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Home My WebLink About224-1087. 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 06-15A Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-108 50-029-20459-02-00 341J ADL 0028311 11277 Surface Intermediate Liner Scab Liner Liner 9068 2648 8595 6030 764 3255 10250 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8895 30 - 2678 28 - 8623 2932 - 8962 8198 - 8962 8022 - 11277 2520 30 - 2678 28 - 8414 2932 - 8752 7994 - 8752 7821 - 9068 None 2670 4760 5410 7500 10530 10250 4930 6870 7240 8430 10160 10070 - 10900 4-1/2" 12.6# 13Cr80 25 - 80818939 - 8934 Conductor 80 20" 30 - 110 30 - 110 1490 470 4-1/2" Baker S-3 Packer No SSSV Installed 7943, 7744 Date: Bo York Operations Manager Jerry Lau jerry.lau@hilcorp.com (907) 360-6233 PRUDHOE BAY 9/9/2025 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 9:03 am, Aug 26, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.26 07:45:57 - 08'00' Bo York (1248) 325-515 Perforate SFD 8/28/2025BJM 9/3/25 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment 10-404 DSR-8/26/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.04 08:18:47 -08'00'09/04/25 RBDMS JSB 090425 CTU Extended Add Perf 06-15A PTD:224-108 Well Name:06-15A API Number:50-029-20459-02 Current Status:Operable Producer Rig:CTU Estimated Start Date:9/09/25 Estimated Duration:2 days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker (907) 564 4915 (O) First Call Engineer:Jerry Lau (907) 360-6233(C) Current Bottom Hole Pressure:3,325psi @ 8,800’ TVD 7.1 PPGE | Average DS06 BHP Max. Expected BHP:3,400 psi @ 8,800’ TVD 7.5 PPGE | Highest BHP on DS06 Max. Anticipated Surface Pressure:2,520 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,500 psi (Taken on 7/28/25) Min ID 2.313” ID at LTP PTSA X-Nip Max Angle:109° Deg @ 9,903’ MD Tie In Log:HES MEMORY COIL FLAG 27-DEC-2024 Brief Well Summary: 06-15A is a CTD sidetrack from December 2024 with 2 perf intervals open since drilling the well. The well is now HGOR. We plan to move uphole and target Z2B perfs in the sump of the lateral. Objective:The intent of this program is to set a CIBP above existing perf intervals and then add 101’ of Z2B perforations using the CTU open hole deployment system. Procedure: Coil: 1. MU and RIH with logging tools and drift BHA: 2” dmy gun & nozzle. 2. RIH and set 2-7/8” CIBP @ 9850’ MD. PT to 1000 psi. 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 Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. 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 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. 3. 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. 4. Load will with 1% KCL/SW down TBG. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 139 bbls i. 4-1/2” Tubing – 8000’ X 0.0152 bpf = 122 bbls ii. 3-1/2” Liner – 930’ X 0.0087 bpf = 8 bbls iii. 3-1/4” Liner – 588’ X 0.0079 bpf = 5 bbls iv. 2-7/8” Liner – 552’ X 0.0058 bpf = 4 bbls 5. At surface, prepare for deployment of TCP guns. 6. 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. CTU Extended Add Perf 06-15A PTD:224-108 Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 7.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders 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. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 8.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *HES 2" Millennium guns were used to estimate for this job and calculate gun weights. Perf Interval Type Gun Length Weight of Gun (lbs) 5.58 lbs/ft 9676 -9777 Guns 101’564 9. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 10. 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. 11. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 12. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 14. RDMO CTU. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layout Diagram x Sundry Change Form Re-establish pressure containment with QTS once all guns are made up, before running in hole on coiled tubing. -bjm CTU Extended Add Perf 06-15A PTD:224-108 Current Wellbore Schematic CTU Extended Add Perf 06-15A PTD:224-108 Proposed Wellbore Schematic CTU Extended Add Perf 06-15A PTD:224-108 Tie-in Log HES MEMORY COIL FLAG 27-DEC-2024 CTU Extended Add Perf 06-15A PTD:224-108 BOP Schematic CTU Extended Add Perf 06-15A PTD:224-108 CTU Extended Add Perf 06-15A PTD:224-108 CTU Extended Add Perf 06-15A PTD:224-108 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) Operations Manager Date 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: 3/2/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250302 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# CLU 11 50133205590000 206058 2/19/2025 AK E-LINE CBL,CIBP CLU 11 50133205590000 206058 2/13/2025 AK E-LINE CIBP END 1-65A 50029226270100 203212 1/27/2025 HALLIBURTON COILFLAG END 2-56A 50029228630100 198058 2/6/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 2/2/2025 HALLIBURTON PPROF MPU F-29 50029226880000 196117 1/31/2025 HALLIBURTON MFC24 MPU L-02A 50029219980100 209147 2/17/2025 READ CaliperSurvey MPU L-36 50029227940000 197148 1/18/2025 HALLIBURTON MFC24 MPU R-144 50029238090000 224148 2/11/2025 HALLIBURTON WFL-TMD3D NCIU A-21 50883201990000 224086 2/18/2025 AK E-LINE Perf ODSN-25 50703206560000 212030 2/16/2025 READ MemoryLeakPoint PBU 06-05A 50029202980100 224115 1/15/2025 BAKER MRPM PBU 06-15A 50029204590200 224108 12/27/2024 HALLIBURTON RBT PBU 06-16B 50029204600200 223072 1/25/2025 BAKER MRPM PBU B-12B 50029203320200 224133 1/19/2025 BAKER MRPM PBU S-126B 50029233630200 224084 2/7/2025 HALLIBURTON RBT PBU V-105 50029230970000 202131 2/9/2025 HALLIBURTON IPROF PBU W-01A 50029218660100 203176 1/19/2025 AK E-LINE CBL PBU W-01B 50029218660200 224149 1/28/2025 HALLIBURTON RBT PCU 02A 50283200220100 224110 1/24/2025 AK E-LINE CIBP Please include current contact information if different from above. T40161 T40161 T40162 T40163 T40164 T40165 T40166 T40167 T40168 T40169 T40170 T40171 T40172 T40173 T40174 T40175 T40176 T40177 T40178 T40179 PBU 06-15A 50029204590200 224108 12/27/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.03 10:15:14 -09'00' 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 06-15A Reset LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-108 50-029-20459-02-00 11277 Conductor Surface Intermediate Production Liner 9068 80 2648 8595 6030 3255 10250 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 8895 30 - 110 30 - 2678 28 - 8623 2932 - 8962 8022 - 11277 30 - 110 30 - 2678 28 - 8414 7240 - 8751 7821 - 9068 none 470 2670 4760 5410 8160 10250 1490 4930 6870 7240 9150 10870 - 10900 4-1/2" 12.6# 13Cr80 25 - 8081 8926 - 8934 Structural 4-1/2" Baker S-3 Perm, 7943 , 7744 No SSSV 7943 7744 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 25 - 7879 188 789 19826 35323 170 343 1654 1195 417 554 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 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.02.21 07:23:23 - 09'00' Bo York (1248) By Gavin Gluyas at 8:54 am, Feb 21, 2025 JJL 2/27/25 DSR-2/24/25 RBDMS JSB 030325 ACTIVITYDATE SUMMARY 1/24/2025 ***WELL FLOWING UPON ARRIVAL*** (profile modification) R/D SLICKLINE EQUIPMENT & TRAVEL TO SHOP(weather) ***CONT'D ON 1/25/25 WSR*** 1/25/2025 ***CONT WSR FROM 1/24/25*** (profile modification) LRS F/P FLOWLINE W/ 60bbls CRUDE AND LOADED TUBING W/ 170 BBLS OF CRUDE. RAN/PULLED 4-1/2" X-SELECTIVE TEST TOOL TO X-NIPPLE @ 7,912' MD.(confirmed ltp covering lower x-nipple) LRS PERFORMED PASSING MIT-T TO 2,585psi. RAN/PULLED 4-1/2" MONOPAC LINER TOP TEST TOOL TO LTP @ 7,971' SLM. LRS PERFORMED FAILING MIT-T TO 2500psi. PULLED 64.5" OF MONO-PAC PACKER FROM 7,971' SLM (appears to of swiveled off, missing 2 elements) RAN 4 1/2" BRUSH, 3.73" 3 PRONG WIRE GRAB TO TOP OF LTP @ 7,971' SLM (recovered 1 element worth of rubber) PERFORMED WELL CONTROL / H2S DRILL WITH CREW RAN 3.80" CENT, 3.70" LIB TO 7,973' SLM ***CONT WSR ON 1/26/25*** 1/25/2025 T/I/O=2500/756/78 Assist SL L&T FP FL with 5 bbls 60/40 and 66 bbls crude. Load tbg with 170 bbls crude. MIT-T # 1: ( PASSED ) Max:2750 psi / Target:2500 psi. Pumped 1.5 bbls crude down TBG to reach max pressure of 2752psi. After first 15 min TBG lost 112 psi. After second 15 min TBG lost 55 psi. Bled back 1.9 bbls. Pumped 3.6 bbls of crude down TBG to attempt another MIT-T. Lost 996 psi in first 15 min. MIT canceled. DSO notified upon departure. Sim Ops complete. Well left in slicklines control. FWHP = 464/737/73 1/26/2025 ***CONT WSR FROM 1/25/24*** (profile modification) PERFORM WELL CONTROL/FIRE DRILL W/ CREW RAN 4-1/2" BRUSH & 3.73" 3-PRONG WIRE GRAB TO FISH @ 7,973' SLM.(no recovery) RAN 4-1/2" BRUSH, 2-7/8" BRUSH & 2.24" 3-PRONG WIRE GRAB TO FISH @ 7,973' SLM.(no recovery, marks on grab) RAN OLD STYLE RELEASEABLE SPEAR(2.56"-2.88" grapples), TOOLS S/D @ 7974' SLM.(unable to spear fish) RAN 3.62" CENT/3.69" CENT BARBELL & 3.60" LIB TO 7,973' SLM.(1/2 moon impression of fish) PULLED REMAINGING 19' LTP ASSY FISH FROM 7,974' SLM.(recovered 1/3 of middle element/springs & lower element) RAN 3-1/2" BRUSH & 2.63" 3-PRONG WIRE GRAB INTO LINER @ 8,550' SLM.(no issues) RAN HES 40 ARM CALIPER FROM 8,500' TO 7,500' SLM (good data) BRUSH DEPLOYMENT SLEEVE W/ 3 1/2" BRUSH @ 8,022' MD ***CONT WSR ON 1/27/25*** Daily Report of Well Operations PBU 06-15A Daily Report of Well Operations PBU 06-15A 1/27/2025 ***CONT WSR FROM 1/26/25*** (profile modification) RAN 20' LTP DRIFT W/ DUMMY STINGER TO DEPLOYMENT SLEEVE @ 7,994' SLM (ring on no-go) LRS LOADED TUBING W/ 170 BBLS OF CRUDE. SET NS 450-368 MONO-PAK LTP, 5' x 2-7/8" SPACER W/ PTSA ASSY IN DEPLOY SLEEVE @ 8,014' MD (top of LTP at 8,000' MD, X-Nip at 8,017' MD) LRS PERFORMED PASSING MIT-T TO 2,607psi. PULLED 2-7/8" RSG FROM LTP ASSY @ 7,993' SLM. ***WELL FLOWING ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 1/27/2025 T/I/O= 2012/719/67 Assist SL L&T ( PROFILE MODIFICATION ) Pumped 170 bbls of crude down TBG to load. Pumped 8.5 bbls of crude down TBG while slickline set LTP. MIT-T (PASSED) Max:2750psi / Target:2500psi. Pumped 2.5 bbls of 60*F crude down TBG to reach max pressure of 2762 psi. After first 15 min TBG lost 104 psi. After second 15 min TBG lost 51 psi. Bled back 2.3 bbls crude. Sim Ops complete. DSO notified upon departure. FWHP = 550/714/67 2/11/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Objective: CIBP, Adperf MIRU and make up 1-11/16" NS MHA with HES GR/CCL in 2.20" carrier with 2.25" DJN. Freeze protect the flowline. L&K the tubing with 170 BBL's of 1% KCL & safelube. Drift cleanly to ~ 10400'. Log at 50 FPM to ~ 7800'. Paint a tie-in flag at ~ 10200'. POOH and confirm good data (-3.75' correction). MU NS 2-7/8" CIBP, load well w/ 115bbls Slick KCL w/ SL and FP cap. RIH, correlate depth at flag, pump 3/8" ball. ***Job in Progress*** 2/12/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Objective: CIBP, Adperf Continue pumping 3/8" ball to set CIBP. The ball landed after 2nd reel volume (67 bbls). Set 2-7/8" CIBP at 10250' MD. POOH pumping 60/40 pipe displacement. Stop at 5000' to pressure test the plug (lost 552 psi in 5 mins, 776 psi in 10 mins). POOH and break down the plug setting tool, recover 3/8" ball. MU 2" x 30' HES Maxforce, 6 SPF, 60 degree phase perf gun. RIH, reference the flag, tie-in off the plug, and perforate 10070' - 10100'. Good indication of shot. POOH and freeze protect the tubing to 2500' TVD. Lay down the perf gun (all shots fired in scallop, 1/2" ball recovered). RDMO. ***Job Complete*** C 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 06-15A 50029204590200 224108 12/26/2024 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.07 13:25:23 -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: 01/17/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 06-15A PTD: 224-108 API: 50-029-20459-02-00 FINAL LWD FORMATION EVALUATION LOGS (12/09/2024 to 12/21/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: Please include current contact information if different from above. 224-108 T39983 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 06-15A Hilcorp Alaska, LLC Permit to Drill Number: 224-108 Surface Location: 355' FSL, 1753' FEL, Sec 02, T10N, R14E, UM, AK Bottomhole Location: 541' FNL, 1433' FEL, Sec 11, 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, GregRU\ C. Wilson Commissioner DATED this 15th day of October 2024. Sincerely, 3-1/2"x3-1/4" Drilling Manager 07/25/24 Monty M Myers By Grace Christianson at 12:15 pm, Jul 25, 2024 A.Dewhurst 09OCT24 MGR28AUG24 DSR-7/31/24WCB 8-26-2024 A *BOPE test to 3500 psi. Annular to 2500 psi. *Variance to 20 AAC 25.112(i). Alternate plug placement approved w/fully cemented liner. All drilling within the PB oil pool. 50-029-20459-02-00224-108 JLC 10/14/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.15 03:28:42 -08'00' 10/15/24 10/15/24 RBDMS JSB 101524 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: July 25, 2024 Re:06-15A Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 06-15 with the Nabors CDR2/CDR3 Coiled Tubing Drilling Unit. Proposed plan for 06-15A Producer: See 06-15 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. 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 dual string 3.80" window + 10' of formation. 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 06-15 Sundry submitted in concert with this request for full details. 1. Coil : Mill XN nipple at 3.80" 2. E-line : Set 4-1/2" Monobore Whipstock at 8960' MD at 0 deg ROHS 3. Valve Shop : Pre-CTD Tree Work 4. 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 3. Drill build section: 4.25" OH, ~369' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1915' (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: 35 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. 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 PTD 224-108 CDR2/CDR3 Sundry 324-429 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 (8960' MD -8,653' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,410 psi 4,410 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ-;ƉƐŝͬŌͿ 538 psi 0 psi 0.09 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,870 psi 3,870 psi 8.6 B+C Mud + ECD Combined 4,407 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: 8,025' MD – 8,950' MD (925' liner) x 3-1/4", 6.6#, 13Cr/Solid: 8,950' MD – 9,500' MD (550' liner) x 2-7/8", 6.5#, 13Cr/Solid: 9,500' MD – 11,244' MD (1,744' 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 105°. Inclination at kick off point is 4°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – ~20,500' x Distance to nearest well within pool – 650 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 is at 8860’ MD in the parent Anti-Collision Failures: x No Anti-collision failures with 06-15A WP02 Hazards: x DS 06 is not an H2S pad. The last H2S reading on 06-15: 10 ppm on 2/14/24. x Max H2S recorded on DS/Pad: 56 ppm. x 1 fault crossings expected. x Low 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 nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee $) $) $) $) $) $) $) $)$)$)$)$)$)$)$)$) !! !!!! !!! !!! ! !!!! ! !!!! ! !! ! !!!! !!! !!! ! !! ! !! !! !! !!! !!!! !!!!! !!!! !!! !!!!!! ! D $)06-15A_BHL 06-15A_TPH 06-15A_SHL Oil Rim PAGas Cap PAADL028311 DS6 PAD 3 U010N014E Sec. 2 Sec. 11 Sec. 1 Sec. 12 PRUDHOE BAY UNIT 06-19 06-15 06-04 OWDW-C 06-24B 06-21A 06-04A OWDW-SW OWDW-NW PR121014 PR111014 PR021014 PR011014 Map Date: 2/16/2024 Prudhoe Bay Unit 06-15A Well wp02 E0 290 580 Feet Legend $)06-15A_BHL !06-15A_SHL D 06-15A_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_06-15A wp02.mxd -1200-800-400040080012001600South(-)/North(+) (800 usft/in)-1200 -800 -400 0 400 800 1200 1600 2000 West(-)/East(+) (800 usft/in)400800120016002000240028003200360040004400480052005600600064006800720076008000840 088009200932806-15 8 8 0 0 900506-15A wp02Top of Window - 8,960'MDEnd 35 dls - 9,329'MDTD - 11,244'MD87008800890090009100True Vertical Depth (200 usft/in)-1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 Vertical Section at 185.00° (400 usft/in)06-1506-15A wp02Top of Window - 8,960'MDEnd 35 dls - 9,329'MDTD - 11,244'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 8960.00 4.85 60.73 8749.50 1069.96 328.49 0.00 0.00 -1094.512 8980.00 6.65 60.73 8769.39 1070.94 330.24 9.00 0.00 -1095.643 9050.00 30.43 84.90 8835.35 1074.55 351.76 35.00 30.00 -1101.124 9217.01 80.00 126.42 8930.23 1025.12 470.55 35.00 50.00 -1062.235 9329.01 80.00 166.23 8949.68 935.17 530.49 35.00 90.00 -977.846 9432.34 76.00 178.23 8971.23 835.26 544.21 12.00 110.00 -879.517 9595.34 76.00 198.39 9010.66 679.56 521.47 12.00 90.00 -722.438 9729.18 90.00 190.44 9026.96 551.29 488.64 12.00 -30.00 -591.789 9857.96 104.50 185.04 9010.74 425.11 471.40 12.00 -20.00 -464.5810 10038.00 104.50 207.35 8965.66 258.77 423.10 12.00 90.00 -294.6611 10288.00 104.50 176.37 8903.07 24.78 373.97 12.00 -90.00 -57.2712 10443.00 104.50 195.57 8864.26 -123.78 358.43 12.00 90.00 92.0713 10571.23 90.00 190.37 8848.11 -247.38 330.05 12.00 -160.00 217.6714 10704.46 75.00 184.77 8865.46 -377.88 312.60 12.00 -160.00 349.2015 10825.00 75.00 169.80 8896.66 -493.85 318.10 12.00 -90.00 464.2516 11010.00 75.00 192.78 8944.54 -671.31 314.10 12.00 90.00 641.3817 11244.00 75.00 163.71 9005.10 -894.81 320.95 12.00 -90.00 863.44Project: Prudhoe BaySite: 06Well: 06-15Wellbore: 06-15APlan: 06-15A wp02WELLBORE DETAILSParent Wellbore:06-15Top of Window: 8960.0006-15A wp02Depth From Depth To Survey/Plan Tool100.00 8960.00 1 : Camera based gyro multisho (06-15)3_CB-Film-GMS28960.00 11244.00 06-15A wp02 (06-15A) 3_MWDWELL DETAILSNorthing: 5940934.78Easting: 685234.85Lattitude: 70° 14' 37.0936 NLongitude: 148° 30' 13.6218 W06-15A wp02SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well 06-15, True NorthVertical (TVD) Reference: Kelly Bushing / Rotary Table @ 68.00usft Measured Depth Reference: Kelly Bushing / Rotary Table @ 68.00usftSection (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !!" # $ % " & ! 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" ' ()* ' + +, -" .# !!" #$% & '()*+,-./.01 */ 23 *,4- 5 &4 .* '#$% & '()*+,-./.01 0 # ' 6 & . * # 8': < 89: =&# 89: 657+ 8': . 0 #/ 8': . 5/ 8': 607 8': - ) * # 8': ()* ' *! >@A? ) = * * = =88*8) *9 3*3=*) 3A9*) 8= 8A*= =A*8)* *) = * * = 88*8) *9 3*3=*) 3A9*) 8= 8A*= A*8)* *) = 9* * = 88*8) *9 3*3=*) 3A9*) 8= 8A*= A*8)* *) = )* * = 988*8) *9 3*3=*) 3A9*) 8= 8A*= 9A*8)* *) = 8* * = )88*8) *9 3*3=*) 3A9*) 8= 8A*= )A*8)* *) * * = 888*8) * 3*AA*) 3A*)8 8= 8A*)8= 8A*8)* *3= * * 88*) * A*A8*99 ) 3A)*9 8= 8=*=A A*)=* *)= 3* )* 88*= *)9 *A*) 3=*8A 8= 8*) A*=A*) 9*A9 A* )* 38*A A8*33 *=3*39 ) 3=*A= 8= 89=*39 33)*A8* =*9 =* * A8*)9 )*== *39*3) 3=8*=A 8= A* A3A*)9 3*A= 8* * 3* =)*)A 88* 8*99*)) 33* 8= A=*98 =)*)A A* *8 * 3=* 98*A A*9 3=*)*8A ) 3* 8= 93*9 *A =* A)*AA 9* 39* 8*) 98*) 38*89)*A) 3*A8 8= *3 *)A* )*93 )* 3)* 9)*) 33*) A*9))*3 ) 3*9 8= *= 8*)* 33)*3 8* 39* )=*) 39*8A =A*3)*3 ) 39*9 8= 39*) 99)*)*A 39=*) * 39* 8A*3) A9* *3=)*A ) 399*39 8= 3A* )9*3)*3= A3*9) * 39* 3=*) A3*98 9**3 ) 3)A*9 8= 38)*) 8*)*) A*=A 3* 39* A*3) =9*= *9*A ) 38*9 8= A=A*9 =*3)*3A =*= A* 39* 33*A8 =3*3 9A*8*9 ) 389*3 8= A))* A=*A8 * =*)= =* 3* 38*)) =8*3 )*8*) A=* 8= =A3*A 33A*))* *39 * 3* A)* A8*= 8*3*)) A*9 8= =9*3 AA** =*39 * 3*3 =9* )3*8 88*33*=9 ) A8*9 8= 8*8 =A**9 )8*A) 9* 3* *8= 3*)3 8*AA*8) A3)*9A 8= A* =83*8=*) A3*8 )* 3* *3 9* 8*)=*) AA)*3 8= *= )A*3*A 9*= 8* 3=* 9=3*8 99*9 A*33=*=) A=9*A 8= =*=A 9=*8 * 9*A 9 * 33* )A=*3= 9=*38 =*)99*A) A9*A 8= )A*3 9*3=3*38 9=*9A 9 * 3* 839* 998*= *))*3)) A9*= 8= 99*= )8*3*A 9)8*) 9 3* )* 9 33*= )*A3 3*=)*A9 ) A9*83 8= 9=)*9) 8=*=3* )3*A 9 A* * 9 9*99 )A9*93 93*933*=A ) A)*A9 8= 99*=A9 =8*99 3*A3 )=8*= 9 =* =* 9 3=*3 )*9A )3*))3*)) A8*=8 8= )*89 =*3*9 )9=*A8 9 * A*3 9 A*AA ))A*9 83*383*A ) =*A 8= )33*8=9 3=A*AA *) )89* 9 * A* 9 =)*93 8*A 88*33*=A ) =*9 8= )==*99 A=*93 * 88*3) 9 9* 3* 9 *3 83*A= 3*3*) =)*3 8= )*)9 =A)*3*3A 8=*99 9 )* 3* 9 A*)8 8=*A 3A*)3*)) =3*A 8= ))*339 A*)8 *3 8*9 9 8* * 9 9*9 8*8 33*A=3*)) =A3*A) 8= 8*9)9 AA*9* 8)*3 ) * * 9 988*9) 8)A*)9 33)*83=*8) =A8* 8= 83A*839 9A*9)*8= *) ) * * 9 )89*8 *) 3A9*938*) ==9*9= 8= 8=*39 )38*8*9) 9*9 ) 3* * 9 88*3) *) 3=9*)=*3 ) =9* 8= 8*A9 83)*3)3*3 AA*) ) A* * ) 8=*99 3)*=8 38*=*3A ) =8* 8= 88*3)) 3*99 * =9*3 ) =* 8* ) 8A*= A8*3) 393*33*39 ) =)*AA 8= 8)*A9) 3*=*= 8* ) * )*9 ) 383*3 =9*)A 3)=*83*=3 ) =8A*83 8= 8)8*3A) 33=*3*3) )*9 ) * 9*3 ) A8*3A =*) 389*38*9) *A 8= 88*))) A3A*3A *9 9*) ) 9* * ) =8* )*8) A9*9)*) *=8 8=3 *8=) =33**3 )*9) ) )* * ) 8* A*3= A*A3*) 3=*89 8=3 *=) 33**= )*99 ) 8* * ) )8*93 9*=A A3=**3 ) A3* 8=3 8*9)) 3*93 *A 8* % " & ! " ' ()* ' + +, -" .# !!" #$% & '()*+,-./.01 */ 23 *,4- 5 &4 .* '#$% & '()*+,-./.01 0 # ' 6 & . * # 8': < 89: =&# 89: 657+ 8': . 0 #/ 8': . 5/ 8': 607 8': - ) * # 8': ()* ' *! ??@ ) ) 8* =*) ) 9=8* 8*8 A3)*=8*9A ) A*8A 8=3 3*=3) )**3 8=* ( '+ ?AB.* ) 8)* * ) 98*A8 9*8= AA*3=*9A ) A)* 8=3 A*==) 9*A8 8* 8*= ) 88* 8*)= ) 998*38 9* AA*9*3 ) A8*8 8=3 =*A) 9*38 A* 8*A3 8 * A*) ) 9)8*8 93* AAA*=99*3A ) =*) 8=3 =*A) 93*8 A* 89*A 8 * *8 ) 98)*9 93*) AA*8)98*A=) ==*A 8=3 *3A) 9A*9A* 89*9) 8 3* 3*A ) ))*3= 9A* AA8*))*=) =9*== 8=3 *)3) 9=*3=A* 8)*9 8 A* 3A*=8 ) )9*A 9A* A=3*9)3*)8 ) *8 8=3 *=3) 9=8*A A* 88*A8 8 =* 3*8 ) )3*9 9=*8 A=*8))=*3 ) *A 8=3 9*) 9)*9 A* *3= 8 * A*=A ) )A*A 9=* A*9)=*8) *) 8=3 9*)) 99*AA* *3 8 * A3*9) ) )=A*) 9=*9) A*88)8*)) *A 8=3 9*8=) 99*)A* *) 8 9* A*A ) )3* 9=*) A3*)8=*3) 9*)8 8=3 9*))) 9)=*A* 3*8 8 )* A9*8 ) )*) 9A*8= A)*8)*3 ) 9*)= 8=3 9*A)) 983*)A* *89 8 8* =*93 ) )9*8 93*) A9=*9*=) )A* 8=3 *=) 988*8A* *== 8 * =A*) ) )9*A3 9*A A)*38=*=3 ) )8*) 8=3 *3) )9*A3 A* * 8 * =* ) ))3*A8 8*=A A))*9*A ) 8*A 8=3 A*A) )=*A8 A* 88*8 8 3* =8*=8 ) ))8*) 9*8 A8*8*) A*A 8=3 *8) )3*)A* 89*=9 8 A* 3*3 ) )8*A9 =*AA =3*=3*)) *89 8=3 )*3) )39*A9 A* 8*A 8 =* *8 ) 8*3= *) =8*)9A*83 ) )* 8=3 *) )AA*3=A* 83*)9 8 * )*9 ) 8*9 9* =9*=8*)) 3*3 8=3 3*A) )A)*9 A* 8* 8 * *)A ) 8*A A*9= =3*3=9*) A=*= 8= 88)*8) )=A*A A* )*98 8 9* =*8) ) 8* =8*=9 =AA*8*A) =3* 8= 88=*) )=)*A* )A*3A 8 )* )* ) 83*) ==*) ==*A3*8) *= 8= 88*) )3*)A* 98*A3 8 8* 9*A= ) 83A*= A8*8A ==8*33*) )*= 8= 8)*A) )*=A* 9* 8 3* 9=*= ) 83*=) A=*8 =9*3A*88 ) *3 8= 8)*A3) ))*=)A* 9*) 8 3* 99*9 ) 83)*)9 38* ==*8)3*=A ) 9=*A9 8= 89=*88) )*)9 A* *99 8 39* )* ) 8A*3A 3*3 =9*3*=3 ) )*= 8= 89*8) )3*3A A* 3*3A 8 33* )* ) 8A*9 3A*A =93*839*=)) )3*=A 8= 88*A)) )3*9A* *) 8 3A* )* ) 8A3*=) 9*3 =)*AA*=) 8*3 8= 8A*A=) )=*=)A* *A 8 3=* )* ) 8A=*33 *=A =)9*9A=*8 ) 89*8 8= 8*)A) )*33 A* =8* 8 3* )* ) 8A*8 A*A =8=*=A)*=) 9=* 8= 8=8*)9) )9*8A* =3*8 8 3* )* ) 8A9*8 88*99 *))=*9) 9*) 8= 8=3*) )8*8 A* A*= 8 39* )* ) 8A8*=A 8)9*) *9==*3) 99*A 8= 8A=*9A) )9*=A A* 3)*3 8 3)* )* ) 8=* 898* 3*=)*)) 933*8 8= 83*) )9A*A* 3* 8 38* )* ) 8=3*8 89*3 *8=3*A) 939*9= 8= 8)*) )9=*8A* 3*A) 8 A* )* ) 8==*= 83* 3*3A*8) 9A3*3 8= 88*=) )9*=A* A*8A 8 A* )* ) 8=*A9 8A* 3=*898*=9 ) 9A*3 8= 8*A)) )9)*A9 A* 88*) 8 A3* )* ) 8=)* 8=A*9A 3)*=A*3 ) 9A8* 8= )8*=) ))*A* 8)*9 8 A38* )* ) 8=8*9 8A*9 A*=8*33 ) 9=3*9 8= ))3*) ))*9 A* 899*) 5>A>AB.* 8 A* 98* ) 8A*=9 8*A A=*8))*A ) 9=9* 8= )3*3) ))*=9 3* 8)*9 8 A9* 9)* ) 8)*A8 )8*)) A8*39*3 ) 9*89 8= )A)*8) )8*A8 3* 8A=*=8 8 =* 99*3 ) 8A*9A )* =3*89=*=A ) 9* 8= )=*==) )8*9A 3* 8* 8 =3* 9*39 ) 88*=9 )=3*A) =A*8=99*A) 99*)8 8= 98*33) 8*=9 3* ))*) 8 =A3*A= 9* ) 89*3A )A*3 ==*39)*3A ) 9)*A= 8= 9)A*) 8A*3A 3* )98* % " & ! " ' ()* ' + +, -" .# !!" #$% & '()*+,-./.01 */ 23 *,4- 5 &4 .* '#$% & '()*+,-./.01 0 # ' 6 & . * # 8': < 89: =&# 89: 657+ 8': . 0 #/ 8': . 5/ 8': 607 8': - ) * # 8': ()* ' *! ?AC@ ) 8 =* 9* ) 89* ))*A ==*=)*=) 9)*8 8= 9*88) 89*3* )3*= 8 =9* 9* ) 8)* 98A*)8 =A*))A*) 9)*9A 8= 9=*9A) 8A*3* )A)*3= 8 * 9* ) 8)9* 98*93 =*=)*) 99*8 8= 99*A) 88*3* )A*88 8 3* 9* ) 88A* 9=*9 A)*)8*8 ) 9=*A= 8= 8A*=) 83*3* 9)8*99 8 * 9* ) 888*8 93*8A AA*3883*9)) 9*3 8= 8*) 8A*8 3* 9* 8 9* 9* 8 *9= 8)*=A 39*388*)9 ) 9==*9) 8= =*8) 8A9*9=3* 9=*93 8 8*A= 9* 8 * 98* 3*=98)*A8 ) 9A8*=A 8= 3*8) 8=3*3* 933*=A 8 * 9*=) 8 *99 9*39 3*8)*) 9A)*3 8= 33*)) 8=A*99 3* 9)*3 8 3* 98*8 8 9* *8 3*998*)) 9A*=3 8= 88*8) 8=8*3* 8=* 8 * )*9 8 3*3A 3)*3A *8*)) 93*3) 8= 9*33) 8A*3A 3* 8*8 8 9* )=*A3 8 3=*39 =*3 =88*88A*) 98*9A 8= *=) 8*39 3* =*=9 8 9* )*8= 8 3*) 98*8 =8=*A83*=) 9=*99 8= 3*3) 8)*)3* 3*9) 8 93* )8* 8 3*8= *= =)8*=8*)) 9*=A 8= 3*) 8)*8=3* 8*8 8 938*) 8* 8 3*8 *38 =))*=8*==) 98*99 8= =89*))) 8)*83* 8*9) 8 9* 83*A 8 3*A A*) =)*A)8*)) 9* 8= =99*A) 8)*A 3* 9* 8 99* 8*9 8 3=*8 *9 =)*8))*) 9A*AA 8= =3*8) 8*83* =*9 8 )* 89*8) 8 33*A =)*) =99*3)9*) 9*= 8= =39*83) 8=*A 3* 3*A) 8 )3* *) 8 9*8 =9* =9=*3)*=) 8)*9 8= =A*A)) 8=8*83* =8*9A 8 )* A* 8 3*9 =A3*) =93*)*A8 ) 8*= 8= A98*3) 8==*9 3* =93*A 8 )9*8 =* 8 *9= =3* =9*=)*=) 8*A 8= A9*A3) 8=3*9=3* ==*) 8 )9* =* 8 *=9 =)*9 =8*)9*) 8=*3) 8= A=*))) 8A)*=9 3* ==)*) 8 8* =* 8 *3 A)=*9) =*888*3) 8*3 8= AA*))) 8A3*33* =3A*8A 8 83* =* ) 88A*8 A*8 =*=8A*A=) )*) 8= A9*9) 83*83* A88*8 8 8* =* ) 8)9*8 AA9*9 ==*)38*==) )*3 8= 3)A*=) 88*8 3* A9* 8 89* =* ) 8)*=A A=*8 ==9*A=88*=) 9=*A 8= 3*A) 8A*=A 3* A3*=) * =* ) 89*) 383* =A)*=33*=) * 8= 3A9*) 89*)3* A38*3A 3* =* ) 8)*83 39*A =3)*933*9A ) *9) 8= 3*3) 8*83 3* A*A9 A)* =* ) 8* 3)*99 =3A*39*A) *== 8= 3A*)) )89*3* 38=* * =* ) 83* 3=)*A8 =9*83*)) =*=8 8= 8A*A) )8=*3* 3)A*) 9* =* ) 8*= 33*AA =9*8A33*9) A9*9 8= 9*) )))*=3* 3*3 * =* ) 8*= 3A*99 A88*)88*) 3)*)) 8= =)*38) ))3*=3* 3A9*98 3* =* ) 8=A*)) )*99 A8*8*9 ) 3*83 8= 3*) )9*))3* 3=*33 * =* ) 8A9*3 9*A8 A)*A)8A*=9 ) *33 8= *8) )8*3 3* 8*A) 9* =* ) 8A*A AA*93 A)*A)8*A9 ) *) 8= 99*98) )A*A3* *A 3* =* ) 83* 8*) A9*9)9*39 ) )*8 8= A*)) )9*3* =3*3 33* =* ) 8)*)= )*93 A9=*3)=*)) *)9 8= 38*9) )*)=3* )* 3* =* ) 83*) * A9A*)*)) *A 8= *=9) )==*)3* 8A*)A 39* =* ) 8*A3 A9*A A9A*A99*8)) 9*= 8= 8)*38) )A)*A3 3* 8*9= 3))* =* ) 8A*9 3=*9) A9A*899*A9 ) )*9 8= 8)*9=) )A*9 3* 9*39 A* =* ) 8* A*9 A9=*99*)) )*8= 8= 89*) )A3*3* =*99 A3* =* ) )8A*) *A A9=*))*8) 8*98 8= 8A3*89) )3*)3* 3*) A* =* ) ))9*= A*3 A9A*9)=*) 8*AA 8= 8)*99) )8*=3* 3* A9* =* ) ))*3) 8*38 A9*A8)9*) 9* 8= ))=*=) )A*3)3* 3*9 =* =* ) )9*3 )A*3 A9*9A8*3) =*=8 8= )*A) )9*3 3* *) =3* =* ) ))*9 *8 A3*9)8A*A=) *3 8= )A*)A) )*93* 9=*)) % " & ! " ' ()* ' + +, -" .# !!" #$% & '()*+,-./.01 */ 23 *,4- 5 &4 .* '#$% & '()*+,-./.01 0 # ' 6 & . * # 8': < 89: =&# 89: 657+ 8': . 0 #/ 8': . 5/ 8': 607 8': - ) * # 8': ()* ' *! ?CA@ ) ==A* =* ) )=*3 3A*9) A)*=A8*9 ) 8*8 8= )8*)) 98*33* 83*9 =* A*9 ) )3* A*A3 A*38*3)) 8=*= 8= )A*39) 98=*3* 8)*9= =9* *)8 ) )9*3A A*8= A*=8=*3=) ))*8 8= 9)8*) 9)8*3A 3* 33*) * 8)* ) )A* 99*)8 A==*8A*33 ) )A* 8= 9*=3) 9)*3* =9*) 3* 8*3A ) )*33 33* AA8*883*3) 9)*9) 8= 9=*)) 9)3*33 3* 9*98 * 83*= ) )=)* 33*A AA=*38*3) 9=*A3 8= 9*=) 9)*3* 8* 9*3A 8* ) )=)* 3=9*A) AA*8*A9 ) 9*) 8= 8*) 9)*3* 39*9 9* )8*9 ) )=)*3 3*8 A38*A)8*3) 9*3) 8= 8*))) 9)*3 3* 33*=A * )*9 ) )=)*83 39*93 A3*9)8*8 ) *) 8= 9*) 9)*83 3* 3=*AA 3* )A*8= ) )*8 A*A A3*=))*) A*A 8= =3*==) 9)3*83* 39*8 * )*3 ) )=*3 A3=*8 A)*3)9*) *)= 8= 9*)) 9)*33* 38*8 9* 9)*A ) ))* A=8*A A*A)*) )*3 8= 8A*A) 98*3* A3*= 9* 9* ) )=*A3 A9A*) A3*8)=*89 ) *)) 8= 8*A) 98*A3 3* A==*)) 9=*= 9* ) )*= A99*)) A3*)=*99 ) *3 8= =*93) 989*=3* A=8*3 93* 9* ) )9*9) A89*) A*A8)3*33 ) *8 8= ==*8) )3*9)3* A8*A 9* 9* ) )99*3 =3*)3 A*98*3 ) *3 8= 3*9) )8*33* A8A* 99* 9* ) ))A*93 ==*8 A3*A9*) 9*)A 8= =8*9) )*93 3* =9* )* 9* ) )8*8 =8*8) A=*=993*8) *9 8= =93*9) )33*8 3* ==*9) )3* 9* ) )8* =8A*) A)*8*)) =*89 8= ==)*8A) )3)*3* ==*3 )* 9* ) 8A*A 9*93 A3*9A93*8) 8*) 8= =3*) )A*A 3* =)9*9 )9* 9* ) 88* =*9 A3=*9*) 93* 8= =*8) )=*3* *= 8* 9* ) 8*9 *)) A3*898*) 9A*93 8= A99*) )=)*9 3* A*A8 83* 9* ) 833*= 8*3 A3=*))3*33 ) 9=*= 8= A3*8) )=*=3* 8*=9 8* 9* ) 838* =* A3A*33)*A3 ) 9A*= 8= A3)*)A) )*3* )A* 89* 9* ) 8A*=) A)*) A3*A3))*=A ) 9*9= 8= A=*)) )9*=)3* 9*9= * 9* ) 8=*8 *) A*=8*A ) 9*= 8= 3)*8A) )9A*83* A*98 * 9* ) 8==*= 9*A A=*83*9)) *A= 8= 39*==) )9*=3* =*A) 3* 9* ) 8=)*=3 )*=8 A*A8*8) 3*9 8= 39*8) ))*=3 3* *9 * 9* ) 8=*)8 98*A A9*3)9*)) 8*A9 8= 3AA*3)) ))*)8 3* 98*)= 9* 9* ) 8*A 9AA*A A=*9)=*9) 9*AA 8= 38*33) )8A*A3* 9A*8) * 9* ) 89*)A 99*=3 AA*3=)*) * 8= )*8) )88*)A 3* 93)* 3* 9* ) 89=*A 9)* AA*3A9)*=8 ) 9*9 8= *8) 8*A3* 93* * 9* ) 8)*99 )*) A=*9*A8 ) 8* 8= A*))) 83*99 3* 99*9 9* 9* ) 8)9*3 )38*) A9*93*3)) 3*3A 8= 3*8) 88*33* 988*9 3* 9* ) 88A*93 )A* A*888*)) *9 8= )8*33) 83*93 3* )3A* 33* 9* 8 *8 )99* A*9*9 ) 93*= 8= *99) 8A3*8 3* )=*3 3==* 9* 8 * )8=*) A3*8A*9) 99*9 8= =)*)) 8A9*3* )A*=A (*B.* % " & ! 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" # $ % &' 1 0 2! : ( 4 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. 224-108 PBU 06-15A PRUDHOE BAY PRUDHOE OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 06-15AInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241080PRUDHOE BAY, PRUDHOE OIL - 640150NA1Permit fee attachedYesADL0283112Lease number appropriateYesNote an expired permit 220-012 with the same name; never drilled3Unique well name and numberYesPRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NAThis well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.18Conductor string providedNAAll drilling on this sidetrack will be below the existing SC shoe.19Surface casing protects all known USDWsNAThis well is an in-zone CTD sidetrack from an existing wellbore with pressure integirty.20CMT vol adequate to circulate on conductor & surf csgNAThis well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.21CMT vol adequate to tie-in long string to surf csgYesFully cemented production liner. Parent well isolates the wellbore.22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesCDR2 and CDR3 have adequate tankage and good trucking support.24Adequate tankage or reserve pitYes25If a re-drill, has a 10-403 for abandonment been approvedYesNo separation factors less than 1.26Adequate wellbore separation proposedNAAll drilling will be below the SC shoe.27If diverter required, does it meet regulationsYesDrilling fluid minimum MW is 8.4 ppg. Res press is 7.1 ppg.28Drilling fluid program schematic & equip list adequateYesCT packoff, flow cross, annular, blind/shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29BOPEs, do they meet regulationYes7-1/16" 5000 psi stack pressure tested to 3500 psi.30BOPE press rating appropriate; test to (put psig in comments)YesFlanged chokc and kill lines between dual combis w/remote choke.31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNoPrudhoe's DS-06 is not an H2S pad. The last reading was 10 ppm.33Is presence of H2S gas probableNAThis is a development well.34Mechanical condition of wells within AOR verified (For service well only)NoDS 06 wells are H2S-bearing. H2S measures are required.35Permit can be issued w/o hydrogen sulfide measuresYesPore pressure anticiapted at 7.1 ppg EMW. MPD to be employed.36Data presented on potential overpressure zonesNAOne fault crossing anticipated.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate10/9/2024ApprWCBDate10/14/2024ApprADDDate10/9/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/14/2024