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Home My WebLink About225-0297. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU F-38B Pull, Replace Ext Length LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-029 50-029-22093-03-00 341J ADL 0028280, 0028281 12525 Surface Intermediate Scab Liner, Liner Liner Liner 9013 2456 10061 7204 168 2273 12503 13-3/8" 9-5/8" 7" x 4-1/2" 3-1/2" x 3-14" 2-3/8" 9013 32 - 2488 28 - 10089 2948 - 10152 10128 - 10296 10252 - 12525 2425 32 - 2484 28 - 8695 2943 - 8748 8728 - 8442 8821 - 9013 None 2260 4760 7020 10530 11780 None 5020 6870 8160 10160 11200 12330 - 12440 4-1/2" 12.6# 13Cr80 26 - 98219012 - 9012 Conductor 80 20" 32 - 112 32 - 112 4-1/2" Baker S3 Packer No SSSV Installed 9599, 8291 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 11/3/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:18 am, Oct 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.17 16:26:19 - 08'00' Torin Roschinger (4662) 325-649 DSR-10/30/25A.Dewhurst 23OCT25 Extended liner top BHA not to exceed 500'. Reestablish pressure containment after extended liner is RIH. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment J.Lau 10/23/25 10-404 10/31/25 Ext liner top packer Pull & Reset F-38B PTD: 225-029 Well Name:F-38B API Number:50-029-22093-03 Current Status:Operable Online Rig:CTU Estimated Start Date:11/03/2025 Estimated Duration:2 days Reg.Approval Reqstd?10-403 Date Reg. Approval Recvd:TBD Regulatory Contact:Abbie Barker (907) 564-4915 First Call Engineer:Finn Oestgaard (907) 564-5026 (907) 350-8420 Current Bottom Hole Pressure:3,300 psi Estimated from average Ivishak BHP KWF:7.3 ppg Use seawater or 1% KCL MPSP:2,425 psi (BHP - .1psi/ft gas gradient) Max Dev:106°@ 11,140 Min ID:1.781 @ 10,263 SIWHP Estimated 2,400 psi Brief Well Summary: F-38B is a recent CTD sidetrack completed with 2-3/8 liner. There are 2 liner tops due to leaving a future CTD kick out point. The previous caliper showed the 3-1/4 L-80 to be in good condition, however after multiple attempts of setting and PTing individual LTPs a spinner/temp log was run & revealed a fluid entry point between the LTPs in the 3-1/4. Due to the complications of setting stacked LTPs and the order of operations to get positive PTs for the lower assembly it was decided to run an extend LTP isolating all of the 3-1/4 behind the LTP. The extended LTP was set 9/20/25 with service coil & appeared to have to have been stung in ~5. The lower liner top. The liner top passes a PT to 1500 psi. The well initially came on strong @ 450 IOR, however the gas has significantly increased over a short period of time suggesting it is no longer holding isolating gas from the liner lap. It is suspected to be lodged in the tree due to the master valve not closing. Objective:Pull & reset extended LTP from 2-3/8 liner up to the 4-1/2 liner. Procedure Coil Extended Patch Recovery &Deployment Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Liner Top Packer job, 24-hour crew and WSS coverage is required. The well will be killed and monitored before entering the well. 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, it will either be killed by bullheading or circulating bottoms up. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH withrunning tools, ensureadequatelubricatorlengthto cover the running tools. 2. Bullhead 1.2x wellbore volume ~196 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi, it is ok to pressure up to 3,000 psi to overcome SIWHP. a.Wellbore volume to top perf =163 bbls b. 4-1/2 tubing/liner 10,128 X .0152 bpf = 154 bbls c. 3-1/4 liner 124 X 0.0079 = 1 bbl d. 2-3/8 liner (to top perf @ 12,330) 2078 X 0.0039 = 8 bbls 3. At surface, prepare for recovery of LTP. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. 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 F-38B Set Ext Length LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-029 50-029-22093-03-00 12525 Surface Intermediate Scab Liner, Liner Liner Liner 9013 2456 10061 7204 168 2273 12503 13-3/8" 9-5/8" 7" x 4-1/2" 3-1/2" x 3-14" 2-3/8" 9013 32 - 2488 28 - 10089 2948 - 10152 10128 - 10296 10252 - 12525 32 - 2484 28 - 8695 2943 - 8748 8728 - 8442 8821 - 9013 None 2260 4760 7020 10530 11780 None 5020 6870 8160 10160 11200 12330 - 12440 4-1/2" 12.6# 13Cr80 26 - 9821 9012 - 9012 Conductor 80 20" 32 - 112 32 - 112 4-1/2" Baker S3 Packer 9599 8291 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 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 0028280, 0028281 26 - 8471 None None 510 477 39,949 34,280 3,733 2,448 1,700 1,700 1,220 1,180 325-505 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9599, 8291 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 12:13 pm, Sep 26, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.25 18:25:33 - 08'00' Torin Roschinger (4662) RBDMS JSB 100225 J.Lau 11/5/25 ACTIVITY DATE SUMMARY 9/11/2025 *** WELL FLOWING ON ARRIVAL *** FUNCTION TEST WLV MAN DOWN DRILL W/ WILL RAGSDALE CO-REP RAN 4-1/2" GS JAR ON LTP @ 10,106' MD (1 HR 1800#) ***CONTINUE 9/12/25*** 9/12/2025 ***CONTINUE FROM 9/11/25*** JAR ON LTP @ 10,106' MD (2.5 HRS .125" 1800#) SWAP TO .160" CARBON JAR ON LTP @ 10,106' MD (3 HRS @ 3000#) ***CONTINUE 9/13/25*** 9/13/2025 ***CONTINUE FROM 9/12/25*** PULLED LTP w/ .160 @ 10,106' MD (RECOVERED ALL ELEMENTS) ***CONTINUE 9/14/2025*** 9/14/2025 ***CONTINUE FROM 9/13/2025*** PULL NS MONO-PAK LTP @ 10250' MD RAN, KJ, 4-1/2 BRUSH, CENTRALIZER, 3-1/2 BRUSH, BRUSH DEPLOYMENT SLEEVE @ 10,128' MD RAN, KJ, 3-1/2 BRUSH, CENTRALIZER, 2-1/4 BRUSH, BRUSH DEPLOYMENT SLEEVE @ 10,154' MD ***WELL LEFT S/I ON DEPARTURE*** 9/19/2025 SLB CTU #8- 1.75" Coil. Job Objective: Open Hole Deploy Extended LTP Mobilize CTU 8 to Location. ***Continue on WSR 9/20/25 *** 9/20/2025 SLB CTU #8- 1.75" Coil. Job Objective: Open Hole Deploy Extended LTP Mobilize CTU 8 to Location. MIRU. BOP Test to 300/4000 psi. Make up NS MHA and nozzle. PT Safety Joint and confirm tag on the stripper brass. Load well with 1% KCl w/ SafeLube and confirm kill, will be maintaining MCHF rate. Function test H2S and LEL Monitors. Perform PJSM with Well Control Drill for deployment of the safety joint and discuss contingencies. MU Extended LTP & RIH. Stack down @ 10,255'. Set LTP @ 10,072' & PT 1500 psi. Last 5 mins lost 22 psi - good test. POOH & FP well to 2500' TVD w/ diesel. RDMO CTU #8. ***Well Control Drill: Well Kick and Deployment of Safety Joint during Openhole operations. ***Job Complete *** 9/21/2025 ***WELL S/I ON ARRIVAL**** HES 759 R/U WELL CONTROL DRILL W/ WSL & NIGHT CREW ***CONT WSR ON 9/22/25*** 9/22/2025 ***CONT WSR FROM 9/21/25*** EQUALIZE & PULL 2-3/8" RSG FROM LTP @ 10,255' MD ***WELL S/I ON DEPARTURE, NOTIFIED PAD-OP ON WELL STATUS*** Daily Report of Well Operations PBU F-38B Ext liner top packer Pull & Reset F-38B PTD: 225-029 Fluids man-watch must be performed whilerecoveringLTPto ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU patch. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of patch. 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. e.At the beginning of each job, the crossover/safety joint must be physically MU to the LTP one time to confirm the threads are compatible. 6.Latch LTP and prepare to un-deploy. - Once latched to LTP full stroke open SSV & Master Valve before moving assembly to minimize potential damage to valves. 7.Break lubricator connection at QTS and begin recovery of LTP. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while undeploying LTP to ensure the well remains killed and there is no excess flow - Investigate for any obvious signs of packer anchoring assembly failure - This will influence if the replacement packer will be a single trip or 2 trip packer. - Have new packer assembly with the higher rated shear ring, PTSA, 5 pup & assemblies required to run as a 2-trip packer onsite to be made up with recovered spacer pipe for the new LTP. 8. Prepare for deployment of new extended LTP. 9.Break lubricator connection at QTS and begin makeup of LTP. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying LTP to ensure the well remains killed and there is no excess flow. Patch assembly Patch Interval (tie-in depths)Patch Length Weight of assembly (lbs) Run #1 10,070 10,252~182~870 lbs (4.8 ppf) 10. RIH with extended liner top packer assembly with RSG plug in the PTSA 11. Stab stinger into deployment sleeve & pressure to a minimum of 2000 psi to confirm stinger seals are holding, communicate results to OE for plan forward. 12. If PT passes RDMO CTU If PT fails, depending on LLR it may be decided to attempt to pull & reset LTP or troubleshoot RSG with SL. Contingent pull & reset extended LTP with service coil if LLR suggests significant mis-set. * End of sundried work. * Slickline 1. If 1 trip packer was run: Pull RSG from PTSA & RDMO If 2 trip packer was run: MU upper packer assembly, RIH, engage lower LTP assembly & set packer. After setting packer, set LTTP in LTP, pressure tubing to 2,000 psi & jar down on packer while holding pressure on the tubing. This secondary sequence will provide assurance LTP is firmly set. No pressure loss in the tubing should be observed. Pull LTTP & pressure test to a minimum of 2,000 psi to confirm entire LTP assembly is holding Ext liner top packer Pull & Reset F-38B PTD: 225-029 Pull RSG from PTSA & RDMO. Ops 1. POP well, gas lift may be needed for initial kick off, not expected to be needed for continuous production. If production data suggests LTP is not holding or has failed, service coil will repeat un-deployment & reset LTP. Attachments: Wellbore Schematic Proposed Schematic Caliper Log BOPE Schematic Standing Orders Equipment Layout Sundry Change Form Ext liner top packer Pull & Reset F-38B PTD: 225-029 Current Proposed Drilling Schematic Ext liner top packer Pull & Reset F-38B PTD: 225-029 Proposed Post Rig Wellbore Schematic Extended LTP Ext liner top packer Pull & Reset F-38B PTD: 225-029 Caliper Log Ext liner top packer Pull & Reset F-38B PTD: 225-029 BOP Schematic Ext liner top packer Pull & Reset F-38B PTD: 225-029 Ext liner top packer Pull & Reset F-38B PTD: 225-029 Ext liner top packer Pull & Reset F-38B PTD: 225-029 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 F-38B Pull LTP, Set LTPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-029 50-029-22093-03-00 12525 Surface Intermediate Scab Liner, Liner Liner Liner 9013 2456 10061 7204 168 2273 12503 13-3/8" 9-5/8" 7" x 4-1/2" 3-1/2" x 3-14" 2-3/8" 9013 32 - 2488 28 - 10089 2948 - 10152 10128 - 10296 10252 - 12525 32 - 2484 28 - 8695 2943 - 8748 8728 - 8442 8821 - 9013 None 2260 4760 7020 10530 11780 None 5020 6870 8160 10160 11200 12330 - 12440 4-1/2" 12.6# 13Cr80 26 - 9821 9012 - 9012 Conductor 80 20" 32 - 112 32 - 112 4-1/2" Baker S-3 Perm Packer 9599 8291 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 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 0028280, 0028281 26 - 8471 N/A N/A 901 446 44420 38880 1723 3197 1966 1000 1079 1260 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9599, 8291 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 1:17 pm, Aug 07, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.07 10:59:54 - 08'00' Torin Roschinger (4662) JJL 8/12/25 DSR-9/10/25 RBDMS JSB 080825 ACTIVITY DATE SUMMARY 7/17/2025 ***WELL S/I ON ARRIVAL*** STBY ON WELL SUPPORT TO SPOT EQUIPMENT ***CONTINUE 7/18/25*** 7/18/2025 ***CONTINUE FROM 7/17/25*** LRS LOADED TBG w/ 187 BBLS CRUDE RAN LTTP TO LOWER LTP @ 10,254' MD, JARRED DOWN WHILE PUMPING, UNABLE TO PRESSURE UP PULLED NS 450-368 MONO-PAK LTP FROM DEP SLEEVE @ 10,128' MD R/D FOR CDR RIG PREP ON NEIGHBORING WELL, WILL RETURN TO PULL LOWER LTP ***WELL S/I ON DEPARTURE*** 7/18/2025 T/I/O = 2328/1258/6 Assist Slickline ( SIDETRACK ) Pumped 257 bbls of crude down TBG to load & displace gas.Well left in Slicklines control Equipment secured, DSO notified upon departure, FWHP= 310/1267/9 7/22/2025 (Assist S-Line) TFS U4 T/IA/OA = 2569/1200/0 Pumped 193 BBLS of Crude down TBG to load, Pumped a additional 31 BBLS of Crude down TBG for a brush and flush. SL attempting drift run for liner, unable to make it to depth, on and off pump to vac out and PT for SL, ***WSR continues for new day*** 7/22/2025 ***WELL S/I ON ARRIVAL*** PULLED NS 350-272 LTP FROM 2.72 DEP SLEEVE @ 10,252' MD T-BIRD LOADED TBG w/ 193 BBLS CRUDE RAN 4-1/2" BRUSH, 3.50" GAUGE RING, 3-1/2" BRUSH TO 3.70" DEP SLEEVE @ 10,128' MD BRUSHED FOR 10 MINS WHILE T-BIRD PUMPED 1 BPM RAN 3-1/2" BRUSH, 2.75" CENT, 2.25" BRUSH TO DEP SLEEVE @ 10,252' MD BRUSHED FOR 10 MINS WHILE T-BIRD PUMPED 1 BPM RAN 3-1/2" GR, 2.73" NS PACKER DRIFT, 2-3/8" SPACER PIPE, 2.72" DEP SLEEVE STINGER (2.25" SEAL BORE) w/ 2 TT PINS (OAL = 14.16') S/D @ 10,230' SLM (TATTLE TALE PINS WERE NOT SHEARED RAN 3-1/2" BRUSH, 2.75" CENT, 2.25" BRUSH TO DEP SLEEVE @ 10,252' MD RAN 3-1/2" BRUSH, 2.75" CENT, 2.25" BRUSH W/ 2.23" SWAGE ON BOTTOM S/D @ 10,227' SLM (1.94" RING ON BOTTOM OF 2.23" SWAGE) RAN 3-1/2" GR, 2.73" NS PACKER DRIFT, 2-3/8" SPACER PIPE, 2.72" DEP SLEEVE STINGER (2.25" SEAL BORE) w/ 2 TT PINS (OAL = 14.16') S/D @ 10,229' SLM (TATTTLE TALE PINS SHEARED ***CONTINUE 7/23/25*** 7/23/2025 T/I/O 975/1200/0 Temp S/I (TFS unit 1 Assist S-Line with LTP) Pumped 16.5 bbls of Crude down the TBG testing a plug. *****WSR Continued on 7-24-2025******* 7/23/2025 ***WSR cont from 7-22-25*** (Assist S-line) TFS U4, T/ I/ 0 = 550/ 1200/ 0 Pumped 18 BBLS of Crude down TBG to assist S-Line with Brush and Flush. Then pumped 15 BBLS of Crude down TBG to pressure up. Unable to pressure up TBG. Released by S-Line. FWHP's = 800/ 1200/0 Well left in control with Pollard S-Line Daily Report of Well Operations PBU F-38B Daily Report of Well Operations PBU F-38B 7/23/2025 ***CONTINUE FROM 7/22/25*** SET NS 350-272 MONO-PAK LTP (14.66' OAL) TOP @ 10,250' MD (w/ 1.781 xx rsg) SET NS 450-368 MONO-PAK LTP (25.91' OAL) TOP @ 10,106' MD (2.31" flow through rsg) T-BIRD ATTEMPT TO PRESSURE TEST, UNABLE TO PRESSURE UP TO 1500 psi R/D FOR SBHPS ON F-36, WILL RETURN TO TROUBLE SHOOT ***MOVE OVER TO F-36*** ***BACK FROM F-36*** PULL 2-7/8" RSG FROM LTP @ 10,106' MD RAN 2.29" LTTP TO LOWER LTP @ 10,250' MD PUMPED 15 BBLS W/ THUNDERBIRD NO PSI CHANGE PULL 2.29" LTP FROM LTP @ 10,250' MD SET 2-7/8" XX PLUG IN LTP @ 10,106' MD ***CONTINUE 7/24/25*** 7/24/2025 ****WSR Continued from 7-23-2025****** (TFS unit 1 Assist S-Line with LTP work) Pumped 80 bbls of Crude down the TBG to assist with setting, pulling, testing plugs and LTP. Well left in S-Line control Final WHPS 750/1200/0 7/24/2025 ***CONTINUE FROM 7/23/25*** BRING THUNDERBIRD ON-LINE TO TEST LTP @ 10,128' MD (GOOD TEST TO 1500 PSI) PULL 1.781" RSG FROM LTP @ 10,252' MD RAN 1.781" RX PLUG TO 10,252' MD THUNDER BIRD PUMPED 20 BBLS & NEVER CAUGHT PRESSURE ON TUBING RAN 2.12" BLIND BOX TO LTP @ 10,252' MD. JARRED DOWN ON LTP WHILE PUMPING @ 1 BPM. NEVER CAUGHT PRESSURE OR SEEN TRAVEL RAN 2.25" LTTP TO 10,252' MD. JARRED DOWN WHILE PUMPING FROM 1 BPM TO 5 BPM. NO TRAVEL. TUBING PRESSURE FALLS RIGHT OFF AFTER T-BIRD SHUTS DOWN RAN READ LEAK DETECT LOG PULL 1.781" RX PLUG FROM LTP @ 10,252' MD ***WELL TURNED OVER TO PAD OP*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU F-38B Set Ext Length LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-029 50-029-22093-03-00 341J ADL 0028280, 0028281 12525 Surface Intermediate Scab Liner, Liner Liner Liner 9013 2456 10061 7204 168 2273 12503 13-3/8" 9-5/8" 7" x 4-1/2" 3-1/2" x 3-14" 2-3/8" 9013 32 - 2488 28 - 10089 2948 - 10152 10128 - 10296 10252 - 12525 2425 32 - 2484 28 - 8695 2943 - 8748 8728 - 8442 8821 - 9013 None 2260 4760 7020 10530 11780 None 5020 6870 8160 10160 11200 12330 - 12440 4-1/2" 12.6# 13Cr80 26 - 98219012 - 9012 Conductor 80 20" 32 - 112 32 - 112 4-1/2" Baker S3 Packer No SSSV Installed 9599, 8291 Date: Torin Roschinger Operations Manager Finn Oestgaard Finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY 9/5/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:26 am, Aug 22, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.22 11:15:03 - 08'00' Torin Roschinger (4662) 325-505 DSR-8/26/25A.Dewhurst 27AUG25JJL 8/25/25 10-404 Extended liner top BHA not to exceed 500'. Reestablish pressure containment after RIH w/ extended LT BHA. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment JLC 8/28/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.28 16:32:55 -08'00'08/28/25 RBDMS JSB 082925 Ext liner top packer F-38B PTD:225-029 WWell Name: F-38B AAPI Number: 50-029-22093-03 Current Status: Operable Online RRig: CTU Estimated Start Date: 9/5/25 EEstimated Duration: 2 days Reg.Approval Req’std? 10-403 DDate Reg. Approval Rec’vd: TBD Regulatory Contact: Abbie Barker (907) 564-4915 First Call Engineer: Finn Oestgaard (907) 564-5026 (907) 350-8420 Current Bottom Hole Pressure: 3,300 psi Estimated from average Ivishak BHP KWF: 7.3 ppg Use seawater or 1% KCL MPSP: 2,425 psi (BHP - .1psi/ft gas gradient) Max Dev: 106 @ 11,140’ Min ID: 1.781” @ 10,263’ SIWHP Estimated 2,400 psi Brief Well Summary: F-38B is a recent CTD sidetrack completed with 2-3/8” liner. There are 2 liner tops due to leaving a future CTD kick out point. The previous caliper showed the 3-1/4” L-80 to be in good condition, however after multiple attempts of setting and PT’ing both LTP’s a spinner/temp log was run showing there to be a fluid entry point between the LTP’s in the 3-1/4”. Due to the complications of setting stacked LTP’s and the order of operations to get positive PT’s for the lower assembly it was decided to run an extend LTP isolating all of the 3-1/4” behind the LTP. Objective:Install extended LTP from 2-3/8” liner up to the 4-1/2” liner. Procedure Coiled Tubing Confirm SL has pulled both LTP’s prior to rigging up 1. Drift with PTSA LTP Drift assembly for 2.720” deployment sleeve to 10,252 & tag deployment sleeve. Record depths & PUH. While POOH stop & flag pipe corrected to extended LTP stinger being @ 10,152’ (~100’ above deployment sleeve) Coil –Extended Patch Deployment Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Patch job, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the patch. This is generally done during the drift/logging run. 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, it will either be killed by bullheading while POOH or circulating bottoms up. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH withrunning tools, ensureadequatelubricatorlengthto cover the running tools. 2. Bullhead 1.2x wellbore volume ~196 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the extended LTP. Timing of the well kill is at the discretion of the WSS.) a.Wellbore volume to top perf =163 bbls b. 4-1/2” tubing/liner – 10,128’ X .0152 bpf = 154 bbls Ext liner top packer F-38B PTD:225-029 c. 3-1/4” liner – 124’ X 0.0079 = 1 bbl d. 2-3/8” liner (to top perf @ 12,330’) – 2078’ X 0.0039 = 8 bbls 3. At surface, prepare for deployment of patch. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KKWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying patch to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU patch. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of patch. 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. e.At the beginning of each job, the crossover/safety joint must be physically MU to the patch one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of patch per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying patch to ensure the well remains killed and there is no excess flow. Patch assembly Patch Interval (tie-in depths)Patch Length Weight of aassembly (lbs) Run #1 10,075’ – 10,252’177’~750 lbs (4.8 ppf) 7. RIH with extended liner top packer assembly with RSG plug in the PTSA with hydraulic setting tool. 8. Stab into liner top and set LTP 9. Pooh with running tool. 10. Pressure Tubing to 1500 psi to confirm LTP is holding, communicate results to OE for plan forward. 11. IIf PT fails, depending on LLR it may be decided to attempt to pull & reset LTP or troubleshoot RSG with SL. Contingent pull & reset LTP with service coil if LLR suggests significant mis-set. If PT passes, RDMO CTU * End of sundried work. * Slickline 1. Pull RSG from PTSA Ops 1. POP well, gas lift may be needed for initial kick off, not expected to be needed for continuous production Attachments: x Wellbore Schematic x Proposed Schematic x Caliper Log x BOPE diagram x Standing Orders x Equipment Layout x Sundry Change Form Ext liner top packer F-38B PTD:225-029 CCurrent Schematic Ext liner top packer F-38B PTD:225-029 Proposed Wellbore Schematic Extended LTP Ext liner top packer F-38B PTD:225-029 Caliper Log Ext liner top packer F-38B PTD:225-029 BOP Schematic Ext liner top packer F-38B PTD:225-029 Ext liner top packer F-38B PTD:225-029 Ext liner top packer F-38B PTD:225-029 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' 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: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' 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: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP Please include current contact information if different from above. T40659 T40660 T40661 T40662 T40663 T40664 T40664 T40664 T40665 T40665 T40665 T40665 T40666 T40667 T40668 T40669 T40670 T40671 T40672 T40673 PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -08'00' 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: 07/01/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU F-38B PTD: 225-029 API: 50-029-22093-03-00 FINAL LWD FORMATION EVALUATION LOGS (05/28/2025 to 06/05/2025) 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. 225-029 T40626 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.01 10:14:03 -08'00' 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 Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Unit, Prudhoe Oil, PBU F-38B Hilcorp Alaska, LLC Permit to Drill Number: 225-029 Surface Location: 2605' FNL, 2402' FWL, Sec. 02, T11N, R13E, UM, AK Bottomhole Location: 56' FNL, 2047' FWL, Sec. 03, T11N, R13E, UM, AK Dear Mr. McLaughlin: 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 L. Chmielowski Commissioner DATED this 16th day of April 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.16 10:15:37 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 12323' TVD: 9090' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 11675' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64.83' 15. Distance to Nearest Well Open Surface: x-651959 y- 5974195 Zone- 4 36.9' to Same Pool: 825' 16. Deviated wells: Kickoff depth: 10295 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 104 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3-1/4" 2-3/8" 4.6# 13Cr80 Hyd 511 2063' 10260' 8826' 12323' 9090' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 32 - 112 32 - 2484 28 - 8695 2943 - 8748 8484 - 8748 8728 - 8741 Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Ryan Ciolkosz Sean McLaughlin Contact Email:ryan.ciolkosz@hilcorp.com Drilling Manager Contact Phone:907-244-4357 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng April 17, 2025 Scab Liner 7204 7" x 4-1/2" 231 Bbls Class G 2948 - 10152 10128 - 12553 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2456 32 - 112 32 - 248813-3/8" 2980 cu ft AS II, 465 cu ft AS II Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: 3-1/4" x 2-7/8" 28 - 10089 290 cu ft Class G 122 sx Class G Liner Liner 10061 316 2425 Intermediate Authorized Name: 10840 - 12500 Conductor 20"80 LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) 59 sx Class G 5120 18. Casing Program: Top - Setting Depth - BottomSpecifications Total Depth MD (ft): Total Depth TVD (ft): 107205344 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 908' FNL, 1442' FEL, Sec. 03, T11N, R13E, UM, AK 56' FNL, 2047' FWL, Sec. 03, T11N, R13E, UM, AK 87-035 3800 Centerpoint Dr, Suite 1400, Anchorage, AK Hilcorp North Slope, LLC 2605' FNL, 2402' FWL, Sec. 02, T11N, R13E, UM, AK ADL 028280 & 028281 PBU F-38B PRUDHOE BAY PRUDHOE OIL Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 8735 - 8740 2189 cu ft Class G 9836 - 101527" 9-5/8" Nooo Nooo Nooo shales: Nooo Noooo Nooo Nooo Noooooo Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.03.28 07:57:33 - 08'00' Sean McLaughlin (4311) 3225 2345 By Grace Christianson at 10:24 am, Mar 28, 2025 SFD 4/9/2025 225-029 50-029-22093-00-00 JJL 4/8/25 DSR-4/2/25 *AOGCC Witnessed BOP Test to 3500 psi, Annular 2500 psi minimum. *Post rig service coil perforating approved for max gun length of 500'. *Window milling approved on service coil *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Variance to 20 AAC 25.036 (c)(2)(A)(iv) approved with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.16 10:15:49 -08'00' 04/16/25 04/16/25 03 JSB RBDMS JSB 041725 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: March 27, 2025 Re:F-38B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well F-38A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for F-38B Producer: See F-38A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 3-1/4" whipstock. 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 or CDR3 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 land in Ivishak Zone 2. The lateral will continue in Zone 3 and 2 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 Prudhoe Pool perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: Reference F-38A Sundry submitted in concert with this request for full details. 1. Fullbore : MIT 2. Slickline : Dummy GLV, Drift and Caliper (if needed) 3. E-line : Set 3-1/4” NS Packer Wedge at 10,295’ MD - 330 deg RHOS 4. Coil : Mill Window (Mill out in Shublik at 330 deg ROHS) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in May 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,345 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.74” Window (if not done pre-rig). 3. Drill production lateral: 3.25" OH, ~2075' (12 deg DLS planned). Swap to KWF for liner. 4. Run 2-3/8” 13Cr solid liner to TD 5. PU ORCA cement stinger with 1" Hydril pipe to run inside liner. String into ORCA valve. 6. Pump primary cement job: 13 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. 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 : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM and perforate (~30’) ,p yppg(p completion will completely isolate and abandon the parent Prudhoe Pool perfs 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”/3-1/8” (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 (10295' MD -8,776' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,472 psi 4,472 psi 9.8 B -360 psi 0 psi 0.035 C 3,925 psi 3,925 psi 8.6 B+C Mud + ECD Combined 4,285 psi 3,925 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 187 psi 548 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The estimated reservoir pressure is expected to be 3,225 psi at 8,800 TVD. (7 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,345 psi (from estimated reservoir pressure). Mud Program: Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Fluids with solids that will not pass through 1/4” screen must go to GNI. Fluids with PH >11 must go to GNI. Hole Size: 3.25 hole for the entirety of the production hole section. Liner Program: 2-3/8", 4.6#, 13Cr Solid: 10,260' MD – 12,323' MD (2,063' liner) The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: BOP diagram is attached. MPD and pressure deployment is planned. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The annular preventer will be tested to 250 psi and 2,500 psi. 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole. 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. Request variance to 20 AC 25.036(c)(2)(A)(iv) to deploy tubulars < 2.375” OD without properly sized pipe rams. 2” safety joint will be utilized while running 1” / 1-1/4” CS hydril. Blind/Shear rams will be utilized in place of pipe rams sized for CTD jointed pipe operations as a worst- case shut-in scenario (in place 1” / 1-1/4” CS hydril pipe rams). The well will be full of KWF prior to running liner or jointed pipe operations. The BHA will be circulated out of hole prior to laying down BHA for jointed pipe operations. The well will be flow checked after laying in KWF, before laying down BHA and before making jointed pipe. Directional: Directional plan attached. Maximum planned hole angle is 104°. Inclination at kick off point is 49°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line – 11,675 ft Distance to nearest well within pool – 825 ft Logging: MWD directional, Gamma Ray and Resistivity will be run through the entire open hole section. Real time bore pressure to aid in MPD and ECD management. Perforating: 30' perforated post rig – See attached extended perforating procedure. 1.69" Perf Guns at 6 spf 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. The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Prudhoe Pool. Formations: Top of Prudhoe Pool: 10,104’ MD in the parent Anti-Collision Failures: No anti-collision failures with F-38B WP02 Hazards: DS/Pad is an H2S pad. The last H2S reading on F-38A: 8 ppm on 05/28/22. Max H2S recorded on DS/Pad: 160 ppm.. 0 fault crossings expected. Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) DS/Pad is an H2S pad. 160 ppm MPD and pressure deployment is planned Pre-Rig – Service Coil – Window Milling The approved sundry and permit to drill will be posted in the Operations Cabin of the unit during the entire window milling operation. Notes for window milling: Window milling with service CTU operations will fully comply with 20 AAC 25.286(d)(3), including the use of pressure control equipment, all BHAs fully lubricated and at no point will any BHA be open-hole deployed. Window Milling Procedure: 1. Kill well with 1% KCL if necessary. Well may already be killed from previous operations. 2. MU and RIH with window milling assembly – Window mill followed by string reamer. NOTE: Confirm milling BHA configuration prior to job execution due to variations in different service provider’s window milling BHAs. 3. RIH & TAG whipstock pinch point, calculate distance till string reamer is out of the window, paint coil flag and note in WSR. 4. Mill window per vendor procedure. – Make note of any WHP changes while milling window in the WSR. 5. Make multiple reciprocating passes through the kickoff point to dress liner exit and eliminate all burs. Perform gel sweeps as necessary to keep window clean. Maximum approved distance to reciprocate beyond the window is 15 ft to ensure confidence the window is prepared for the sidetrack.DO NOT RECIPROCATE DEEPER than 15 ft. 6. Confirm exited liner & string reamer dressed entire window with coil flag and note bottom of window and total milled depth in WSR. 7. FP well to 2,500’ TVD with 60/40 MeOH while POOH. 8. Once on surface inspect BHA, measure OD of mill and string reamer & document in WSR. 9. RDMO 10. Communicate to Operations to tag wing valve “Do Not POP”. . Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. 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 2.0" 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 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 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. PRUDHOE OIL 225-029 PBU F-38B PRUDHOE BAY WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT F-38BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2250290NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes Surface is in ADL0025280; top prod interval and TD in ADL0028281.2 Lease number appropriateYes3 Unique well name and numberYes Prudhoe Oil Pool4 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 seNA15 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)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes Approved for alternate abandonment plug placement 25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes Approved with documented well control drills performed29 BOPEs, do they meet regulationYes 5000 psi30 BOPE press rating appropriate; test to (put psig in comments)No31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes The last H2S reading on F-38A: 8 ppm on 05/28/22.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No PBU F-Pad is an H2S Pad. Measures required.35 Permit can be issued w/o hydrogen sulfide measuresYes Underpressured reservoir expected. MPD will be utilized.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate4/9/2025ApprJJLDate4/8/2025ApprSFDDate4/9/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 4/16/2025