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225-096
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: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -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: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Lau, Jack J (OGC) To:Leif Knatterud Subject:RE: [EXTERNAL] RE: C-33B CTD 407 Extension Date:Tuesday, January 6, 2026 2:09:29 PM Leif, Your extension request for a 30-day extension on the C-33B 407 is approved. Jack From: Leif Knatterud <leif.knatterud@hilcorp.com> Sent: Tuesday, January 6, 2026 8:52 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: C-33B CTD 407 Extension C-33 came on very low rate and we need to shoot additional footage. If it appears that acid was beneficial on C-32 once we get it POP’d, we would like to acidize the perfs on C-33 while coil is on it. Thanks, Leif Knatterud 432-227-4342 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, January 6, 2026 8:45 AM To: Leif Knatterud <leif.knatterud@hilcorp.com> Subject: [EXTERNAL] RE: C-33B CTD 407 Extension Please elaborate on the reason and plan. Jack From: Leif Knatterud <leif.knatterud@hilcorp.com> Sent: Tuesday, January 6, 2026 7:16 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com>; Lea Peters <lpeters@hilcorp.com> Subject: C-33B CTD 407 Extension 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. Good morning Jack, I am requesting a 30-day extension on the 407 for C-33B. The well came on low rate similarly to C-32E. We want to execute a plan based on the lessons learned from C-32 but we only have 14 days left on the 407, so we will need a little more time. Let me know if you approve or have any questions. Thanks, Leif Knatterud 432-227-4342 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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. 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, pleaseimmediately 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. 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: 01/05/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU C-33B PTD: 225-096 API: 50-029-22373-02-00 FINAL LWD FORMATION EVALUATION LOGS (11/19/2025 to 12/06/2025) 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. 225-096 T41237 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.06 08:08:24 -09'00' 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 Field, Prudhoe Oil, PBU C-33B Hilcorp Alaska, LLC Permit to Drill Number: 225-096 Surface Location: 701' FNL, 1222' FEL, Sec 19, T11N, R14E, SM, AK Bottomhole Location: 218' FNL, 1299' FEL, Sec 17, T11N, R14E, SM, 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 26th day of September 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.26 13:50:01 -08'00' Joe Engel for Sean McLaughlin By Grace Christianson at 7:43 am, Sep 12, 2025 Digitally signed by Joseph Engel (2493) DN: cn=Joseph Engel (2493) Date: 2025.09.11 15:46:06 - 08'00' Joseph Engel (2493) 225-096 *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 and retainer/cement as planned approved for C-33A. DSR-9/12/25 *AOGCC Witnessed BOP Test to 3500 psi, Annular 2500 psi minimum. *Post rig service coil perforating approved for max gun length of 500'. *Window milling approved on service coil. *Variance to 20 AAC 25.036 (c)(2)(A)(iv) with compliance to rules in CO 823. 50-029-22373-02-00 TS 9/26/25JJL 9/25/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.26 13:50:14 -08'00' 09/26/25 09/26/25 RBDMS JSB 093025 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 11, 2025 Re:C-33B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well C-33A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for C-33B Producer: See C-33A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN-nipple. Coil will perform a 3-1/2”x7” IA cement squeeze to aid in the dual string exit. E-line will set a 3-1/2" whipstock. If unable to set the whipstock 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 3-1/2" whipstock and mill a single string 2.80" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 3 and 2, landing in Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference C-33A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy GLMs, SL Whipstock Drift, CT drift and Caliper 2. Fullbore : MIT-IA and/or MIT-T (2,500 psi min) 3. Service Coil : SQZ IA at KOP. Plug ~10,800', Punch ~10,795' and ~10,650', Set retainer ~10,790' and sqz 145' of IA (~4 bbls of 15.8 ppg Class G cement). Mill XN. 4. Eline : Set 3-1/2” Packer Whipstock 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start October 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,420 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.80” Dual String 3-1/2"x7" Window 3. Drill build section: 3.25" OH, ~259' (24 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~2,550' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr solid liner 6. Make up 1" CS Hydril cementing string with ORCA system and run in to PBTD. 7. Pump primary cement job: 19.5 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 8. Only if not able to do with service coil extended perf post rig – Perforate Liner with 1" CS Hydril perf string 9. Freeze protect well to a min 2,200' TVD. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP (if necessary). Set live GLVs. 3. Service Coil : Post rig CBL and perforate (~500-800’) - see extended perf procedure attached. 4. Testing : Portable test separator flowback. 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 (10778' MD -8,638' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,402 psi 4,402 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 970 psi 0 psi 0.09 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,863 psi 3,863 psi 8.6 B+C Mud + ECD Combined 4,833 psi 3,863 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 539 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,300 psi at 8,800 TVD. (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,420 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 2.75” to 3.25” hole for the entirety of the production hole section. Liner Program: x 2-3/8", 4.6#, 13Cr/Solid: 10,730' MD – 13,587' MD (2,857' 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. Jointed Pipe Work String Program: x 1-1/4" CS Hydril, 3.02#, P-110: up to 4,000' MD x 1” CS Hydril, 2.25#, P-110: up to 4,000' MD x Used for contingency CTD liner cleanout/logging runs, deployment of perforation guns (if performed by rig), inner string 2-3/8” liner cement jobs and contingency inner string 2-7/8” liner cement jobs. 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 A X-over shall be available to be made up to a 2-3/8” or 2” safety joint including a TIW valve for all tubulars ran in hole. x 2-3/8” or 2” safety joint will be utilized while running solid/slotted liner, perforation guns and CS Hydril jointed pipe. 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” or 2” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. x CO823 – Hilcorp CTD Qualification Blind-Shear Test: CDR2 test on 09/04/2025 (see Hilcorp Alaska CTD CO823 Qualification report previously sent to AOGCC for more information). x CO823 – Safety Joint Drills: Provide AOGCC opportunity to witness once per well that a CTD liner is ran. Directional: x Directional plan attached. Maximum planned hole angle is 98°. Inclination at kick off point is 53°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 12,300 ft x Distance to nearest well within pool – 500 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 500-800' perforated post rig – See attached extended perforating procedure. x 1.56 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 10,501’ MD in the parent Anti-Collision Failures: x C-18A Fails AC at 13,238’ MD (C-33B depth) and 14,451’ MD (C-18A depth) o Well is P&A’d / sidetracked (12,284’ MD) above close approach to current well (C-18B) o Center to center distance is 92’ 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 x C-20C Fails AC at 11,553’ MD (C-33B depth) and 14,350’ MD (C-20C depth) o Center to center distance is 540’ 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 C-20C in the event of a collision. o At least offset tubing volume of KWF is on location at all times while drilling by well. o The potential of intersection and proper response will be discussed with the crew. x 15-33A Fails AC at 12,295’ MD (C-33B depth) and 14,111’ MD (15-33A depth) o Well is P&A’d / sidetracked (10,350’ MD) above close approach to current well (15-33C) o Center to center distance is 270’ 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 Hazards: x DS/Pad is an H2S pad. The last H2S reading on C-33A: 24 ppm (2023) x Max H2S recorded on DS/Pad: 115 ppm. x 1 fault crossings expected. x low lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) 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 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 113' 10,778' 10,778' 10,778' 10,778' 113' % 3UXGKRH%D\8QLW $'/ $'/ $'/ $'/ 6HF 6HF 6HF 6HF 6HF 6HF 6HF 6HF 6HF 81( &3$' 2LO5LP3$ &%B6+/ &%B73+ &%B%+/ /HJHQG &%B%+/ &%B6+/ %&%B73+ 2WKHU6XUIDFH+ROHV 6+/ 2WKHU%RWWRP+ROHV %+/ 2WKHU:HOO3DWKV 3DG)RRWSULQW 2LODQG*DV8QLW%RXQGDU\ 3DUWLFLSDWLQJ$UHD%RXQGDU\ $,2& &2- Map Date: 8/11/2025 )HHW 'RFXPHQW3DWK 2 ?$:6?*,6?'URSER[?-XOLHDQQD3RWWHU?3URMHFWB+DQGRII?3URMHFWB+DQGRIIDSU[3UXGKRH%D\8QLW &%:HOOu 3ODQ &%ZS 865087008750880088508900True Vertical Depth (100 usft/in)1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 Vertical Section at 335.00° (400 usft/in)C-33PB1C-33AC-33C-33B wp03Top of Window - 10,778'MDEnd 24dls - 11,037'MDTD - 13,587'MDC-33B wp03405045004950540058506300South(-)/North(+) (900 usft/in)3150 3600 4050 4500 4950 5400 5850 6300 6750 West(-)/East(+) (900 usft/in)15-18A884615-33C88 3715-33A8000840 088008884C-33PB18917C-33A8880C-338 4 00 8 8 00 8 9 83 C-208800C-19B88008797C-18A6400680072007600C-18840088009074C-1988008924C-19BPB18800C-19A8912C-20C9021C-04C wp028 8 0 08839C-33B wp03Top of Window - 10,778'MDEnd 24dls - 11,037'MDTD - 13,587'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 10778.00 53.40 53.25 8638.90 4166.09 4297.46 0.00 0.00 1959.572 10798.00 51.60 53.25 8651.07 4175.58 4310.17 9.00 180.00 1962.803 10868.00 34.80 53.25 8701.92 4204.14 4348.42 24.00 180.00 1972.524 11036.89 74.00 66.62 8798.61 4267.86 4466.51 24.00 20.00 1980.375 11152.00 74.00 80.99 8830.34 4298.64 4572.49 12.00 90.00 1963.476 11282.00 74.00 64.76 8866.17 4335.31 4691.52 12.00 -90.00 1946.417 11392.00 74.00 78.49 8896.49 4368.56 4791.63 12.00 90.00 1934.238 11533.41 90.00 84.22 8916.12 4389.39 4929.59 12.00 20.00 1894.819 11639.00 91.10 71.60 8915.11 4411.46 5032.62 12.00 -85.00 1871.2710 11804.00 92.72 91.34 8909.56 4435.82 5194.89 12.00 85.00 1824.7611 11984.00 97.83 70.26 8892.82 4464.17 5370.77 12.00 -75.50 1776.1212 12364.00 95.47 24.39 8846.35 4713.30 5640.42 12.00 -90.00 1887.9613 12544.00 93.62 2.80 8831.92 4886.67 5682.29 12.00 -94.00 2027.3914 12651.60 90.00 350.39 8828.51 4993.80 5675.91 12.00 -106.00 2127.1715 13031.60 89.11 304.80 8831.64 5306.23 5477.63 12.00 -91.25 2494.1316 13361.60 89.31 344.41 8836.39 5569.88 5290.29 12.00 90.00 2812.2617 13587.00 89.39 317.36 8838.99 5764.96 5181.62 12.00 -90.00 3034.98Depth From Depth To Survey/Plan Tool432.00 11641.78 1 : MWD - Standard (C-33PB1) 3_MWD11674.34 10778.00 1 : MWD - Standard (C-33) 3_MWD10778.00 13587.00 C-33B wp03 (Plan: C-33B) 3_MWDSECTION DETAILSSURVEY PROGRAMProject: Prudhoe BaySite: CWell: C-33Wellbore: Plan: C-33BPlan: C-33B wp03REFERENCE INFORMATIONCoordinate(N/E) Reference: Well C-33, True NorthVertical (TVD) Reference: Kelly Bushing / Rotary Table @ 67.70usftMeasured Depth Reference: Kelly Bushing / Rotary Table @ 67.70usftSection (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureParent Wellbore: C-33Top of Window: 10778.00Northing: 5960513.20Easting: 664140.42Lattitude: 70° 17' 54.4230 NLongitude: 148° 40' 14.3673 WNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04REFERENCE INFORMATIONWELLBORE DETAILSWELL DETAILSHilcorp Alaska, LLCPROJECT DETAILSC-33B wp03 !! 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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 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 BAY PRUDHOE OIL 225-096 PBU C-33B WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT C-33BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250960Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1Permit fee attachedYesADL0283052Lease 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 pitYes*Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement with fully cemented liner25If a re-drill, has a 10-403 for abandonment been approvedYesYes, no notable risks.26Adequate 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) with compliance to rules 29BOPEs, do they meet regulationYes5K.30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesThe last H2S reading on C-33A: 24 ppm (2023)33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoC-Pad wells are H2S-bearing. H2S measures are required.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure range is 0.374 psi/ft (7.2 ppg EMW), MPD will be utilized 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]ApprTCSDate9/26/2025ApprJJLDate9/25/2025ApprTCSDate9/26/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&: JLC 9/26/2025
