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Home My WebLink About223-0717. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-18B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-071 50-029-20767-02-00 12435 Surface Intermediate Scab Liner / Tie-Bac Liner Liner 9087 2475 9773 870 2696 1918 11270 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 8866 37 - 2512 35 - 9808 33 - 9869 9449 - 9960 9356 - 12430 37 - 2512 35 - 8565 33 - 8618 8252 - 8688 8171 - 9085 none 2670 4760 5410 10530 11780 11270 , 11810 , 12100 5380 6870 7240 10160 11200 11193 - 12346 4-1/2" 12.6# 13Cr80 31 - 9504 8887 - 9055 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" HES TNT Perm , 8893 , 7777 No SSSV 8893 , 9449 7777 , 8252 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028311 31 - 8229 188 82 17439 5415 1228 8 1807 752 345 249 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 Perm , 9449 , 8252 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:32 am, Oct 15, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.10.14 16:14:39 - 08'00' Bo York (1248) RBDMS JSB 101625 J.Lau 11/10/25 ACTIVITYDATE SUMMARY 9/18/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Scope: Drift/Log/CIBP/Perforate Spot in and rig up. Stab on and function test BOP's. Make up 1-11/16" NS MHA, 1.75" x 4.00' LRS stingers (x2), 1.75" DJN. Start loading the tubing with KCL. ***Job in Progress*** 9/19/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Scope: Drift/Log/CIBP/Perforate L&K the tubing with 144 BBL's of 1% KCL w/ safelube. RIH with 1-11/16" NS MHA, 1.75" LRS stingers (x2), 1.75" DJN. Tag the 2-3/8" NS CIBP at ~ 11840' E / 11810' MD. POOH and make up 1-11/16" HES GR/CCL logging toolstring. RIH and log from 11500' to 8600' at 50 FPM . Paint a tie-in flag at 11280'. POOH and confirm good data (-10' correction). Make up 2-3/8" NS CIBP and RIH. Set the plug at 11270'. Pressure test the plug to ~ 1000 psi (lost 10 psi in 10 min). POOH and lay down setting tool (3/8" ball recovered). Make up 1.56" x 17' HES Millenium, 6 SPF, 60 degree phase gun. RIH and perforate 11193' - 11210' CTM. Good indication of shot, start POOH. Cap the well with 5 BBL's of 60/40. ***Job in Progress*** 9/20/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Scope: Drift/Log/CIBP/Perforate Continue POOH and lay down spent perf gun (all shots fired in scallop, 1/2" ball recovered). RDMO. ***Job Complete*** Daily Report of Well Operations PBU 06-18B 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-18B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-071 50-029-20767-02-00 12435 Surface Intermediate Scab Liner / Tie-Bac Liner Liner 9087 2475 9773 870 2696 1918 11810 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 8850 37 - 2512 35 - 9808 33 - 9869 9449 - 9960 9356 - 12430 37 - 2512 35 - 8565 33 - 8618 8252 - 8688 8171 - 9085 none 2670 4760 5410 10530 11780 11810 , 12100 5380 6870 7240 10160 11200 11544 - 12346 4-1/2" 12.6# 13Cr80 31 - 9504 8819 - 9055 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" HES TNT Perm , 8893 , 7777 No SSSV 8893 , 9449 7777 , 8252 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028311 31 - 8229 188 141 17439 25070 1228 12 1807 915 345 374 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 Perm , 9449 , 8252 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:00 am, Sep 11, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.09.10 13:33:54 - 08'00' Bo York (1248) RBDMS JSB 091625 DSR-9/11/25J.Lau 11/6/25 ACTIVITYDATE SUMMARY 8/24/2025 LRS CTU #1 1.5" CT .134" WT HT-110 Job Objective: Drift/Log Plug and Perf Depart K-20 and travel to 06-18. Start rig up. ***Job Continued on WSR 8-25-25*** 8/25/2025 LRS CTU #1 1.5" CT .134" WT HT-110 Job Objective: Drift/Log Plug and Perf Continue RU. Nipple up and function test BOPs. Make up 1.75" nozzle drift BHA, L&K well with 175bbls of 1% KCL with Safelub. RIH Tag CIBP @ 12,118' CTM. PUH paint flag 12,100' CTM. POOH. BD LRS 1.75" drift BHA. NU NS ctc/MHA & HES GR/CCL logging BHA. RIH to Flag / 12,100' CTM. Log up 50 fpm and paint flag @ 12,761,16 CTM. Log 50 fpm to 8900.35' CTM. POOH. BD HES logging tools -9' Correction. MU NS 2-3/8" CIBP BHA. RIH and correct depth at flag, set top of CIBP at 11,810' PT plug to 1300psi. POOH. ***Job Continued on WSR 8-26-25*** 8/26/2025 LRS CTU #1 1.5" CT .134" WT HT-110 Job Objective: Drift/Log Plug and Perf POOH with CIBP tools. Make up 1.56" x 30' Tripoint, 6 SPF, 60 degree phase gun. RIH and perforate 11610' - 11640'. POOH and lay down gun (all shots fired in scallop, 1/2" ball recovered). Make up 1.56" x 30' Tripoint, 6 SPF, 60 degree phase gun. RIH and perforate 11544' - 11574'. POOH and lay down gun (all shots fired in scallop, 1/2" ball recovered). Perform weekly BOP test. RDMO. ***Job Complete on 08/26/25*** 9/1/2025 T/I/O/OO = 2470/2300/0/90. Temp = SI. Cold TIFL PASSED (eval high IAP). ALP= 1990 psi, SI @ CV. IA FL @ 8708' (sta # 1 SO). Bled IAP to OT to 850 psi in 50 min. IA FL unchanged. Bled ALP to 0+, unable to bleed to 0 psi due to AL CV leaking by, Monitored for 1 hr. IAP increased 10 psi, IA FL unchanged. Released to Ops for POP. Final WHPs = 2470/860/0/90. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 16:00 Daily Report of Well Operations PBU 06-18B 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-18B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-071 50-029-20767-02-00 12435 Surface Intermediate Scab Liner / Tie-Bac Liner Liner 9087 2475 9773 870 2696 1918 12100 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 8957 37 - 2512 35 - 9808 33 - 9869 9449 - 9960 9356 - 12430 37 - 2512 35 - 8565 33 - 8618 8252 - 8688 8171 - 9085 none 2670 4760 5410 10530 11780 12100 5380 6870 7240 10160 11200 12005 - 12346 4-1/2" 12.6# 13Cr80 31 - 9504 8919 - 9055 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" HES TNT Perm , 8893 , 7777 No SSSV 8893 , 9449 7777 , 8252 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028311 31 - 8229 269 249 16788 16120 1294 1465 1117 962 468 462 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 Perm , 9449 , 8252 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Gavin Gluyas at 9:04 am, Feb 06, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.02.06 04:24:20 - 09'00' Bo York (1248) RBDMS JSB 021925 JJL 2/27/25 DSR-2/28/25 ACTIVITYDATE SUMMARY 1/15/2025 LRS CTU #1, 1.5" Coil, 0.134" WT. Job Objective: Log/Drift & Set CIBP MIRU CTU #1. BOP Test ***Continue on WSR 1/16/25*** 1/16/2025 LRS CTU #1, 1.5" Coil, 0.134" WT. Job Objective: Log/Drift & Set CIBP BOP Test. NU BOP & Fnc Test BOPs. Trim 30' 1.5" CT. MU NS 1.69" ctc & MHA. Freeze Protect Flowline 118 bbls diesel. MU HES GR/CCL tools w/ 1.75" bullnose. RIH. Load well with 5bbls 60/40, 135bbls safelube, capped with 10bbls 60/40. log from 12,250 to 11000. POOH. -18' correction. M/U NS CIBP, RIH and set at 12,100'. POOH RDMO ***Job Complete*** Daily Report of Well Operations PBU 06-18B 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-18B Set LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-071 50-029-20767-02-00 12435 Surface Intermediate Scab Liner / Tie-Bac Liner Liner 9087 2475 9773 870 2696 1918 12412 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9079 37 - 2512 35 - 9808 33 - 9869 9449 - 9960 9356 - 12430 37 - 2512 35 - 8565 33 - 8618 8252 - 8688 8171 - 9085 none 2670 4760 5410 10530 11780 none 5380 6870 7240 10160 11200 12005 - 12346 4-1/2" 12.6# 13Cr80 31 - 9504 8919 - 9055 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" HES TNT Perm , 8893 , 7777 No SSSV 8893 , 9449 7777 , 8252 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028311 31 - 8229 246 248 17619 16590 1341 1749 1241 1173 472 428 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 Perm , 9449 , 8252 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Samantha Coldiron at 7:35 am, Jan 09, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.01.08 07:02:35 - 09'00' Bo York (1248) DSR-1/16/25SFD 3/25/2025JJL 2/7/25 RBDMS JSB 011525 ACTIVITYDATE SUMMARY 12/10/2024 ***WELL FLOWING ON ARRIVAL*** (Sidetrack) RAN 4 1/2" BLB, 3.80" GAUGE RING, 3 1/2" BLB TO BRUSH DEPLOYMENT SLEEVE & TBG @ 9,356' MD RAN 45 KB DRIFT,4' SECTION, PTSA DRIFT TO DEPLOYMENT SLEEVE SET 4 1/2" MONO-PAK LTP (W/ 2-7/8" X NIPPLE) TOP@ 9,356' MD ***CONTINUED ON 12/11/24 WSR*** 12/10/2024 (Perform Freeze Protect for SL) Job cancelled upon arrival 12/10/2024 T/I/O = 2200/1050/0 (Perform Freeze Protect for SL) Pumped 5 bbls 60/40 for spear followed by 125 bbls Crude down FL for FP. Pressured FL to 1500psi per DSO. Further pumped 38 bbls Crude down TBG for FP. Pollard SL in control of well upon TFS departure FINAL WHPS = 1950/1050/0 12/11/2024 ***CONTINUED ON 12/11/24***(Sidetrack) PULLED RSG FROM LTP @ 9,374' SLM ***WELL S/I ON DEPARTURE*** 12/14/2024 ***WELL ONLINE ON ARRIVAL*** T-BIRD PUMP 120 BBL'S SET 2-7/8" XX PLUG IN NS LTP @ 9,356' MD T-BIRD PERFORM PASSING PRESURE TEST TO 2500# ON TBG (-10psi in 15min) EQ & PULL 2-7/8" XX PLUG FROM NS LTP @ 9,356' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 12/14/2024 T/I/O= 2200/1050/0 TFS Unit 4 Assist Slickline. Pumped a total of 2 bbls of 60/40 followed by 118 bbls of DSL down TBG to assist SL with trouble shooting Liner Top. SL Left in cotrol of well upon departure. EWHP= 669/1000/0 Daily Report of Well Operations PBU 06-18B Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 11/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 06-18B PTD: 223-071 API: 50-029-20767-02-00 FINAL LWD FORMATION EVALUATION LOGS (09/16/2024 to 09/24/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: Please include current contact information if different from above. 223-071 T39768 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.13 08:54:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241030 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-26 50283202010000 224098 10/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/14/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/12/2024 AK E-LINE Perf GP-ST-18742-33 50733203060000 177032 10/9/2024 AK E-LINE LeakDetect/Packer IRU 11-06 50283201300000 208184 10/4/2024 AK E-LINE Plug/Perf MPU B-28 50029235660000 216027 10/4/2024 READ CaliperSurvey MPU F-13 50029225490000 195027 10/15/2024 READ CaliperSurvey MPU L-36 50029227940000 197148 10/17/2024 READ CaliperSurvey MRU G-01RD 50733200370100 191139 10/10/2024 AK E-LINE Hoist NCIU A-21 50883201990000 224086 10/8/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/1/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/11/2024 AK E-LINE Perf PBU 06-18B 50029207670200 223071 10/2/2024 HALLIBURTON RBT PBU 14-32B 50029209990200 224073 10/13/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON WSTT PBU NK-26A 50029224400100 218009 10/14/2024 HALLIBURTON PPROF PCU 02A 50283200220100 224110 9/30/2024 AK E-LINE CBL PCU 02A 50283200220100 224110 10/4/2024 AK E-LINE Perf SDI 3-25B 50029221250200 203021 10/17/2024 AK E-LINE Patch Please include current contact information if different from above. T39726 T39727 T39728 T39732 T39733 T39734 T39735 T39736 T39737 T39738 T39739 T39739 T39740 T39741 T39742 T39742 T39743 T39744 T39744 T39745 PBU 06-18B 50029207670200 223071 10/2/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.01 13:27:33 -08'00' Drilling Manager 08/01/24 Monty M Myers 324-446 By Grace Christianson at 12:48 pm, Aug 01, 2024 A.Dewhurst 02AUG24 * inclusive of 06-16C completion report 10-407 MGR01AUG24 DSR-8/12/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.12 15:10:32 -08'00'08/12/24 RBDMS JSB 081324 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: August 1, 2024 Re: PBU 06-18A Sundry Request Sundry approval is requested to change the proposed drilling of 06-18B as stated in PTD #223-071 from rig CDR2 to rig CDR3. There are no other planned changes from the original sundry #323-440 or PTD procedure at this time. An updated BOPE layout for CDR3 is attached as well as an updated wellbore schematic to incorporate the production casing leak repair performed separately from the CTD permit program. Anticipated start date of pre-rig work is scheduled on or before August 9, 2024. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka 907-244-4357 3-1/4" Whipstock - 9960 2-3/8" 13CR HYD511 - 12314 3.70" DPLY Sleeve - 9425 B Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil, PBU 06-18B Hilcorp Alaska, LLC Permit to Drill Number: 223-071 Surface Location: 114' FSL, 885' FEL, Sec 02, T10N, R14E, UM, AK Bottomhole Location: 466' FNL, 2133' FEL, Sec 12, T10N, R14E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above-referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie Chmielowski Commissioner DATED this ___ day of September 2023. 25 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.25 15:18:28 -08'00' PBU 06-18B Liner 8.3.2023 By Grace Christianson at 1:36 pm, Aug 04, 2023 Drilling Manager 08/03/23 Monty M Myers 50-029-20767-02-00 BOPE test to 3500 psi. Variance to 20 AAC 25.112(i) Approved for alternate plug placement of parent well with fully cemented liner on this sidetrack. 223-071 A.Dewhurst 20SEP23MGR04AUG23 DSR-8/7/23*&: 09/25/23 09/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.25 15:18:45 -08'00' To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: August 3, 2023 Re: 06-18B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 06-18A with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for 06-18B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, E-line will set a 3-1/4" whipstock, and coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and drill an S- shaped well through Zones 3 and 4 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via cement squeeze, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work - (Estimated to start in August 2023): Pre-Rig Work 1SLDummy WS drift to ~10,000 MD, Set Dummy GLVs, MIT-IA to 2500 psi 2ELSet 3-1/4" Monobore packer whipstock at 9,961' MD 0 deg ROHS 3CTMill Window with rig (if unit is available) 4 Valve Shop Pre-CTD tree work (install sarber spool, PT swab, leak-tight master) 5 Valve Shop Bleed wellhead pressures down to zero. 6 Valve Shop Bleed production, flow and GL lines down to zero and blind flange. 7 Opearations Remove wellhouse and level pad. Rig Work 1 MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,414 psi). 2 Mill 2.74” Window. (If not done pre-rig) 3 Drill build section: 3.25" OH, ~495' (25 deg DLS planned). 4 Drill production lateral: 3.25" OH, ~1859' (12 deg DLS planned). 5 Run 2-3/8” 13Cr liner 6 Pump primary cement job: 19 bbls, 15.3 ppg Class G, TOC at TOL*. 7 Freeze protect well to a min 2,200' TVD. 8 Close in tree, RDMO. Post-Rig Work 1 Valve Shop Valve & tree work 2 Slickline Set LTP* (if necessary). Set live GLVs. Sundry 223-440 PTD 323- 3 Service Coil Post rig perforate (~30’) and RPM. * Approved alternate plug placement per 20 AAC 25.112(i) Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (9961’ MD - 8687’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,427 psi 4,427 psi 9.8 B Annular friction - ECD (psi/ft)349 psi 0 psi 0.035 C Mud Hydrostatic (ppg)3,885 psi 3,885 psi 8.6 B+C Mud + ECD Combined 4,233 psi 3,885 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 193 psi 542 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The reservoir pressure is expected to be 3294 psi at 8800’ TVDSS (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2414 psi. x A min EMW of 8.4 ppg for this well will be 561 psi over-balance to the reservoir. Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 3.25” hole for the entirety of the production hole section. Liner Program: x 2-3/8”, 4.6#, 13CR solid/cemented liner: 9425’ MD – 12,314’ MD (2889’ liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 2,500 psi. x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole. x 2” safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre- installed TIW valve). When closing on a 2” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 108°. Inclination at kick off point is 54°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 19,000’ x Distance to nearest well within pool – 880’ Logging: x MWD directional and Gamma Ray will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x ~30’ perforated post rig – See future perf sundry. x 1-11/16” Perf Guns at 6 spf x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or post rig under this PTD. x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. Anti-Collision Failures: x All wells pass AC with WP01. Hazards: x DS-06 is not an H2S pad. H2S reading on 06-18A: 5 ppm on 5/21/2022. x Max H2S recorded on DS-06: 75 ppm. x No expected fault crossings. x Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) 395 ppm on DS 06-09 (1987). H2S measures required. -A.Dewhurst 20 SEP 23 ! " # 78 7 5 80 5 0 82 2 5 84 0 0 85 7 5 87 5 0 89 2 5 91 0 0 92 7 5 94 5 0 True Vertical Depth (350 usft/in) -7 0 0 - 5 2 5 - 3 5 0 - 1 7 5 0 1 7 5 3 5 0 5 2 5 7 0 0 8 7 5 1 0 5 0 1 2 2 5 1 4 0 0 1 5 7 5 1 7 5 0 1 9 2 5 2 1 0 0 2 2 7 5 2 4 5 0 2 6 2 5 Ve r t i c a l S e c t i o n a t 2 4 . 6 7 ° ( 3 5 0 u s f t / i n ) DS 0 6 - 1 8 B w p 0 1 t g t 1 DS 0 6 - 1 8 B w p 0 1 t g t 5 DS 0 6 - 1 8 B w p 0 1 t g t 2 DS 0 6 - 1 8 B w p 0 1 t g t 3 DS 0 6 - 1 8 B w p 0 1 t g t 4 DS 0 6 - 1 8 B w p 0 1 90 0 0 95 00 10 0 0 0 10 5 0 0 10 6 5 0 06 - 1 8 TI P KO P 90 0 0 95 00 10 00 0 10500 11000 11 500 1 20 0 0 1 2 50 0 13000 13500 14000 06 - 1 8 A 9 5 / 8 " 7" 2 3 / 8 " x 3 1 / 4 " 90 0 0 95 00 1 0 0 0 0 10500 11000 1150 0 12000 12314 06 - 1 8 B w p 0 1 St a r t D i r 9 º / 1 0 0 ' : 9 9 6 0 ' M D , 8 6 8 7 . 7 4 ' T V D : 0 ° R T T F St a r t D i r 2 5 º / 1 0 0 ' : 9 9 8 0 ' M D , 8 6 9 9 . 0 9 ' T V D St a r t D i r 1 2 º / 1 0 0 ' : 1 0 4 5 5 ' M D , 8 9 2 3 . 5 ' T V D To t a l D e p t h : 1 2 3 1 4 . 4 2 ' M D , 9 0 3 2 ' T V D Hi l c o r p N o r t h S l o p e , L L C Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Er r o r S y s t e m : IS C W S A Sc a n M e t h o d : C l o s e s t A p p r o a c h 3 D Er r o r S u r f a c e : E l l i p s o i d S e p a r a t i o n Wa r n i n g M e t h o d : E r r o r R a t i o WE L L D E T A I L S : 0 6 - 1 8 Gr o u n d L e v e l : 3 7 . 0 5 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0 . 0 0 5 9 4 0 7 1 5 . 4 7 0 6 8 6 1 0 9 . 2 5 0 70 ° 1 4 ' 3 4 . 7 2 5 3 N 14 8 ° 2 9 ' 4 8 . 3 6 3 9 W SU R V E Y P R O G R A M Da t e : 2 0 2 3 - 0 4 - 0 3 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m D e p t h T o S u r v e y / P l a n T o o l 10 0 . 0 0 9 8 0 0 . 0 0 1 : C a m e r a b a s e d g y r o m u l t i s h o ( 0 6 - 1 8 ) 3 _ C B - F i l m - G M S 98 6 3 . 5 0 9 9 6 0 . 0 0 M W D ( 0 6 - 1 8 A ) 3 _ M W D 99 6 0 . 0 0 1 2 3 1 4 . 4 2 0 6 - 1 8 B w p 0 1 ( 0 6 - 1 8 B ) 3 _ M W D FO R M A T I O N T O P D E T A I L S No f o r m a t i o n d a t a i s a v a i l a b l e RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l 0 6 - 1 8 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : Ke l l y B u s h i n g / R o t a r y T a b l e @ 7 4 . 0 0 u s f t Me a s u r e d D e p t h R e f e r e n c e : Ke l l y B u s h i n g / R o t a r y T a b l e @ 7 4 . 0 0 u s f t Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pr o j e c t : Pr u d h o e B a y Si t e : 06 We l l : 06 - 1 8 We l l b o r e : 06 - 1 8 B De s i g n : 06 - 1 8 B w p 0 1 CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 90 3 2 . 0 0 8 9 5 8 . 0 0 1 2 3 1 4 . 4 2 2 - 3 / 8 2 3 / 8 " x 3 1 / 4 " SE C T I O N D E T A I L S Se c MD I n c A z i T V D + N / - S + E / - W D l e g T F a c e V S e c t Ta r g e t An n o t a t i o n 1 9 9 6 0 . 0 0 5 4 . 5 4 1 1 5 . 8 6 8 6 8 7 . 7 4 - 2 4 0 4 . 0 7 3 1 8 3 . 9 4 0 . 0 0 0 . 0 0 0 . 0 0 S t a r t D i r 9 º / 1 0 0 ' : 9 9 6 0 ' M D , 8 6 8 7 . 7 4 ' T V D : 0 ° R T T F 2 9 9 8 0 . 0 0 5 6 . 3 4 1 1 5 . 8 6 8 6 9 9 . 0 9 - 2 4 1 1 . 2 5 3 1 9 8 . 7 6 9 . 0 0 0 . 0 0 - 0 . 3 4 S t a r t D i r 2 5 º / 1 0 0 ' : 9 9 8 0 ' M D , 8 6 9 9 . 0 9 ' T V D 3 1 0 2 3 0 . 0 0 6 3 . 4 5 4 2 . 5 6 8 8 3 8 . 3 2 - 2 3 7 0 . 1 0 3 3 8 7 . 0 8 2 5 . 0 0 - 1 0 5 . 0 0 1 1 5 . 6 6 4 1 0 4 5 5 . 0 0 7 5 . 6 2 3 4 3 . 4 3 8 9 2 3 . 5 0 - 2 1 7 5 . 6 6 3 4 2 7 . 3 5 2 5 . 0 0 - 9 0 . 0 0 3 0 9 . 1 7 S t a r t D i r 1 2 º / 1 0 0 ' : 1 0 4 5 5 ' M D , 8 9 2 3 . 5 ' T V D 5 1 0 7 0 0 . 0 0 7 7 . 5 1 1 3 . 6 1 8 9 8 1 . 7 1 - 1 9 4 0 . 5 0 3 4 2 1 . 5 3 1 2 . 0 0 9 0 . 0 0 5 2 0 . 4 3 6 10 9 7 9 . 7 5 1 0 8 . 0 0 3 5 9 . 3 9 8 9 6 8 . 3 7 - 1 6 6 6 . 8 8 3 4 5 3 . 1 7 1 2 . 0 0 - 2 5 . 0 0 7 8 2 . 2 8 7 1 1 1 5 9 . 7 5 1 0 7 . 8 0 2 2 . 1 0 8 9 1 2 . 3 8 - 1 4 9 9 . 9 1 3 4 8 4 . 8 8 1 2 . 0 0 8 7 . 0 0 9 4 7 . 2 4 8 1 1 3 1 9 . 7 5 1 0 7 . 7 6 1 . 9 3 8 8 6 3 . 0 7 - 1 3 5 1 . 8 0 3 5 1 6 . 4 0 1 2 . 0 0 - 8 7 . 0 0 1 0 9 4 . 9 9 9 1 1 5 4 4 . 7 5 9 3 . 1 9 2 5 . 1 2 8 8 2 1 . 7 3 - 1 1 3 9 . 0 7 3 5 6 8 . 6 6 1 2 . 0 0 1 2 0 . 0 0 1 3 1 0 . 1 1 10 1 1 6 4 4 . 7 5 8 3 . 9 9 3 2 . 8 4 8 8 2 4 . 1 9 - 1 0 5 1 . 7 7 3 6 1 7 . 0 0 1 2 . 0 0 1 4 0 . 0 0 1 4 0 9 . 6 2 11 1 1 8 4 4 . 7 5 6 9 . 1 7 5 2 . 3 2 8 8 7 0 . 9 0 - 9 0 8 . 9 9 3 7 4 6 . 8 0 1 2 . 0 0 1 3 0 . 0 0 1 5 9 3 . 5 5 12 1 2 0 4 4 . 7 5 7 0 . 2 4 2 6 . 7 3 8 9 4 1 . 3 0 - 7 6 5 . 6 9 3 8 6 4 . 8 2 1 2 . 0 0 - 9 2 . 0 0 1 7 7 3 . 0 3 13 1 2 2 4 4 . 7 5 7 0 . 8 0 5 2 . 2 0 9 0 0 9 . 0 0 - 6 2 1 . 6 4 3 9 8 3 . 5 0 1 2 . 0 0 9 3 . 0 0 1 9 5 3 . 4 7 1 4 1 2 3 1 4 . 4 2 7 0 . 7 2 4 3 . 3 4 9 0 3 2 . 0 0 - 5 7 7 . 4 9 4 0 3 2 . 1 5 1 2 . 0 0 - 9 2 . 0 0 2 0 1 3 . 9 0 D S 0 6 - 1 8 B w p 0 1 t g t 5 T o t a l D e p t h : 1 2 3 1 4 . 4 2 ' M D , 9 0 3 2 ' T V D -2800 -2625 -2450 -2275 -2100 -1925 -1750 -1575 -1400 -1225 -1050 -875 -700 -525 -350 -175 0 So u t h ( - ) / N o r t h ( + ) ( 3 5 0 u s f t / i n ) 2275 2450 2625 2800 2975 3150 3325 3500 3675 3850 4025 4200 4375 4550 4725 West(-)/East(+) (350 usft/in) DS06-18B wp01 DS06-18B wp01 tgt 4 DS06-18B wp01 tgt 3 DS06-18B wp01 tgt 2 DS06-18B wp01 tgt 5 DS06-18B wp01 tgt 1 06-18 TIPKOP 06 - 1 8 A 9 5/8"7" 2 3/8" x 3 1/4" 7250 7500 775 0 800 0 8250 8500 875 0 9 0 0 0 90 32 06-18 B w p0 1 Start Dir 9º/100' : 9960' MD, 8687.74'TVD : 0° RT TF Start Dir 25º/100' : 9980' MD, 8699.09'TVD Start Dir 12º/100' : 10455' MD, 8923.5'TVD Total Depth : 12314.42' MD, 9032' TVD CASING DETAILS TVD TVDSS MD Size Name 9032.00 8958.00 12314.42 2-3/8 2 3/8" x 3 1/4" Project: Prudhoe Bay Site: 06 Well: 06-18 Wellbore: 06-18B Plan: 06-18B wp01 WELL DETAILS: 06-18 Ground Level: 37.05 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 5940715.470 686109.250 70° 14' 34.7253 N 148° 29' 48.3639 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well 06-18, True North Vertical (TVD) Reference:Kelly Bushing / Rotary Table @ 74.00usft Measured Depth Reference:Kelly Bushing / Rotary Table @ 74.00usft Calculation Method:Minimum Curvature $ ! % # ! & '() & * *+ ",#!" - 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eparation Factor 99 7 5 1 0 1 5 0 1 0 3 2 5 1 0 5 0 0 1 0 6 7 5 1 0 8 5 0 1 1 0 2 5 1 1 2 0 0 1 1 3 7 5 1 1 5 5 0 1 1 7 2 5 1 1 9 0 0 1 2 0 7 5 1 2 2 5 0 1 2 4 2 5 1 2 6 0 0 1 2 7 7 5 1 2 9 5 0 1 3 1 2 5 1 3 3 0 0 Me a s u r e d D e p t h ( 3 5 0 u s f t / i n ) 06 - 1 8 A 06 - 0 8 B 06 - 0 8 06 - 0 8 B P B 1 06 - 0 8 A 06 - 0 8 C w p 0 6 06 - 2 0 B w p 0 3 06 - 2 0 06 - 2 0 A 06 - 0 7 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : 0 6 - 1 8 N A D 1 9 2 7 ( N A D C O N C O N U S ) Al a s k a Z o n e 0 4 Gr o u n d L e v e l : 3 7 . 0 5 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0. 0 0 59 4 0 7 1 5 . 4 7 0 6 8 6 1 0 9. 2 5 0 7 0 ° 1 4 ' 3 4 . 7 2 5 3 N 1 4 8 ° 2 9 ' 4 8 . 3 6 3 9 W RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l 0 6 - 1 8 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : Ke l l y B u s h i n g / R o t a r y T a b l e @ 7 4 . 0 0 u s f t Me a s u r e d D e p t h R e f e r e n c e : Ke l l y B u s h i n g / R o t a r y T a b l e @ 7 4 . 0 0 u s f t Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e SU R V E Y P R O G R A M Da t e : 2 0 2 3 - 0 4 - 0 3 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m D e p t h T o S u r v e y / P l a n To o l 10 0 . 0 0 9 8 0 0 . 0 0 1 : C a m e r a b a s e d g y r o m u l t i s h o ( 0 6 - 1 8 ) 3 _ C B - F i l m - G M S 98 6 3 . 5 0 9 9 6 0 . 0 0 M W D ( 0 6 - 1 8 A ) 3 _ M W D 99 6 0 . 0 0 1 2 3 1 4 . 4 2 0 6 - 1 8 B w p 0 1 ( 0 6 - 1 8 B ) 3 _ M W D 0. 0 0 30 . 0 0 60 . 0 0 90 . 0 0 12 0 . 0 0 15 0 . 0 0 18 0 . 0 0 Centre to Centre Separation (60.00 usft/in) 99 7 5 1 0 1 5 0 1 0 3 2 5 1 0 5 0 0 1 0 6 7 5 1 0 8 5 0 1 1 0 2 5 1 1 2 0 0 1 1 3 7 5 1 1 5 5 0 1 1 7 2 5 1 1 9 0 0 1 2 0 7 5 1 2 2 5 0 1 2 4 2 5 1 2 6 0 0 1 2 7 7 5 1 2 9 5 0 1 3 1 2 5 1 3 3 0 0 Me a s u r e d D e p t h ( 3 5 0 u s f t / i n ) 06 - 1 8 GL O B A L F I L T E R A P P L I E D : A l l w e l l p a t h s w i t h i n 2 0 0 ' + 1 0 0 / 1 0 0 0 o f r e f e r e n c e 99 6 0 . 0 0 T o 1 2 3 1 4 . 4 2 Pr o j e c t : P r u d h o e B a y Si t e : 0 6 We l l : 0 6 - 1 8 We l l b o r e : 0 6 - 1 8 B Pl a n : 0 6 - 1 8 B w p 0 1 CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 90 3 2 . 0 0 8 9 5 8 . 0 0 1 2 3 1 4 . 4 2 2 - 3 / 8 2 3 / 8 " x 3 1 / 4 " Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. X PBU 06-18B 223-071 PRUDHOE OIL PRUDHOE BAY W E L L P E R M I T C H E C K L I S T Co m p a n y Hi l c o r p N o r t h S l o p e , L L C We l l N a m e : PR U D H O E B A Y U N I T 0 6 - 1 8 B In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t 11 6 5 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 0 7 1 0 PR U D H O E B A Y , P R U D H O E O I L - 6 4 0 1 5 0 NA 1 P e r m i t f e e a t t a c h e d Ye s A D L 0 2 8 3 1 1 2 L e a s e n u m b e r a p p r o p r i a t e Ye s 3 U n i q u e w e l l n a m e a n d n u m b e r Ye s P R U D H O E B A Y , P R U D H O E O I L - 6 4 0 1 5 0 - g o v e r n e d b y 3 4 1 J 4 W e l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 S u f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 I f d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 O p e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 O p e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 P e r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 P e r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 C a n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r NA 15 A l l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 P r e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 N o n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 18 C o n d u c t o r s t r i n g p r o v i d e d Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 20 C M T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 21 C M T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s F u l l y c e m e n t e d p r o d u c t i o n l i n e r . P a r e n t w e l l i s o l a t e s t h e r e s e r v o i r . 22 C M T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 23 C a s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s C D R 2 h a s a d e q u a t e t a n k a g e a n d g o o d t r u c k i n g s u p p o r t . 24 A d e q u a t e t a n k a g e o r r e s e r v e p i t Ye s S u n d r y 3 2 3 - 4 4 0 25 I f a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s H a l l i b u r t o n c o l l i s i o n s c a n i d e n t i f i e s n o c l o s e a p p r o a c h e s . 26 A d e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d NA 27 I f d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s M P D b u t r e s e r v o i r p r e s s u r e b e l o w w a t e r g r a d i e n t . 28 D r i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s C T P a c k o f f , f l o w c r o s s , a n n u l a r , b l i n d s h e a r , C T p i p e s l i p s , f l o w c r o s s , B H A p i p e s l i p s , C T p i p e s l i p s 29 B O P E s , d o t h e y m e e t r e g u l a t i o n Ye s 7 - 1 / 1 6 " 5 0 0 0 p s i s t a c k p r e s s u r e t e s t e d t o 3 5 0 0 p s i . 30 B O P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s F l a n g e d c h o k e a n d k i l l l i n e s b e t w e e n d u a l c o m b i ' s w r e m o t e c h o k e 31 C h o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 W o r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n Ye s P B U D S 0 6 i s n o t a n H 2 S P a d 33 I s p r e s e n c e o f H 2 S g a s p r o b a b l e NA 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No D S 0 6 w e l l s a r e H 2 S - b e a r i n g . H 2 S m e a s u r e s a r e r e q u i r e d . ( M a x H 2 S o n p a d i n 0 6 - 0 9 : 3 9 5 p p m i n 1 9 8 7 ) 35 P e r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s E x p e c t e d r e s e r v o i r p r e s s u r e i s 7 . 3 p p g E M W ; w i l l b e d r i l l e d u s i n g 8 . 4 p p g m u d a n d M P D t a r g e t i n g 9 . 8 p p g 36 D a t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 S e i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 S e a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 C o n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 9/ 2 0 / 2 0 2 3 Ap p r MG R Da t e 8/ 1 0 / 2 0 2 3 Ap p r AD D Da t e 9/ 2 0 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *& : JL C 9 / 2 5 / 2 0 2 3