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Home My WebLink About225-067Nolan 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: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -09'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 11/03/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: PBU A-24B PTD: 225-067 API: 50-029-20743-02-00 FINAL LWD FORMATION EVALUATION LOGS (09/30/2025 to 10/09/2025) x Multiple Propagation and Azimuthal Resistivity (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Surveys x Pressure While Drilling SFTP Transfer – Main Folders: Please include current contact information if different from above. 225-067 T41049 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.03 15:25:51 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/24/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251024 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BR 11-86 (REVISED) 50733207370000 225057 8/1/2025 HALLIBURTON RMT3D BRU 241-34T 50283201810000 220052 9/23/2025 AK E-LINE Perf END 2-36 50029220140000 190024 10/13/2025 READ Caliper Survey MPI 2-72 50029237810000 224016 10/2/2025 AK E-LINE Patch MPU I-01 50029220650000 190090 9/25/2025 AK E-LINE Punch MPU J-08A 50029224970100 199117 10/22/2025 HALLIBURTON COILFLAG MPU R-109 50029238220000 225073 9/24/2025 YELLOWJACKET SCBL NCIU A-06A 50883200260100 225071 9/25/2025 AK E-LINE CBL NCIU A-06A 50883200260100 225071 9/26/2025 AK E-LINE Perf PBU A-24B 50029207430200 225067 10/20/2025 HALLIBURTON RBT PBU GC-2E 50029227400000 197018 10/21/2025 HALLIBURTON TEMP PBU W-35A 50029217990200 225076 10/10/2025 HALLIBURTON RBT SP-03-NE2 50629236390000 219089 9/25/2025 AK E-LINE Caliper Please include current contact information if different from above. T41022 T41023 T41024 T41025 T41026 T41027 T41028 T41029 T41029 T41030 T41031 T41032 T41033 PBU A-24B 50029207430200 225067 10/20/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.24 13:32:55 -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 Field, Prudhoe Oil, PBU A-24B Hilcorp Alaska, LLC Permit to Drill Number: 225-067 Surface Location: 2761' FNL, 1703' FEL, Sec. 35, T11N, R13E, UM, AK Bottomhole Location: 1457' FNL, 2611' FWL, Sec. 36, 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 AOGCCreserves 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 AOGCCspecifically 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 AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, *UHJRU\ &. :LOVRQ Commissioner DATED this 25th day of August 2025. Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.25 16:13:47 -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: 13183' TVD: 8920' 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: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 90.33' 15. Distance to Nearest Well Open Surface: x-653699 y- 5947671 Zone- 4 50.48' to Same Pool: 720' 16. Deviated wells: Kickoff depth: 10741 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 4-1/4"3-1/2"x3-1/4"9.3#/6.6# 13Cr85 STL/TCII 3283' 9900' 7953' 13183' 8920' x2-7/8' 6.5# /H511 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 38 - 118 37 - 2684 36 - 8526 2387 - 8115 8133 - 8658 8023 - 9083 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: Trevor Hyatt Sean McLaughlin Contact Email:trevor.hyatt@hilcorp.com Drilling Manager Contact Phone:907-223-3087 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 September 1, 2025 15913' Liner 649 7" 390 cu ft Class G 10131 - 10780 9991 - 12885 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): 2729 8 cu yds Concrete 38 - 118 37 - 276613-3/8" 4522 cu ft Permafrost II Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: 3-1/2" x 2-7/8" 36 - 10620 165 Bbls Class G 115 sx Class G Scab Liner Liner 10584 7687' 2894 Intermediate Authorized Name: 11596 - 12840 Conductor/Structural 20"80 LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) 226 sx Class G 2560 18. Casing Program: Top - Setting Depth - BottomSpecifications 3340 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 2460 39' FSL, 2160' FEL, Sec. 25, T11N, R13E, UM, AK 1457' FNL, 2611' FWL, Sec. 36, T11N, R13E, UM, AK 69-026 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 Hilcorp North Slope, LLC 2761' FNL, 1703' FEL, Sec. 35, T11N, R13E, UM, AK ADL 028286 PBU A-24B PRUDHOE BAY, PRUDHOE OIL Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 8836 - 9063 1480 cu ft Class G, 130 cu ft PF C 2421 - 101087" x 5-1/2" x 4-1/2" 9-5/8" 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: 2025.06.26 12:00:05 - 08'00' Sean McLaughlin (4311) 12900 9090 12500 12500 8910 10762, 12789 225-067 By Gavin Gluyas at 8:09 am, Jun 27, 2025 50-029-20743-02-00 DSR-6/30/25 *Variance to 20 AAC 25.036 (c)(2)(A)(iv) with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. Provide AOGCC opportunity to witness. *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. JJL 7/18/25 *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. TS 8/25/25JLC 8/25/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.25 16:12:13 -08'00' 08/25/25 08/25/25 RBDMS JSB 082725 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: June 26, 2025 Re:A-24B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well A-24A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for A-24B Producer: See A-24A Sundry request for complete pre-rig details - MIT, pull dreamcatcher and dummy GLMs. Eline will set CIBP and cut existing CTD liner. Service coil to bait and pick up cut liner to confirm free and leave for rig. 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. The rig will pull existing CTD liner out from cut. A drift and caliper will be run followed by setting a 4-1/2"x7" whipstock. The rig will then mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 3. The lateral will continue in Zone 3 up into Zone 4 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 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 A-24A Sundry submitted in concert with this request for full details. 1. Slickline : Pull dreamcatcher and dummy GLMs 2. E-Line : Set CIBP and cut existing 3-1/2" CTD liner at ~10,754' MD. 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 4. Coil / Slickline : Bait and pick up liner to confirm free. Drop and leave for rig to pull. 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in September 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,460 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Pull 3-1/2" CTD liner from pre-rig cut and lay down. 3. Cleanout, drift and caliper run past whipstock set location. 4. Set 4-1/2"x7" Whipstock at 10,736’ MD at 0 degrees ROHS 5. Mill 3.80” Window. 6. Drill build section: 4.25" OH, ~309' (35 deg DLS planned). 7. Drill production lateral: 4.25" OH, ~2,133' (12 deg DLS planned). Swap to KWF for liner. 8. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 9. Pump primary cement job: 50 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP. 10. Only if not able to do with service coil extended perf post rig – Perforate Liner 11. Freeze protect well to a min 2,200' TVD. 12. Close in tree, RDMO. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post rig RPM and perforate (~30’) 3. Slickline : Set live GLVs. 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 (10,741' MD -8,625' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,395 psi 4,395 psi 9.8 B - ECD 644 psi 0 psi 0.06 C 3,857 psi 3,857 psi 8.6 B+C Mud + ECD Combined 4,501 psi 3,857 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 538 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The estimated reservoir pressure is expected to be 3,340 psi at 8,800 TVD. (7.3 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 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: 4.25" hole for the entirety of the production hole section. Liner Program: 3-1/2", 9.3#, 13Cr/Solid: 9,900' MD – 9,930' MD (30' liner) 3-1/4", 6.6#, 13Cr/Solid: 9,930' MD – 11,200' MD (1,270' liner) 2-7/8", 6.5#, 13Cr/Solid: 11,200' MD – 13,183' MD (1,983' 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. Solid 2-7/8” Liner Running Ram Change: Change out 3”/3-1/8” 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. A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. 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: Directional plan attached. Maximum planned hole angle is 104°. Inclination at kick off point is 34°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line – 15913 ft Distance to nearest well within pool – 720 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. 2.0” 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 is 10,661’ MD in the parent Anti-Collision Failures: All Wells Pass AC scan Hazards: A Pad is an H2S pad. The last H2S reading on A-24A: 33 ppm in 2025. Max H2S recorded on DS/Pad: 130 ppm. 0 fault crossings expected. Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) 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”. Pre-Rig – Service Coil – Window Milling – BOP Diagram 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 Prudhoe 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 10,736' 11,200' 11,200' 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 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" 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"or 3-1/8" 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 2-3/8" 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 Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PRUDHOE BAY 225-067 PBU A-24B PRUDHOE OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT A-24BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250670Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1Permit fee attachedYesADL0282862Lease number appropriateYes3Unique 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) (For NA15All 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)Yes18Conductor string providedYes19Surface casing protects all known USDWsYes20CMT vol adequate to circulate on conductor & surf csgYes21CMT vol adequate to tie-in long string to surf csgYes22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitYesVariance as per 20 AAC 25.112(i): Approved for alternate plug placement with fully cemented liner.25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYes28Drilling fluid program schematic & equip list adequateYes*Variance to 20 AAC 25.036 (c)(2)(A)(iv) for tubulars <2.375" OD without properly sized rams29BOPEs, do they meet regulationYes30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableNAA Pad is an H2S pad. The last H2S reading on A-24A: 33 ppm in 2025.34Mechanical condition of wells within AOR verified (For service well only)NoA-Pad wells are H2S-bearing. H2S measures are required.35Permit can be issued w/o hydrogen sulfide measuresYesExpected reservoir pressure gradient is 7.3 ppg EMW. MPD to maintain an ECD of 9.8 ppg EMW.36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprTCSDate8/25/2025ApprJJLDate7/18/2025ApprTCSDate8/25/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 8/25/2025