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Home My WebLink About224-0957. 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 06-19B Gel Squeeze, Reperforate Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-095 50-029-20791-02-00 11345 Surface Intermediate Production Liner Liner 8862 2482 4983 8668 300 2886 11097 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8907 23 - 2505 22 - 5005 21 - 8689 8512 - 8812 8459 - 11345 23 - 2505 22 - 5005 21 - 8566 8395 - 8680 8343 - 8862 None 2670 4760 5410 7500 8160 11097 5380 6870 7240 8430 9150 10848 - 10878 4-1/2" 12.6# 13Cr80 20 - 8525 8947 - 8942 Conductor 83 20" 28 - 111 28 - 111 1490 470 4-1/2" Baker S-3 Perm Packer 8406 8292 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 0028311 20 - 8408 10848 - 10878' Pump 17-bbls of Equiseal Gel. Final pressure = 2311-psi. 216 187 23739 22643 2031 1963 1340 1124 921 766 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8406, 8292 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 12:49 pm, May 15, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.15 12:11:18 - 08'00' Bo York (1248) JJL 6/13/25 DSR-6/3/25 ACTIVITY DATE SUMMARY 4/13/2025 T/I/O = 2100/1079/26. LRS 70. (GEL TREATMENT) Pumped 7 bbls 60/40 and 173 bbls 1% KCL into TBG for injectivity test, HES pumped 10 bbls of 1% KCL, 17 bbls of Equiseal Gel and displaced with 10 bbls of 1% KCL. LRS pumped 115 bbls Diesel on turbine meter / 127 bbls on stroke counter for displacement. During diesel displacement we reached max pressure of 2,000 psi and 111 bbls of diesel away. We were able to squeeze in 4 more bbls over 4 hours. Estimated top of gel ~8,214' MD per turbine meter / ~9650' MD per stroke counter. The injectivity plot suggests 8- 10 bbls of gel out of the target 12 bbls went into perfs. See log. Flush surface lines w/ 2 bbls Diesel. DSO notified upon LRS departure. ***Wait on gel until 4/18*** Final WHPs = 2250/1085/29 5/3/2025 LRS CTU #1 - 1.5" Blue Coil, 0.134" WT. Job Objective: Clean out gel and perf MIRU. Function test BOPs upon installation. Make up and RIH with 2.25" FCO BHA. Begin jetting at 9000'. clean out down to 11090CTM, Circulate bottoms up while POOH, FP CT and cap well. L/D clean out BHA. M/U HES GR/CCL ***Cont to WSR on 5/4/25*** 5/4/2025 LRS CTU #1 - 1.5" Blue Coil, 0.134" WT. Job Objective: Clean out gel and perf RIH w/ HES GR/CCL. Log from CIBP at 11097CTM, paint blud flag at 10800', log up to 8400. POOH, Lay in 15bbls 60/40 and diesel from 6200'. POOH. OOH with logging tools and have good data the shows a -4.5' correction, OE approves. Log correlated to HES coil flag 12/11/2024. Bring on gas lift and unload the tubing to the flowline. Shoot fluid level and TBG FL is at the dome. Bring on again for 1 hour. Shut down and shoot a fluid level, inconclusive. Discuss with OE and opt to forgo the underbalance. Make up and RIH with HES 2" x 30' maxforce perf gun. Tag at 300'. POOH, lay down perf guns, and pick up 2.25" DJN BHA. Roll coil to methanol. Jet through 2 bridges at 85' and 150', and then had injection. Bullhead 33 bbl of 60/40. RIH. ***Job in Progress*** 5/4/2025 T/I/O = 1350/1420/40. Temp = SI. T/IA FL (CTU request). ALP = 1960 psi, SI @ CV. T FL Inconclusive. IA FL @ 5686' (st#3 SO). CTU in control of valves upon departure 5/5/2025 LRS CTU #1 - 1.5" Blue Coil, 0.134" WT. Job Objective: Clean out gel and perf Cont RIH w/2" max force guns (30'). Correct at flag, perforate 10,848-10,878. POOH. Lay down perf gun BHA. Well freeze protected with diesel. Notified DSO of well status. Rig down CTU and standby on winds to lower the mast. ***Job Complete*** 5/6/2025 LRS CTU 1 w/ 1.5" x .134" WT Blue Coil Job Objective: Jet out gel and Re-perf Continue weather standby (high winds). Lower CTU mast and resume weather standby for snow removal. Snow removal complete. Drive unit to V-pad. ***Job Complete*** Daily Report of Well Operations PBU 06-19B 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: 5/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250515 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-23 50283201910000 223061 4/24/2025 AK E-LINE Plug/Perf T40412 END 2-72 50029237810000 224016 4/4/2025 READ CoilFlag T40413 IRU 241-01 50283201840000 221076 4/30/2025 AK E-LINE Perf T40414 IRU 241-01 50283201840000 221076 4/23/2025 AK E-LINE Plug/Perf T40414 KU 33-08 50133207180000 224008 4/22/2025 AK E-LINE PPROF T40415 MRU D-16RD 50733201830100 180110 4/21/2025 AK E-LINE Cement/Perf T40416 NSU NS-06 50029230880000 202101 4/21/2025 AK E-LINE PPROF T40417 NSU NS-19 50029231220000 202207 4/27/2025 AK E-LINE Perf T40418 NSU NS-20 50029231180000 202188 4/24/2025 AK E-LINE Perf T40419 NSU NS-23 50029231460000 203050 4/23/2024 AK E-LINE Packer T40420 PBU 02-10B 50029201630200 200064 3/21/2025 BAKER SPN T40421 PBU 06-19B 50029207910200 224095 3/1/2025 BAKER MRPM Borax T40422 PBU S-100A 50029229620100 224083 2/28/2025 BAKER MRPM Borax T40423 PBU Z-235 (Revised)50029237600000 223055 4/1/2025 READ InectionProfile T40424 SRU 231-33 50133101630100 223008 5/1/2025 AK E-LINE Plug/Perf T40425 Revision Explanation: Processing report added Please include current contact information if different from above. T40422PBU 06-19B 50029207910200 224095 3/1/2025 BAKER MRPM Borax Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.16 08:15:21 -08'00' 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 06-19B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-095 50-029-20791-02-00 11345 Surface Intermediate Production Liner Liner 8862 2482 4983 8668 300 2886 11076 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8910 23 - 2505 22 - 5005 21 - 8689 8512 - 8812 8459 - 11345 23 - 2505 22 - 5005 21 - 8566 8395 - 8680 8343 - 8862 none 2670 4760 5410 7500 8160 11076 5380 6870 7240 8430 9150 10848 - 10878 4-1/2" 12.6# 13Cr80 20 - 8525 8947 - 8942 Conductor 83 20" 28 - 111 28 - 111 1490 470 4-1/2" Baker S-3 Perm , 8406 , 8292 No SSSV 8406 8292 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 0028311 20 - 8408 156 191 25264 18005 1730 2164 1923 1319 854 894 N/A 13b. Pools active after work:PRUDHOE OIL 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 9:36 am, Apr 01, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.03.28 12:17:17 - 08'00' Bo York (1248) RBDMS JSB 040325 JJL 4/9/25 ACTIVITYDATE SUMMARY 2/28/2025 LRS CTU 1 w/ 1.5" Blue Coil. Job Objective: Drift, RPM/Borax, Caliper, Set CIBP MIRU. Perform Weekly BOPTest 250psi/4000psi - No Failures. Install BOPs on tree and Function Test. Make up and RIH with 2.25" Down Jet Nozzle Drift BHA. Bullhead 135 bbls 1% KCL w/ Safelube. Well went on a Vac. Tag 11,292'e / 11293' m. PU clean. PU paint Flag. POOH ***Job in Progress*** 3/1/2025 LRS CTU 1 w/ 1.5" Blue Coil. Job Objective: Drift, RPM/Borax, Caliper, Set CIBP POOH, Lay down Drift BHA, Make up BKR Atlas RPM BHA. RIH w/ RPM BHA. Bullhead 1% KCL. Log baseline passes at 30, 60, & 60fpm pumping .3-.6bpm down the CTBS. Injectivity got progressively tighter. Swap to circulate the borax down the coil for the (2) 60fpm borax passes. Perform 1st pass with 30bbl of borax behind pipe and an additional 30bbl behind pipe for second pass. POOH and circ out borax from well.7 bbl Meth cap on well. Pop off. Pull & LD RPM BHA. Check data, MU Caliper , RIH ***Job in Progress***e 3/2/2025 LRS CTU 1 w/ 1.5" Blue Coil. Job Objective: Drift, RPM/Borax, Caliper, Set CIBP RIH with Caliper. RIH 20' past flag. 11,282' e/11,255'm/11,281.81 hes. Caliper log f/ 11,282' to 8300' . Paint coil flag for plug at 11000'. POOH. OOH with caliper and have good data that shows a -4' correction. Confirmed by OE. Make up and RIH with 2-7/8" CIBP and set at 11076. Freeze protect well with 38bbl of 60/40 & diesel. RDMO. ***Job Complete*** Daily Report of Well Operations PBU 06-19B 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: 2/8/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type BCU 09A 50133204450100 224113 11/13/2024 YELLOWJACKET GPT-PERF BCU 09A 50133204450100 224113 10/30/2024 YELLOWJACKET GPT BCU 11A 50133205210100 224123 11/9/2024 YELLOWJACKET SCBL BCU 25 50133206440000 214132 11/2/2024 YELLOWJACKET SCBL END 2-74 REVISED 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 HVA 10 50231200280000 204186 11/13/2024 YELLOWJACKET GPT-PERF KU 23-07A 50133207300000 224126 11/23/2024 YELLOWJACKET SCBL NCIU A-21 50883201990000 224086 11/29/2024 AK E-LINE CaliperSurvey PAXTON 6 50133207070000 222054 11/7/2024 YELLOWJACKET PERF PBU 01-37 50029236330000 219073 11/23/2024 BAKER MRPM PBU 06-15A 50029204590200 224108 12/26/2024 BAKER MRPM PBU 06-19B 50029207910200 224095 12/10/2024 BAKER MRPM PBU 07-29E 50029217820500 213001 11/26/2024 BAKER SPN PBU 14-31A 50029209890100 224090 11/10/2024 BAKER MRPM PBU 14-41A 50029222900100 224076 11/9/2024 BAKER MRPM SRU 241-33B 50133206960000 221053 11/5/2024 YELLOWJACKET GPT-PERF Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. T40053 T40053 T40054 T40055 T40056 T40057 T40058 T40059 T40060 T40061 T40062 T40063 T40064 T40065 T40066 T40067 PBU 06-19B 50029207910200 224095 12/10/2024 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.07 13:25:23 -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: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -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: 01/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 06-19B + PB1 + PB2 PTD: 224-095 API: 50-029-20791-02-00 (06-19B) 50-029-20791-70-00 (06-19BPB1) 50-029-20791-71-00 (06-19BPB2) FINAL LWD FORMATION EVALUATION LOGS (11/03/2024 to 12/04/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: SFTP Transfer - Data Sub-Folders: Please include current contact information if different from above. T39950 T39951 T39952 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.13 08:23:39 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 06-19B JBR 01/28/2025 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 2 3/8" and 3.5" test joints used for testing. During test #4 CMV #2 failed. The valve was serviced and retested for a pass. Good test. Test Results TEST DATA Rig Rep:Operator:Hilcorp North Slope, LLC Operator Rep:M. Igtanloc/ Rig Owner/Rig No.:Nabors CDR3AC PTD#:2240950 DATE:11/17/2024 Type Operation:DRILL Annular: 250/3500Type Test:BIWKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC241116175614 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 2387 Sundry No: 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 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 1 7 1/16" 5000 P #1 Rams 1 Blind/Shear P #2 Rams 1 2 3/8" Solid P #3 Rams 1 2 3/8" x 5" V P #4 Rams 1 2 3/8" Solid P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA BOP Misc 2 2" Piper P System Pressure P3050 Pressure After Closure P2350 200 PSI Attained P18 Full Pressure Attained P45 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@1950 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P11 #1 Rams P4 #2 Rams P3 #3 Rams P2 #4 Rams P4 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9999 9 9 9 9 9 9 9 FP CMV #2 failed. 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 Pool, PBU 06-19B Hilcorp Alaska, LLC Permit to Drill Number: 224-095 Surface Location: 231' FSL, 910' FEL, Sec 02, T10N, R14E, UM, AK Bottomhole Location: 25' FNL, 775' FWL, 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, Gregory C. Wilson Commissioner DATED this 15th day of October 2024. Sincerely, 3-1/2"x3-1/4" Drilling Manager 07/10/24 Monty M Myers By Grace Christianson at 2:28 pm, Jul 10, 2024 *BOPE test to 3500 psi. *Variance to 20 AAC 25.112(i) approved for alternate plug placement. with fully cemented production liner. DSR-7/10/24 224-095 MGR24JULY24 50-029-20791-02-00 A.Dewhurst 11OCT24 WCB 07-23-2024 T10N JLC 10/14/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.15 03:34:01 -08'00'10/15/24 RBDMS JSB 101524 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: July 10, 2024 Re:06-19B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 06-19A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for 06-19B Producer: See 06-19A Sundry request for complete pre-rig details - Prior to drilling activities, slickline will drift for a whipstock and run a caliper(if needed), E-line will set a 4-1/2" packer whipstock, E-line or service coil will mill the XN nipple, and (if a unit is available) service coil will mill the 3.80" window. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will mill a single string 3.80" window + 10' of formation(if not done pre-rig). The well will kick off drilling in the Ivishak Zone 4 and drill an S-shaped well through Zones 2, 3, and 4 to TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will target isolating and abandoning the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference 06-19A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and Caliper 2. Fullbore : MIT 3. E-Line : Set Whipstock at 8810' MD at 0 deg ROHS 4. Coil : Mill XN nipple and 3.80" Window (if window not possible, mill with rig) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in November 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). 2. Mill 3.80” Window (only if not done pre-rig) 3. Drill build section: 4.25" OH, ~174' (25 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2383' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 34 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~30’) and RPM/CBL. Sundry 324-392 * 24 hour notice to AOGCC for opportunity to witness BOPE test to 3500 psi. 10-401 from here down. 10-403 from here up. 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” (big hole) & 2-3/8” (slim hole) 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 (8810' MD -8,653' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,410 psi 4,410 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 529 psi 0 psi 0.09 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,870 psi 3,870 psi 8.6 B+C Mud + ECD Combined 4,398 psi 3,870 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 540 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,267 psi at 8,800 TVD. (7.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,387 psi (from estimated reservoir pressure). 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 4.25" hole for the entirety of the production hole section. Liner Program: x 3-1/2", 9.3#, 13Cr/Solid: 8,480' MD – 8,800' MD (320' liner) x 3-1/4", 6.6#, 13Cr/Solid: 8,800' MD – 9,100' MD (300' liner) x 2-7/8", 6.5#, 13Cr/Solid: 9,100' MD – 11,367' MD (2,267' 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 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8” x 3-1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. x A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. x 2 3/8" 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 3/8" 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 30°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – ~21,000' x Distance to nearest well within pool – 540 ft Logging: x MWD directional, Gamma Ray and Resistivity 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 attached extended perforating procedure. x 2" 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. x Formations: Top of Ivishak: 8808’ MD in the parent Anti-Collision Failures: x No Anti-Collision failures with 06-19B wp 03 Hazards: x DS/Pad 06 is not an H2S pad. The last H2S reading on 06-19A: 20 ppm on 04/16/2022. x Max H2S recorded on DS/Pad 06: 56 ppm. x 1 fault crossings expected. x Moderate lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram 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 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" 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 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee $) $) $) $) $) $) $) $) $) $) $) $)$)$)$)$)$)$)$)$) !! !!!! !!! !!! ! !!!! ! !!!! ! !! ! !!!! !!! !!! ! !! ! !! !! !! !!! !!!! !!!!! !!!! !!! !!!!!! ! D $)06-19B_BHL 06-19B_TPH 06-19B_SHL Oil Rim PAGas Cap PAADL028311 DS6 PAD 3 U010N014E Sec. 2 Sec. 1 Sec. 11 Sec. 12 PRUDHOE BAY UNIT 06-23 06-19 06-15 06-13 06-05 06-04 OWDW-C 06-24B 06-23B 06-19A 06-04A OWDW-SW PR121014 PR111014 PR021014 Map Date: 2/16/2024 Prudhoe Bay Unit 06-19B Well wp03 E0330660 Feet Legend T06_19B_wp03 $)06-19B_BHL !06-19B_SHL D 06-19B_TPH $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint PA Boundary CO_341J AIO_4G Document Path: O:\AWS\GIS\Products\Alaska\NS\Wells\TRS_Distance\mxds\2024\NorthSlope_06-19B wp03.mxd -800-400040080012001600South(-)/North(+) (800 usft/in)0 400 800 1200 1600 2000 2400 2800 West(-)/East(+) (800 usft/in)50010001500200025003000350006-02500100015002000250030003500400045005000550006-0350010001500200025003000350040004500500055006000650006-0450010001500200025003000350040004500500055006000650070007500800085009000933406-0 5 Top of Window - 9304'MDEnd 35dls - 9666'MD900006-05A 500100015002000250030003500400006-062906-06B wp08296-06B PB1 WP045001000150020002500300035004000450050005500600006-0750010001500200025003000350040004500500055006000650006-08400045005000550060006500700006-135000550006-13APB1500100015002000250030003500400006-175001000150020002500300035004000450006-1850010001500200025003000350040004500500055006000650070007500800085009000921106-1950005500600065007000750080008500900006-19A50010001500200025003000350040004500500055006000650070007500800085009000922006-2006-20A06-20B5001000150020002500300035004000450050000 6 -2150010001500200025003000350040004500500006-21C50010001500200025003000350040004500500055006000650070000 6-22 5001000150020002500300035004000450050005500600065007000750006-239000900006-19B wp03Top of Window - 8810'MDEnd 25dls - 8985'MDTD - 11367'MD85508700885090009150True Vertical Depth (300 usft/in)-525 -450 -375 -300 -225 -150 -75 0 75 150 225 300 375 450 525 600 675 750 825 900 Vertical Section at 160.00° (150 usft/in)06-19A06-19B wp03Top of Window - 8810'MDEnd 25dls - 8985'MDTD - 11367'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 8810.00 30.58 18.80 8677.87 473.24 741.29 0.00 0.00 -191.162 8830.00 32.38 18.80 8694.93 483.13 744.66 9.00 0.00 -199.303 8900.00 49.88 18.80 8747.45 526.55 759.44 25.00 0.00 -235.054 8984.46 71.00 18.80 8788.88 595.71 782.98 25.00 0.00 -291.995 9265.00 71.00 54.40 8880.21 805.26 938.59 12.00 90.00 -435.686 9335.00 71.00 45.51 8903.00 847.80 989.21 12.00 -90.00 -458.347 9593.00 71.00 78.25 8987.00 961.20 1201.45 12.00 90.00 -492.318 9794.70 90.00 93.53 9020.33 974.59 1398.40 12.00 40.00 -437.549 10027.13 107.50 115.61 8984.67 918.41 1618.72 12.00 50.00 -309.3910 10267.00 105.28 145.55 8915.54 770.45 1790.96 12.00 90.00 -111.4411 10512.00 103.27 175.84 8853.77 549.22 1868.15 12.00 90.00 122.8512 10645.89 90.00 184.97 8838.29 416.68 1867.07 12.00 145.00 247.0313 10772.44 75.75 190.28 8853.96 292.57 1850.54 12.00 160.00 358.0014 10903.00 75.75 206.44 8886.10 172.87 1810.82 12.00 90.00 456.9015 11083.00 75.75 184.16 8930.41 5.65 1765.08 12.00 -90.00 598.3916 11263.00 75.75 206.44 8974.71 -161.58 1719.33 12.00 90.00 739.8817 11367.00 75.75 193.57 9000.31 -256.10 1684.93 12.00 -90.00 816.93Project: Prudhoe BaySite: 06Well: 06-19Wellbore: 06-19BPlan: 06-19B wp03WELLBORE DETAILSParent Wellbore:06-19ATop of Window: 8810.0006-19B wp03Depth From Depth To Survey/Plan Tool91.30 4991.30 06-19 Srvy 1 Boss Gyro (06-19) 3_Gyro-SR-GMS15005.00 5318.10 06-19A Srvy 1 GYD GC SS (06-19A) 3_Unknown Gyro25346.07 8625.92 06-19A Srvy 2 MWD+IFR+MS (06-19A)3_MWD (BP MWD+IFR+MS-WOCA)8702.20 8810.00 06-19A Srvy 3 MWD+IFR+MS (06-19A)3_MWD (BP MWD+IFR+MS-WOCA)8810.00 11367.00 06-19B wp03 (06-19B) 3_MWDWELL DETAILSNorthing: 5940832.13Easting: 686081.24Lattitude: 70° 14' 35.8792 NLongitude: 148° 29' 49.0942 W06-19B wp03SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well 06-19 - Slot 19, True NorthVertical (TVD) Reference: KB @ 65.30usft (06-19A)Measured Depth Reference: KB @ 65.30usft (06-19A)Section (VS) Reference: Slot - 19(0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !"##$ % & $ ' # $ ( )*+ ( , ,- .$ /% !!" #$%&'() * +0+' +-,- . /, /+ ( #$%&'() * 1 % ( 0 / / ' 2 +' & / 3 '+'1 23),4 * 5 -23)5 -65651* 5 157/,-/ /, 89 " 1:0( 1:: ( 4 ' # # 0 5 1 %0 60 2$ .0 /9 ( ( ( ;&9 < % 9 ==&% =9 39&== & 3;9>9&%2=%5 9=;'>2&22920 , , # 0 # 60 1 %0 ( 768, 718 5 ( ( (2 #. 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"<<# / 7 " ;-"<; -"- !"; -<"<< 7- - - #;!" #-" -@"-! #!"@ "! / - - - <" !!"# <;" -"!- ";; - - - <" "# <!" -#" <"! 7- - - #;!" --" -@"-! #!"@< "! / - - - <" @!" <;" -"!- ";; - - - <" !" <!" -#" <"! / - - - <" @!" <;" -"!- ";; - - - <" !" <!" -#" <"! 7- - - #" !<" ;"#- <"# !"-; - - -2 $ . - - -2 $ . - - -2 $ . - - -2 $ . -- -- --2 $ . -- -- --2 $ . -- -- --2 $ . -- --' --'2 $ . -# -# -#2 $ . -# -# -#2 $ . -# -# -#2 $ . -# -#' -#'2 $ . -# -# -#2 $ . + ( ,. 7 $ / " () ) !"#$ %&*+,()'() - ) !"#$ %&.,()( ) */ ()" $ 0) + , 1 . )(2) 3 -" . 20)" $ (24, 4)/0+1+ */ 2$$ 0 (,5) 3#3(( *+,() #! < ! @ - @ ; - + ( 0) (( ' ! ! ! > ! '58 ! ! 3 > # # # >- >- >- - - - ># - - - >! - - - > / 6 / 5 0 ( , 8 ( 9 ' -< %/= & D @ 6( ,. $ 8 "@E +( !E F " 2$$ 0) , 2$$ 0 $ 0) , !"#$ %& + ( ,. 7 $ / " () ) !"#$ %&*+,()'() - ) !"#$ %&.,()( ) */ ()" $ 0) + , 1 . )(2) 3 -" . 20)" $ (24, 4)/0+1+ */ 2$$ 0 (,5) 3#3(( *+,() " #" " " 7 - @ ; + ( 0) 56 D 0. ,( G( '( G" 52/2 7 ' ! ! ! > ! '58 ! ! 3 > # # # >- >- >- - - - ># - - - >! - - - > / 6 / 5 0 ( , 8 ( 9 ' -< %/= & D @ 6( ,. $ 8 "@E +( !E F " 2$$ 0) , 2$$ 0 $ 0) , !"#$ %& + ( ,. 7 $ / 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 no greater 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. PBU 06-19B 224-095 PRUDHOE OILPRUDHOE BAY WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 06-19BInitial Class/Type / 1-OILGeoArea890Unit11650On/Off ShoreOnProgramField & PoolWell bore segAnnular DisposalPTD#:2240950PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL0283112 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA This well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.18 Conductor string providedNA All drilling on this sidetrack will be below the existing SC shoe.19 Surface casing protects all known USDWsNA This well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.20 CMT vol adequate to circulate on conductor & surf csgNA This well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.21 CMT vol adequate to tie-in long string to surf csgYes Fully cemented production liner. Parent well isolates the reservoir.22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes CDR2 and CDR3 have adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 324-39225 If a re-drill, has a 10-403 for abandonment been approvedYes No separation factors less than 1.26 Adequate wellbore separation proposedNA All drilling will be below the SC shoe.27 If diverter required, does it meet regulationsYes MPD but reservoir press of 7.1 ppg equivalent is below water gradient of 8.33 ppg.28 Drilling fluid program schematic & equip list adequateYes CT packoff, flow cross, annular, blind/shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29 BOPEs, do they meet regulationYes 7-1/16" 5000 psi stack pressure tested to 3500 psi30 BOPE press rating appropriate; test to (put psig in comments)Yes Flanged choke and kill lines between dual combis w/remote choke.31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo Prudhoe's N-Pad is not an "H2S pad."33 Is presence of H2S gas probableNA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only)No DS 06 wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 7.1 ppg EMW. MPD will be utilized36 Data presented on potential overpressure zonesNo37 Seismic analysis of shallow gas zonesNo38 Seabed condition survey (if off-shore)No39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate10/14/2024ApprWCBDate9/9/2024ApprADDDate10/10/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/14/2024