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Home My WebLink About225-099Nolan 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: 12/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 05-04A 50029201520100 196089 10/30/2025 BAKER RPM PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey END 1-55 50029217880000 188021 11/26/2025 READ PressTempSurvey END 1-57 50029218730000 188114 11/18/2025 READ CaliperSurvey END 1-63 50029219050000 189006 11/23/2025 READ PressTempSurvey END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey END 2-20 50029220480000 190060 11/24/2025 READ PressTempSurvey END 2-32 50029220840000 190119 11/30/2025 READ PressTempSurvey END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey NCI A-13 50883200870000 192106 11/27/2025 READ Caliper Survey NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Please include current contact information if different from above. T41175 T41176 T41177 T41178 T41179 T41180 T41181 T41182 T41183 T41184 T41185 T41186 T41187 PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.05 11:03:29 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -09'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 11/25/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU F-18B PTD: 225-099 API: 50-029-20636-02-00 FINAL LWD FORMATION EVALUATION LOGS (10/23/2025 to 10/29/2025) 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. 225-099 T41169 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.25 10:33:07 -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 F-18B Hilcorp Alaska, LLC Permit to Drill Number: 225-099 Surface Location: 2955' FNL, 2195' FEL, Sec 02, T11N, R13E, UM, AK Bottomhole Location: 1871' FSL, 1077' FWL, Sec 36, T12N, R13E, UM, AK Dear Mr. McLaughlin: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCCreserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, *UHJRU\ &. :LOVRQ Commissioner DATED this 25th day of September 2025. Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.25 14:18:45 -08'00' RUSH 225-099 By Gavin Gluyas at 1:45 pm, Sep 23, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.09.23 13:28:01 - 08'00' Sean McLaughlin (4311) *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. TS 9/24/25 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. 50-029-20636-02-00 JJL 9/24/25 DSR-9/23/25JLC 9/25/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.25 14:18:22 -08'00' 09/25/25 09/25/25 RBDMS JSB 092925 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 23, 2025 Re:F-18B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well F-18A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for F-18B Producer: See F-18A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and caliper. Coil will lay in a cement plug in slotted liner for drilling losses. E-line will set a 3- 1/2"x4-1/2" 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 whipstock and mill a single string 2.80" window + 10' of formation. The well will kick off drilling in the Sag and lands in Ivishak Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x2-3/8” 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 F-18A Sundry submitted in concert with this request for full details. 1. Coil : Lay cement plug in slotted liner (~ 30 bbls of Class G cement or similar) to help minimize drilling losses. Estimated TOC @ 10,800'. 2. SL : Drift for whipstock 3. E-Line : Set 3-1/2"X4-1/2" Whipstock at 10,760’ MD at 180 degrees ROHS (if unable to set with Eline, set with rig) 4. Coil : Mill 2.80" Single String 4-1/2" Window (if window not possible, mill with rig). 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in October 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,346 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.80” Single String 4-1/2" Window (if not already done pre-rig) 3. Drill production lateral: 3.25" OH, ~2,049' (12 deg DLS planned). Swap to KWF for liner. 4. Run 3-1/2” 2-3/8” 13Cr solid liner 5. Pump primary cement job*: 19.6 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). 6. Only if not able to do with service coil extended perf post rig – Perforate Liner 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. Post Rig Work: 1. Coil : Liner Lap, RPM/CBL/Perforate ~30' 2. Slickline : Set KO GLV design, contingent LTP Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3”/3-1/8” (big hole) & 2-3/8” (slim hole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (10,760' MD -8,775' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,472 psi 4,472 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ-;ƉƐŝͬŌͿ 377 psi 0 psi 0.035 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,924 psi 3,924 psi 8.6 B+C Mud + ECD Combined 4,301 psi 3,924 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 171 psi 548 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,226 psi at 8,800 TVD. (7 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,346 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 3-1/2", 9.3#, 13Cr/Solid: 10,480' MD – 10,515' MD (35' liner) x 2-3/8", 4.6#, 13Cr/Solid: 10,515' MD – 12,809' MD (2,294' 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" safety joint including a TIW valve for all tubulars ran in hole. x 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" 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 108°. Inclination at kick off point is 74°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 6,015 ft x Distance to nearest well within pool – 920 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 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 10,692’ MD in the parent Anti-Collision Failures: x All Wells Pass AC scan Hazards: x DS/Pad is an H2S pad. The last H2S reading on F-18A: 10 ppm on 4/9/2021. x Max H2S recorded on DS/Pad: 160 ppm. x 0 fault crossings expected. x Low 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 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 % 3UXGKRH%D\8QLW $'/ $'/ 6HF6HF 6HF 6HF 6HF 6HF81( 81( )3$' 2LO5LP3$ )%B6+/ )%B73+ )%B%+/ )% /HJHQG )%B%+/ )%B6+/ %)%B73+ 2WKHU6XUIDFH+ROHV6+/ 2WKHU%RWWRP+ROHV%+/ 2WKHU:HOO3DWKV 3DG)RRWSULQW 2LODQG*DV8QLW%RXQGDU\ 3DUWLFLSDWLQJ$UHD%RXQGDU\ $,2& &2- Map Date: 5/6/2025 )HHW 'RFXPHQW3DWK2?$:6?*,6?'URSER[?-XOLHDQQD3RWWHU?3URMHFWB+DQGRII?3URMHFWB+DQGRIIDSU[NAD 1927 StatePlane Alaska 4 FIPS 5004 3UXGKRH%D\8QLW )%:HOO ZS u 8600870088008900900091009200True Vertical Depth (200 usft/in)1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 Vertical Section at 90.00° (400 usft/in)F-18AF-18B wp01Top of Window - 10760'MDTD - 12809'MDF-18B wp01350040004500500055006000South(-)/North(+) (1000 usft/in)500 1000 1500 2000 2500 3000 3500 4000 West(-)/East(+) (1000 usft/in)9032E-29A8800 F-05B720076008000840 08 80 0 9 2 0 0 9 35 0 F-0588009173F-05A60006400680072007600800084008800F-1864006800720076008000840088008798F-18A800084008800F-19B560060006400680072007600F-19640068007200F-19A88 008844 F-33A84 0 0 88008900 F-33APB188008777F-34C76008000840088009083F-34B760080008400880092009311F-348800F-34A76008000840088008988F-34APB1680072007600800084008 8 0 0F-359113F-35A88009154F-18B wp01Top of Window - 10760'MDTD - 12809'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 10760.00 74.24 47.90 8774.97 4711.48 1459.54 0.00 0.00 1459.542 10780.00 72.44 47.90 8780.70 4724.33 1473.75 9.00 180.00 1473.753 10880.00 60.44 47.90 8820.60 4785.68 1541.64 12.00 180.00 1541.644 11088.50 43.21 71.29 8950.07 4870.72 1678.71 12.00 140.00 1678.715 11493.19 90.00 86.15 9107.07 4932.49 2033.31 12.00 20.00 2033.316 11653.19 108.00 92.94 9082.11 4933.98 2190.58 12.00 20.00 2190.587 11759.00 108.00 106.29 9049.42 4917.20 2289.57 12.00 90.00 2289.578 11939.00 108.00 83.58 8993.79 4902.57 2459.02 12.00 -90.00 2459.029 12049.00 108.00 97.46 8959.80 4901.63 2563.37 12.00 90.00 2563.3710 12207.95 90.00 91.04 8935.01 4890.26 2719.22 12.00 -160.00 2719.2211 12448.69 63.00 101.73 8990.85 4865.74 2949.49 12.00 160.00 2949.4912 12554.00 63.00 87.54 9038.66 4858.18 3042.77 12.00 -90.00 3042.7713 12694.00 63.00 106.40 9102.22 4843.10 3166.03 12.00 90.00 3166.0314 12809.00 63.00 90.91 9154.43 4827.72 3267.02 12.00 -90.00 3267.02Depth From Depth To Survey/Plan Tool100.00 6475.00 F-18A GyroData Gyro (F-18) 3_Gyro-CT_Drill pipe6500.00 10433.00 F-18A Srvy 5 GYD-CT-CMS (F-18A) 3_Gyro-CT_Drill pipe10582.85 10606.89 F-18A Srvy 3 MWD+IFR+MS (F-18A) 3_MWD (BP MWD+IFR+MS-WOCA)10675.89 10760.00 F-18A Srvy 4 MWD+IFR+MS (F-18A) 3_MWD (BP MWD+IFR+MS-WOCA)10760.00 12809.00 F-18B wp01 (F-18B) 3_MWDSECTION DETAILSSURVEY PROGRAMProject: Prudhoe BaySite: FWell: F-18Wellbore: F-18BPlan: F-18B wp01REFERENCE INFORMATIONCoordinate(N/E) Reference: Well F-18, True NorthVertical (TVD) Reference: KB @ 65.20usft (F-18A)Measured Depth Reference: KB @ 65.20usft (F-18A)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureParent Wellbore: F-18ATop of Window: 10760.00Northing: 5973858.63Easting: 652648.89Lattitude: 70° 20' 8.0391 NLongitude: 148° 45' 41.3911 WNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04REFERENCE INFORMATIONWELLBORE DETAILSWELL DETAILSHilcorp Alaska, LLCPROJECT DETAILSF-18B wp01 !!" #$ % & " % ! " ' ()* ' + + #,%"# -$ ! 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ell 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 nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" 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 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. PBU F-18B PRUDHOE OILPRUDHOE BAY 225-099 WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT F-18BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250990Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL028280, ADL0282772 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 pitYes *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug with fully cemented sidetrack liner25 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 *Variance to 20 AAC 25.036 (c)(2)(A)(iv) with compliance to rules 29 BOPEs, do they meet regulationYes 5K30 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 F-18A: 10 ppm on 4/9/2021.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No F-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure range is 0.364 psi/ft (7 ppg EMW), MPD will be utilized.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]ApprTCSDate9/24/2025ApprJJLDate9/24/2025ApprTCSDate9/24/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 9/25/2025