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Home My WebLink About225-009Nolan 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 T41328 PBU B-30B 50029215420200 225009 1/24/2026 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' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU B-30B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-009 50-029-21542-02-00 12800 Surface Intermediate Liner Liner Liner 9075 2636 9512 331 684 3223 12260 13-3/8" 9-5/8" 7" 5-1/2" x 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8899 40 - 2676 36 - 9548 9308 - 9639 8955 - 9639 9530- 12753 40 - 2676 36 - 8563 8418 - 8614 8187 - 8614 8553 - 9061 None 2670 4760 7020 6820 10530 12260 5380 6870 8160 7740 10160 12195 - 12305 4-1/2" 12.6# 13Cr80 34 - 8960 8879 - 8913 Conductor 80 20" x 30" 40 - 120 40 - 120 4-1/2" HES TNT Perm Packer 8838 8106 Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 9075644667 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028310 34 - 8190 N/A N/A 167 197 23663 35939 1515 66 600 550 660 975 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8838, 8106 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 7:47 am, Aug 13, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.13 05:50:55 - 08'00' Torin Roschinger (4662) DSR-9/11/25JJL 9/5/25 ACTIVITY DATE SUMMARY 7/30/2025 LRS CTU #1 1.50" CT 0.134" WT HT-110 Job Objective- Drift/Log, Set CIBP and Perf MIRU. Perform weekly BOP test. Passing test. Function Test BOP on well. MU NS MHA and HES memory gamma/CCL w/ 2.25" drift nozzle. PT PCE 263 / 4165psi. L/K well w/ 10bbls 50/50, 190bbls slick 1%KCL w/ safelube. Drift clean to 12550', attempt to log up and overpull at 12365'. F&S fill at 1.5bpm from 12250'- 12550' across open perf interval. Re-drift from 12000' - 12550'. Begin logging up and overpull at 11775'ctm, work free w/out pumping, looks like minimal fill. Continue F&S at 1.5bpm from 11400' to 12350'ctm. ***Continue on 7-31-25*** 7/31/2025 LRS CTU #1 1.50"CT 0.134"WT HT-110 Job Objective: Drift/Log, Set CIBP and Perf F&S from 11400' to 12350', Re-drift clean from 11,300' to 12550'. Log interval 12550- 10250'ctm. Paint white flag at 12210.08'ctm. POOH top filling 1% KCL w/ safelube. +8' correction of the log. MU NS 2-7/8" CIBP, RIH, correlate at the flag to COE. Set CIBP 12260' COE. Set weight on plug. POOH. Setting tool looks good. Standby for HES TCP to finish retrieving guns on CDR-2. RIH w/ 2.0"x20' MaxForce 6spf 60degree phasing 7gr perf guns, correlate to the flag to bottom shot. Perf interval 12195'-12215'. POOH. ***Continue on 8-01-25 WSR*** 8/1/2025 LRS CTU #1 1.50"CT 0.134"WT HT-110 Job Objective: Drift/Log, Set CIBP and Perf Continue POOH w, HES perf gun. All shots in scallop. Well left w/o freeze protect per pad-op. RDMO. ***Job Complete*** Daily Report of Well Operations PBU B-30B 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: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -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: 06/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU B-30B PTD: 225-009 API: 50-029-21542-02-00 FINAL LWD FORMATION EVALUATION LOGS (03/22/2025 to 03/31/2025) 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. 225-009 T40361 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.07 14:59:52 -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 North Slope, LLC 3800 Centerpoint, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay, Prudhoe Oil, PBU B-30B Hilcorp North Slope, LLC Permit to Drill Number: 22-009 Surface Location: 619’ FNL, 1894’ FEL, Sec. 31, T11N, R14E, UM, AK Bottomhole Location: 393’ FSL, 1450’ FWL, Sec. 30, T11N, R14E, 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 3rd day of March, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.03 09:16:39 -09'00' Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.30 14:20:09 - 09'00' Sean McLaughlin (4311) By Grace Christianson at 3:31 pm, Jan 30, 2025 Witnessed BOP Test to 3500 psi. Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well with fully cemented liner on upcoming sidetrack. Variance to 20 AAC 25.036 (c)(2)(A)(iv) approved with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. Post rig service coil perforating approved for BHA length < 500'. 50-029-21542-02-00 JJL 2/25/25 225-009 A.Dewhurst 20FEB25 DSR-1/31/25*&: 3/3/2025 3/3/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.03 09:16:54 -09'00' RBDMS JSB 030425 WELL NAME: 19. Setting Depth MD Setting Depth TVD Casing Length Size Top Bottom Top Bottom Cement Volume Liner 1890 5-1/2"x4-1/2" 8955 10845 8187 9010 102 Bbls Class G Liner 2457 3-3/16"x2-7/8" 10412 12859 8910 9037 24 Bbls Class G Attachment - Present Well Condition Summary (for Redrill Operations) PBU B-30A To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: January 30, 2025 Re:B-30B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well B-30 with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for B-30B Producer: See B-30A Sundry request for complete pre-rig details - Slickline will run a whipstock drift. E-line will set a 4-1/2" whipstock. If unable to set the whipstock, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" whipstock. A dual string 3.80" window + 10' of formation will be milled. The well will kick off drilling Ivishak Zone 4. The lateral will continue in Zone 4, 3 and 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 Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference B-30 Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift, set DMGLV's, & caliper liner across whipstock target depth(Send caliper data to ODE and Whipstock Vendor) 2. E-Line : Set 4-1/2" Baker Whipstock TOWS at 9615' @ 180 deg ROHS 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in March 18, 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,451 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” - 4-1/2"x7" Dual String Window. 3. Drill build section: 4.25" OH, ~712' (26 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2252' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 36 bbls, 14.8 ppg Class G (1.33 ft3/sk yeild), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Liner Lap test, Post rig RPM (rush process), CBL, Perforate ~40' of 2" guns 3. Slickline : Contingent LTP set (dependent on Liner lap test) & set GLV's 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 (9640' MD -8,614' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,390 psi 4,390 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ-;ƉƐŝͬŌͿ 578 psi 0 psi 0.06 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,852 psi 3,852 psi 8.6 B+C Mud + ECD Combined 4,431 psi 3,852 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain -41 psi 538 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,331 psi at 8,800 TVD. (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,451 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 : 9,615' MD – 9,635' MD (20' liner) x 3-1/4", 6.6#, 13Cr : 9,635' MD – 10,400' MD (765' liner) x 2-7/8", 6.5#, 13Cr : 10,400' MD – 12,604' MD (2,204' 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” safety joint including a TIW valve for all tubulars ran in hole. x 2” safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre- installed TIW valve). When closing on a 2” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. x Request variance to 20 AC 25.036(c)(2)(A)(iv) to deploy tubulars < 2.375” OD without properly sized pipe rams. x 2” safety joint will be utilized while running 1” / 1-1/4” CS hydril. x Blind/Shear rams will be utilized in place of pipe rams sized for CTD jointed pipe operations as a worst- case shut-in scenario (in place 1” / 1-1/4” CS hydril pipe rams). x The well will be full of KWF prior to running liner or jointed pipe operations. x The BHA will be circulated out of hole prior to laying down BHA for jointed pipe operations. x The well will be flow checked after laying in KWF, before laying down BHA and before making jointed pipe. Directional: x Directional plan attached. Maximum planned hole angle is 110°. Inclination at kick off point is 60°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 22,700 ft x Distance to nearest well within pool – 950 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 40' (estimated)' perforated post rig – See attached extended perforating procedure. x 2" Perf Guns at 6 spf x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or post rig under this PTD. x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Prudhoe Pool. x Formations: Top of Prudhoe Pool at 9339’ MD in the parent Anti-Collision Failures: x The B-30B WP04 wellpath fails anti-collision with B-03A and B-03BPB1. The B-03A and B-03BPB1 laterals were abandoned as part of drilling the B-03B wellbore. Hazards: x DS/Pad is an H2S pad. The last H2S reading on B-30: 21 ppm on 01/17/2025. x Max H2S recorded on DS/Pad: 160 ppm.. x 0 fault crossings expected. x Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) 9,399' Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram $)$) $) $) $) $) !! !!! ! !! !!! !!! !! ! !! !!!!!! !!!!! !! !! ! D $) Prudhoe Bay Unit ADL28310 B-03 B-03A B-08A B-15 B-18 C-28B Sec. 31 (607) Sec. 30 (604) U011N014E B PAD PLAN: B-30B_SHL PLAN: B-30B_TPH PLAN: B-30B_BHL Map Date: 4/24/2024 Prudhoe Bay Unit B-30B Well wp04 E0 410 820Feet Legend $)PLAN: B-30B_BHL !PLAN: B-30B_SHL D PLAN: B-30B_TPH $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint Oil and Gas Unit Boundary CO - 341J AIO_3C Well located within PA - IPA Document Path: O:\AWS\GIS\Products\Alaska\NS\Wells\TRS_Distance\mxds\2024\NorthSlope_PBU_B-30B_wp04.mxd 500100015002000250030003500South(-)/North(+) (1000 usft/in)-3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West(-)/East(+) (1000 usft/in)9040C-28B40004400B-07A B -0 7 B-2 8 48005200B -0 4 56 0 0 B -2 0 4800520056006000640068007200760080008400880092009272B-03B-27400044004800520056006000640068007200760080008400880092009273B-0888009 0 79 B -08A 68007200760080008 4 0 0880092009247 B-18 44004800520056006000640068007200760080008400880092009257B-03A84008800B-03B9140B-03BPB156006000640068007200760080008400880092009234B-198800B-19A440048005200560060006400680072007600800084008800B-308 8 0 0 9011B-30B wp04Top of Window - 9640'MDEnd 26dls - 10352'MDTD - 12604'MD850086008700880089009000True Vertical Depth (200 usft/in)-3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 Vertical Section at 200.00° (400 usft/in)B-30 B-30B wp04Top of Window - 9640'MDEnd 26dls - 10352'MDTD - 12604'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 9640.00 58.27 353.94 8614.36 3174.19 -1062.71 0.00 0.00 -2619.292 9660.00 56.47 353.94 8625.15 3190.94 -1064.48 9.00 -180.00 -2634.423 9730.00 38.27 353.94 8672.36 3241.93 -1069.90 26.00 -180.00 -2680.494 10105.00 66.78 134.59 8968.73 3234.57 -921.86 26.00 144.00 -2724.215 10351.71 90.00 196.25 9023.17 3012.93 -870.13 26.00 78.00 -2533.626 10529.57 110.00 203.87 8992.39 2849.23 -929.53 12.00 20.00 -2359.487 10635.00 110.00 190.40 8956.34 2754.77 -958.65 12.00 -90.00 -2260.768 10815.00 110.00 213.39 8894.77 2598.88 -1021.31 12.00 90.00 -2092.849 10970.00 110.00 193.60 8841.76 2465.96 -1079.08 12.00 -90.00 -1948.1810 11115.00 110.00 212.11 8792.17 2340.95 -1131.78 12.00 90.00 -1812.6911 11265.00 110.00 192.96 8740.86 2211.37 -1185.55 12.00 -90.00 -1672.5212 11441.44 90.00 200.05 8710.34 2045.82 -1234.95 12.00 160.00 -1500.0613 11583.59 74.00 206.04 8730.08 1916.72 -1289.72 12.00 160.00 -1360.0214 11704.00 74.00 191.09 8763.27 1807.31 -1326.47 11.94 -90.00 -1244.6315 11884.00 74.00 213.45 8812.88 1648.20 -1391.63 11.94 90.00 -1072.8416 12064.00 74.00 191.09 8862.50 1489.09 -1456.78 11.94 -90.00 -901.0417 12244.00 74.00 213.45 8912.11 1329.98 -1521.93 11.94 90.00 -729.2418 12424.00 74.00 191.09 8961.73 1170.87 -1587.08 11.94 -90.00 -557.4519 12604.00 74.00 213.45 9011.34 1011.76 -1652.23 11.94 90.00 -385.65Project: Prudhoe BaySite: BWell: B-30Wellbore: PLAN: B-30BPlan: B-30B wp04WELLBORE DETAILSParent Wellbore:B-30Top of Window: 9640.00B-30B wp04Depth From Depth To Survey/Plan Tool102.30 9640.00 B-30 Srvy 1 GCT-MS (B-30) 3_Gyro-CT_pre-1998_Csg19640.00 12604.00 B-30B wp04 (PLAN: B-30B) 3_MWDWELL DETAILSNorthing: 5950025.00Easting: 663737.00Lattitude: 70° 16' 11.3758 NLongitude: 148° 40' 32.7775 WB-30B wp04SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well B-30, True NorthVertical (TVD) Reference: KB @ 82.33usft (B-30)Measured Depth Reference: KB @ 82.33usft (B-30)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !""# $ " % & # ' " # ( )*+ ( , ,- .# /$ !!" #$%&'()* +0+, +--. / 0- /+ (#$%&'()* % $ ( 1 0 / ' 1 +' & / 2 '+'2 34&5)-6 * .34&5) .772* 280-.0 0- 9, " 2:1( 2:: ( 3 ' " " 0 4 % $0 50 1# .0 0333, ( ( ( ;3'& < = 4,> ,,'&& >>& 4,'= ' 5;3=?>',5= 3,%;,3?&&'%,&51 , , " 0 " 50 % $0 ( 657, 6%7 4 ( ( (1 ". 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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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 3-1/8" Pipe / Slip Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PRUDHOE OIL 225-009 PRUDHOE BAY PBU B-30B WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT B-30BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposaPTD#:2250090PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL0283102 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 NA15 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 pitYes25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes Do not have BOPs for CS Hydril, CoA WC Drills w/ safety joint29 BOPEs, do they meet regulationYes30 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 The last H2S reading on B-30: 21 ppm on 01/17/202533 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No B-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure gradient is 7.3 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)ApprADDDate2/20/2025ApprJJLDate2/28/2025ApprADDDate2/20/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 3/3/2025