The URL can be used to link to this page

Home My WebLink About225-072David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 09/24/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: Well: PBU W-35APH1 PTD: 225-072 API: 50-029-21799-01-00 FINAL LWD FORMATION EVALUATION LOGS (08/16/2025 to 09/01/2025) x BaseStar and DGR Gamma Ray, EWR-P4 and StrataStar Resistivity, ALD, CTN x Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer – Main Folders: Please include current contact information if different from above. 225-072 T40923 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.24 14:38:57 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PBU W-35A (PTD# 225-072) 9-5/8" Intermediate Casing CBL Date:Monday, September 22, 2025 9:38:06 AM Attachments:PBU W-35A Radial Cement Bond Log 9-17-2025.pdf PBU W-35A Approved 10-401 8-8-25.pdf PBU W-35APH1 9.625 Csg test-FIT 8-26-25.pdf From: Tyson Shriver <tyson.shriver@hilcorp.com> Sent: Thursday, September 18, 2025 7:22 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Engel <jengel@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PBU W-35A (PTD# 225-072) 9-5/8" Intermediate Casing CBL Jack, Please see the attached CBL for the 9-5/8” intermediate casing on PBU W-35A (PTD# 225-072). The 9-5/8” intermediate cement job was completed 8/24/2025. A total of 12 bbls were lost during the job but good lift pressure was observed. Log results show TOC greater than 250’ TVD above the top of pool through the confining interval. I have also attached the approved PTD, 9-5/8” casing test and FIT for quick reference. Let me know if you need anything additional. Thank you, Tyson Shriver Hilcorp Alaska PBU GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 delete this 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. CASING AND LEAK-OFF FRACTURE TESTS Well Name:PPB W W -35APH1 Date:8/26/2024 Csg Size/Wt/Grade:9.625" 40# L -80 Supervisor:Mo n tag u e/Menapac e Csg Setting Depth:8,048 TMD 4963 TVD Mud Weight:9.2 ppg LOT / FIT Press =753 psi LOT / FIT =12.12 ppg Hole Depth =8076 md Fluid Pumped=1.7 Bbls Volume Back =1.7 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here HHere Here HHere ->00 ->00 ->380 ->10 187 ->6 159 ->20 429 ->9 254 ->30 799 ->12 355 ->40 1083 ->15 455 ->50 1388 ->18 535 ->60 1703 ->21 607 ->70 2041 ->24 672 ->80 2369 ->27 753 ->90 2685 -> ->91 2705 -> -> -> -> -> -> Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 753 ->0 2705 ->1 717 ->1 2695 ->2 702 ->2 2690 ->3 688 ->3 2685 ->4 675 ->4 2680 ->5 664 ->5 2678 ->6 653 ->10 2667 ->7 643 ->15 2661 ->8 633 ->20 2658 ->9 625 ->25 2653 ->10 617 ->30 2650 -> -> -> -> -> -> 0 3 6 9 12 15 18 21 24 27 0 10 20 30 40 50 60 70 80 9091 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 102030405060708090100Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 753717702688675664653643633625617 270526952690268526802678 2667 2661 2658 2653 2650 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT W-35APH1 JBR 10/27/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 4.5", 5" and 7" test joints used for testing. The manual choke valve failed and was serviced for a fail on the retest. The valve was rebuilt and passed. 20 precharge bottles ranging from 1000 to 1100 psi. Test Results TEST DATA Rig Rep:J. Sture/E. EvansOperator:Hilcorp North Slope, LLC Operator Rep:J. Lott/D. Pickworth Rig Owner/Rig No.:Hilcorp Innovation PTD#:2250720 DATE:9/5/2025 Type Operation:DRILL Annular: 250/3000Type Test:BIWKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopGDC250907111622 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9.5 MASP: 1692 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8" x 5.5" P #2 Rams 1 Blinds P #3 Rams 1 7" solids P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 FP HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1500 200 PSI Attained P29 Full Pressure Attained P100 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2258 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P11 #1 Rams P9 #2 Rams P9 #3 Rams P9 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1        CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PBU W-35APH1 (PTD: 225-072) 9-5/8" Casing Test & FIT Date:Tuesday, August 26, 2025 4:44:26 PM Attachments:PBU W-35APH1 9.625 Csg test-FIT 8-26-25.pdf From: Joseph Engel <jengel@hilcorp.com> Sent: Tuesday, August 26, 2025 4:35 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU W-35APH1 (PTD: 225-072) 9-5/8" Casing Test & FIT Jack – Attached is the casing test and FIT for the 9-5/8” casing on W-35APH1. 9-5/8” cement job went well, we pumped 210bbls of 12# lead and 183bbls of 15.8# tail and only saw ~12 bbls of losses throughout the entire job (pumping cement and displacement). -Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CASING AND LEAK-OFF FRACTURE TESTS Well Name:PPB W W -35APH1 Date:8/26/2024 Csg Size/Wt/Grade:9.625" 40# L -80 Supervisor:Mo n tag u e/Menapac e Csg Setting Depth:8,048 TMD 4963 TVD Mud Weight:9.2 ppg LOT / FIT Press =753 psi LOT / FIT =12.12 ppg Hole Depth =8076 md Fluid Pumped=1.7 Bbls Volume Back =1.7 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here HHere Here HHere ->00 ->00 ->380 ->10 187 ->6 159 ->20 429 ->9 254 ->30 799 ->12 355 ->40 1083 ->15 455 ->50 1388 ->18 535 ->60 1703 ->21 607 ->70 2041 ->24 672 ->80 2369 ->27 753 ->90 2685 -> ->91 2705 -> -> -> -> -> -> Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 753 ->0 2705 ->1 717 ->1 2695 ->2 702 ->2 2690 ->3 688 ->3 2685 ->4 675 ->4 2680 ->5 664 ->5 2678 ->6 653 ->10 2667 ->7 643 ->15 2661 ->8 633 ->20 2658 ->9 625 ->25 2653 ->10 617 ->30 2650 -> -> -> -> -> -> 0 3 6 9 12 15 18 21 24 27 0 10 20 30 40 50 60 70 80 9091 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 102030405060708090100Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 753717702688675664653643633625617 270526952690268526802678 2667 2661 2658 2653 2650 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PBU W-35APH1 (PTD: 225-072) 13-3/8" Casing Test & FIT Date:Monday, August 18, 2025 8:26:05 AM Attachments:PBU W-35APH1 13.375 Csg test-FIT 8-17-25.pdf From: Joseph Engel <jengel@hilcorp.com> Sent: Sunday, August 17, 2025 2:07 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU W-35APH1 (PTD: 225-072) 13-3/8" Casing Test & FIT Jack – Attached is the 13-3/8” casing test and window FIT for W-35APH1. Thanks. Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 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. CASING AND LEAK-OFF FRACTURE TESTS Well Name:PPBW W-35APH1 Date:88/17/2024 Csg Size/Wt/Grade:113.375" 68# L -80 Supervisor:L o tt/Men ap ace Csg Setting Depth:1,858 TMD 1858 TVD Mud Weight:9.5 ppg LOT / FIT Press =224 psi LOT / FIT =11.82 p pg Hole Depth =1878 md Fluid Pumped=0.4 Bbls Volume Back =0.3 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here HHere Here HHere ->019 ->046 ->248 ->5 108 ->3 100 ->10 301 ->4 135 ->15 579 ->5 168 ->20 886 ->6 202 ->25 1238 ->7 224 ->30 1596 -> ->35 1978 -> ->37 2157 -> -> -> -> -> -> -> -> -> -> Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 224 ->0 2157 ->1 173 ->1 2150 ->2 154 ->2 2146 ->3 144 ->3 2143 ->4 134 ->4 2138 ->5 130 ->5 2130 ->6 125 ->10 2125 ->7 120 ->15 2117 ->8 114 ->30 2114 ->9 111 -> ->10 109 -> -> -> -> -> -> -> 0 2 3 4 5 6 7 0 5 10 15 20 25 30 35 37 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 010203040Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 224 173154144134130125120114111109 215721502146214321382130 2125 2117 2114 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Unit Field, Schrader Bluff Oil, PBU W-35APH1 Hilcorp Alaska, LLC Permit to Drill Number: 225-072 Surface Location: 4029' FSL, 1451' FEL, Sec. 21, T11N, R12E, UM, AK Bottomhole Location: 1173' FNL, 396' FEL, Sec. 07, T11N, R12E, 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 8 WK day of August 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.08 11:27:56 -08'00' By Grace Christianson at 7:47 am, Jul 03, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.07.02 16:47:25 - 08'00' Sean McLaughlin (4311) 225-072 *AOGCC witnessed BOP test to 3000 psi, Annular to 2500 psi. *Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FITs. *W-241 shut in during production hole drilling. DSR-7/3/25JJL 7/18/25 50-029-21799-01-00 A.Dewhurst 08AUG25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.08 11:28:09 -08'00'08/08/25 08/08/25 RBDMS JSB 081225 56 87 161718 21 56 87 161718 21 CHEV181112 K071112PB1 K091112 MP00151112 W-02 W-03W-03A W W W-16 W-18 W-19 W-19B W-20 W-200 W-200PB1 W-204 W-204L1 W-21 W-213 W W W- W-22 W-23 W-24 W-25 W-26 W-27 W-29 W-30 W-31W-31A W-32 W-34 W-39W-40 W-42 W-44 W-51 W-56 W-59W-59PB1 WETW Z-03 Z-06 Z-100 Z-102 Z-103 Z-113PB1 Z-114 Z-115 Z-116 Z-19A Z-210 Z-210PB1 Z-34 5PB1 Z-39 Z-40 Z-50 Z-61 Z-65 Z-68 Z-69 Z-220PB1 Z-220 Z-228 Z-229 Z-222 Z-223 W-241 W-26B Z-234 Z-235 Z-235PB1 W-235 WP W-35A WP HILCORP NORTH SLOPE Greater Prudhoe Bay SCHRADER BLUFF W-35A Area of Review FEET 0 1,000 2,000 3,000 POSTED WELL DATA Well Label WELL SYMBOLS Location INJ Well (Water Flood) P&A Oil/Gas J&A Temporarily Abandoned Plugback Active Oil Injector Location Producer Location Shut in Injector REMARKS Quarter Mile Radius highlighted with well symbols posted at OBC top By: BTR May 22, 2025 PETRA 5/22/2025 2:42:00 PM This permit is for a pilot hole that will not be injecting. See PBU W-35A (PTD 225-076) for related injector and AOR. - A.Dewhurst 05AUG25 Well Name PTD API Distance / StatusTop of Oil Pool (SB OBc, MD)Top of Oil Pool (SB OBc, TVDss)Top of Cmt (MD)Top of Cmt (TVDss)Zonal IsolationCommentsPBU W-26 189-080 50-029-21964-00-001275' / Abandoned6392' 4933' 4974' 3892'ClosedSingle stage cement job, 9-5/8". Pumped 997 sx 13.5 ppg Class 'G' cement followed by 500 sx 15.6 ppg Class 'G' cement (total cement volume of 2398 cu ft). No losses reported. Plugs did not bump and cement was found inside the 9-5/8" casing at 11,201' MD. A USIT log run 9/18/1999 during an Ivishak rotary sidetrack shows the presence of cement up to the top of logged interval at 4974' MD. The 9-5/8" casing was later abandonded for a second sidetrack in 12/2022.PBU W-26B 222-151 50-029-21964-02-00567' / Producer8196' 4833' 6393' 4130'ClosedTwo stage cement job, 9-5/8". First stage pumped 281 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. No returns during first stage. ES Cementer opened at 2234' MD. Second stage cement job pumped 200 bbls 10.7 ppg ArcticCem followed by 58 bbls 15.8 ppg Class 'G' cement. No losses noted throughout second stage with a total of 200 bbls cement circulated to surface. CAST CBL 12/31/2022 shows first stage TOC at 6393' MD. Schrader Bluff OBd producer, not open to Schrader Bluff OBc.Passing MIT-IA to 3500 psi 1/8/2023.PBU W-241 222-154 50-029-23741-00-00175' / Injector7358' 4871' 6386' 4482'ClosedSingle stage cement job, 7". Pumped 47 bbls 15.8 ppg cement. No losses noted during job. Including shoe track volume, volumetric calculations place TOC in the 7" x 8-1/2" annulus at 6386' MD when accounting for 30% washout. Schrader Buff OBd injector, not open to Schrader Bluff OBc.Passing MIT-IA to 2321 psi 2/25/2023.PBU Z-223 222-080 50-029-23720-00-001318' / Injector6135' 4609' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 213 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. 10 bbls lost throughout first stage. ES Cementer opened at 2282' MD. 64 bbls of cement was circulated out to surface. Second stage cement job pumped 359 bbls 10.7 ppg ArcticCem followed by 56 bbls 15.8 ppg Type I/II cement. No losses noted throughout second stage with a total of 269 bbls cement circulated to surface. Schrader Bluff OBc injector.Passing MIT-IA to 3076 psi 10/6/2024.PBU Z-229 222-104 50-029-23726-00-001316' / Producer7360' 4770' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 290 bbls 12.0 ppg VariCem, followed by 82 bbls 15.8 ppg Type I/II cement. Full returns throughout first stage. ES Cementer opened at 2313' MD. 30 bbls of cement was circulated out to surface. Second stage cement job pumped 427 bbls 10.7 ppg ArcticCem followed by 54 bbls 15.8 ppg Class 'G' cement. No losses noted throughout second stage with a total of 330 bbls cement circulated to surface. Schrader Bluff OBc producer.Passing MIT-IA to 3500 psi 10/25/2022.PBU Z-235 223-055 50-029-23760-00-001547' / Injector7978' 4808' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 334 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. Full returns throughout first stage. ES Cementer opened at 2449' MD. 104 bbls of cement was circulated out to surface. Second stage cement job pumped 442 bbls 10.7 ppg ArcticCem followed by 56 bbls 15.8 ppg Type I/II cement. No losses noted throughout second stage with a total of 248 bbls cement circulated to surface. Schrader Bluff OBc injector.Passing MIT-IA to 2430 psi 9/11/2023.Area of Review PBU W-35AThis permit is for a pilot hole that will not be injecting. See PBU W-35A (PTD 225-076) for related injector and AOR.-A.Dewhurst 05AUG25 26 June 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill Hilcorp North Slope, LLC W-35APH1 Dear Sir/Madam, Hilcorp North Slope, LLC hereby applies for a Permit to Drill an onshore pilot hole injector well from the W Pad in Prudhoe Bay, Alaska. W-35APH1 is planned to be a lateral well targeting the Schrader Bluff Sands. The parent bore, W-35 will be reservoir abandoned on a prior sundry. The approximate spud date is anticipated to be August 5th, 2025, pending rig schedule. The Innovation rig will be used to drill this well. The directional plan is a two-hole section sidetrack. A 12-1/4” intermediate hole exiting the 13-3/8” casing at ~1830’ MD drilled into the Schrader Bluff OBc, with 9-5/8” casing ran and cemented. A 6-1/8” lateral will be initiated in the OBc sand and then directionally drilled to complete W-35APH1 by drilling to confirm Schrader Bluff Sands, with a TD staying within the Orion pool. After drilling the W-35APH1 profile, the well will be open hole sidetracked to finish the W-35A Schrader Bluff OBc lateral. A 4-1/2” cemented liner will be run in the open hole section, followed by 4-1/2” tubing. PH1 will be isolated by the cemented liner completion of W-35A. A separate Permit to Drill application will be submitted for the W-35A profile. Please find enclosed for your review Form 10-401 Permit to Drill with information as required by 20 AAC 25.005. If there are any questions, please contact me at (907)777-8395 or jengel@hilcorp.com. Respectfully, Joe Engel Senior Drilling Engineer Hilcorp North Slope, LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill 8.5" Lateral - JJL Prudhoe Bay Unit (PBU) W-35APH1 Version 1 6/25/2025 Prudhoe Bay W-35APH1 Table of Contents 1. Well Name ...................................................................................................................................... 3 2. Location Summary .......................................................................................................................... 3 3. Blowout Prevention Equipment Information ................................................................................. 4 4. Drilling Hazards Information........................................................................................................... 5 5. Procedure for Conducting Formation Integrity Tests ..................................................................... 6 6. Casing and Cementing Program ..................................................................................................... 6 7. Diverter System Information .......................................................................................................... 7 8. Drilling Fluid Program ..................................................................................................................... 7 9. Abnormally Pressured Formation Information .............................................................................. 8 10. Seismic Analysis ............................................................................................................................ 8 11. Seabed Condition Analysis............................................................................................................ 8 12. Evidence of Bonding ..................................................................................................................... 8 13. Proposed Drilling Program ........................................................................................................... 9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ................................................ 11 15. Proposed Variance Request........................................................................................................ 11 Attachment 1: Location & GIS Maps ................................................................................................ 12 Attachment 2: BOPE Equipment ...................................................................................................... 15 Attachment 3: Hole Section Hazards ................................................................................................ 17 Attachment 4: LOT / FIT Test Procedure .......................................................................................... 21 Attachment 5: Cement Summary ..................................................................................................... 22 Attachment 6: Prognosed Formation Tops ...................................................................................... 2 3 Attachment 7: Well Schematic ......................................................................................................... 24 Attachment 8: Formation Evaluation Program ................................................................................ 26 Attachment 9: Wellhead Diagram .................................................................................................... 27 Attachment 10: Management of Change ......................................................................................... 2 8 Attachment 11: Drill Pipe Specs ....................................................................................................... 29 Attachment 12: Kick Tolerance Calculations .................................................................................... 30 Attachment 13: Directional Plan ...................................................................................................... 33 Prudhoe Bay W-35APH1 As per 20 AAC 25.005 (c), an application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. 1. Well Name 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as W-35APH1. This will be a development production well. 2. Location Summary 20 AAC 25.005 (c) (2) A plat identifying the property and the property's owners and showing: (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth Location at Surface Reference to Government Section Lines 4,029' FSL, 1,451' FEL, Sec 21, T11N, R12E, UM, AK NAD 27 Coordinate System X: 611,789.02 Y: 5,959,002.08 Innovation Rig KB Elevation 26.5’ above GL Ground Level 53.2’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 1814' FSL, 275' FWL, Sec 16, T11N, R12E, UM, AK NAD 27 Coordinate System X: 608,182.7 Y: 5,962,013.9 Measured Depth, Rig KB (MD) 7900’ Total Vertical Depth, Rig KB (TVD) 4,966.3’ Total vertical Depth, Subsea (TVDSS) 4,886.7’ Location at Bottom of Productive Interval –W-35APH1 Reference to Government Section Lines 1173' FNL, 396' FEL, Sec 7, T11N, R12E, UM, AK NAD 27 Coordinate System X: 602,102.8 Y: 5,969,501.6 Measured Depth, Rig KB (MD) 18,113.5’ Total Vertical Depth, Rig KB (TVD) 4,570.7’ Total Vertical Depth, Subsea (TVDSS) 4,491.2’ Prudhoe Bay W-35APH1 (D) other information required by 20 AAC 25.050(b); 20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must: (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 1: Location Maps, Attachment 6: Formation Tops and Attachment 13: Directional Plan for further details. (2) for all wells within 200 feet of the proposed wellbore: (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The applicant is the only affected owner. 3. Blowout Prevention Equipment Information 20 AAC 25.005 (c) (3) A diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; BOP test frequency for W-35APH1 will be 7 days until window milling is initiated, afterwards 14- days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14-day BOP test period should not be requested. Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 12-1/4” & 8-1/2” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in bottom cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc. Initial Test: 250/3000 (Annular 2500 psi) Subsequent Tests: 250/3000 (Annular 2500 psi) Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are in the doghouse and on accumulator unit. Please refer to Attachment 2: BOPE Equipment for further details. Prudhoe Bay W-35APH1 4. Drilling Hazards Information 20 AAC 25.005 (c) (4) Information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure; 12-1/4” Intermediate Hole Pressure Data Maximum anticipated BHP 2,187 psi in the Schrader OBc at 4,891’ TVD Maximum surface pressure 1,692 psi from the Schrader OBc (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,000 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 12-1/4” 11.8 ppg EMW FIT after drilling 20’ of new hole outside of 13- 3/8” window If unable to achieve 11.8 ppg EMW, hole section will be drilled on diverter (PBU W-26B as precedent) 11.8 provides greater than 25bbl KT based on 9.3ppg MW 13-3/8” Casing Test 2,000 psi, chart for 30 min 8-1/2” Production Hole Pressure Data Maximum anticipated BHP 2,190 psi in the Schrader OBc at 4,977’ TVD Maximum surface pressure 1,692 psi from the Schrader OBc (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,000 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 8-1/2” hole 12.0 ppg EMW FIT after drilling 20’ of new hole outside of 9- 5/8” 12.0 provides greater than 25 bbl based on 9.3 ppg MW, 8.44 ppg pore pressure 9.5 ppg minimum to drill ahead, 10.5 EMW for drilling ECDs 9-5/8” Casing Test 2,500 psi, chart for 30 min (Test pressure driven by 50% of Casing Burst) (B) data on potential gas zones; and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please refer to Attachment 3: Hole Section Hazards *Note: Deleted this contingency per conversation with drilling engineer. Prudhoe Bay W-35APH1 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (c) (5) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment 4: LOT / FIT Test Procedure 6. Casing and Cementing Program 20 AAC 25.005 (c) (6) A complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perforated liner, or screen to be installed; Casing/Tubing Program Hole Size Tubular O.D. Tubular ID (in)Wt/Ft Grade Conn Length Top MD Bottom MD / TVD 12-1/4” 9-5/8” 8.835” 40# L-80 TXP 8,030’ Surface 8,030’ / 4,975’ 8.5” 7” 6.276” 26# L-80 H563 ~1,530 ~6,500 8,030’ / 4,975’ 4-1/2” Solid 3.958” 12.6# L-80 H563 ~12,426 ~8,030’ 20,456’ / 4,959’ Tubing 4-1/2” Solid 3.958” 12.6# L-80 JFEBear ~8,000 Surface ~8,000 / 4,973’ Please refer to Attachment 5: Cement Summary for further details. Prudhoe Bay W-35APH1 7. Diverter System Information 20 AAC 25.005 (c) (7) A diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Diverter system is not applicable to a sidetrack well. 8. Drilling Fluid Program 20 AAC 25.005 (c) (8) A drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Intermediate Hole Production Hole Mud Type LSND 3% KCl BaraDril-N Mud Properties: Mud Weight PV YP HPHT Fluid Loss pH MBT 8.8-9.5 ppg 15-30 25-45 < 11.0 8.5-9.0 < 8 8.8 – 9.5 ppg 15-25 15-30 < 11 9-10 <8 A diagram of drilling fluid system on Innovation is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033 Prudhoe Bay W-35APH1 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) (9) For an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A – Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis 20 AAC 25.005 (c) (10) For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A – Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis 20 AAC 25.005 (c) (11) For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); The W-35APH1 is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) (12) Evidence showing that the requirements of 20 AAC 25.025 have been met; Evidence of bonding for Hilcorp North Slope, LLC is on file with the Commission. Prudhoe Bay W-35APH1 13. Proposed Drilling Program 20 AAC 25.005 (c) (13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to W-35APH1 is listed below. Please refer to Attachments for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Completed Pre Rig Work 1. Reservoir was abandoned as per prior approved separate sundry 2. 4-1/2” tubing cut at ~4,000’ MD Proposed Drilling Program W-35APH1 1. MIRU Innovation Rig 2. Verify well is dead. Circulate KWF if needed 3. Set BPV, ND Tree, NU BOPE, test as per PTD a. AOGCC opportunity to witness, 3000psi, annular 2500psi 4. Pull BPV, MU landing joint and BOLDS 5. CBU with new 9.5ppg mud 6. Pull 4-1/2” tubing, pre rig cut ~ 4,000’ MD, confirm with OE 7. MU mechanical cutter, RIH and cut 9-5/8” at ~ 2000’ MD 8. POOH LD cutter 9. MU Spear, engage casing hanger, BOLDS 10. Pull 9-5/8” casing 11. MU 13-3/8” mill/scraper assembly, RIH to top of 9-5/8” cut 12. Displace well to 9.5ppg milling fluid 13. MU and RIH with 13-3/8” CIBP, set and test 2000 psi for 30 min 14. MU 13-3/8” whipstock assembly, RIH t/ ~ 1,830’ MD 15. Orient Whipstock with GWD, set anchor and shear off 16. Mill 13-3/8” window & 20’ of new hole 17. Pull milling assembly back into casing, RU and perform FIT to 11.8 ppg EMW a. If unable to achieve 11.5 ppg EMW, hole section will be drilled on diverter b. W-26B used a precedent, see Attachment 12 18. POOH and LD milling assembly, gauge mills a. If mills are under gauge, PU back up mills and dress of window 19. MU motor BHA, RIH, trip through window with pumps off and no rotary, drill to ~2500’MD. POOH. 20. MU 12-1/4” RSS BHA, TIH, trip through window with no pumps or rotary, trip to bottom. Displace well to drilling fluid, 9.3 ppg a. Install MPD RCD, to be used to monitor well conditions *Email digital FIT to AOGCC upon completion - JJL 10 Prudhoe Bay W-35APH1 21. Drill 12-1/4” hole to TD, in Schrader Obc called by geo 22. CBU and BROOH 23. POOH to window, pull BHA through window with no pumps or rotary, POOH and LD BHA 24. Run 9-5/8” long string to TD a. Circulate casing every ~ 2000’MD while RIH 25. Cement 9-5/8” casing as per cement program 26. Lay down landing joint and RILDS 27. Freeze protect 13-3/8” x 9-5/8” annulus 28. MU 8-1/2” cleanout assembly, TIH top of 9-5/8” shoe track 29. PT 9-5/8” casing to 2500 psi, chart test 30. Drill out 9-5/8” shoe track & 20’ of new hole 31. Pull back into 9-5/8” shoe, perform FIT t/ 12.0 ppg EMW 32. POOH, LD Cleanout BHA 33. MU 8-1/2” RSS BHA, RIH to bottom 34. Drill 8-1/2” lateral as per geologist to TD of the W-35APH1 directional plan a. Install MPD RCD to be used to monitor wellbore conditions during connections 35. BROOH to surface casing shoe 36. POOH LD BHA 37. RU and make up 4-1/2” OH P&A Kit a. Including ~2400’ of 4-1/2” sacrificial liner and OH packer 38. RIH with 4-1/2” OH P&A Kit to TD of W-35APH1 open hole a. Setting OH Packer at ~ 15,700’ MD i. OH packer to be set inside the OBc, top OBC ~15,761’ MD ii. This will isolate all lobes of Schrader Bluff sand drilled through in the pilot hole 39. Circulate Mud and perform cement job as per plan a. Cement to fill entire annular and inner capacity of the 8.5” OH x 4-1/2” Liner hole section 40. Inflate OH Packer and release running tool 41. CBU 42. POOH and LD Running tool 43. MU 8-1/2” RSS BHA, RIH to Bottom 44. Tag top of OH P&A Kit, ~ 15,700’ MD ___________________________________________________________________________ Transfer from W-35APH1 PTD to W-35A PTD (PTD 225-076) * Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FIT - JJL Prudhoe Bay W-35APH1 21. Drill 12-1/4” hole to TD, in Schrader Obc called by geo 22. CBU and BROOH 23. POOH to window, pull BHA through window with no pumps or rotary, POOH and LD BHA 24. Run 9-5/8” long string to TD a. Circulate casing every ~ 2000’MD while RIH 25. Cement 9-5/8” casing as per cement program 26. Lay down landing joint and RILDS 27. Freeze protect 13-3/8” x 9-5/8” annulus 28. MU 8-1/2” cleanout assembly, TIH top of 9-5/8” shoe track 29. PT 9-5/8” casing to 2500 psi, chart test 30. Drill out 9-5/8” shoe track & 20’ of new hole 31. Pull back into 9-5/8” shoe, perform FIT t/ 12.0 ppg EMW 32. POOH, LD Cleanout BHA 33. MU 8-1/2” RSS BHA, RIH to bottom 34. Drill 8-1/2” lateral as per geologist to TD of the W-35APH1 directional plan a. Install MPD RCD to be used to monitor wellbore conditions during connections ___________________________________________________________________________ Transfer from W-35APH1 PTD to W-35A PTD Superseded by revised procedure to cement open hole. -A.Dewhurst 08AUG25 (PTD 225-076) * Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FIT - JJL Prudhoe Bay W-35APH1 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) (14) A general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. All cuttings and mud generated during drilling operations will be hauled to Prudhoe G&I on Pad 4. Drilling mud and cuttings will be hauled offsite as it is generated via truck. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. 15. Proposed Variance Request Hilcorp would like to request a variance from 20 AAC 25.412.(b) which states: “A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone.” To effectively produce this fault block, the current well plan has the intermediate casing shoe landing at the OBc production interval at ~87 degrees inclination. To make the ball and rod we land to set the production packer slickline accessible, the X nipple in the tubing tail must be landed at less than 70 degrees inclination. The MD we currently have planned for 70 degrees is at ~6,900’ MD. The X-nipple below the production packer will be set at ~6,800’ MD / 4,770’ TVD and the production packer will be ~50’ MD above the X nipple which puts it at ~6,750’ MD / ~4750’ TVD. The intermediate casing shoe is planned at ~8030’ MD / ~4,974’ TVD which means the planned packer depth is ~1,280’ MD away. From a TVD standpoint, the production tubing packer is ~200’ TVD from the intermediate casing shoe. With the intermediate casing set in the Schrader Bluff sand, and the injection packer set inside the intermediate casing, injection fluids will be confined to the Schrader bluff sands. This variance request is not applicable to the pilot hole. See PBU W-35A PTD (225-076). -A.Dewhurst 08AUG25 Prudhoe Bay W-35APH1 Attachment 1: Location & GIS Maps Prudhoe Bay W-35APH1 Prudhoe Bay W-35APH1 Prudhoe Bay W-35APH1 Attachment 2: BOPE Equipment Innovation Rig BOPE Schematic Per 20 AAC 25.035(e)1.A For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) (iii) one annular type Prudhoe Bay W-35APH1 BOPE Configuration for each operation: Decomplete / Mill Window / Drill Intermediate / Run 9-5/8” Casing: x 13-5/8” Annular x UPR: 2-7/8” x 5-1/2” VBR x Blind Rams x LPR: 9-5/8” Solid Body Drill Production / Run 4-1/2” Liner & Completion: x 13-5/8” Annular x UPR: 2-7/8” x 5-1/2” VBR x Blind Rams x LPR: 7” solid body Innovation Rig Choke Manifold Schematic Prudhoe Bay W-35APH1 Attachment 3: Hole Section Hazards 12-1/4” Intermediate Hole Section Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates/Free Gas Gas hydrates have been seen on PBU W Pad. Be prepared for them. They have been reported between 1800’ and 3140’ TVD across Prudhoe. MW has been chosen based upon successful trouble free penetrations of offset wells. • Be prepared for gas hydrates o Keep mud temperature as cool as possible, Target 60-70*F o Dump and dilute as necessary to maintain temp, utilize cold water on the rig as well as cold premade mud on trucks ready o Drill through hydrate sands and quickly as possible, do not backream. Remember that hydrate gas behaves differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Isolate/dump contaminated fluid to remove hydrates from the system. Cretaceous Over Pressure: W-Pad does not have a history of over-pressure in the cretaceous interval (4500-5300’ TVD). However, as a precaution ensure MW is above 9.0. Be prepared while drilling this interval. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPM’s when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Wellbore stability (Permafrost, running sands and gravel) Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Maintain mud parameters and increase MW to combat running Prudhoe Bay W-35APH1 sands and gravel formations. Stuck pipe, wood chunks over shakers and other hole stability issues are specific to W pad. Be prepared and review Pad Data Sheet. Bad see pad data sheet Prudhoe Bay W-35APH1 8-1/2” Production Hole Section Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Prudhoe Bay W-35APH1 PBU W Pad has a history of H2S. Ensure detectors are tested and functioning. x AOGCC to be notified withing 24 hours if H2S is encountered more than 20 ppm during drilling operations x Rig will have fully functional automatic H2S detection equipment meeting the requirements of 20 AAC 25.066 x In the event H2S is detected, well work will be suspended and personnel evacuated until a detailed mitigation procured can be developed. Wells with over 100ppm H2S readings on W Pad: There are no wells with H2S 100ppm or greater Prudhoe Bay W-35APH1 Attachment 4: LOT / FIT Test Procedure Prudhoe Bay W-35APH1 Attachment 5: Cement Summary 9-5/8” Intermediate Casing Cement OH x CSG 12-1/4” OH x 9-5/8” Casing Basis Cement Vol Open hole volume + excess + 120’ ft shoe track TOC 500’ MD above SV1 (Top SV1: 3,228’ MD, TOC 2,728’ MD) (TOC Required is 500’ Above Ugnu MA, significant hydrocarbon zone) Lead TOC: 2,728’ MD Tail TOC: 5,647’ MD Total Cement Volume Spacer 60 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess, Lead & Tail System 12.0ppg Lead: 211.7 bbl, 1187 ft3, 505.4 sks - 2.35 cuft/sk 15.8ppg Tail: 181.6 bbls, 1018.8 ft3, 878.2 sks – 1.16 cuft/sk BHST 100 deg F Displacement (8,026’–120’) * .0758bpf = 599.3 bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 12-1/4" OH x 9-5/8" Casing (5,647-2,728') x 0.0558 bpf x 1.3 211.7 1187.6 Total Lead 211.7 1187.6 505.4 12-1/4" OH x 9-5/8" Casing (8,026-5,647') x 0.0558 bpf x 1.3 = 172.5 967.7 9-5/8" Shoetrack 120' x 0.0758 bpf = 9.1 51.0 Total Tail 181.6 1018.8 878.2LeadTail 23 Prudhoe Bay W-35APH1 8-1/2” OH P&A Kit OH x CSG 8.5” OH x 4-1/2” Liner Basis Cement Vol Open hole volume + excess + 4-1/2” capacity TOC ~15,700’ MD, Top of OH P&A Kit Total Cement Volume Spacer 30 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess, Single Slurry 15.8ppg Tail: 195.2 bbls, 1095 ft3, 944 sks – 1.16 cuft/sk BHST 100 deg F Displacement 15,700’ * .0171 (5” DP Capacity) = 268.47 bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 8-1/2" OH x 4-1/2" (18,114 - 15,700)' x 0.0505 bpf x 1.3 = 158.5 889.2 4-1/2" Liner Volume 2414' x 0.0152 bpf = 36.7 205.9 Total Tail 195.2 1095.1 944.0Tail Prudhoe Bay W-35APH1 Attachment 6: Prognosed Formation Tops All formations expected to be normally pressured. W Pad Permafrost is ~ 1,760’ TVD ANTICIPATED FORMATION TOPS & GEOHAZARDS Reference Plan: KOP 1,830 1,830 -1751 805 0.44 SV4 2,042 2,042 -1963 899 0.44 SV3 2,578 2,563 -2484 1,128 0.44 SV1 Gas Hydrates 3,228 3,078 -2999 1,354 0.44 Ugnu 4A Heavy Oil 3,962 3,442 -3362 1,514 0.44 UG3 Heavy Oil 4,675 3,776 -3697 1,662 0.44 Ugnu MA Heavy Oil 6,147 4,466 -4386 1,965 0.44 NB Water 6,626 4,688 -4608 2,063 0.44 OA Top Water 6,958 4,813 -4733 2,118 0.44 Oba Top Oil 7,123 4,860 -4781 2,139 0.44 Obc Top Oil 7,868 4,970 -4891 2,187 0.44 Obc Top Oil 15,761 4,935 -4855 2,171 0.44 Oba top Oil 16,248 4,832 -4752 2,126 0.44 OA top Oil/Water 16,576 4,762 -4682 2,095 0.44 NC Oil/Water 17,129 4,645 -4565 2,044 0.44 W-35A PH1 wp08 TOP NAME EXPECTED FLUID MD (FT) TVD (FT) TVDSS (FT) Est. Pressure Gradient Prudhoe Bay W-35APH1 Attachment 7: Well Schematic Post Sundry Schematic, Well Status When Rig Arrives _____________________________________________________________________________________ 8/7/2025 PROPOSED SCHEMATIC Prudhoe Bay Unit Well: PBU W-35APH1 Last Completed: TBD PTD: TBD OPEN HOLE / CEMENT DETAIL 42”8 cu yds Concrete 17-1/2”3844 cu ft Cold Set II 12-1/4"505 sks 12.0 ppg Lead, 878 sks 15.8 Tail 8-1/2”944 Sx Class G (Sacrificial Liner OH P&A) CASING DETAIL Size Type Wt / Grade / Conn ID Top Btm BPF 20"Conductor N/A Surface ~110’N/A 13-3/8"Surface 68 / L-80 / BTC 12.415 Surface ~1,830’0.1497 9-5/8”Intermediate 40 / L-80 / TXP 8.835 Surface ~8,030’0.0758 4-1/2”Sacrificial Liner 12.6/L-80/Vamtop 3.958 15,700 18,114 .0152 WELL INCLINATION DETAIL A KOP @ 1830’ 90° Hole Angle = @ 8,122’ MD TREE & WELLHEAD Tree Cameron 4-1/16" 5M w/ 4-1/16” 5M Cameron Wing Wellhead McEvoy 13-5/8” 5K w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-21799-01 Completion Date: TBD JEWELRY DETAIL No.Top MD*Item ID 1 ~15,700 OH P&A Packer 4.170” _____________________________________________________________________________________ Revised By: TJS 6/4/2025 PROPOSED SCHEMATIC Prudhoe Bay Unit Well: PBU W-35A Last Completed: TBD PTD: TBD OPEN HOLE / CEMENT DETAIL 42” 8 cu yds Concrete 17-1/2” 3844 cu ft Cold Set II 12-1/4" 505 sks 12.0 ppg Lead, 878 sks 15.8 Tail 8-1/2” 2759.5 sx 15 ppg SoluCem TD =20,456’ (MD) / TD =4,879’ (TVD) 4 20” Orig. KB Elev.: 79.52’ / GL Elev.: 53.2’ 8 3 13-3/8” window @ ~1,830’ MD 9-5/8” 1 See Liner DetailW-35APH1 15,500 – 18114’ MD 2 PBTD =20,200’ (MD) / PBTD =4,879’(TVD) 7 9 6 6 5 99999999999999999999999999 CASING DETAIL Size Type Wt / Grade / Conn ID Top Btm BPF 20" Conductor N/A Surface ~110’ N/A 13-3/8" Surface 68 / L-80 / BTC 12.415 Surface ~1,830’ 0.1497 9-5/8” Intermediate 40 / L-80 / TXP 8.835 Surface ~8,030’ 0.0758 7”x4-1/2” Liner 26 x 12.6 / L-80 / W563 3.958 ~6,500’ ~20,456’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / JFE Bear 3.958 Surface ~8,000’ 0.0152 WELL INCLINATION DETAIL A KOP @ 1830’ 90° Hole Angle = @ 8,122’ MD TREE & WELLHEAD Tree Cameron 4-1/16" 5M w/ 4-1/16” 5M Cameron Wing Wellhead McEvoy 13-5/8” 5K w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-21799-01 Completion Date: TBD JEWELRY DETAIL No. Top MD* Item ID 1 ~2,600 X Nipple 3.813” 2 ~6,490 7” x 9-5/8” Liner Hanger w/ Tieback Sleeve 6.160” 3 ~6,500 Liner Top Packer 6.180” 4 ~6,650 X Nipple 3.813” 5 ~6,700 Production Packer 3.865” 6 ~6,750 X Nipple 3.813” 7 ~8,000 WLEG 3.958” 8 ~8,030 7” x 4-1/2” XO 3.958” *All depths are approximate and are subject to change based on actual drilled depths. 4-1/2” Sliding Sleeve Liner Detail Size SPF Top (MD) Btm (MD) Type 4-1/2” SLV Sleeves Every 400’ NCS Sliding Sleeves Superseded by revised schematic. -A.Dewhurst 05AUG25 Prudhoe Bay W-35APH1 Attachment 8: Formation Evaluation Program 12-1/4” Intermediate Hole LWD Gamma Ray (including at-bit Gamma) Resistivity 8-1/2” Production Hole LWD Gamma Ray Resistivity Azimuthal Resistivity Density Neutron Mudlogging No mudlogging is planned. Prudhoe Bay W-35APH1 Attachment 9: Wellhead Diagram Prudhoe Bay W-35APH1 Attachment 10: Management of Change Prudhoe Bay W-35APH1 Attachment 11: Drill Pipe Specs Prudhoe Bay W-35APH1 Attachment 12: Kick Tolerance Calculations W-26B Intermediate Hole on Diverter 2021 Prudhoe Bay W-35APH1 Prudhoe Bay W-35APH1 Prudhoe Bay W-35APH1 Attachment 13: Directional Plan Intermediate Section Offset Wells with CF < 1.0: x W-35: This well is the parent bore for this sidetrack Production Section Offset Wells with CF < 1.0: x W-241/PB1: CF .9+, This well is a Schrader Bluff OBd lateral injector, separated from the OBc by silt, we will have geologic separation from the well. W-241 will be shut in during production hole drilling. o PB1 is a plugback with no casing/liner. Standard Proposal Report 16 June, 2025 Plan: W-35A PH1 wp08 Hilcorp North Slope, LLC Prudhoe Bay W Plan: W-35 Plan: W-35A PH1 150022503000375045005250True Vertical Depth (1500 usft/in)0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250Vertical Section at 300.00° (1500 usft/in)W-35A wp03 tgt02W-35A wp03 tgt011500200025003000350040004500500055006000W-3513-3/8" x 17 1/2" TOW9-5/8" x 12 1/4"8-1/2" Production Open Ho20002500300035004000450050005500600065007000750080008500 9000 9500 10000 10500 11 000 11 500 12000 12500 13000 13500 14000 14500 15000 15500 160 00 1 650 0 17 0 00 17500 18000 18114W-35A PH1 wp08Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TFEnd Dir : 1855' MD, 1854.98' TVDStart Dir 4.04º/100' : 1885' MD, 1884.96'TVDStart Dir 4.5º/100' : 2085' MD, 2083.64'TVDEnd Dir : 3361.67' MD, 3111.14' TVDStart Dir 3º/100' : 6448.14' MD, 4618.01'TVDEnd Dir : 7582.4' MD, 4944.1' TVDStart Dir 3º/100' : 7982.4' MD, 4972'TVDEnd Dir : 8121.73' MD, 4976.64' TVDStart Dir 1.5º/100' : 13621.74' MD, 4959.36'TVDEnd Dir : 13855.38' MD, 4959' TVDStart Dir 5º/100' : 15500' MD, 4959'TVDStart Dir 4.96º/100' : 15800.24' MD, 4926.96'TVDEnd Dir : 16550.24' MD, 4761.99' TVDStart Dir 5º/100' : 17178.52' MD, 4628.69'TVDEnd Dir : 17363.52' MD, 4604.17' TVDTotal Depth : 18113.52' MD, 4564.91' TVDSV4SV3SV1Ugnu 4AUG3Ugnu MANBOA TopOba TopObc TopHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: W-35Ground Level: 53.02+N/-S+E/-WNorthingEastingLatittudeLongitude0.000.005959002.08611789.02 70° 17' 49.0154 N 149° 5' 41.0699 WSURVEY PROGRAMDate: 2025-04-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool88.75 1830.00 W-35 Srvy 1 BOSS-GYRO (W-35) 3_Gyro-SR-GMS1830.00 2230.00 W-35A PH1 wp08 (Plan: W-35A PH1)GYD_Quest GWD2230.00 8026.00 W-35A PH1 wp08 (Plan: W-35A PH1)3_MWD+IFR2+MS+Sag8026.00 18113.52 W-35A PH1 wp08 (Plan: W-35A PH1)3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPathTVDssPath MDPath Formation2042.24 1962.72 2043.04 SV42563.48 2483.96 2590.64 SV33078.26 2998.74 3297.17 SV13441.91 3362.39 4039.18 Ugnu 4A3776.17 3696.65 4723.83 UG34465.55 4386.03 6135.86 Ugnu MA4687.70 4608.18 6598.26 NB4812.89 4733.37 6924.74 OA Top4860.49 4780.97 7085.89 Oba Top4970.45 4890.93 7960.18 Obc TopREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: W-35, True NorthVertical (TVD) Reference:W-35A planned RKB @ 79.52usftMeasured Depth Reference:W-35A planned RKB @ 79.52usftCalculation Method:Minimum CurvatureProject:Prudhoe BaySite:WWell:Plan: W-35Wellbore:Plan: W-35A PH1Design:W-35A PH1 wp08CASING DETAILSTVD TVDSS MD SizeName1830.08 1750.56 1830.10 13-3/8 13-3/8" x 17 1/2" TOW4974.54 4895.02 8026.00 9-5/8 9-5/8" x 12 1/4"4564.91 4485.39 18113.52 8-1/2 8-1/2" Production Open HoleSECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 1830.00 0.15 134.10 1829.98 2.53 -4.09 0.00 0.00 4.81 Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TF2 1855.00 2.10 239.78 1854.98 2.28 -4.46 8.60 109.65 5.00 End Dir : 1855' MD, 1854.98' TVD3 1885.00 2.10 239.78 1884.96 1.72 -5.41 0.00 0.00 5.55 Start Dir 4.04º/100' : 1885' MD, 1884.96'TVD4 2085.00 10.18 239.78 2083.64 -9.04 -23.89 4.04 0.00 16.17 Start Dir 4.5º/100' : 2085' MD, 2083.64'TVD5 3361.67 60.78 307.90 3111.14 302.96 -611.04 4.50 73.90 680.66 End Dir : 3361.67' MD, 3111.14' TVD6 6448.14 60.78 307.90 4618.01 1957.64 -2736.52 0.00 0.00 3348.71 Start Dir 3º/100' : 6448.14' MD, 4618.01'TVD7 7582.40 86.00 332.00 4944.10 2785.68 -3412.66 3.00 46.71 4348.29 End Dir : 7582.4' MD, 4944.1' TVD8 7982.40 86.00 332.00 4972.00 3138.00 -3599.99 0.00 0.00 4686.69 W-35A wp03 tgt01 Start Dir 3º/100' : 7982.4' MD, 4972'TVD9 8121.73 90.18 332.00 4976.64 3260.93 -3665.36 3.00 0.00 4804.76 End Dir : 8121.73' MD, 4976.64' TVD10 13621.74 90.18 332.00 4959.36 8117.13 -6247.44 0.00 0.00 9469.01 W-35A wp03 tgt02 Start Dir 1.5º/100' : 13621.74' MD, 4959.36'TVD11 13855.38 90.00 328.50 4959.00 8319.94 -6363.36 1.50 -92.94 9670.80 End Dir : 13855.38' MD, 4959' TVD12 15500.00 90.00 328.50 4959.00 9722.21 -7222.67 0.00 0.00 11116.12 Start Dir 5º/100' : 15500' MD, 4959'TVD13 15800.24 102.25 319.76 4926.96 9963.57 -7396.88 5.00 -35.00 11387.67 Start Dir 4.96º/100' : 15800.24' MD, 4926.96'TVD14 16550.24 102.25 281.66 4761.99 10330.32 -8014.38 4.96 -85.81 12105.81 End Dir : 16550.24' MD, 4761.99' TVD15 17178.52 102.25 281.66 4628.69 10454.41 -8615.68 0.00 0.00 12688.60 Start Dir 5º/100' : 17178.52' MD, 4628.69'TVD16 17363.52 93.00 281.66 4604.17 10491.42 -8795.07 5.00 180.00 12862.46 End Dir : 17363.52' MD, 4604.17' TVD17 18113.52 93.00 281.66 4564.91 10642.79 -9528.58 0.00 0.00 13573.39 Total Depth : 18113.52' MD, 4564.91' TVD -1400 -700 0 700 1400 2100 2800 3500 4200 4900 5600 6300 7000 7700 8400 9100 9800 10500 11200 11900 South(-)/North(+) (1400 usft/in)-9800 -9100 -8400 -7700 -7000 -6300 -5600 -4900 -4200 -3500 -2800 -2100 -1400 -700 0 West(-)/East(+) (1400 usft/in) W-35A wp03 tgt01 W-35A wp03 tgt02 25003 2 5 04 0 0 0 4 5 0 0 50 0 0 5 5 0 0 600062506750725077508250850087509205W-35 13-3/8" x 17 1/2" TOW 9-5/8" x 12 1/4" 8-1/2" Production Open Hole 2500300032503500375040004250450047504565W-35A PH1 wp08 Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TF End Dir : 1855' MD, 1854.98' TVD Start Dir 4.04º/100' : 1885' MD, 1884.96'TVD Start Dir 4.5º/100' : 2085' MD, 2083.64'TVD End Dir : 3361.67' MD, 3111.14' TVD Start Dir 3º/100' : 6448.14' MD, 4618.01'TVD End Dir : 7582.4' MD, 4944.1' TVD Start Dir 3º/100' : 7982.4' MD, 4972'TVD End Dir : 8121.73' MD, 4976.64' TVD Start Dir 1.5º/100' : 13621.74' MD, 4959.36'TVD End Dir : 13855.38' MD, 4959' TVD Start Dir 5º/100' : 15500' MD, 4959'TVD Start Dir 4.96º/100' : 15800.24' MD, 4926.96'TVD End Dir : 16550.24' MD, 4761.99' TVD Start Dir 5º/100' : 17178.52' MD, 4628.69'TVD End Dir : 17363.52' MD, 4604.17' TVD Total Depth : 18113.52' MD, 4564.91' TVD CASING DETAILS TVD TVDSS MD Size Name 1830.08 1750.56 1830.10 13-3/8 13-3/8" x 17 1/2" TOW 4974.54 4895.02 8026.00 9-5/8 9-5/8" x 12 1/4" 4564.91 4485.39 18113.52 8-1/2 8-1/2" Production Open Hole Project: Prudhoe Bay Site: W Well: Plan: W-35 Wellbore: Plan: W-35A PH1 Plan: W-35A PH1 wp08 WELL DETAILS: Plan: W-35 Ground Level: 53.02 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5959002.08 611789.02 70° 17' 49.0154 N 149° 5' 41.0699 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: W-35, True North Vertical (TVD) Reference: W-35A planned RKB @ 79.52usft Measured Depth Reference:W-35A planned RKB @ 79.52usft Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Prudhoe Bay, North Slope, UNITED STATES Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: W, TR-11-12 usft Map usft usft °0.84Slot Radius:"0 5,957,194.18 609,919.18 5.00 70° 17' 31.5064 N 149° 6' 36.3426 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: W-35, W-35 usft usft 0.00 0.00 5,959,002.08 611,789.02 53.20Wellhead Elevation:usft0.00 70° 17' 49.0154 N 149° 5' 41.0699 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Plan: W-35A PH1 Model NameMagnetics BGGM2025 10/17/2025 13.72 80.59 57,067.83023944 Phase:Version: Audit Notes: Design W-35A PH1 wp08 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:1,830.00 300.000.000.0026.50 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.00-4.092.531,829.98134.100.151,830.00 1,750.46 109.65422.737.798.60-4.462.281,854.98239.782.101,855.00 1,775.46 0.000.000.000.00-5.411.721,884.96239.782.101,885.00 1,805.44 0.000.004.044.04-23.89-9.042,083.64239.7810.182,085.00 2,004.12 73.905.343.964.50-611.04302.963,111.14307.9060.783,361.67 3,031.62 0.000.000.000.00-2,736.521,957.644,618.01307.9060.786,448.14 4,538.49 46.712.122.223.00-3,412.662,785.684,944.10332.0086.007,582.40 4,864.58 0.000.000.000.00-3,599.993,138.004,972.00332.0086.007,982.40 4,892.48 0.000.003.003.00-3,665.363,260.934,976.64332.0090.188,121.73 4,897.12 0.000.000.000.00-6,247.448,117.134,959.36332.0090.1813,621.74 4,879.84 -92.94-1.50-0.081.50-6,363.368,319.944,959.00328.5090.0013,855.38 4,879.48 0.000.000.000.00-7,222.679,722.214,959.00328.5090.0015,500.00 4,879.48 -35.00-2.914.085.00-7,396.889,963.574,926.96319.76102.2515,800.24 4,847.44 -85.81-5.080.004.96-8,014.3810,330.324,761.99281.66102.2516,550.24 4,682.47 0.000.000.000.00-8,615.6810,454.414,628.69281.66102.2517,178.52 4,549.17 180.000.00-5.005.00-8,795.0710,491.424,604.17281.6693.0017,363.52 4,524.65 0.000.000.000.00-9,528.5810,642.794,564.91281.6693.0018,113.52 4,485.39 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -53.02 Vert Section 26.50 0.00 26.50 0.00 0.000.00 611,789.025,959,002.08-53.02 0.00 0.00 88.75 0.23 88.75 0.06 -0.11296.31 611,788.915,959,002.139.23 0.37 0.12 188.75 0.17 188.75 0.22 -0.42300.50 611,788.605,959,002.29109.23 0.06 0.47 288.75 0.17 288.75 0.37 -0.67302.31 611,788.345,959,002.44209.23 0.01 0.77 388.75 0.17 388.75 0.57 -0.89323.31 611,788.125,959,002.64309.23 0.06 1.05 488.75 0.12 488.75 0.79 -1.00349.20 611,788.015,959,002.86409.23 0.08 1.26 588.75 0.62 588.75 1.25 -1.43310.61 611,787.585,959,003.31509.23 0.53 1.86 688.75 0.60 688.74 1.81 -2.32293.40 611,786.685,959,003.85609.22 0.18 2.91 788.75 0.15 788.74 2.04 -2.93278.20 611,786.065,959,004.07709.22 0.46 3.55 888.75 0.12 888.74 2.11 -2.9758.10 611,786.025,959,004.15809.22 0.25 3.63 988.75 0.43 988.74 2.39 -3.18306.20 611,785.805,959,004.42909.22 0.49 3.95 1,088.75 0.27 1,088.74 2.77 -3.3146.10 611,785.665,959,004.801,009.22 0.55 4.26 1,188.75 0.03 1,188.74 2.94 -3.1271.39 611,785.865,959,004.981,109.22 0.24 4.17 1,288.75 0.33 1,288.73 3.11 -3.33303.70 611,785.645,959,005.141,209.21 0.35 4.44 1,388.75 0.27 1,388.73 3.17 -3.79243.89 611,785.195,959,005.191,309.21 0.30 4.86 1,488.75 0.13 1,488.73 3.01 -3.90119.20 611,785.085,959,005.031,409.21 0.36 4.88 1,588.75 0.23 1,588.73 3.06 -3.97301.20 611,785.005,959,005.081,509.21 0.36 4.97 1,688.75 0.30 1,688.73 2.93 -4.26206.10 611,784.725,959,004.941,609.21 0.39 5.15 1,788.75 0.22 1,788.73 2.60 -4.20116.81 611,784.785,959,004.621,709.21 0.37 4.94 1,830.00 0.15 1,829.98 2.53 -4.09134.10 611,784.895,959,004.551,750.46 0.21 4.81 Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TF 1,830.10 0.15 1,830.08 2.53 -4.09134.10 611,784.895,959,004.551,750.56 0.00 4.81 13-3/8" x 17 1/2" TOW 1,850.00 1.67 1,849.98 2.36 -4.32238.76 611,784.665,959,004.381,770.46 8.64 4.92 1,855.00 2.10 1,854.98 2.28 -4.46239.78 611,784.525,959,004.291,775.46 8.60 5.00 End Dir : 1855' MD, 1854.98' TVD 1,885.00 2.10 1,884.96 1.72 -5.41239.78 611,783.585,959,003.721,805.44 0.00 5.55 Start Dir 4.04º/100' : 1885' MD, 1884.96'TVD 1,900.00 2.71 1,899.94 1.40 -5.96239.78 611,783.045,959,003.401,820.42 4.04 5.86 2,000.00 6.75 1,999.58 -2.74 -13.08239.78 611,775.985,958,999.141,920.06 4.04 9.96 2,043.04 8.49 2,042.24 -5.62 -18.01239.78 611,771.105,958,996.201,962.72 4.04 12.79 SV4 2,085.00 10.18 2,083.64 -9.04 -23.89239.78 611,765.275,958,992.692,004.12 4.04 16.17 Start Dir 4.5º/100' : 2085' MD, 2083.64'TVD 2,100.00 10.39 2,098.40 -10.31 -26.25243.38 611,762.935,958,991.382,018.88 4.50 17.57 2,200.00 12.63 2,196.42 -15.66 -45.17263.14 611,744.095,958,985.752,116.90 4.50 31.29 2,300.00 15.84 2,293.36 -15.53 -69.61276.04 611,719.655,958,985.512,213.84 4.50 52.52 2,400.00 19.56 2,388.63 -9.93 -99.42284.42 611,689.775,958,990.682,309.11 4.50 81.13 2,500.00 23.55 2,481.62 1.13 -134.41290.14 611,654.625,959,001.212,402.10 4.50 116.96 2,590.64 27.29 2,563.48 15.79 -170.42293.92 611,618.405,959,015.332,483.96 4.50 155.48 SV3 2,600.00 27.68 2,571.78 17.55 -174.36294.25 611,614.435,959,017.042,492.26 4.50 159.78 2,700.00 31.91 2,658.55 39.25 -219.03297.36 611,569.445,959,038.072,579.03 4.50 209.32 2,800.00 36.20 2,741.38 66.10 -268.15299.81 611,519.945,959,064.182,661.86 4.50 265.28 2,900.00 40.53 2,819.78 97.92 -321.41301.80 611,466.215,959,095.202,740.26 4.50 327.31 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 2,813.73 Vert Section 3,000.00 44.88 2,893.25 134.51 -378.49303.47 611,408.615,959,130.942,813.73 4.50 395.04 3,100.00 49.26 2,961.34 175.66 -439.02304.90 611,347.475,959,171.182,881.82 4.50 468.04 3,200.00 53.65 3,023.64 221.11 -502.65306.15 611,283.185,959,215.672,944.12 4.50 545.86 3,297.17 57.93 3,078.26 269.13 -567.06307.23 611,218.075,959,262.722,998.74 4.50 625.65 SV1 3,300.00 58.06 3,079.76 270.58 -568.97307.26 611,216.145,959,264.153,000.24 4.50 628.03 3,361.67 60.78 3,111.14 302.96 -611.03307.90 611,173.605,959,295.903,031.62 4.50 680.65 End Dir : 3361.67' MD, 3111.14' TVD 3,400.00 60.78 3,129.85 323.51 -637.43307.90 611,146.905,959,316.053,050.33 0.00 713.79 3,500.00 60.78 3,178.67 377.12 -706.29307.90 611,077.255,959,368.623,099.15 0.00 800.23 3,600.00 60.78 3,227.49 430.73 -775.16307.90 611,007.615,959,421.203,147.97 0.00 886.67 3,700.00 60.78 3,276.32 484.34 -844.02307.90 610,937.965,959,473.773,196.80 0.00 973.12 3,800.00 60.78 3,325.14 537.95 -912.89307.90 610,868.315,959,526.353,245.62 0.00 1,059.56 3,900.00 60.78 3,373.96 591.56 -981.75307.90 610,798.665,959,578.933,294.44 0.00 1,146.01 4,000.00 60.78 3,422.78 645.17 -1,050.62307.90 610,729.015,959,631.503,343.26 0.00 1,232.45 4,039.18 60.78 3,441.91 666.18 -1,077.60307.90 610,701.725,959,652.103,362.39 0.00 1,266.32 Ugnu 4A 4,100.00 60.78 3,471.60 698.78 -1,119.48307.90 610,659.365,959,684.083,392.08 0.00 1,318.89 4,200.00 60.78 3,520.43 752.40 -1,188.35307.90 610,589.725,959,736.653,440.91 0.00 1,405.34 4,300.00 60.78 3,569.25 806.01 -1,257.21307.90 610,520.075,959,789.233,489.73 0.00 1,491.78 4,400.00 60.78 3,618.07 859.62 -1,326.08307.90 610,450.425,959,841.803,538.55 0.00 1,578.22 4,500.00 60.78 3,666.89 913.23 -1,394.94307.90 610,380.775,959,894.383,587.37 0.00 1,664.67 4,600.00 60.78 3,715.71 966.84 -1,463.81307.90 610,311.125,959,946.963,636.19 0.00 1,751.11 4,700.00 60.78 3,764.54 1,020.45 -1,532.67307.90 610,241.475,959,999.533,685.02 0.00 1,837.55 4,723.83 60.78 3,776.17 1,033.22 -1,549.08307.90 610,224.885,960,012.063,696.65 0.00 1,858.16 UG3 4,800.00 60.78 3,813.36 1,074.06 -1,601.53307.90 610,171.835,960,052.113,733.84 0.00 1,924.00 4,900.00 60.78 3,862.18 1,127.67 -1,670.40307.90 610,102.185,960,104.683,782.66 0.00 2,010.44 5,000.00 60.78 3,911.00 1,181.28 -1,739.26307.90 610,032.535,960,157.263,831.48 0.00 2,096.89 5,100.00 60.78 3,959.82 1,234.89 -1,808.13307.90 609,962.885,960,209.833,880.30 0.00 2,183.33 5,200.00 60.78 4,008.65 1,288.50 -1,876.99307.90 609,893.235,960,262.413,929.13 0.00 2,269.77 5,300.00 60.78 4,057.47 1,342.11 -1,945.86307.90 609,823.585,960,314.993,977.95 0.00 2,356.22 5,400.00 60.78 4,106.29 1,395.72 -2,014.72307.90 609,753.935,960,367.564,026.77 0.00 2,442.66 5,500.00 60.78 4,155.11 1,449.33 -2,083.59307.90 609,684.295,960,420.144,075.59 0.00 2,529.10 5,600.00 60.78 4,203.93 1,502.94 -2,152.45307.90 609,614.645,960,472.714,124.41 0.00 2,615.55 5,700.00 60.78 4,252.75 1,556.55 -2,221.32307.90 609,544.995,960,525.294,173.23 0.00 2,701.99 5,800.00 60.78 4,301.58 1,610.16 -2,290.18307.90 609,475.345,960,577.864,222.06 0.00 2,788.44 5,900.00 60.78 4,350.40 1,663.77 -2,359.04307.90 609,405.695,960,630.444,270.88 0.00 2,874.88 6,000.00 60.78 4,399.22 1,717.38 -2,427.91307.90 609,336.045,960,683.024,319.70 0.00 2,961.32 6,100.00 60.78 4,448.04 1,770.99 -2,496.77307.90 609,266.405,960,735.594,368.52 0.00 3,047.77 6,135.86 60.78 4,465.55 1,790.22 -2,521.47307.90 609,241.425,960,754.454,386.03 0.00 3,078.77 Ugnu MA 6,200.00 60.78 4,496.86 1,824.61 -2,565.64307.90 609,196.755,960,788.174,417.34 0.00 3,134.21 6,300.00 60.78 4,545.69 1,878.22 -2,634.50307.90 609,127.105,960,840.744,466.17 0.00 3,220.65 6,400.00 60.78 4,594.51 1,931.83 -2,703.37307.90 609,057.455,960,893.324,514.99 0.00 3,307.10 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,538.49 Vert Section 6,448.14 60.78 4,618.01 1,957.63 -2,736.52307.90 609,023.925,960,918.634,538.49 0.00 3,348.71 Start Dir 3º/100' : 6448.14' MD, 4618.01'TVD 6,500.00 61.85 4,642.91 1,985.98 -2,772.10309.18 608,987.935,960,946.444,563.39 3.00 3,393.70 6,598.26 63.91 4,687.70 2,042.63 -2,838.71311.55 608,920.485,961,002.094,608.18 3.00 3,479.72 NB 6,600.00 63.95 4,688.46 2,043.67 -2,839.88311.59 608,919.305,961,003.114,608.94 3.00 3,481.24 6,700.00 66.09 4,730.70 2,105.20 -2,906.42313.91 608,851.855,961,063.644,651.18 3.00 3,569.64 6,800.00 68.26 4,769.49 2,170.41 -2,971.54316.15 608,785.785,961,127.874,689.97 3.00 3,658.64 6,900.00 70.47 4,804.73 2,239.12 -3,035.06318.33 608,721.255,961,195.624,725.21 3.00 3,748.00 6,924.74 71.02 4,812.89 2,256.65 -3,050.51318.86 608,705.555,961,212.914,733.37 3.00 3,770.14 OA Top 7,000.00 72.69 4,836.33 2,311.15 -3,096.80320.45 608,658.455,961,266.714,756.81 3.00 3,837.48 7,085.89 74.63 4,860.49 2,375.50 -3,148.28322.23 608,606.035,961,330.294,780.97 3.00 3,914.24 Oba Top 7,100.00 74.94 4,864.19 2,386.29 -3,156.60322.51 608,597.555,961,340.954,784.67 3.00 3,926.83 7,200.00 77.21 4,888.25 2,464.33 -3,214.28324.54 608,538.725,961,418.124,808.73 3.00 4,015.82 7,300.00 79.50 4,908.44 2,545.07 -3,269.70326.52 608,482.115,961,498.024,828.92 3.00 4,104.18 7,400.00 81.79 4,924.70 2,628.29 -3,322.70328.48 608,427.885,961,580.434,845.18 3.00 4,191.68 7,500.00 84.10 4,936.98 2,713.74 -3,373.13330.42 608,376.195,961,665.124,857.46 3.00 4,278.09 7,582.40 86.00 4,944.10 2,785.68 -3,412.67332.00 608,335.595,961,736.464,864.58 3.00 4,348.30 End Dir : 7582.4' MD, 4944.1' TVD 7,600.00 86.00 4,945.33 2,801.19 -3,420.91332.00 608,327.125,961,751.844,865.81 0.00 4,363.19 7,700.00 86.00 4,952.30 2,889.27 -3,467.74332.00 608,278.995,961,839.204,872.78 0.00 4,447.78 7,800.00 86.00 4,959.28 2,977.35 -3,514.57332.00 608,230.855,961,926.574,879.76 0.00 4,532.38 7,900.00 86.00 4,966.25 3,065.43 -3,561.41332.00 608,182.725,962,013.934,886.73 0.00 4,616.98 7,960.18 86.00 4,970.45 3,118.43 -3,589.59332.00 608,153.765,962,066.514,890.93 0.00 4,667.89 Obc Top 7,982.40 86.00 4,972.00 3,138.00 -3,600.00332.00 608,143.065,962,085.924,892.48 0.00 4,686.69 Start Dir 3º/100' : 7982.4' MD, 4972'TVD 8,000.00 86.53 4,973.15 3,153.51 -3,608.24332.00 608,134.585,962,101.304,893.63 3.00 4,701.58 8,026.00 87.31 4,974.54 3,176.43 -3,620.43332.00 608,122.065,962,124.044,895.02 3.00 4,723.60 9-5/8" x 12 1/4" 8,100.00 89.53 4,976.59 3,241.74 -3,655.16332.00 608,086.375,962,188.824,897.07 3.00 4,786.33 8,121.73 90.18 4,976.64 3,260.93 -3,665.36332.00 608,075.885,962,207.854,897.12 3.00 4,804.76 End Dir : 8121.73' MD, 4976.64' TVD 8,200.00 90.18 4,976.40 3,330.04 -3,702.10332.00 608,038.125,962,276.404,896.88 0.00 4,871.13 8,300.00 90.18 4,976.08 3,418.33 -3,749.05332.00 607,989.875,962,363.984,896.56 0.00 4,955.94 8,400.00 90.18 4,975.77 3,506.63 -3,796.00332.00 607,941.615,962,451.564,896.25 0.00 5,040.74 8,500.00 90.18 4,975.45 3,594.92 -3,842.94332.00 607,893.365,962,539.144,895.93 0.00 5,125.55 8,600.00 90.18 4,975.14 3,683.21 -3,889.89332.00 607,845.115,962,626.714,895.62 0.00 5,210.35 8,700.00 90.18 4,974.83 3,771.51 -3,936.84332.00 607,796.865,962,714.294,895.31 0.00 5,295.15 8,800.00 90.18 4,974.51 3,859.80 -3,983.78332.00 607,748.615,962,801.874,894.99 0.00 5,379.96 8,900.00 90.18 4,974.20 3,948.10 -4,030.73332.00 607,700.365,962,889.454,894.68 0.00 5,464.76 9,000.00 90.18 4,973.88 4,036.39 -4,077.68332.00 607,652.115,962,977.034,894.36 0.00 5,549.57 9,100.00 90.18 4,973.57 4,124.69 -4,124.62332.00 607,603.865,963,064.614,894.05 0.00 5,634.37 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,893.74 Vert Section 9,200.00 90.18 4,973.26 4,212.98 -4,171.57332.00 607,555.615,963,152.194,893.74 0.00 5,719.18 9,300.00 90.18 4,972.94 4,301.27 -4,218.52332.00 607,507.365,963,239.774,893.42 0.00 5,803.98 9,400.00 90.18 4,972.63 4,389.57 -4,265.47332.00 607,459.115,963,327.344,893.11 0.00 5,888.79 9,500.00 90.18 4,972.31 4,477.86 -4,312.41332.00 607,410.855,963,414.924,892.79 0.00 5,973.59 9,600.00 90.18 4,972.00 4,566.16 -4,359.36332.00 607,362.605,963,502.504,892.48 0.00 6,058.39 9,700.00 90.18 4,971.68 4,654.45 -4,406.31332.00 607,314.355,963,590.084,892.16 0.00 6,143.20 9,800.00 90.18 4,971.37 4,742.75 -4,453.25332.00 607,266.105,963,677.664,891.85 0.00 6,228.00 9,900.00 90.18 4,971.06 4,831.04 -4,500.20332.00 607,217.855,963,765.244,891.54 0.00 6,312.81 10,000.00 90.18 4,970.74 4,919.33 -4,547.15332.00 607,169.605,963,852.824,891.22 0.00 6,397.61 10,100.00 90.18 4,970.43 5,007.63 -4,594.09332.00 607,121.355,963,940.404,890.91 0.00 6,482.42 10,200.00 90.18 4,970.11 5,095.92 -4,641.04332.00 607,073.105,964,027.974,890.59 0.00 6,567.22 10,300.00 90.18 4,969.80 5,184.22 -4,687.99332.00 607,024.855,964,115.554,890.28 0.00 6,652.03 10,400.00 90.18 4,969.49 5,272.51 -4,734.93332.00 606,976.605,964,203.134,889.97 0.00 6,736.83 10,500.00 90.18 4,969.17 5,360.81 -4,781.88332.00 606,928.345,964,290.714,889.65 0.00 6,821.63 10,600.00 90.18 4,968.86 5,449.10 -4,828.83332.00 606,880.095,964,378.294,889.34 0.00 6,906.44 10,700.00 90.18 4,968.54 5,537.39 -4,875.78332.00 606,831.845,964,465.874,889.02 0.00 6,991.24 10,800.00 90.18 4,968.23 5,625.69 -4,922.72332.00 606,783.595,964,553.454,888.71 0.00 7,076.05 10,900.00 90.18 4,967.91 5,713.98 -4,969.67332.00 606,735.345,964,641.034,888.39 0.00 7,160.85 11,000.00 90.18 4,967.60 5,802.28 -5,016.62332.00 606,687.095,964,728.604,888.08 0.00 7,245.66 11,100.00 90.18 4,967.29 5,890.57 -5,063.56332.00 606,638.845,964,816.184,887.77 0.00 7,330.46 11,200.00 90.18 4,966.97 5,978.87 -5,110.51332.00 606,590.595,964,903.764,887.45 0.00 7,415.26 11,300.00 90.18 4,966.66 6,067.16 -5,157.46332.00 606,542.345,964,991.344,887.14 0.00 7,500.07 11,400.00 90.18 4,966.34 6,155.45 -5,204.40332.00 606,494.095,965,078.924,886.82 0.00 7,584.87 11,500.00 90.18 4,966.03 6,243.75 -5,251.35332.00 606,445.845,965,166.504,886.51 0.00 7,669.68 11,600.00 90.18 4,965.72 6,332.04 -5,298.30332.00 606,397.585,965,254.084,886.20 0.00 7,754.48 11,700.00 90.18 4,965.40 6,420.34 -5,345.24332.00 606,349.335,965,341.664,885.88 0.00 7,839.29 11,800.00 90.18 4,965.09 6,508.63 -5,392.19332.00 606,301.085,965,429.234,885.57 0.00 7,924.09 11,900.00 90.18 4,964.77 6,596.93 -5,439.14332.00 606,252.835,965,516.814,885.25 0.00 8,008.90 12,000.00 90.18 4,964.46 6,685.22 -5,486.09332.00 606,204.585,965,604.394,884.94 0.00 8,093.70 12,100.00 90.18 4,964.14 6,773.52 -5,533.03332.00 606,156.335,965,691.974,884.62 0.00 8,178.50 12,200.00 90.18 4,963.83 6,861.81 -5,579.98332.00 606,108.085,965,779.554,884.31 0.00 8,263.31 12,300.00 90.18 4,963.52 6,950.10 -5,626.93332.00 606,059.835,965,867.134,884.00 0.00 8,348.11 12,400.00 90.18 4,963.20 7,038.40 -5,673.87332.00 606,011.585,965,954.714,883.68 0.00 8,432.92 12,500.00 90.18 4,962.89 7,126.69 -5,720.82332.00 605,963.335,966,042.294,883.37 0.00 8,517.72 12,600.00 90.18 4,962.57 7,214.99 -5,767.77332.00 605,915.085,966,129.864,883.05 0.00 8,602.53 12,700.00 90.18 4,962.26 7,303.28 -5,814.71332.00 605,866.825,966,217.444,882.74 0.00 8,687.33 12,800.00 90.18 4,961.95 7,391.58 -5,861.66332.00 605,818.575,966,305.024,882.43 0.00 8,772.13 12,900.00 90.18 4,961.63 7,479.87 -5,908.61332.00 605,770.325,966,392.604,882.11 0.00 8,856.94 13,000.00 90.18 4,961.32 7,568.16 -5,955.55332.00 605,722.075,966,480.184,881.80 0.00 8,941.74 13,100.00 90.18 4,961.00 7,656.46 -6,002.50332.00 605,673.825,966,567.764,881.48 0.00 9,026.55 13,200.00 90.18 4,960.69 7,744.75 -6,049.45332.00 605,625.575,966,655.344,881.17 0.00 9,111.35 13,300.00 90.18 4,960.37 7,833.05 -6,096.40332.00 605,577.325,966,742.924,880.85 0.00 9,196.16 13,400.00 90.18 4,960.06 7,921.34 -6,143.34332.00 605,529.075,966,830.494,880.54 0.00 9,280.96 13,500.00 90.18 4,959.75 8,009.64 -6,190.29332.00 605,480.825,966,918.074,880.23 0.00 9,365.77 13,600.00 90.18 4,959.43 8,097.93 -6,237.24332.00 605,432.575,967,005.654,879.91 0.00 9,450.57 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,879.84 Vert Section 13,621.74 90.18 4,959.36 8,117.13 -6,247.44332.00 605,422.085,967,024.694,879.84 0.00 9,469.01 Start Dir 1.5º/100' : 13621.74' MD, 4959.36'TVD 13,700.00 90.12 4,959.16 8,185.84 -6,284.89330.83 605,383.625,967,092.844,879.64 1.50 9,535.79 13,800.00 90.04 4,959.02 8,272.51 -6,334.77329.33 605,332.465,967,178.754,879.50 1.50 9,622.33 13,855.38 90.00 4,959.00 8,319.94 -6,363.36328.50 605,303.165,967,225.744,879.48 1.50 9,670.80 End Dir : 13855.38' MD, 4959' TVD 13,900.00 90.00 4,959.00 8,357.98 -6,386.67328.50 605,279.295,967,263.434,879.48 0.00 9,710.01 14,000.00 90.00 4,959.00 8,443.25 -6,438.92328.50 605,225.785,967,347.904,879.48 0.00 9,797.90 14,100.00 90.00 4,959.00 8,528.51 -6,491.17328.50 605,172.275,967,432.374,879.48 0.00 9,885.78 14,200.00 90.00 4,959.00 8,613.78 -6,543.42328.50 605,118.775,967,516.844,879.48 0.00 9,973.66 14,300.00 90.00 4,959.00 8,699.04 -6,595.67328.50 605,065.265,967,601.314,879.48 0.00 10,061.54 14,400.00 90.00 4,959.00 8,784.30 -6,647.92328.50 605,011.755,967,685.784,879.48 0.00 10,149.42 14,500.00 90.00 4,959.00 8,869.57 -6,700.17328.50 604,958.245,967,770.254,879.48 0.00 10,237.30 14,600.00 90.00 4,959.00 8,954.83 -6,752.42328.50 604,904.745,967,854.724,879.48 0.00 10,325.19 14,700.00 90.00 4,959.00 9,040.10 -6,804.67328.50 604,851.235,967,939.194,879.48 0.00 10,413.07 14,800.00 90.00 4,959.00 9,125.36 -6,856.92328.50 604,797.725,968,023.664,879.48 0.00 10,500.95 14,900.00 90.00 4,959.00 9,210.62 -6,909.17328.50 604,744.215,968,108.134,879.48 0.00 10,588.83 15,000.00 90.00 4,959.00 9,295.89 -6,961.42328.50 604,690.705,968,192.604,879.48 0.00 10,676.71 15,100.00 90.00 4,959.00 9,381.15 -7,013.67328.50 604,637.205,968,277.074,879.48 0.00 10,764.59 15,200.00 90.00 4,959.00 9,466.42 -7,065.92328.50 604,583.695,968,361.544,879.48 0.00 10,852.48 15,300.00 90.00 4,959.00 9,551.68 -7,118.17328.50 604,530.185,968,446.014,879.48 0.00 10,940.36 15,400.00 90.00 4,959.00 9,636.94 -7,170.42328.50 604,476.675,968,530.484,879.48 0.00 11,028.24 15,500.00 90.00 4,959.00 9,722.21 -7,222.67328.50 604,423.175,968,614.954,879.48 0.00 11,116.12 Start Dir 5º/100' : 15500' MD, 4959'TVD 15,600.00 94.09 4,955.43 9,806.06 -7,276.99325.63 604,367.615,968,697.984,875.91 5.00 11,205.09 15,700.00 98.18 4,944.74 9,886.65 -7,335.16322.72 604,308.265,968,777.694,865.22 5.00 11,295.76 15,800.24 102.25 4,926.96 9,963.57 -7,396.88319.76 604,245.405,968,853.674,847.44 5.00 11,387.67 Start Dir 4.96º/100' : 15800.24' MD, 4926.96'TVD 15,900.00 102.56 4,905.51 10,035.06 -7,463.02314.70 604,178.215,968,924.174,825.99 4.96 11,480.70 16,000.00 102.79 4,883.56 10,100.52 -7,535.31309.62 604,104.965,968,988.554,804.04 4.96 11,576.04 16,100.00 102.91 4,861.31 10,159.29 -7,613.07304.54 604,026.345,969,046.144,781.79 4.96 11,672.76 16,200.00 102.93 4,838.94 10,210.91 -7,695.70299.45 603,942.965,969,096.524,759.42 4.96 11,770.13 16,300.00 102.86 4,816.60 10,255.00 -7,782.60294.36 603,855.425,969,139.314,737.08 4.96 11,867.43 16,400.00 102.69 4,794.48 10,291.23 -7,873.11289.28 603,764.405,969,174.194,714.96 4.96 11,963.93 16,500.00 102.42 4,772.73 10,319.34 -7,966.55284.20 603,670.565,969,200.904,693.21 4.96 12,058.90 16,550.24 102.25 4,761.99 10,330.32 -8,014.38281.66 603,622.575,969,211.174,682.47 4.96 12,105.81 End Dir : 16550.24' MD, 4761.99' TVD 16,600.00 102.25 4,751.44 10,340.15 -8,062.00281.66 603,574.815,969,220.294,671.92 0.00 12,151.97 16,700.00 102.25 4,730.22 10,359.90 -8,157.71281.66 603,478.835,969,238.614,650.70 0.00 12,244.73 16,800.00 102.25 4,709.00 10,379.65 -8,253.41281.66 603,382.855,969,256.934,629.48 0.00 12,337.49 16,900.00 102.25 4,687.78 10,399.40 -8,349.12281.66 603,286.875,969,275.264,608.26 0.00 12,430.25 17,000.00 102.25 4,666.56 10,419.15 -8,444.83281.66 603,190.895,969,293.584,587.04 0.00 12,523.01 17,100.00 102.25 4,645.35 10,438.90 -8,540.53281.66 603,094.905,969,311.904,565.83 0.00 12,615.77 17,178.52 102.25 4,628.69 10,454.41 -8,615.68281.66 603,019.545,969,326.294,549.17 0.00 12,688.60 Start Dir 5º/100' : 17178.52' MD, 4628.69'TVD 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,544.81 Vert Section 17,200.00 101.18 4,624.33 10,458.66 -8,636.28281.66 602,998.885,969,330.234,544.81 5.00 12,708.57 17,300.00 96.18 4,609.25 10,478.63 -8,733.07281.66 602,901.825,969,348.764,529.73 5.00 12,802.37 17,363.52 93.00 4,604.17 10,491.42 -8,795.07281.66 602,839.645,969,360.634,524.65 5.00 12,862.46 End Dir : 17363.52' MD, 4604.17' TVD 17,400.00 93.00 4,602.26 10,498.79 -8,830.75281.66 602,803.865,969,367.464,522.74 0.00 12,897.04 17,500.00 93.00 4,597.02 10,518.97 -8,928.55281.66 602,705.775,969,386.194,517.50 0.00 12,991.83 17,600.00 93.00 4,591.79 10,539.15 -9,026.35281.66 602,607.695,969,404.914,512.27 0.00 13,086.62 17,700.00 93.00 4,586.56 10,559.33 -9,124.15281.66 602,509.615,969,423.634,507.04 0.00 13,181.41 17,800.00 93.00 4,581.32 10,579.52 -9,221.95281.66 602,411.535,969,442.364,501.80 0.00 13,276.21 17,900.00 93.00 4,576.09 10,599.70 -9,319.76281.66 602,313.445,969,461.084,496.57 0.00 13,371.00 18,000.00 93.00 4,570.86 10,619.88 -9,417.56281.66 602,215.365,969,479.814,491.34 0.00 13,465.79 18,100.00 93.00 4,565.62 10,640.07 -9,515.36281.66 602,117.285,969,498.534,486.10 0.00 13,560.58 18,113.52 93.00 4,564.91 10,642.79 -9,528.58281.66 602,104.015,969,501.064,485.39 0.00 13,573.39 Total Depth : 18113.52' MD, 4564.91' TVD - 8-1/2" Production Open Hole Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Targets Dip Angle (°) Dip Dir. (°) W-35A wp03 tgt02 4,959.36 5,967,024.68 605,422.078,117.11 -6,247.450.00 0.00 - plan misses target center by 0.01usft at 13621.73usft MD (4959.36 TVD, 8117.12 N, -6247.44 E) - Point W-35A wp03 tgt01 4,972.00 5,962,085.92 608,143.063,138.00 -3,599.990.00 0.00 - plan hits target center - Point W-35A wp03 tgt03 4,959.00 5,972,801.28 601,771.3213,947.88 -9,812.180.00 0.00 - plan misses target center by 3340.56usft at 18113.52usft MD (4564.91 TVD, 10642.79 N, -9528.58 E) - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 13-3/8" x 17 1/2" TOW1,830.081,830.10 13-3/8 17-1/2 9-5/8" x 12 1/4"4,974.548,026.00 9-5/8 12-1/4 8-1/2" Production Open Hole4,564.9118,113.52 8-1/2 8-1/2 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 9 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A PH1 Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A PH1 wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations Vertical Depth SS 4,039.18 3,441.91 Ugnu 4A 6,924.74 4,812.89 OA Top 6,598.26 4,687.70 NB 3,297.17 3,078.26 SV1 7,960.18 4,970.45 Obc Top 4,723.83 3,776.17 UG3 7,085.89 4,860.49 Oba Top 2,590.64 2,563.48 SV3 6,135.86 4,465.55 Ugnu MA 2,043.04 2,042.24 SV4 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 1,830.00 1,829.98 2.53 -4.09 Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TF 1,855.00 1,854.98 2.28 -4.46 End Dir : 1855' MD, 1854.98' TVD 1,885.00 1,884.96 1.72 -5.41 Start Dir 4.04º/100' : 1885' MD, 1884.96'TVD 2,085.00 2,083.64 -9.04 -23.89 Start Dir 4.5º/100' : 2085' MD, 2083.64'TVD 3,361.67 3,111.14 302.96 -611.03 End Dir : 3361.67' MD, 3111.14' TVD 6,448.14 4,618.01 1,957.63 -2,736.52 Start Dir 3º/100' : 6448.14' MD, 4618.01'TVD 7,582.40 4,944.10 2,785.68 -3,412.67 End Dir : 7582.4' MD, 4944.1' TVD 7,982.40 4,972.00 3,138.00 -3,600.00 Start Dir 3º/100' : 7982.4' MD, 4972'TVD 8,121.73 4,976.64 3,260.93 -3,665.36 End Dir : 8121.73' MD, 4976.64' TVD 13,621.74 4,959.36 8,117.13 -6,247.44 Start Dir 1.5º/100' : 13621.74' MD, 4959.36'TVD 13,855.38 4,959.00 8,319.94 -6,363.36 End Dir : 13855.38' MD, 4959' TVD 15,500.00 4,959.00 9,722.21 -7,222.67 Start Dir 5º/100' : 15500' MD, 4959'TVD 15,800.24 4,926.96 9,963.57 -7,396.88 Start Dir 4.96º/100' : 15800.24' MD, 4926.96'TVD 16,550.24 4,761.99 10,330.32 -8,014.38 End Dir : 16550.24' MD, 4761.99' TVD 17,178.52 4,628.69 10,454.41 -8,615.68 Start Dir 5º/100' : 17178.52' MD, 4628.69'TVD 17,363.52 4,604.17 10,491.42 -8,795.07 End Dir : 17363.52' MD, 4604.17' TVD 18,113.52 4,564.91 10,642.79 -9,528.58 Total Depth : 18113.52' MD, 4564.91' TVD 6/16/2025 4:17:25PM COMPASS 5000.17 Build 04 Page 10 Clearance SummaryAnticollision Report16 June, 2025Hilcorp North Slope, LLCPrudhoe BayWPlan: W-35Plan: W-35A PH15002921799W-35A PH1 wp08Reference Design: W - Plan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp08Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 5,959,002.08 N, 611,789.02 E (70° 17' 49.02" N, 149° 05' 41.07" W)Datum Height: W-35A planned RKB @ 79.52usftScan Range: 1,830.00 to 18,113.52 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.17 Build: 04Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A PH1 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 1,830.00 to 18,113.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: W - Plan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningWPlan: W-35 - W-35 - W-350.011,832.68-1.211,843.930.0041,832.68Clearance FactorFAIL - W-02 - W-02 - W-02 189.57 1,830.00 163.81 1,838.97 7.3611,830.00Clearance Factor Pass - W-02 - W-02A - W-02A 189.57 1,830.00 164.10 1,837.77 7.4421,830.00Clearance Factor Pass - W-02 - W-02B - W-02B 189.57 1,830.00 164.03 1,837.77 7.4231,830.00Clearance Factor Pass - W-03 - W-03 - W-03 263.65 1,830.00 242.18 1,839.57 12.2801,830.00Clearance Factor Pass - W-03 - W-03A - W-03A 263.65 1,830.00 242.18 1,831.77 12.2801,830.00Clearance Factor Pass - W-04 - W-04 - W-04 271.05 1,830.00 249.51 1,842.17 12.5841,830.00Clearance Factor Pass - W-05 - W-05 - W-05 519.67 1,830.00 500.28 1,653.68 26.8081,830.00Clearance Factor Pass - W-05 - W-05A - W-05A 519.67 1,830.00 500.28 1,653.68 26.8081,830.00Clearance Factor Pass - W-05 - W-05AL1 - W-05AL1 519.67 1,830.00 500.28 1,653.68 26.8081,830.00Clearance Factor Pass - W-05 - W-05AL1PB1 - W-05AL1PB1 519.67 1,830.00 500.28 1,653.68 26.8081,830.00Clearance Factor Pass - W-06 - W-06 - W-06 443.68 1,830.00 423.16 1,723.98 21.6211,830.00Clearance Factor Pass - W-06 - W-06A - W-06A 443.68 1,830.00 423.16 1,725.04 21.6211,830.00Clearance Factor Pass - W-06 - W-06B - W-06B 443.68 1,830.00 423.16 1,725.04 21.6211,830.00Clearance Factor Pass - W-06 - W-06B PB1 - W-06B PB1 443.68 1,830.00 423.16 1,725.04 21.6211,830.00Clearance Factor Pass - W-06 - W-06PB1 - W-06PB1 443.68 1,830.00 423.16 1,723.97 21.6201,830.00Clearance Factor Pass - W-08 - W-08 - W-08 398.92 1,830.00 378.38 1,739.80 19.4221,830.00Clearance Factor Pass - W-08 - W-08A - W-08A 398.92 1,830.00 378.38 1,733.88 19.4221,830.00Clearance Factor Pass - W-211 - W-211 - W-211 369.53 1,830.00 341.53 1,808.02 13.1981,830.00Clearance Factor Pass - W-241 - W-241 - W-24158.5314,071.94-3.6512,990.040.94114,071.94Centre DistanceFAIL - W-241 - W-241 - W-241115.0814,955.00-10.8013,870.780.91414,955.00Clearance FactorFAIL - W-241 - W-241 - W-241121.6015,055.00-11.1213,972.850.91615,055.00Ellipse SeparationFAIL - W-241 - W-241PB1 - W-241PB166.4614,127.85-4.8213,046.000.93214,127.85Centre DistanceFAIL - W-241 - W-241PB1 - W-241PB166.4814,130.00-5.1813,046.000.92814,130.00Clearance FactorFAIL - W-25 - W-25 - W-25 269.54 1,830.00 248.08 1,842.63 12.5581,830.00Ellipse Separation Pass - W-25 - W-25 - W-25 271.14 1,930.00 249.54 1,942.65 12.5521,930.00Clearance Factor Pass - W-25 - W-25A - W-25A 269.54 1,830.00 248.08 1,842.63 12.5581,830.00Ellipse Separation Pass - W-25 - W-25A - W-25A 271.14 1,930.00 249.54 1,942.65 12.5521,930.00Clearance Factor Pass - 16 June, 2025 - 16:15COMPASSPage 2 of 8 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A PH1 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 1,830.00 to 18,113.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: W - Plan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningW-26 - W-26 - W-26 429.19 1,830.00 409.13 1,708.35 21.3901,830.00Ellipse Separation Pass - W-26 - W-26 - W-26 663.89 6,380.00 532.06 5,841.63 5.0366,380.00Clearance Factor Pass - W-26 - W-26A - W-26A 429.19 1,830.00 409.13 1,699.09 21.3901,830.00Ellipse Separation Pass - W-26 - W-26A - W-26A 663.89 6,380.00 532.06 5,832.37 5.0366,380.00Clearance Factor Pass - W-26 - W-26AL1 - W-26AL1 429.19 1,830.00 409.13 1,699.09 21.3901,830.00Ellipse Separation Pass - W-26 - W-26AL1 - W-26AL1 663.89 6,380.00 532.06 5,832.37 5.0366,380.00Clearance Factor Pass - W-26 - W-26B - W-26B 594.58 16,680.00 267.73 15,951.68 1.81916,680.00Clearance Factor Pass - W-26 - W-26B - W-26B 511.35 16,880.00 251.17 16,093.01 1.96516,880.00Ellipse Separation Pass - W-26 - W-26B - W-26B 371.52 17,592.28 277.30 16,665.69 3.94317,592.28Centre Distance Pass - W-27 - W-27 - W-27 329.91 1,830.00 308.38 1,844.49 15.3261,830.00Ellipse Separation Pass - W-27 - W-27 - W-27 332.26 1,955.00 310.53 1,968.42 15.2881,955.00Clearance Factor Pass - W-27 - W-27A - W-27A 329.91 1,830.00 308.38 1,844.49 15.3261,830.00Ellipse Separation Pass - W-27 - W-27A - W-27A 332.26 1,955.00 310.53 1,968.42 15.2881,955.00Clearance Factor Pass - W-29 - W-29 - W-29 413.07 1,830.00 391.66 1,843.17 19.2941,830.00Ellipse Separation Pass - W-29 - W-29 - W-29 445.66 2,705.00 421.79 2,676.05 18.6712,705.00Clearance Factor Pass - W-30 - W-30 - W-30 439.80 1,830.00 418.51 1,843.47 20.6551,830.00Ellipse Separation Pass - W-30 - W-30 - W-30 472.52 2,930.00 447.92 2,892.05 19.2082,930.00Clearance Factor Pass - W-34 - W-34 - W-3435.201,830.009.161,841.181.3521,830.00Clearance FactorPass - W-34 - W-34A - W-34A35.201,830.009.161,841.181.3521,830.00Clearance FactorPass - W-34 - W-34APB1 - W-34APB135.201,830.009.161,841.181.3521,830.00Clearance FactorPass - W-36 - W-36 - W-36 40.58 2,014.40 18.76 2,025.42 1.8602,014.40Ellipse Separation Pass - W-36 - W-36 - W-36 40.64 2,030.00 18.77 2,040.88 1.8582,030.00Clearance Factor Pass - W-37 - W-37 - W-37 69.32 2,112.00 47.14 2,121.49 3.1262,112.00Clearance Factor Pass - W-37 - W-37A - W-37A 69.32 2,112.00 47.14 2,121.49 3.1262,112.00Clearance Factor Pass - W-38 - W-38 - W-38 427.10 1,830.00 407.74 1,692.78 22.0661,830.00Clearance Factor Pass - W-38 - W-38A - W-38A 427.10 1,830.00 407.74 1,690.13 22.0661,830.00Clearance Factor Pass - W-39 - W-39 - W-39 142.79 2,153.51 107.85 2,162.17 4.0872,153.51Centre Distance Pass - W-39 - W-39 - W-39 142.79 2,155.00 107.84 2,163.63 4.0852,155.00Ellipse Separation Pass - W-39 - W-39 - W-39 143.12 2,180.00 107.94 2,188.13 4.0682,180.00Clearance Factor Pass - W-39 - W-39A - W-39A 142.79 2,153.51 107.85 2,162.17 4.0872,153.51Centre Distance Pass - 16 June, 2025 - 16:15COMPASSPage 3 of 8 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A PH1 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 1,830.00 to 18,113.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: W - Plan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningW-39 - W-39A - W-39A 142.79 2,155.00 107.84 2,163.63 4.0852,155.00Ellipse Separation Pass - W-39 - W-39A - W-39A 143.12 2,180.00 107.94 2,188.13 4.0682,180.00Clearance Factor Pass - W-40 - W-40 - W-40 173.87 2,160.47 151.63 2,169.73 7.8162,160.47Ellipse Separation Pass - W-40 - W-40 - W-40 174.04 2,180.00 151.74 2,188.89 7.8032,180.00Clearance Factor Pass - W-40 - W-40A - W-40A 173.87 2,160.47 151.63 2,169.73 7.8162,160.47Ellipse Separation Pass - W-40 - W-40A - W-40A 174.04 2,180.00 151.74 2,188.89 7.8032,180.00Clearance Factor Pass - W-400 - W-400 - W-400 380.48 1,830.00 359.26 1,711.47 17.9311,830.00Clearance Factor Pass - W-42 - W-42 - W-42 239.64 2,181.68 217.35 2,190.09 10.7492,181.68Ellipse Separation Pass - W-42 - W-42 - W-42 239.87 2,205.00 217.50 2,212.88 10.7272,205.00Clearance Factor Pass - W-44 - W-44 - W-44 284.16 2,246.80 261.41 2,251.10 12.4922,246.80Centre Distance Pass - W-44 - W-44 - W-44 284.18 2,255.00 261.40 2,258.63 12.4752,255.00Ellipse Separation Pass - W-44 - W-44 - W-44 287.63 2,355.00 264.42 2,354.01 12.3892,355.00Clearance Factor Pass - W-45 - W-45 - W-45 384.08 1,830.00 361.26 1,753.27 16.8251,830.00Clearance Factor Pass - W-51 - W-51 - W-51 218.85 3,323.47 186.32 3,186.40 6.7293,323.47Centre Distance Pass - W-51 - W-51 - W-51 219.91 3,355.00 185.92 3,209.32 6.4703,355.00Ellipse Separation Pass - W-51 - W-51 - W-51 226.29 3,405.00 190.28 3,243.79 6.2833,405.00Clearance Factor Pass - W-59 - W-59 - W-59 487.03 1,830.00 468.80 1,635.68 26.7211,830.00Ellipse Separation Pass - W-59 - W-59 - W-59 1,606.51 6,005.00 1,487.99 5,620.13 13.5556,005.00Clearance Factor Pass - W-59 - W-59PB1 - W-59PB1 487.03 1,830.00 468.80 1,635.68 26.7201,830.00Ellipse Separation Pass - W-59 - W-59PB1 - W-59PB1 1,575.22 6,005.00 1,455.07 5,624.50 13.1106,005.00Clearance Factor Pass - ZZ-116 - Z-116 - Z-116 1,399.66 11,730.00 1,177.91 10,407.36 6.31211,730.00Clearance Factor Pass - Z-116 - Z-116 - Z-116 1,308.86 12,180.00 1,117.68 10,570.06 6.84612,180.00Ellipse Separation Pass - Z-116 - Z-116 - Z-116 1,304.61 12,298.75 1,123.45 10,589.52 7.20112,298.75Centre Distance Pass - Z-116 - Z-116PB1 - Z-116PB1 1,399.66 11,730.00 1,177.91 10,407.36 6.31211,730.00Clearance Factor Pass - Z-116 - Z-116PB1 - Z-116PB1 1,308.86 12,180.00 1,117.68 10,570.06 6.84612,180.00Ellipse Separation Pass - Z-116 - Z-116PB1 - Z-116PB1 1,304.61 12,298.75 1,123.45 10,589.52 7.20112,298.75Centre Distance Pass - Z-116 - Z-116PB2 - Z-116PB2 1,399.66 11,730.00 1,177.91 10,407.36 6.31211,730.00Clearance Factor Pass - Z-116 - Z-116PB2 - Z-116PB2 1,308.86 12,180.00 1,117.68 10,570.06 6.84612,180.00Ellipse Separation Pass - Z-116 - Z-116PB2 - Z-116PB2 1,304.61 12,298.75 1,123.45 10,589.52 7.20112,298.75Centre Distance Pass - 16 June, 2025 - 16:15COMPASSPage 4 of 8 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A PH1 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 1,830.00 to 18,113.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: W - Plan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningZ-220 - Z-220 - Z-220 520.57 17,555.00 309.87 17,691.00 2.47117,555.00Clearance Factor Pass - Z-220 - Z-220 - Z-220 387.38 17,830.00 258.36 17,691.00 3.00317,830.00Ellipse Separation Pass - Z-220 - Z-220 - Z-220 378.52 17,912.38 263.43 17,691.00 3.28917,912.38Centre Distance Pass - Z-221 - Z-221 - Z-221 1,296.21 15,555.00 996.60 17,186.00 4.32615,555.00Clearance Factor Pass - Z-221 - Z-221 - Z-221 1,267.80 15,805.00 982.35 17,186.00 4.44115,805.00Ellipse Separation Pass - Z-221 - Z-221 - Z-221 1,183.02 16,692.08 992.23 17,186.00 6.20116,692.08Centre Distance Pass - Z-222 - Z-222 - Z-222 442.01 17,530.00 219.47 17,618.00 1.98617,530.00Clearance Factor Pass - Z-222 - Z-222 - Z-222 346.51 17,730.00 192.45 17,618.00 2.24917,730.00Ellipse Separation Pass - Z-222 - Z-222 - Z-222 335.09 17,818.24 199.24 17,618.00 2.46717,818.24Centre Distance Pass - Z-223 - Z-223 - Z-223 1,374.88 15,355.00 1,080.83 16,855.00 4.67615,355.00Clearance Factor Pass - Z-223 - Z-223 - Z-223 1,367.10 15,455.00 1,076.62 16,855.00 4.70615,455.00Ellipse Separation Pass - Z-223 - Z-223 - Z-223 1,365.79 15,545.05 1,079.96 16,855.00 4.77815,545.05Centre Distance Pass - Z-228 - Z-228 - Z-228 1,149.33 13,855.00 901.03 13,725.00 4.62913,855.00Clearance Factor Pass - Z-228 - Z-228 - Z-228 1,148.06 13,905.00 900.34 13,725.00 4.63513,905.00Ellipse Separation Pass - Z-228 - Z-228 - Z-228 1,148.05 13,909.28 900.40 13,725.00 4.63613,909.28Centre Distance Pass - Z-229 - Z-229 - Z-229 1,309.13 13,780.00 1,065.64 13,305.00 5.37713,780.00Clearance Factor Pass - Z-229 - Z-229 - Z-229 1,307.94 13,830.00 1,064.92 13,305.00 5.38213,830.00Ellipse Separation Pass - Z-229 - Z-229 - Z-229 1,307.81 13,852.26 1,065.08 13,305.00 5.38813,852.26Centre Distance Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool88.75 1,830.003_Gyro-SR-GMS1,830.00 2,230.00 W-35A PH1 wp08 GYD_Quest GWD2,230.00 8,026.00 W-35A PH1 wp08 3_MWD+IFR2+MS+Sag8,026.00 18,113.52 W-35A PH1 wp08 3_MWD+IFR2+MS+Sag16 June, 2025 - 16:15COMPASSPage 5 of 8 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A PH1 wp08Ellipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.16 June, 2025 - 16:15COMPASSPage 6 of 8 0.001.002.003.004.00Separation Factor2550 3400 4250 5100 5950 6800 7650 8500 9350 10200 11050 11900 12750 13600 14450 15300 16150 17000 17850Measured Depth (1700 usft/in)Z-222Z-220W-36W-241W-241PB1W-35W-26BNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: W-35 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 53.02+N/-S +E/-W Northing Easting Latittude Longitude0.000.005959002.08611789.0270° 17' 49.0154 N149° 5' 41.0699 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: W-35, True NorthVertical (TVD) Reference:W-35A planned RKB @ 79.52usftMeasured Depth Reference:W-35A planned RKB @ 79.52usftCalculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2025-04-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool88.75 1830.00 W-35 Srvy 1 BOSS-GYRO (W-35) 3_Gyro-SR-GMS1830.00 2230.00 W-35A PH1 wp08 (Plan: W-35A PH1) GYD_Quest GWD2230.00 8026.00 W-35A PH1 wp08 (Plan: W-35A PH1) 3_MWD+IFR2+MS+Sag8026.00 18113.52 W-35A PH1 wp08 (Plan: W-35A PH1) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)2550 3400 4250 5100 5950 6800 7650 8500 9350 10200 11050 11900 12750 13600 14450 15300 16150 17000 17850Measured Depth (1700 usft/in)W-36W-241W-37W-39W-34NO GLOBAL FILTER: Using user defined selection & filtering criteria1830.00 To 18113.52Project: Prudhoe BaySite: WWell: Plan: W-35Wellbore: Plan: W-35A PH1Plan: W-35A PH1 wp08CASING DETAILSTVD TVDSS MD Size Name1818.83 1739.31 1830.10 13-3/8 13-3/8" x 17 1/2" TOW7227.81 7148.29 8026.00 9-5/8 9-5/8" x 12 1/4"18113.52 8-1/2 8-1/2" Production Open Hole 1 Dewhurst, Andrew D (OGC) From:Joseph Engel <jengel@hilcorp.com> Sent:Thursday, 7 August, 2025 18:14 To:Dewhurst, Andrew D (OGC) Cc:Joseph Lastufka; Lau, Jack J (OGC) Subject:PBU W-35APH1 (PTD 225-072) Updated Schematic and Pages Attachments:PBW W-35APH1 Page 23 v2.pdf; PBU W-35APH1 Proposed Schematic_08.07.2025.pdf; PBW W-35APH1 Page 10 v2.pdf Andy – As per our phone call this morning, attached is the updated schematic and pages (operational steps and cement calculations) for adding the OH P&A kit prior to sidetracking to being drilling W-35. Upon further discussion with our team, Hilcorp deems this the best way to isolate the sands that are drilled through in the pilot hole. These additional steps cover all operations covered under the W-35APH1 PTD submittal, leaving the W- 35A PTD submittal unchanged. Please let me know if you have any questions. Thank you for your time. Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Tuesday, 5 August, 2025 15:00 To:Joseph Engel Cc:Lau, Jack J (OGC); Joseph Lastufka Subject:RE: [EXTERNAL] PBU W-35APB1 (PTD 225-072): Questions Joe, Thank you for this info. And no, “PH1” makes more sense here; calling it “PB1” was a mistake on my end. Andy From: Joseph Engel <jengel@hilcorp.com> Sent: Tuesday, 5 August, 2025 14:02 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] PBU W-35APB1 (PTD 225-072): Questions Thanks, Andy. Answers below. Attached is a new schematic for W-35APH1, speciƱc and up to all operations covered by the W-35A PH1 PTD submittal. Talking with the geologist for this project, Ben Rickards, we do not plan to cross any faults. The depth of the permafrost in the parent bore W-35 is 1805’ MD. A clariƱcation question regarding naming convention, I want to make sure we are on the same page. Prior to submitting these PTDs we were given the guidance to use ‘PH1’ as this is a planned event(email attached), in your email you are referring to the Ʊrst PTD as ‘PB1’. Which would you like us to use going forward? Let me know if you have any more questions for W-35A PH1. I will get answers to your questions on W- 35A later this week. Thanks for your time. Joe From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, August 4, 2025 6:15 PM To: Joseph Engel <jengel@hilcorp.com> 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. 2 Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: [EXTERNAL] PBU W-35APB1 (PTD 225-072): Questions Joe, Thanks for calling earlier. I am completing my review of the PBU W-35APB1 PTD and have a few questions/requests. I will send a separate email for the W-35A PTD. • Would you please create a clearer schematic for the pilot hole? The schematic included is for the W-35A. I see the KOP of the pilot hole, but this could confuse people who might think the pilot hole has been completed with cemented liner etc. • Is this well planning to cross any faults? If so, are there anticipated to be any changes in pore pressure? • What is the depth of the base of permafrost from the parent wellbore? Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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. SCHRADER BLUFF OIL 225-072 PBU W-35APH1 PRUDHOE BAY WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT W-35APH1Initial Class/TypeSER / PENDGeoArea890Unit11650On/Off ShoreOnProgramSERWell bore segAnnular DisposalPTD#:2250720Field & Pool:PRUDHOE BAY, SCHRADER BLUF OIL - 640135NA1Permit fee attachedYesADL028263, ADL028262, and ADL0474502Lease number appropriateYes3Unique well name and numberYesPRUDHOE BAY, SCHRADER BLUF OIL - 640135 - governed by CO 505B, 505B.0044Well 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 pitYes25If a re-drill, has a 10-403 for abandonment been approvedYesW-241 will be shut in during production hole26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYes28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYes5000 psi30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesPBU W Pad has a history of H2S. Ensure detectors are tested and functioning.33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures required35Permit can be issued w/o hydrogen sulfide measuresYesAnticipating pore pressure of 7.1 ppg EMW. Though there is offset WAG injection.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]ApprADDDate31-Jul-25ApprJJLDate06-Aug-25ApprADDDate31-Jul-25AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 8/8/2025