O0 000 DCAI,, LWD IN 548955 O0 000 DPHI LWD PU 548955 O0 000 TNpH LWD Pti 548955 O0 000 hTR LWD OH~M 548955 O0 000 PSR LWD OH~M 548955 O0 000 ~OpE LWD F/HR 548955 O0 000 G~ LWD GAPI 548955 O0 000 O0 0 1 1 1 4 68 0000000000 00 0 I 1. 1 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 1 1, 4 68 0000000000 O0 0 ! I 1, 4 68 0000000000 00 0 1 1 1 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 * * D A T A * * DEPT. 7450.000 DCAL.I,,WD -999.250 PSR.LWD -999.250 O~:PT l~oo ooo DC Al.,." I,,WD999:250 PSR.LWD ,,999.250 DEPT 7300. [~0(.) PSP.LWD 2,498 DE,PT 7200.000 pc~t,:/,,wo o. 233 PSR.LWD 5.867 OEP.t; 7100. 000 DCAt:~: t, wo o. 2 2 7 DEPT 7000. 000 DCA[,: [,i~D 0.3 !.3 Ps~. [,wo t. 551 RHOB.LWD -999.250 DRHO.I.,,WD -999.250 DPH. I.LWD -999.250 TNPH.bWD -999,250 ROPE.LWD 73.471 GR.I..,WD -999.250 RHOB.LWD :999 ~50 DRH[) bWO -999 250 'OPHIol, WD 999:250 TNPH:I, WD -999:250 ROP~.n~D e7.412 GR,LWD -999.250 ~HOB.LWD 2.510 DREO,LWD 0.010 DPMI.LWO 0.085 TNPH.LWl) 36,200 ROPE.LWD 49,316 GR.LWD 83.607 RHOB.I..,W9 2 478 DRHO.LWD -0.013 DPHI.bWO 0:104 TNP~.LWD 34.700 ROPE.I. WD 118.420 GR.LWD 84.213 RF!OB.LW[) 2,484 DRHO.LWD 0,022 OPHI. I.,.WD O, 1,00 TNPH. [wD 40.1 oO ROPE. L, WD 56. 961. G~.LWD 106. 637 PEF bWD PEF. 5WD ATR L, D PEF. ATR.LWD . El: LWD ~T~: ~D PEF. I, WD ATR.LWD P,EF. I~'W D AYR.LWD -999.250 -999. 250 '999.250 -999 · ~250 3.684 2.633 3.125 6,369 I.:973 .330 3.377 1.555 Tape verl, fication bistir)g 'hlumberger Alaska Co.mputing Center D E P T. 6 9 0 0,0 0 0 R ~ 0 0. b W D D C A L. L W D 0.2 2 0 D P H I. h W 0 P$~,LWD 2,270 ROPE.L~D DEPT,. D 6800,000 RHOB.13WD D C A t,. L W 0.246 O P 'H I. L W D P $ R. L W 0 2.729 R q P E. I, ~ D · 6700,000 RHOB. [,WD DE ,1]WD 0,264 DPHI,,LWD E~.,:PT 6600 000 RHOB LwD [)CAI.,,LWD 0,145 OPBI,LWD PS R . L ~WD 2 , 94. 5 R O P E . L bt D D g P T, 6500,000 R ii O t%, h W I) D C .A [,', I~ W D 0,24 o D P H !, I..~ W D PSR.[.WD 3.521 ROPE.LWO DEPT, 6400.000 R ~':10...~ LWD D C g L" [,, W D 0.051 D 'P H I:. t.,,, W D PB~,I.,WD 3.454 ROPE.LWD P ~.: P T, 6300,00 o '~ H 0 g, L w 'D DCAL,,LWD 0,198 DPHI.LWO PSR.LWD 3.475 ROPE,LWD DEPT 6200,000 RHOa,LWD PS~,L~D 2..45~ ROPE.LWD DEPT 6100,000 RHOB.LWD DCAL:LWD O. l()O OPHI.LWD PS~,LW.D 2.574 ROPE. I...,WD DEPT 6000,000 DCAL:LW.~ 0.1.62 DPHI.LWD PSR. t, WD 1.164 DEPT. 5900.000 DCAL.I.,WD 0.376 OPHI.LWD PS,~. LWD 2.671 ROPE. I,,,WD DE,PT 5~00.000 R}'{08, LWD DCAI..,:I..,~!D ' ' 0.292 DPUI.LWO PSR.IJWD 2.336 ROPE.LWD DEPT,.w~ 5700.000 RH. 06. t, WD DCAL,u :,~ 0.385 DPHI.LWD PSR,LWD 2 390 R3PE i,~!D 26-jUN-.1992 08:43 2,459 DRHg,LWD 0,1 !6 TNPH, hWD 197,821, GR,LWD 2.649 DRHO,L~D 0,00! TNPH,L'WD 2.492 DRHt3, hWD 0,096 206.293 G R, h ~: D 0 O! 5 39 '. 30'0 119· 429 30 O0 201 333 ' 0,008 35 000 117:710 2.5~1 DRNO.hWD 0,009 0.0 2 TNPa,bWD ]3,200 2,36.959 (;R,LWD $3.328 2.474 DRBO,LWO 0 006 .1~0 ~.P~.~:,hWD 2.200 21,5,161 GR,I,:,WD 94,.762 2.401 I)RHO,L~D 0 022 206,~9~ GR,LWD 82,i62 2.4.26 O~UO. t,~i) 0 136 TNPH.LWD 251:518 GR.LWD 2.330 DRHO.LWD 0.194 T N P H. L w 'O 255. 805 GR. LWD 2.399 DRhO,LWD 0.152 TNP!q,LWD 278,173 GR,LWD 2.293 DRHO.LWO 0.21,6 TNPH.LWD 251.040 GR.LWD 2.360 DRHO.LWD O. 176 TNPH.bWD 298.730 GR. LWD -0.~13 37. O0 99. 089 0.024 31.900 80.283 -0.003 33.600 70.875 0.024 33,100 70.111 PEF, hWD A ~ R, I, W P P E F, 1,~ W D A T R., [, W D PEF.I,,WD ATR.LWD PEF.LWD hTR.L~D gT L~D PEF.LWD ATR.L~D PEF.LWD ATR.LWD PEF.LWD ATR.LWD PEF.LWD ATR.LWD PEF.LWD ATR.LWD PEF.LWD ATR.!.,WD `PAGE: 3.81, 6 2,4!2 8.497 2,913 3.764 2,824 ,803 ',243 3.960 ~.9~! .237 '753 010 2.952 2.965 2.717 2.531 999 iS TaD~ Verificatior~ ,Listing chlumberger AlaSKa ¢.~.om~..ut,.n Center DCAL.LWD 0.268 .DPHI.LWD PSR.LWD 3.864 ROPE.bWD DEPT. 5500.000 R.HOB. I,,WD [)~8~, [,'WD 2,9!8 uOPE,LWD 5400.000 R PS~.LWD 2. 001 RLPE. DEPT. 5300,000 Rk]OB.bWD DCAL. 1,%,~ [) 0.063 DPHI.LWD PSR,L~D 1.519 DE:PT, 5200,000 ~HOS.LWD DCAL.LWD 0.021 DPH,I.L~D PS~.LWD 1.487 DgPT, 5100. 000 RHOB. D C A L, 5 W D 0,000 D P H I, , 59 ROPE. PS~ l,., W g I · 9 ' ~' DEPT. 5000,000 RHOB, I,,WD D~AL,LWD 0,000 D~HI,LWD D E P T, 4900,000 R H O B. D C A L, L W D 0.000 D P'H I, PSR.LWD 3.079 ROPE. DEPT. 4800. 000 RHO8. DCAL LWD 0.104 DPHI. PSR:LWD 2,592 DE;PT. 4700,000 RHOB.LWD DCAL.LWD 0.000 DPHI.LWD PSR.LWD 2.973 ROPE.I, WD DEPT. 4600.000 RHOB. i, WD DCAL.LWD 0.097 DPHi.[,WD PS~.LWD 2.875 ROPE.I, WD DEPT. 4500.000 RHOB.LWD DCAL. I.,WD 0.43~ DPHI.LWD PS~.LWD ~.985 ROPE.LWD D~PT. 4400.()00 RI~'~OB. LWD DCAt,.LWO 0.000 OPHI.LWD PS~. LWD 2. 459 ROPE. 26-JUN-lg92 08:43 2.330 O [:~, H 0. b W D 0.1,, 94 T N P H. L'W P 189,2B8 GR. I,..WD 2.435 DRH(,':). LW D 0.1~ TNPq ~WD ~,, ~ · 308.5 . GR.LWO 2.316 DRHG.LWD 0.203 TNPH,EWD 312.720 2.380 DRHO. 0.163 TNPH. I,,WD 262. 309 2.305 DRHO,LWD 0.209 T N P H. 5 W D 258.611 G ~ · ,b W 0 2.317 DRH(,), }EWD 0 202 246~ 582 G'R. LWD 2.324 D 0.19~ TNPH..LWD 312 * 812 2,306 DRHO. [.,WD 0.209 ~ N P H * L W D 322. 994 GR, 2,384 D~80,h~D 0,161 TNPH,bWD ~, ]07 D~HO. LWD 0.208 TNPM.hWD 238.477 GR, 2.358 O. 177 TNPH.LWD 328,114 GR.LWD 2.394 DRHO.LWD 0. ~ 55 T H. H. 3~8.03~ GR.LWD 2. 265 DRHO, LWD 0 233 TNPM,LWD 312~7~3 ' GR, L,~D 026 -o. 800 . . -0.006 37.200 108.375 ~0 35 111.106 O. 006 40,400 173., ~{ 44 -0.006 39 300 -0 005 10 , .89 7 0,015 35.200 108.079 0 3 105.160 0.035 34,~00 100. 99 '0,001 36,000 72,426 0.011 33 500 1527 -0.030 36.100 66.757 -0,018 39.800 90,767 2,591 2,372 3,338 3'406 2'828 1,942 3,445 2'055 2'926 1,562 3,143 2'177 2'924 2,35.8 2.957 3.375 3.245 2,834 2,823 3'326 3.037 3,124 2.805 3.080 2.819 2.694 $ Tape Verification Listinq blumberoer AlasKa Computind Center DEP?. 4300,000 DCAI..,LWD 0.000 PS~,LWD 2,338 DPHI.LWD R[]PE,LWD DPH I ,LWD R ~73 P E. b W D RH. OB, I.~WD DPH I, ~ D ROPE,LWD RHOB. LWD D P H I, L W D R [] P El, [,, W D RHOB,bwD D P H I, L W D R 0 P E. L RHOB. DPHI. LWD ROPE. L~D RHOB. DPHI. LWD ROPE. R HOB. LWD DPMI. LWD ROPE. bW O RHO5, LWD 'OPHI, LWD ROPE. LWD RHOB. I..WD DPH I. LWD ROPE, LWD RHOB, DPRI.LWD ROPE. LWD RHOB, hWD DPH I. ROPE. LWD RHOB.LWD DPMt. LWD R OPE. LWD DEPT, 4200.000 DCAL,LWD 0,000 P$~.[,,WD 2. 814 DEFT, 4100.000 DCAL, LWD O. 189 PSR. L%.JD 2. 937 DEPT. 4000,000 DCAL,LWD O, 000 PSR, I..,l,i' O 3. 324 DEFT, 3900,000 DCAb. LWD 0.000 PSR , :[,W O 3 . 600 DEPT, 3800.000 DCAL,LWD O, 1.07 PSR.LWD 2,602 DEPT, 3700,000 D C !k L, L W D 0,000 PSR., I. WD .3 · 068 DEPT. 3600,000 DCAL.bWD 0,000 PSR,LWD 4,484 DEPT. 3500.000 DCAL,LWD 0.060 PSR,LWD 5.482 DEPT. 3400.000 DCAL,LWD 0.000 PSR.LWD 3.896 DEFT, 3300.000 DCAL,LWD 0,163 PSR.LWD 6.632 DEPT. 3200,000 DCAL.LWD 0.230 PSR,LWD 3.853 DEPT. 3100,000 DCbL.LWD 0.324 PSR.LWD '7.455 26-JUN-199~ 08:43 2,254 DRHO,bWO 0.240 TNPH,bWD 414.803 GR,LWD 2.293 DRHO,b~D 0.216 TNPH,DWD 266,1~5 GR.bWD 2.231 DRMO,LWD 0.254 258,611 GR,bMD 2.218 DRHD.bWD 0,262 TNPH,LWD 345,461, G'R,LWD 2.2~6 O~aO,bWO 574,0~6 GR,LWD 2,174 DRMO,b'WD 0.289 TNPH,LWD 571.$12 GR.LWD 2,203 DRHO.hWD 0.271 TNPH,LWD 301.044 GR.LWD 2. 112 DRHO, LWD 0 326 136 ~ 005 2 222 DRHO,LWD 01259 TNPH.LWD 281,272 GR,LWD 2.207 DRMO.LWD 0 268 TNPH,LWD 2.209 0.268 TNPH.bWO 317,937 2.266 DRNO.bWO 0,220 TNPH.LWD -999.250 GR.hWi) 0 002 37i300 79 063 0.002 35,200 76.083 -0.013 36,600 80.932 '0.O09 40.400 68,060 0,0o0 40,900 75.249 -0.008 44,.400 114'96.2 ~0.006 ,,3,900 90,883 0.0,1'3 42,300 87.173 -0 008 42i300 70215 0 0,12 4o:,goo 97,975 -0.005 38 60O 0.006 ~0 0 -0.341 51 800 PEF,LWD ATR,L~D PEF.L~D PEF'LWD ATR.LWD PEF.LWD ATR,LWD PEF.LWD ATR..LWD PEF.L~D ATR.LWD PEF,LWD ATR,bWD PEF*LWD .ATR,b~D PEF,L~D ATR,bWD PEF.LWD ATR,LWD PEF.LWD ATR,LWD PEF.LWD ATR,LwD PEF.LWD ATR.LWD PAGE: 3.0~5 2,6 0 2.791 3.059 2,599 3.253 2,721 3,796 2.8~7 3~956 ~,049 2,980 2,71.5 3.375 2.939 5,~77 2,475 6.510 2.836 4.365 2.752 7,789 2,802 4.575 100,000 0.096 $ Tame Verification bistina blU~,beroer AlosKa Computinq Center DEPT. 3000. 000 P SP,,, I,,, WD -999i :250 26-JIJ~:!, J. 992 08:43 DEPT. 2968. 000 DgAL [,~D -999,250 $~:LWD -999.250 ** END OF DATA 999.250 D R ~ 0. h W D -999.250 P E F. t, '~ D -999,250 GR' L~[) 99.250 -999,250 DRHO,bWD 999,~50 PEF.LWD '999,250 -999.250 G R.LWD -999.2 -999. 2250 -999.. 50 -999., 250 -999.250 **** F'~LE T~AII, ER FihE NAME : EDIT , SERVICE : FhlC VER. 8 I{.~N : OO1A06 DATF : 92/06/26 ~AX .REC SIZE : 1024 F"I'~L,E TYPE : bO ia~ST FIbE **** TAPE TRAIbER **** SERVICE NA~E : EDIT DATE : 92/06/26 O~IgIN : FbIC TAPE NA~E : 92378 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., 1~-21, KUPARUK RIVER, 50-103-20171-00 **** REEL TRA.ILEP **** SERVICE NA~.~E : EDIT DA'r~ : 92/06/26 ORIGIN : FLIC REEl., NAME : 92378 CONTINUATION PREVIOUS REEb CONMENT : ARCO ALASKA I~C., 2M-24, ~UPARUK RIVER, 50-103-20171-00