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Home My WebLink About225-0687. 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 C-34C Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-068 50-029-21785-03-00 341J ADL 028286, 028305, 028310 14552 Surface Intermediate Intermediate Liner Liner 9098 2652 3342 11418 256 3302 14522 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 9085 48 - 2700 46 - 3388 44 - 11462 11300 - 11556 11250 - 14552 3400 48 - 2700 46 - 3388 44 - 8493 8360 - 8569 8319 - 9098 None 2260 4760 5410 7500 10530 None 5020 6870 7240 8430 10160 13929 - 14449 4-1/2" 12.6# 13Cr85 42 - 113008874 - 9053 Conductor 80 20" 49 - 129 49 - 129 4-1/2" HES TNT Packer No SSSV Installed 11185, 8266 Date: Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 907-564-4667 PRUDHOE BAY 10/20/2025 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 8:33 am, Oct 07, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.07 04:45:49 - 08'00' Torin Roschinger (4662) 325-605 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 A.Dewhurst 10OCT25 10-404 J.Lau 10/14/25 DSR-10/10/25 10/14/25 Plug and Ext Perf C-34C PTD: 225-068 Well Name:C-34C API Number: 50-029-21785-03 Current Status:Operable Producer Rig:CTU Estimated Start Date:10/20/2025 Estimated Duration:3 days Reg.Approval Reqstd?10-403, 10-404 Date Reg. Approval Recvd:Check status Regulatory Contact:Abbie Barker First Call Engineer:Leif Knatterud (907) 564-4667 (O)(432) 227-4342 (M) Second Call Engineer:Finn Oestgaard (907) 564-5026 (O)(907) 350-8420 (M) Current Bottom Hole Pressure:3250 psi @ 8,800 TVD 7.1 PPGE | (Estimated) Maximum Expected BHP:3400 psi @ 8,800 TVD 7.5 PPGE | (Highest Ivishak BHP) Max. Anticipated Surface Pressure:2520psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1200psi (9/20/25) Min ID:2.313 @ 11,243 at LTP Max Angle:110 Deg @ 13,152 Brief Well Summary: C-34C a new GDWFI Sidetrack completed August 2025. Initial toe stages were low rate and high WC. On 9/20/25, 10 of perforations were added in the toe. Total fluid increased but still had a high WC and GOR. We will now plug off the toe stages and extended perforate the mid-lateral. Objective:This program will isolate the lower liner with a CIBP and then perforate up-hole. Procedure: 1. MU GR/CCL with ~2.25 JSN drift (NS Bridge plug 278-210 is 2.1 OD). RIH to ~13,510. Flag pipe and pull tie-in log. a. Flag pipe for plug set (13,510) and perforating depth (12,747-13,117) (130 perf add). b. Last drift: Tractor in 10 of 2 guns to 14,400 on 9/20/25 2. POOH. Correlate with HAL Memory RCBL 8/25/25 (see attached log Main Pass). Correct flag and send to Corey Ramstad and OE. 3. MU NS 278-210 Bridge Plug or similar. RIH. 4. Prior to entering liner fluid pack well down CTBS with KWF. See bullhead volumes below in step 11. 5. Set CIBP at 13,510. 6. POOH. Coil Extended Perforating If liner integrity test passed then proceed with extended perforating Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations 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. 7. 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. 8. Bullhead 1.2X wellbore volume - 225 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. a. Wellbore volume to top perf = 188 bbls b. 4-1/2 Tubing 11,247 X .0152 bpf = 171 bbls Plug and Ext Perf C-34C PTD: 225-068 c. 3-1/2 Liner 73 X 0.0087 bpf = 1 bbls d. 3-1/4 Liner 569 X .0079 bpf = 4 bbls e. 2-7/8 Liner 2044 X .0058 bpf = 12 bbls 9. At surface, prepare for deployment of TCP guns. 10. 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. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 11.*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 spacedout, 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. 12.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 Use 2 Maxforce guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 12,747 12,827 - Gun 12,827 13,067 Blank 13,067 13,117 - Gun 130 3702072 lbs (5.6 ppf) 13. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. f. Note any tubing pressure change in WSR. 14. After perforating, PUH to top of liner or into tubing tail to ensure debris doesnt fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 15. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 16. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 17. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 18. RDMO CTU. 19. Turn well over to Operations POP. Attachments: Wellbore Schematic Proposed Schematic Tie-In Log BOPE Schematic Standing Orders Equipment Layout diagram Sundry Change Form Plug and Ext Perf C-34C PTD: 225-068 Current Wellbore Schematic Plug and Ext Perf C-34C PTD: 225-068 Proposed Wellbore Schematic Plug and Ext Perf C-34C PTD: 225-068 Tie-in Log Plug and Ext Perf C-34C PTD: 225-068 CIBP: ~13,510 Plug and Ext Perf C-34C PTD: 225-068 Perf: 12,747-12,827 Perf: 13,067-13,117 Plug and Ext Perf C-34C PTD: 225-068 BOP Schematic Plug and Ext Perf C-34C PTD: 225-068 Plug and Ext Perf C-34C PTD: 225-068 Plug and Ext Perf C-34C PTD: 225-068 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: 09/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250919 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-35T 50283200970000 198161 8/10/2025 AK E-LINE PPROF T40899 BRU 223-34T 50283202060000 225059 8/17/2025 AK E-LINE CBL T40900 BRU 234-27 50283202070000 225065 9/12/2025 AK E-LINE CBL T40901 BRU 242-04 50283201640000 212041 6/9/2025 AK E-LINE Perf T40902 KBU 11-08Z 50133206290000 214044 9/8/2025 AK E-LINE Perf T40903 MPU H-03 50029220630000 190088 9/9/2025 AK E-LINE SetPacker T40904 MPU H-11 50029228020000 197163 2/9/2025 AK E-LINE Caliper T40905 MPU M-62 50029237440000 223006 8/31/2025 AK E-LINE LDL T40906 NCIU A-06 50883200260000 169050 8/25/2025 AK E-LINE TubingCut T40907 NCIU A-21A 50883201990100 225075 8/26/2025 AK E-LINE Perf T40908 ODSK-33 50703205620000 207183 9/10/2025 READ Caliper Survey T40909 ODSN-01a 50703206480100 216008 9/8/2025 READ Caliper Survey T40910 ODSN-06 50703207150000 215098 9/9/2025 READ Jewelry Log T40911 PBU C-34C 50029217850300 225068 8/25/2025 BAKER MRPM T40912 PBU Q-06A 50029203460100 198090 8/21/2025 BAKER SPN T40913 TBU M-25 50733203910000 187086 8/31/2025 AK E-LINE Drift T40914 Please include current contact information if different from above. PBU C-34C 50029217850300 225068 8/25/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.22 13:22:50 -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: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -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: 09/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU C-34C PTD: 225-068 API: 50-029-21785-03-00 FINAL LWD FORMATION EVALUATION LOGS (08/03/2025 to 08/15/2025) 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. 225-068 T40856 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.08 15:03:58 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PBU C-34C (PTD #225-068) - BOP Test Extension Date:Monday, August 18, 2025 8:35:43 AM From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, August 15, 2025 1:06 PM To: Trevor Hyatt <trevor.hyatt@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Alaska NS - CDR2 - DSM <AlaskaNS-CDR2-DSM@hilcorp.com> Subject: Re: PBU C-34C (PTD #225-068) - BOP Test Extension Trevor, You are approved for a 24 hr BOP test extension. Jack From: Trevor Hyatt <trevor.hyatt@hilcorp.com> Sent: Friday, August 15, 2025 12:55 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Alaska NS - CDR2 - DSM <AlaskaNS-CDR2-DSM@hilcorp.com> Subject: PBU C-34C (PTD #225-068) - BOP Test Extension Jack, We have drilled to TD with major losses (over 100 BPH) on C-34C with CDR2. We have crossed three large shale sections and are currently cleaning up the well in preparation to run liner. Our BOP test is do Saturday night (tomorrow). With the losses and shale open we would like to get liner on bottom as soon as possible so we don’t lose this hole. Current projections put us running liner to TD tomorrow night. We would like to request a 24-hour BOP test extension so we can hopefully get liner on bottom and cemented in the most efficient way possible. Let me know if you have any questions. Thank you for your time and consideration. Trevor Hyatt Hilcorp Alaska, LLC Senior Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 2025-0816_Safety_Joint_Drill_Nabors_CDR2AC_PBU C-34C_gc Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 8/16/2025 P. I. Supervisor FROM: Guy Cook SUBJECT: Coil Tubing Drilling Safety Joint Drill Petroleum Inspector PBU C-34C Hilcorp North Slope LLC PTD 2250680; Sundry 325-389 8/16/2025: I arrived at Nabors CDR2AC (coil tubing drilling rig) for a Safety Joint Drill. I met with the Company representative Robert O’Neal and the Tool Pusher Robert Coyne and discussed the drill. The cross-over for the safety joint was installed on the tubing first and tightened by pipe wrench, and then the safety joint was installed and torqued on with their Little Jerks which is a small iron roughneck. After torquing the safety joint the cross-over was torqued with the Little Jerks as well. The next step was to run the safety joint into the hole and close the rams and then close the FOSV. Before the joint could be lowered into the hole a dog-collar and slips needed to be removed. The rig personnel called into the driller to let them know they were in their positions (pits, accumulator, etc.) for well control operations. Start to finish, the drill took three minutes and forty-seven seconds to complete. A video of this drill (“CDR2 Safety Joint Video 8-16-25 GC”) can be viewed at the following file location: G:\AOGCC\Inspections\Inspection Photos Attachments: none      CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Trevor Hyatt Cc:Alaska NS - CDR2 - DSM; Ryan Ciolkosz; Joseph Lastufka Subject:RE: PBU C-34C (PTD #225-068) - Cement Down Squeeze Date:Friday, August 15, 2025 3:19:02 PM Hi Trevor, The contingency cement down squeeze outlined below is approved. Jack From: Trevor Hyatt <trevor.hyatt@hilcorp.com> Sent: Friday, August 15, 2025 3:07 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Alaska NS - CDR2 - DSM <AlaskaNS-CDR2-DSM@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU C-34C (PTD #225-068) - Cement Down Squeeze Jack, We are currently on high losses on C-34C (with CDR2) after drilling to TD. It has been over an 100 BPH loss rate. We are planning to cement per the PTD with our standard cement practice. However, we might not see any returns while cementing and could see the cement only make it from the shoe to the loss zone (mid lateral). If we see losses while cementing, we might decide we need a cement down squeeze from the top of the liner down to the loss zone after the initial cement job. If we decide we need the cement down squeeze, we would like to request approval to perform a cement down squeeze after the initial cement job with CDR2 before moving off. Down Squeeze Plan: 1. Trip out of hole with initial cementing BHA after pumping cement. 2. Make up cement down squeeze BHA and run in to top of liner. 3. Displace tubing to diesel, holding MPD backpressure to remain overbalanced. 4. Pump cement down coil, out cementing BHA and down back side of CTD liner to loss zone. 5. Come out of hole and pressure un-deploy down squeeze BHA and RDMO. Trevor Hyatt Hilcorp Alaska, LLC Senior Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 C-34C Hilcorp Alaska, LLC Permit to Drill Number: 225-068 Surface Location: 1565' FNL, 882' FEL, Sec 19, T11N, R14E, UM, AK Bottomhole Location: 1689' FNL, 2083' FEL, Sec 25, 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 15th day of July 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.15 14:48:56 -08'00' 3-1/2"x3-1/4" 11595, 11635, 11675,11944, 12580, 15650 225-068 By Gavin Gluyas at 10:25 am, Jun 27, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.06.27 10:05:47 - 08'00' Sean McLaughlin (4311) DSR-6/30/25 *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 50-029-21785-03-00 *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 s ized pipe rams. Provide AOGCC opportunity to witness. *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. A.Dewhurst 10JUL25 JJL 7/15/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.15 14:48:11 -08'00' 07/15/25 07/15/25 RBDMS JSB 071625 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: June 27, 2025 Re:C-34C Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well C-34B with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for C-34C Producer: See C-34B 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 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window pre-rig, 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 pre-rig, the rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 2. The lateral will continue in Zone 2 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: x Reference C-34B Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock at 11,575’ MD at 0 degrees ROHS 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 4. Coil : Mill Window (if window not possible, mill with rig). - see attached procedure 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in August 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,355 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~199' (20 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,734' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job*: 40 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. 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. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post rig RPM and perforate (~30’) - see attached procedure 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 (11575' MD -8,584' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,374 psi 4,374 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 694 psi 0 psi 0.06 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,839 psi 3,839 psi 8.6 B+C Mud + ECD Combined 4,533 psi 3,839 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 536 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,235 psi at 8,800 TVD. (7.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,355 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: 11,240' MD – 11,270' MD (30' liner) x 3-1/4", 6.6#, 13Cr/Solid: 11,270' MD – 11,900' MD (630' liner) x 2-7/8", 6.5#, 13Cr/Solid: 11,900' MD – 14,508' MD (2,608' 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”/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. 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 102°. Inclination at kick off point is 37°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 20,764 ft x Distance to nearest well within pool – 850 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 2.0" 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 Prudhoe Pool. x Formations: Top of Prudhoe Pool is 11,463’ MD in the parent Anti-Collision Failures: x C-05A Fails AC at 11,421’ MD (C-05A depth) and 12,175’ MD (C-34C depth) o Center to center distance is 400’ o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o Pad operator will be aware of the failed anticollision scan and is prepared to shut in well in the event of a collision. o At least offset tubing volume of KWF will on location at all times while drilling by well. o The potential of intersection and proper response will be discussed with the crew. x A-25A Fails AC at 12,647,’ MD (A-25A depth) and 14,235’ MD (C-34C depth) o Center to center distance is 130’ o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o Well abandoned and sidetracked to A-25B above close approach at 8,179’ MD. x A-25 Fails AC at 12,549’ MD (A-25 depth) and 14,457’ MD (C-34C depth) o Center to center distance is 160’ o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o Well abandoned and sidetracked to A-25B above close approach at 8,179’ MD. Hazards: x C Pad is not an H2S pad. The last H2S reading on C-34B : 16 ppm in 2025. x Max H2S recorded on DS/Pad: 28 ppm. x 0 fault crossings expected. x 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: x 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: 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 Kuparuk 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 11,900'11,900' 14,508' % Prudhoe Bay Unit ADL028310 ADL028305 ADL028286 ADL028285 Sec. 17 Sec. 20 Sec. 13 Sec. 24 Sec. 29Sec. 25 Sec. 18 (599) Sec. 19 (601) Sec. 30 (604) U011N013E U011N014E BOC GC3 CC1 C PAD TRUCK FILL CPS GC1 WATER INTAKE Oil Rim PA C-34C_SHL C-34C_TPH C-34C_BHL C-34C Legend C-34C_BHL C-34C_SHL %C-34C_TPH Other Surface Holes (SHL) Other Bottom Holes (BHL) Other Well Paths Pad Footprint Oil and Gas Unit Boundary Participating Area Boundary AIO 3C CO 341J Map Date: 6/26/2025 0 670 1,340 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxNAD 1927 StatePlane Alaska 4 FIPS 5004 Prudhoe Bay Unit C-34C Well wp04 u 1:20,000 -6500-6000-5500-5000-4500-4000-3500South(-)/North(+) (1000 usft/in)-7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 West(-)/East(+) (1000 usft/in)9 0 22 C-05A7200 76008 00 0 8 4 0 0 8 8 0 0 9 0 89 C-058 8 0 0 91 4 1 A-25A76008000840088009192A-259078B-19A9 03 8C-23D9 0 3 8 C-24B80008400880092009270C-268 8 0 0 9036C-26A72007600800084008506C-34BPB176008000840088008652C-34B8 8 00 8541D-21A wp01840088009199D-2188009 0 2 4 C-34C wp04Top of Window - 11575'MDEnd 20ls - 11774'MDTD - 14508'MD84008600880090009200True Vertical Depth (400 usft/in)5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 Vertical Section at 230.00° (400 usft/in)C-34BPB1C-34BC-34C wp04Top of Window - 11575'MDEnd 20ls - 11774'MDTD - 14508'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 11575.00 37.56 192.44 8584.13 -4314.78 -3909.01 0.00 0.00 5767.962 11595.00 39.36 192.44 8599.79 -4326.93 -3911.69 9.00 0.00 5777.823 11665.00 53.36 192.44 8647.98 -4376.27 -3922.57 20.00 0.00 5817.884 11773.54 74.00 200.00 8695.91 -4468.92 -3950.13 20.00 20.00 5898.545 12014.00 74.00 230.01 8762.19 -4656.09 -4081.23 12.00 90.00 6119.286 12214.00 74.00 205.05 8817.31 -4807.34 -4197.43 12.00 -90.00 6305.527 12414.00 74.00 230.01 8872.44 -4958.60 -4313.63 12.00 90.00 6491.768 12584.00 74.00 208.80 8919.30 -5084.14 -4416.77 12.00 -90.00 6651.479 12724.00 74.00 226.27 8957.89 -5190.45 -4498.44 12.00 90.00 6782.3610 12865.41 90.00 232.00 8977.52 -5281.63 -4604.04 12.00 20.00 6921.8711 12971.94 102.00 236.44 8966.40 -5343.49 -4689.78 12.00 20.00 7027.3112 13240.00 102.00 269.33 8910.67 -5419.61 -4936.94 12.00 90.00 7265.5713 13362.00 102.00 254.36 8885.30 -5436.50 -5054.73 12.00 -90.00 7366.6614 13582.00 102.00 281.35 8839.56 -5444.48 -5267.79 12.00 90.00 7535.0115 13688.21 90.00 277.02 8828.48 -5427.70 -5371.86 12.00 -160.00 7603.9416 13821.44 75.00 271.43 8845.83 -5417.88 -5503.15 12.00 -160.00 7698.2117 13932.00 75.00 285.16 8874.45 -5402.52 -5608.57 12.00 90.00 7769.0918 14152.00 75.00 257.83 8931.39 -5397.02 -5819.00 12.00 -90.00 7926.7519 14332.00 75.00 280.19 8977.97 -5400.00 -5991.74 12.00 90.00 8060.9920 14508.00 75.00 258.33 9023.53 -5402.18 -6160.70 12.00 -90.00 8191.82Project: Prudhoe BaySite: CWell: C-34Wellbore: C-34CPlan: C-34C wp04WELLBORE DETAILSParent Wellbore:C-34BTop of Window: 11575.00C-34C wp04Depth From Depth To Survey/Plan Tool53.81 3375.91 1 : Schlumberger GCT multishot (C-34)3_Gyro-CT_pre-1998_Csg13388.00 3854.03 SLB GWD SS 8-1/2" (C-34B) 3_Gyro-MWD_OWSG23883.90 4165.00 SLB MWD 8-1/2" (C-34B) 3_MWD (BP MWD+IFR+MS-WOCA)4233.32 11435.70 BHGE ATK MWD 8-1/2" (C-34B) 3_MWD (BP MWD+IFR+MS-WOCA)11501.67 11575.00 BHGE ATK MWD 6-1/8" (C-34B) 3_MWD (BP MWD+IFR+MS-WOCA)11575.00 14508.00 C-34C wp04 (C-34C) 3_MWDWELL DETAILSNorthing: 5959657.00Easting: 664504.00Lattitude: 70° 17' 45.9255 NLongitude: 148° 40' 4.3168 WC-34C wp04SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well C-34, True NorthVertical (TVD) Reference: C-34B KB @ 83.32usft (Actual P272)Measured Depth Reference: C-34B KB @ 83.32usft (Actual P272)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !! 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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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 OILPRUDHOE BAY 225-068 PBU C-34C WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT C-34CInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250680Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL028305, ADL028310, and ADL0282862 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For sNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)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 Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement with fully cemented liner.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 adequateYes29 BOPEs, do they meet regulationYes ariance to 20 AAC 25.036 (c)(2)(A)(iv) for tubulars <2.375" OD without properly sized pipe 30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes C Pad is not an H2S pad. The last H2S reading on C-34B : 16 ppm in 2025.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No C-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure gradient is 7.1 ppg EMW. MPD to maintain an ECD of 9.8 ppg EMW.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]ApprADDDate7/10/2025ApprJJLDate7/15/2025ApprADDDate7/10/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 7/16/2025