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Home My WebLink About223-090Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40659 BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf T40660 BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf T40661 BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf T40662 BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf T40663 BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf T40664 BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf T40664 BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF T40664 BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf T40665 BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP T40665 BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf T40665 BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf T40665 KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf T40666 KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf T40667 LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch T40668 MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP T40669 PBU 01-12B 50029202690200 223090 4/9/2025 BAKER MRPM T40685 PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN T40670 PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf T40671 PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM T40672 SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP T40673 Please include current contact information if different from above. T40685PBU 01-12B 50029202690200 223090 4/9/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.25 11:56:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/29/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250529 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 5/10/2025 AK E-LINE GPT/CIBP/Perf HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL IRU 241-01 50283201840000 221076 5/7/2025 AK E-LINE Plug/Perf KBU 22-06Y 50133206500000 215044 5/6/2025 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 5/7/2025 AK E-LINE Perf KBU 24-06RD 50133204990100 206013 4/8/2025 YELLOWJACKET GPT-PLUG MPI 1-61 50029225200000 194142 5/10/2025 AK E-LINE Perf MPU E-42 50029236350000 219082 5/3/2025 AK E-LINE Patch MPU S-55 50029238130000 225006 5/13/2025 AK E-LINE CBL OP16-03 50029234420000 211017 4/25/2025 READ LeakDetect PAXTON 13 50133207330000 225021 4/29/2025 YELLOWJACKET SCBL PBU 01-12B 50029202690200 223090 4/8/2025 HALLIBURTON RBT PBU D-08B 50029203720200 225007 3/22/2025 BAKER MRPM PBU H-17B (REVISION)50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU J-25B 50029217410200 224134 3/10/2025 BAKER MRPM PBU K-19C (REVISION)50029225310300 224004 3/27/2025 BAKER MRPM PBU K-19C 50029225310300 224004 3/27/2025 HALLIBURTON RBT SRU 241-33B 50133206960000 221053 3/12/2025 YELLOWJACKET PERF Revision Explanation: Both wells had wrong side stack well name and API#/PTD on previous upload H-17b was marked as H-17A and K-19C was marked as K-19B. Well name now reflets correct sidetrack and has correct SPI# and PTD. T40489 T40490 T40491 T40492 T40492 T40493 T40494 T40495 T40496 T40497 T40498 T40499 T40500 T40501 T40502 T40503 T40503 T40504 PBU 01-12B 50029202690200 223090 4/8/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.29 14:33:01 -08'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 04/25/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: Well: PBU 01-12B PTD: 223-090 API: 50-029-20269-02-00 FINAL LWD FORMATION EVALUATION LOGS (02/21/2025 to 03/27/2025) x BaseStar, iCruise & PCG Gamma Ray, StrataStar & ADR Resistivity, ALD, CTN x Invert/Revert Presentations (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer – Main Folders: Please include current contact information if different from above. 223-090 T40342 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 09:16:45 -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: HAK PBE 01-12B (PTD: 223-090) 7" Casing Test and FIT Date:Saturday, March 15, 2025 11:08:12 AM Attachments:HAK PBE 01-12B 7in Casing Test and FIT.pdf From: Joseph Engel <jengel@hilcorp.com> Sent: Saturday, March 15, 2025 9:36 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: HAK PBE 01-12B (PTD: 223-090) 7" Casing Test and FIT Jack – Attached is the 7” casing test and FIT from 01-12B. Cement job went well. Pumped 32 bbls of 15.8ppg cement with full returns throughout the job. -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 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:PBE 01-12B Date:3/15/2025 Csg Size/Wt/Grade:7"/29#L-80 Supervisor:Clint Montague Csg Setting Depth:9620 TMD 8532 TVD Mud Weight:8.8 ppg LOT / FIT Press =756 psi LOT / FIT =10.50 ppg Hole Depth =9644 md Fluid Pumped=1.05 Bbls Volume Back =1.0 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->0 0 ->0 0 ->2 49 ->2 90 ->4 137 ->4 195 ->6 245 ->6 305 ->8 341 ->8 415 ->10 450 ->10 520 ->12 539 ->15 767 ->14 631 ->20 1034 ->16 718 ->25 1317 ->17 756 ->30 1625 -> ->35 1929 -> ->40 2246 -> ->46 2653 -> -> Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 756 ->0 2653 ->1 731 ->5 2645 ->2 726 ->10 2641 ->3 722 ->15 2640 ->4 719 ->20 2638 ->5 716 ->25 2637 ->6714 ->30 2637 ->7713 -> ->8711 -> ->9709 -> ->10 708 -> -> -> -> -> -> -> 0 2 4 6 8 10 12 14 16 17 0 2 4 6 8 10 15 20 25 30 35 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 0 1020304050Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 756731726722719716714713711709708 2653 2645 2641 2640 2638 2637 2637 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: HAK PBU 01-12B (PTD: 223-090) 9-5/8" Casing Test & FIT Date:Monday, March 3, 2025 11:38:09 AM Attachments:HAK PBU 01-12B 9.625 Casing Test & FIT.pdf From: Joseph Engel <jengel@hilcorp.com> Sent: Monday, March 3, 2025 10:33 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: HAK PBU 01-12B (PTD: 223-090) 9-5/8" Casing Test & FIT Jack – Attached is the casing test and FIT for the 9-5/8” window on 01-12B. 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 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:PBE 01-12B Date:3/2/2025 Csg Size/Wt/Grade:9 5/8"L-80 Supervisor:James Lott Csg Setting Depth:2885 TMD 2885 TVD Mud Weight:9.5 ppg LOT / FIT Press =450 psi LOT / FIT =12.50 ppg Hole Depth =2919 md Fluid Pumped=0.5 Bbls Volume Back =0.5 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->0 0 ->0 27 ->2 64 ->2 132 ->4 156 ->4 263 ->6 270 ->6 377 ->8 361 ->8 469 ->10 436 ->10 555 ->11 455 ->12 642 ->14 ->14 723 ->16 ->16 831 ->18 ->18 924 ->20 ->20 1040 -> ->30 1624 -> ->40 2205 -> ->48 2720 Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 455 ->0 2720 ->1 418 ->5 2648 ->2 398 ->10 2610 ->3 383 ->15 2588 ->4 373 ->20 2572 ->5 363 ->25 2562 ->6353 ->30 2556 ->7343 -> ->8336 -> ->9328 -> ->10 321 -> -> -> -> -> -> -> 0 2 4 6 8 1011 0 2 4 6 8 10 12 14 16 18 20 30 40 48 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 102030405060Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 455418398383373363353343336328321 2720 2648 2610 2588 2572 2562 2556 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 North Slope, LLC 3800 Centerpoint, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay, Prudhoe Oil, PBU 01-12B Hilcorp North Slope, LLC Permit to Drill Number: 223-090 Revised Surface Location: 780’ FNL, 755’ FWL, Sec. 08, T10N, R15E, UM, AK Bottomhole Location: 806’ FSL, 2348’ FEL, Sec. 04, T10N, R15E, 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 AOGCCwithin 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCCreserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this day of )HEUXDU\, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.11 14:39:10 -09'00' Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.31 11:48:36 - 09'00' Sean McLaughlin (4311) By Grace Christianson at 1:28 pm, Jan 31, 2025 50-029-20269-02-00 JJL 2/10/25 223-090 DSR-1/31/25A.Dewhurst 06FEB25 *AOGCC Witnessed BOP Test to 3500 psi, Annular to 2500 psi. *Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FIT. 8:29 am, Feb 06, 2025 *&: 10/23/2023 2/11/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.11 14:39:23 -09'00' RBDMS JSB 021225 28 January 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 01-12B Dear Sir/Madam, Hilcorp North Slope , LLC hereby applies for a Permit to Drill an onshore development well from the Drillsite 01 in Prudhoe Bay, Alaska. 01-12B is planned to be a horizontal producer targeting the Ivishak sands. The parent bore, 01-12A has been reservoir abandoned on a prior sundry. The approximate spud date is anticipated to be February 22th, 2025, pending rig schedule. The Innovation rig will be used to drill this well. The directional plan is two-hole section sidetrack. An 8-1/2” x 9-7/8” intermediate hole exiting the 9-5/8” casing at ~2900’ MD drilled into the top of the Sag River, with 7” casing ran and cemented. A 6-1/8” lateral will be drilled in the Ivishak. A 4-1/2” cemented liner will be run in the open hole section, followed by 4-1/2” tubing. 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 Prudhoe Bay East (PBU) 01-12B Version 1 1/21/2025 Prudhoe Bay East 01-12B Producer 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 .................................................................................................. 14 Attachment 3: Drilling Hazards .................................................................................................... 16 Attachment 4: LOT / FIT Test Procedure ...................................................................................... 1 8 Attachment 5: Cement Summary ................................................................................................. 19 Attachment 6: Prognosed Formation Tops ................................................................................... 20 Attachment 7: Well Schematic..................................................................................................... 21 Attachment 8: Formation Evaluation Program ............................................................................. 23 Attachment 9: Wellhead Diagram ................................................................................................ 24 Attachment 10: Management of Change ..................................................................................... 25 Attachment 11: Directional Plan .................................................................................................. 26 Prudhoe Bay East 01-12B Producer 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 01-12B.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 780' FNL, 755' FWL, Sec 8, T10N, R15E, UM, AK NAD 27 Coordinate System X: 698,088.3 Y: 5,940,126.1 Innovation Rig KB Elevation 26.5’ above GL Ground Level 39.7’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 1140' FSL, 1385' FEL, Sec 5, T10N, R15E, UM, AK NAD 27 Coordinate System X: 701,170.1 Y: 5,942,128.7 Measured Depth, Rig KB (MD) 9,781.12’ Total Vertical Depth, Rig KB (TVD) 8,659.5’ Total vertical Depth, Subsea (TVDSS) 8,560’ Location at Bottom of Productive Interval Reference to Government Section Lines 806' FSL, 2348' FEL, Sec 4, T10N, R15E, UM, AK NAD 27 Coordinate System X: 705,495 Y: 5,941,911 Measured Depth, Rig KB (MD) 14,401.4’ Total Vertical Depth, Rig KB (TVD) 8,739.5’ Total Vertical Depth, Subsea (TVDSS) 8,640’ Prudhoe Bay East 01-12B Producer (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 11: 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 01-12B 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) 8-1/2” x 9-7/8” & 6-1/8” 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: 250/3500 Subsequent Tests: 250/3500 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 located in the doghouse and on accumulator unit. Please refer to Attachment 2: BOPE Equipment for further details. Prudhoe Bay East 01-12B Producer 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; 8-1/2” x 9-7/8” Intermediate Hole Pressure Data Maximum anticipated BHP 3,163 psi in the top Sag River at 8,532’ TVD Maximum surface pressure 2,312 psi from the Sag River (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 8-1/2” x 9-7/8” 12.5 ppg EMW FIT after drilling 20’ of new hole outside of 9- 5/8” window 12.5 provides greater than 25bbl KT based on 10.0 ppg MW 9-5/8” Casing Test 2,500 psi, chart for 30 min (Test pressure driven by 50% of Casing Burst) 6-1/8” Production Hole Pressure Data Maximum anticipated BHP 3,334 psi in the Ivishak Zone 2 at 9,029’ TVD Maximum surface pressure 2,478 psi from the Ivishak Zone 2 (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 6-1/8” hole 10.5 ppg EMW FIT after drilling 20’ of new hole outside of 7” 10.5 provides greater than 25 bbl based on 8.8 ppg MW, 7.2 ppg pore pressure 7” Casing Test 2,500 psi , chart for 30 min (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: Drilling Hazards Prudhoe Bay East 01-12B Producer 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 8-1/2” x 9-7/8” 7” 6.184” 29# L-80 VAMTOP 9,638’ Surface 9,638’ / 8,540’ 6-1/8”4-1/2” Solid 3.958” 12.6# 13Cr80 VAMTOP ~4,886 ~9,488’ 14,374’ / 8,713’ Tubing 4-1/2” Solid 3.958” 12.6# 13Cr80 VAMTOP ~9,488 Surface ~9,488’ / 8,424’ Please refer to Attachment 5: Cement Summary for further details. Prudhoe Bay East 01-12B Producer 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 below the surface casing. 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 6% KCl LSND 3% KCl BaraDril-N Mud Properties: Mud Weight PV YP HPHT Fluid Loss pH MBT 9.5-10.8 ppg 15-25 15-25 < 11.0 9-10 < 12 8.8 – 9.5 ppg 15-25 15-25 < 11 9-10 <7 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 East 01-12B Producer 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 01-12B 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 East 01-12B Producer 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 01-12B 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 approved sundry #324-596 2. 5-1/2” tubing cut at ~3000’ MD Proposed Drilling Program 01-12B 1. MIRU Innovation Rig 2. Verify well is dead. Circulate KWF if needed 3. Set BPV, ND Tree, NU BOPE, test as per PTD 4. Pull BPV, MU landing joint and BOLDS 5. Pull 5-1/2” tubing, pre rig cut ~ 3,000’ MD, confirm with OE 6. MU Mill BHA and perform scraper/cleanout run to top of 5-1/2” tubing stub. 7. PU storm packer and hang off mill bha 8. ND BOPE and tubing spool and install 7” casing spool. NU and shell test same. a. Barriers: Cement plug, KWF, Storm Packer 9. Release storm packer and POOH LD mill bha 10. MU Whipstock and Mill assembly and RIH to set depth ~2091’ MD 11. Orient whipstock to 45* LOHS, set anchor and shear off 12. Circulate wellbore to 9.5ppg milling fluid 13. Test 9-5/8” casing to 2500 psi f/ 30 min, chart test 14. Mill 9-5/8” window & 20’ of new hole 15. Pull milling assembly back into casing, RU and perform FIT to 12.5 ppg EMW 16. POOH and LD milling assembly, gauge mills a. If mills are under gauge, PU back up mills and dress of window 17. MU motor BHA, RIH, trip through window with pumps off and no rotary, drill to 2491’MD to bury 8-1/2” x 9-7/8” RSS BHA. POOH. 18. MU 8-1/2” x 9-7/8” RSS BHA, TIH, trip through window with no pumps or rotary, trip to bottom. Displace well to drilling fluid, 9.5 ppg 19. Drill 8-1/2” x 9-7/8” hole to ~200’ MD above HRZ 20. CBU and perform short trip to window 21. TIH to bottom, add black product to mud for shale stability, increase MW to 10.0ppg and drill ahead to TD 9,638’ MD a. Hold constant bottom hole pressure of ~11.0-11.5 ppg EMW for shale stability *Email digital data of casing test and FIT to AOGCC upon completion of FIT *Test storm packer to 2500 psi before ND BOP Prudhoe Bay East 01-12B Producer 22. CBU, and increase MW t/ 10.5 for shale stability 23. POOH to window offsetting swab with MPD, pull BHA through window with no pumps or rotary, POOH and LD BHA 24. Run 7” long string to TD a. Circulate casing every ~ 2000’MD while RIH 25. Cement 7” casing as per cement program, 26. Lay down landing joint and RILDS 27. Freeze protect 9-5/8” x 7” annulus and 28. Laydown 5” DP and PU 4” DP 29. MU 6-1/8” cleanout assembly, TIH top of 7” shoe track 30. PT 7” casing to 2500 psi, chart test 31. Drill out 7” shoe track & 20’ of new hole 32. Pull back into 7” shoe, perform FIT t/ 10.5 ppg EMW 33. POOH, LD Cleanout BHA 34. MU 6-1/8” RSS BHA, RIH to bottom 35. Drill 6-1/8” lateral as per directional plan to TD 14,374’ MD 36. CBU, and POOH to 7” shoe 37. POOH and LD BHA 38. RU and run 4-1/2” Liner on 4” DP to TD 39. Cement 4-1/2” Liner as per plan 40. Set Liner Hanger/liner top packer, release running tool 41. CBU to remove any cement above liner top packer 42. RU and PT liner to packer / 7” annulus t. 1500 psi f/ 10 min, charted 43. POOH LD running tool 44. Run 4-1/2” tubing as per tally 45. Land Hanger, RILDS 46. Install TWC, ND BOPE, NU Tree 47. PT tubing hanger void 500/5000 psi, PT tree to 250/5000psi 48. Spot CI Brine & Freeze protect 49. Drop Ball & Rod, set tubing packer 50. PT Tubing 3500 psi, with 1000 psi on IA, PT IA to 3500 psi a. All tests 30 min, charted 51. Bleed Pressure on IA to 0 psi, tubing to 200 psi, RU jumper to allowed freeze protect to swap 52. RDMO Post Rig Work 1. Wireline: Pull ball and rod, RHC Plug 2. Service Coil: Perforate Well (Separate Sundry) 3. Well Tie In 4. Put Well on Production Note: This well will not be fracture stimulated *Email digital data of casing test and FIT to AOGCC upon completion of FIT Prudhoe Bay East 01-12B Producer 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 There are no variance requests for this well at this time. Prudhoe Bay East 01-12B Producer Attachment 1: Location & GIS Maps Prudhoe Bay East 01-12B Producer Prudhoe Bay East 01-12B Producer 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 East 01-12B Producer BOPE Configuration: x 13-5/8” Annular x UPR: 4-1/2” x 7” VBR x Blind Rams x LPR: 2-7/8” x 5-1/2” VBR Innovation Rig Choke Manifold Schematic Prudhoe Bay East 01-12B Producer Attachment 3: Drilling Hazards 8-1/2” x 9-7/8” Intermediate Hole Section Hazard Mitigations Hole Cleaning Maintain rheology of mud system, 6 rpm value greater than hole diameter. Maintain flow rates of 200 ft/min AV, 120 rpm. Do not out drill our ability to clean the hole. Pump sweeps as needed. Montior ECDs Lost Circulation / Breathing Monitor ECD with MWD tools. Monitor active mud system. Pump LCM as needed. Ensure adequate LCM is available, follow lost circulation decision tree, Do not drill into sag any further than necessary. Breathing has been seen, treat all flow at wellbore influx until proven otherwise. Casing run Underreamed hole section, sufficient wellbore clean up, pinned float shoe, circulation schedule while RIH, monitor drag trends Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations – MPD to maintain CBHP Shale Stability Hole section will cross multiple shale formations. Directional plan and MW have been chosen based upon historical stability window. Ensure black product has been added to the mud system, MPD to maintain CBHP to minimize pressure cycling, swab pressures. Ensure sufficient MW is left in the well at TD. Pack Off During Cementing Clean up well bore at TD, and prior to running casing. Stage circulation rates up following circulation schedule Circulate bottoms up at multiple depths to condition mud the way in the hole. Circulate at TD to planned cementing rates and ensure hole is clean. Keep circulation rates below drilling ECDS, model accordingly, low displacement rates Gas Cut Mud Gas cut mud as been seen. Ensure sufficient MW is used during hole section. Monitor wells and MPD while drilling and on connections. Ensure gas detectors are tested and functioning. Watch swab effect while TOOH 6-1/8” Production Hole Section Hazard Mitigations Offset Injection There are no offset injectors that need to be shut in Lost Returns / Breathing Monitor ECD with MWD tools. Have adequate LCM available. Breathing has been seen, treat all flow as influx until proven otherwise. Have sufficient fluid available. Faulting Be prepared for faulting, known and unknown. Losses can occur after faults, if losses are extreme consider suspending well operations. Hole Swabbing Reduce tripping speed, lower mud rheology, offset swab with MPD, pump out of the hole if required. Abnormal Pressures Lower than normal pressures in the target reservoir. Ensure LCM Prudhoe Bay East 01-12B Producer in the mud systems and monitor fluid systems. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Anti Collision See Close Approaches in Directional Plan attachment. Continually monitor surveys for magnetic interference. Shale / Wellbore Instability Maintain adequate mud weight / back-pressure for wellbore stability. Monitor cuttings returns, LWD logs, and drilling. Production hole could cross multiple shale formations. MPD to minimize pressure cycles on formation. DS 01 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. DS 01 H2S History: Wells with over 100ppm H2S readings: Prudhoe Bay East 01-12B Producer Attachment 4: LOT / FIT Test Procedure Prudhoe Bay East 01-12B Producer Attachment 5: Cement Summary 7” Intermediate Casing Cement OH x CSG 8.5” x 9-7/8” OH x 7” Casing Basis Cement Vol Open hole volume + excess + 120’ ft shoe track TOC 500’ MD above Sag (Top Sag: 9632’ MD, TOC 9132’ MD) Total Cement Volume Spacer 60 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess 15.8ppg:31.7 bbls, 177.8 ft3, 153.3 sks HalCem Class G – 1.16 cuft/sk BHST 170 deg F Displacement (9638’ – 120’) * .0371bpf =353.6 bbl 4-1/2” Liner Cement OH x CSG 6-1/8” OH x 4-1/2” Liner Basis Cement Vol CH volume (150’ 7” Liner Lap) + (OH volume x 30%) + 120’ ft shoe track TOC 7” x 5” Liner Top, ~ 9,488’ MD Total Cement Volume Spacer 30 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess 15.8ppg:107.8 bbls, 604.8 ft3, 521.3 sks HalCem Class G – 1.16 cuft/sk BHST 170 -180 deg F Displacement (14374 – 9488 – 120) * .0152bpf (4-1/2” capacity) + 9638 * .0103 bpf (4” dp capacity) 72.4 + 99.3 =171.7 bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 8.5" Pilot Hole x 7" (120') (9638 - 9518)' x 0.0226 bpf x 1.3 = 3.6 20.2 9.875" OH x 7" (9518 - 9132) x .0471bpf x 1.3 = 23.6 132.4 7" Shoetrack 120' x 0.0372 bpf = 4.5 25.2 Total Tail 31.7 177.8 153.3Tail Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 6-1/8" OH x 4-1/2" (14,374 - 9,638)' x 0.0168 bpf x 1.3 = 103.4 580.1 7" CH x 4-1/2" (9,638 - 9,488) x .0175 bpf = 2.6 14.6 4-1/2" Shoetrack 120' x 0.0152 bpf = 1.8 10.1 Total Tail 107.8 604.8 521.3Tail Prudhoe Bay East 01-12B Producer Attachment 6: Prognosed Formation Tops ͏͐ϱ͐͑϶ſŕ͏͘ >ĺŘıÍťĖĺĲ "ôŜèŘĖŕťĖĺĲ «"a" ĺŘôώŘôŜŜŪŘô @ώ(a®ώŕŜĖ «͔ ϱ͔͑͗͘ ͕͕͑͑8.4 1135 «͓ ϱ͕͑͗͐ ͑͗͗͘8.4 1235 «͒ ϱ͓͕͒͒ ͔͒͒͑8.4 1506 «͑ ϱ͕͕͒͒ ͖͔͒͑8.4 1594 «͐ ϱ͓͏͕͒ ͓͕͑͑9.1 1918 @͒ ČĲŪώϼŜÍĲîŜϽ ϱ͓͕͗͗ ͔͓͕͑9.1 2298 @͐ ČĲŪώϼŜÍĲîŜϽ ϱ͔͔͒͑ ͕͏͔͘9.1 2612 ®͑ èēŘÍîôŘώϼŜÍĲîŜϽ ϱ͕͐͏͖ ͕͖͕͐9.1 2883 ®͐ èēŘÍîôŘώϼŜÍĲîŜϽ ϱ͕͓͐͏ ͖͐͒͑8.5 2826 a͒ ĺīŽĖīīôώϼŜēÍīôϽ ϱ͕͖͓͔ ͖͔͓͑8.8 3097 a͑ ĺīŽĖīīôώϼŜēÍīôϽ ϱ͖͏͘͏ ͖͕͓͘9.8 3613 a͐ ĺīŽĖīīôώϼŜēÍīôϽ ϱ͖͖͕͒ ͖͗͗͗9.8 3956 F¾ F¾ώϼŜēÍīôϽ ϱ͗͐͑͘ ͔͑͒͘ F¾ F¾ώϼŜēÍīôϽ ϱ͗͒͑͑ ͓͖͐͘ [ώϯώÍŜôώXĖĲČÍħ XĖĲČÍħώϼŜēÍīôϽ ϱ͔͗͒͐ ͔͘͏͕ @ ÍČώϼŜÍĲîϽ ϱ͓͔͗͘ ͕͒͑͘7.2 3163 F ēŪæīĖħώϼŜēÍīôϽ ϱ͓͗͘͏ ͕͖͕͘ " IŽĖŜēÍħώϼŜÍĲîϽ ϱ͔͕͗͏ ͖͕͕͘7.2 3187 ͓ώϼ͓͑bϽ ϱ͕͗͗͏ ͒͒͘͘7.2 3232 ¾͒ώϼ@[Ͻ ϱ͖͓͓͗ ͐͏͏͒͑7.2 3256 ͑ώϼ@[Ͻ ϱ͖͗͘͘ ͐͏͐͑͘7.2 3276 ͑ώϼ͓͑bϽ ϱ͗͘͏͏ ͐͏͔͔͒7.2 3314 ͑ώϼ͑͑Ͻ ϱ͔͕͗͘ ͐͏͔͖͕7.2 3334 Prudhoe Bay East 01-12B Producer Attachment 7: Well Schematic Post Sundry Schematic, Well Status When Rig Arrives Prudhoe Bay East 01-12B Producer Prudhoe Bay East 01-12B Producer Attachment 8: Formation Evaluation Program 8-1/2” x 9-7/8”” Intermediate Hole LWD Gamma Ray Resistivity 6-1/8” Production Hole LWD Gamma Ray Resistivity Density Neutron Mudlogging No mudlogging is planned for 01-12B Prudhoe Bay East 01-12B Producer Attachment 9: Wellhead Diagram Prudhoe Bay East 01-12B Producer Attachment 10: Management of Change Prudhoe Bay East 01-12B Producer Attachment 11: Directional Plan Intermediate Section Offset Wells with CF < 1.0: x 01-12/12A, Close approach at 2,902’ MD, is the parent well bore for this sidetrack and 01-12B will deviate from it Production Section Offset Wells with CF < 1.0: x 01-06, close approach at 12,875’ MD, is an abandoned wellbore. The only risk is damage to the bit. x 01-01A, close approach 13,887 – 14000’ MD, is an abandoned wellbore. The only risk is damage to the bit Standard Proposal Report 22 January, 2025 Plan: 01-12B wp09 Hilcorp North Slope, LLC Prudhoe Bay 01 Plan: 01-12 Plan: 01-12B 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750True Vertical Depth (1500 usft/in)0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 Vertical Section at 100.00° (1500 usft/in) 01-12B wp09 tgt3 01-12B wp09 tgt201-12B wp09 tgt1 01-12B wp09 tgt411000115001 2 0 0 0 12 5 00 12580 01-12A 2500 3 5 0 0 4 000 4500500055006000650070007500800085009000950010000105001100011500120001200101-12 7" x 8 1/2" 4 1/2" x 6 1/8" 3 0 00 3500 4000 450 0 5 0 0 0 5 5 0 0 6 0 00 6500 7 0 0 0 7 5 0 0 8 0 00 8 5 0 0 9 0 0 0 9 5 0 0 1000010500110001150012000125001300013500140001437501-12B wp09 KOP : Start Dir 12.3º/100' : 2900' MD, 2899.59'TVD : 30° LT TF End Dir : 2917' MD, 2916.55' TVD Start Dir 4º/100' : 2937' MD, 2936.47'TVD Start Dir 3.5º/100' : 3237' MD, 3230.62'TVD End Dir : 3906.67' MD, 3834.58' TVD Start Dir 6º/100' : 9632.72' MD, 8536.08'TVD End Dir : 11024.16' MD, 8997.88' TVD Start Dir 6º/100' : 11867.89' MD, 8756.33'TVD End Dir : 12464.87' MD, 8757.19' TVD Start Dir 6º/100' : 12940.94' MD, 8900.42'TVD Start Dir 5º/100' : 13254.35' MD, 8948'TVD End Dir : 13560.37' MD, 8910.65' TVD Total Depth : 14374.92' MD, 8713' TVD SV3 SV2 SV1 UG3 UG1 WS2 WS1 CM3 CM2 CM1 THRZ BHRZ LCU TSGR TSHU TSAD T4A (42N)T4A (42N)TZ3 (TCGL) TZ3 (TCGL) T2C (BCGL) T2C (BCGL) T2B (24N) T2A (22P) Hilcorp North Slope, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: 01-12 Ground Level: 39.70+N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5940126.51 698088.31 70° 14' 25.9320 N 148° 24' 0.6554 W SURVEY PROGRAM Date: 2024-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 500.00 2900.00 1 : Camera based gyro multisho (01-12) 3_CB-Film-GMS 2900.00 3100.00 01-12B wp09 (Plan: 01-12B) GYD_Quest GWD 3100.00 9637.00 01-12B wp09 (Plan: 01-12B) 3_MWD+IFR2+MS+Sag 9637.00 14374.92 01-12B wp09 (Plan: 01-12B) 3_MWD+IFR2+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation2662.00 2589.00 2662.26 SV5 2889.00 2816.00 2889.40 SV4 3509.00 3436.00 3533.40 SV3 3709.00 3636.00 3757.75 SV2 4136.00 4063.00 4273.77 SV1 4941.00 4868.00 5254.20 UG35605.00 5532.00 6062.90 UG16180.00 6107.00 6763.20 WS26483.00 6410.00 7132.23 WS1 6818.00 6745.00 7540.24 CM3 7163.00 7090.00 7960.42 CM2 7836.00 7763.00 8780.08 CM1 8202.00 8129.00 9225.84 THRZ 8395.00 8322.00 9460.90 BHRZ8424.00 8351.00 9496.22 LCU8532.00 8459.00 9627.75 TSGR8563.00 8490.00 9665.77 TSHU8633.00 8560.00 9754.62 TSAD8753.00 8680.00 9920.87 T4A (42N) 8817.00 8744.00 10020.80 TZ3 (TCGL) 8872.00 8799.00 10116.93 T2C (BCGL) 8973.00 8900.00 10343.39 T2B (24N) 9029.00 8956.00 10565.81 T2A (22P) REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: 01-12, True North Vertical (TVD) Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Measured Depth Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Calculation Method:Minimum Curvature Project:Prudhoe Bay Site:01 Well:Plan: 01-12 Wellbore:Plan: 01-12B Design:01-12B wp09 CASING DETAILS TVD TVDSS MD Size Name 2900.59 2827.59 2901.00 9-5/8 9 5/8" x 12 1/4" TOW 8540.41 8467.41 9638.00 7 7" x 8 1/2" 8713.00 8640.00 14374.92 4-1/2 4 1/2" x 6 1/8" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 2900.00 3.00 118.00 2899.59 -15.54 27.01 0.00 0.00 29.30 KOP : Start Dir 12.3º/100' : 2900' MD, 2899.59'TVD : 30° LT TF 2 2917.00 4.92 105.73 2916.55 -15.95 28.10 12.30 -30.00 30.44 End Dir : 2917' MD, 2916.55' TVD 3 2937.00 4.92 105.73 2936.47 -16.42 29.75 0.00 0.00 32.15 Start Dir 4º/100' : 2937' MD, 2936.47'TVD 4 3237.00 16.77 93.56 3230.62 -22.62 85.54 4.00 -17.00 88.17 Start Dir 3.5º/100' : 3237' MD, 3230.62'TVD 5 3906.67 34.81 56.45 3834.58 78.42 344.88 3.50 -59.99 326.02 End Dir : 3906.67' MD, 3834.58' TVD 6 9632.72 34.81 56.45 8536.08 1884.83 3068.93 0.00 0.00 2695.01 Start Dir 6º/100' : 9632.72' MD, 8536.08'TVD 7 10725.41 90.00 100.00 9041.00 1972.05 3967.09 6.00 49.18 3564.38 01-12B wp09 tgt1 8 11024.16 106.64 106.77 8997.88 1904.26 4253.58 6.00 21.53 3858.29 End Dir : 11024.16' MD, 8997.88' TVD 9 11867.89 106.64 106.77 8756.33 1671.00 5027.60 0.00 0.00 4661.06 Start Dir 6º/100' : 11867.89' MD, 8756.33'TVD 10 12135.90 92.00 100.00 8713.00 1610.30 5284.12 6.00 -154.83 4924.21 01-12B wp09 tgt2 11 12464.87 72.49 96.97 8757.19 1562.25 5604.88 6.00 -171.41 5248.45 End Dir : 12464.87' MD, 8757.19' TVD 12 12940.94 72.49 96.97 8900.42 1507.18 6055.55 0.00 0.00 5701.83 Start Dir 6º/100' : 12940.94' MD, 8900.42'TVD 13 13254.35 90.00 90.00 8948.00 1488.89 6363.36 6.00 -22.10 6008.14 01-12B wp09 tgt3 Start Dir 5º/100' : 13254.35' MD, 8948'TVD 14 13560.37 104.04 83.86 8910.65 1504.86 6665.75 5.00 -23.14 6303.17 End Dir : 13560.37' MD, 8910.65' TVD 15 14374.92 104.04 83.86 8713.00 1589.34 7451.44 0.00 0.00 7062.25 01-12B wp09 tgt4 Total Depth : 14374.92' MD, 8713' TVD -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 South(-)/North(+) (800 usft/in)0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 West(-)/East(+) (800 usft/in) 01-12B wp09 tgt4 01-12B wp09 tgt1 01-12B wp09 tgt2 01-12B wp09 tgt3 8 7 5 0914501-12A 125030003250375040004250450047505000525055005750600062506500675070007250750077508000825085008750929601-12 7" x 8 1/2" 4 1/2" x 6 1/8" 3 7 5 0 4 2 5 0 4 5 0 0 4 7 5 0 5 0 0 0 5 2 5 0 5 5 0 0 5 7 5 0 6 0 0 0 6 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 0 7 5 0 0 7 7 5 0 8 0 0 0 8 2 5 0 8 5 0 0 87509000871301-12B wp09 KOP : Start Dir 12.3º/100' : 2900' MD, 2899.59'TVD : 30° LT TF End Dir : 2917' MD, 2916.55' TVD Start Dir 4º/100' : 2937' MD, 2936.47'TVD Start Dir 3.5º/100' : 3237' MD, 3230.62'TVD End Dir : 3906.67' MD, 3834.58' TVD Start Dir 6º/100' : 9632.72' MD, 8536.08'TVD End Dir : 11024.16' MD, 8997.88' TVD Start Dir 6º/100' : 11867.89' MD, 8756.33'TVD End Dir : 12464.87' MD, 8757.19' TVD Start Dir 6º/100' : 12940.94' MD, 8900.42'TVD Start Dir 5º/100' : 13254.35' MD, 8948'TVD End Dir : 13560.37' MD, 8910.65' TVD Total Depth : 14374.92' MD, 8713' TVD CASING DETAILS TVD TVDSS MD Size Name 2900.59 2827.59 2901.00 9-5/8 9 5/8" x 12 1/4" TOW 8540.41 8467.41 9638.00 7 7" x 8 1/2" 8713.00 8640.00 14374.92 4-1/2 4 1/2" x 6 1/8" Project: Prudhoe Bay Site: 01 Well: Plan: 01-12 Wellbore: Plan: 01-12B Plan: 01-12B wp09 WELL DETAILS: Plan: 01-12 Ground Level: 39.70 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5940126.51 698088.31 70° 14' 25.9320 N 148° 24' 0.6554 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: 01-12, True NorthVertical (TVD) Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Measured Depth Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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: 01, TR-10-15 usft Map usft usft °1.50Slot Radius:"0 5,941,932.14 697,237.60 5.00 70° 14' 43.9047 N 148° 24' 24.0037 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: 01-12, 01-12 usft usft 0.00 0.00 5,940,126.51 698,088.31 39.70Wellhead Elevation:usft0.00 70° 14' 25.9320 N 148° 24' 0.6554 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Plan: 01-12B Model NameMagnetics BGGM2024 3/23/2025 14.55 80.68 57,046.60808282 Phase:Version: Audit Notes: Design 01-12B wp09 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:2,900.00 100.000.000.0033.30 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 0.000.000.000.0027.01-15.542,899.59118.003.002,900.00 2,826.59 -30.00-72.2011.3112.3028.10-15.952,916.55105.734.922,917.00 2,843.55 0.000.000.000.0029.75-16.422,936.47105.734.922,937.00 2,863.47 -17.00-4.053.954.0085.54-22.623,230.6293.5616.773,237.00 3,157.62 -59.99-5.542.693.50344.8878.423,834.5856.4534.813,906.67 3,761.58 0.000.000.000.003,068.931,884.838,536.0856.4534.819,632.72 8,463.08 49.183.995.056.003,967.091,972.059,041.00100.0090.0010,725.41 8,968.00 21.532.275.576.004,253.581,904.268,997.88106.77106.6411,024.16 8,924.88 0.000.000.000.005,027.601,671.008,756.33106.77106.6411,867.89 8,683.33 -154.83-2.53-5.466.005,284.121,610.308,713.00100.0092.0012,135.90 8,640.00 -171.41-0.92-5.936.005,604.881,562.258,757.1996.9772.4912,464.87 8,684.19 0.000.000.000.006,055.551,507.188,900.4296.9772.4912,940.94 8,827.42 -22.10-2.225.596.006,363.361,488.898,948.0090.0090.0013,254.35 8,875.00 -23.14-2.014.595.006,665.751,504.868,910.6583.86104.0413,560.37 8,837.65 0.000.000.000.007,451.441,589.348,713.0083.86104.0414,374.92 8,640.00 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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 -39.70 Vert Section 33.30 0.00 33.30 0.00 0.000.00 698,088.315,940,126.51-39.70 0.00 0.00 500.00 0.17 500.00 -0.48 0.50134.00 698,088.825,940,126.04427.00 0.04 0.57 1,000.00 0.17 1,000.00 -0.59 1.6557.00 698,089.985,940,125.96927.00 0.04 1.73 1,400.00 0.25 1,400.00 -0.22 3.0287.00 698,091.345,940,126.371,327.00 0.03 3.02 1,500.00 1.00 1,499.99 -0.64 4.00119.00 698,092.335,940,125.981,426.99 0.80 4.05 1,600.00 1.00 1,599.97 -1.88 5.07160.00 698,093.425,940,124.771,526.97 0.70 5.31 1,700.00 1.00 1,699.96 -3.57 5.36180.00 698,093.775,940,123.081,626.96 0.35 5.90 1,800.00 1.00 1,799.94 -5.31 5.46174.00 698,093.905,940,121.341,726.94 0.10 6.29 1,900.00 1.00 1,899.93 -6.73 6.22129.00 698,094.715,940,119.951,826.93 0.77 7.30 2,000.00 1.00 1,999.92 -7.69 7.67118.00 698,096.185,940,119.031,926.92 0.19 8.89 2,100.00 1.00 2,099.90 -7.81 9.2771.00 698,097.785,940,118.942,026.90 0.80 10.48 2,200.00 1.00 2,199.89 -7.35 10.9578.00 698,099.455,940,119.452,126.89 0.12 12.06 2,300.00 1.50 2,299.86 -6.92 13.0979.00 698,101.575,940,119.942,226.86 0.50 14.09 2,400.00 1.50 2,399.83 -6.51 15.6783.00 698,104.145,940,120.422,326.83 0.10 16.56 2,500.00 1.50 2,499.80 -6.88 18.16114.00 698,106.655,940,120.112,426.80 0.80 19.08 2,600.00 1.50 2,599.76 -8.44 20.17142.00 698,108.695,940,118.602,526.76 0.73 21.33 2,700.00 1.50 2,699.73 -10.52 21.76143.00 698,110.345,940,116.572,626.73 0.03 23.26 2,734.00 1.67 2,733.72 -11.27 22.33142.59 698,110.935,940,115.832,660.72 0.50 23.95 13 3/8" 2,800.00 2.00 2,799.68 -12.94 23.62142.00 698,112.265,940,114.202,726.68 0.50 25.51 2,900.00 3.00 2,899.59 -15.54 27.01118.00 698,115.715,940,111.682,826.59 1.43 29.30 2,900.01 3.00 2,899.60 -15.54 27.01118.00 698,115.715,940,111.682,826.60 0.01 29.30 KOP : Start Dir 12.3º/100' : 2900' MD, 2899.59'TVD : 30° LT TF 2,901.00 3.11 2,900.59 -15.57 27.05116.87 698,115.765,940,111.662,827.59 12.42 29.35 9 5/8" x 12 1/4" TOW 2,917.00 4.92 2,916.55 -15.95 28.10105.73 698,116.825,940,111.302,843.55 12.30 30.44 End Dir : 2917' MD, 2916.55' TVD 2,937.00 4.92 2,936.47 -16.42 29.75105.73 698,118.485,940,110.882,863.47 0.00 32.15 Start Dir 4º/100' : 2937' MD, 2936.47'TVD 3,000.00 7.37 2,999.11 -17.85 36.3499.97 698,125.105,940,109.622,926.11 4.00 38.88 3,100.00 11.32 3,097.76 -19.98 52.4295.99 698,141.235,940,107.913,024.76 4.00 55.09 3,200.00 15.30 3,195.06 -21.94 75.3594.05 698,164.205,940,106.563,122.06 4.00 78.01 3,237.00 16.77 3,230.62 -22.62 85.5493.56 698,174.415,940,106.153,157.62 4.00 88.17 Start Dir 3.5º/100' : 3237' MD, 3230.62'TVD 3,300.00 17.97 3,290.75 -22.74 104.3287.36 698,193.195,940,106.533,217.75 3.50 106.69 3,400.00 20.22 3,385.26 -18.77 136.7179.14 698,225.465,940,111.343,312.26 3.50 137.90 3,500.00 22.77 3,478.31 -9.72 172.1672.59 698,260.665,940,121.323,405.31 3.50 171.23 3,533.40 23.67 3,509.00 -5.57 184.6670.71 698,273.045,940,125.793,436.00 3.50 182.82 SV3 3,600.00 25.54 3,569.56 4.37 210.5367.35 698,298.645,940,136.413,496.56 3.50 206.57 3,700.00 28.46 3,658.66 23.47 251.6863.09 698,339.285,940,156.583,585.66 3.50 243.79 3,757.75 30.20 3,709.00 36.74 276.6560.98 698,363.895,940,170.503,636.00 3.50 266.07 SV2 3,800.00 31.49 3,745.28 47.48 295.4659.58 698,382.415,940,181.733,672.28 3.50 282.73 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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 3,761.58 Vert Section 3,906.67 34.81 3,834.58 78.42 344.8856.45 698,430.995,940,213.963,761.58 3.50 326.02 End Dir : 3906.67' MD, 3834.58' TVD 4,000.00 34.81 3,911.21 107.87 389.2856.45 698,474.605,940,244.563,838.21 0.00 364.63 4,100.00 34.81 3,993.32 139.41 436.8556.45 698,521.325,940,277.353,920.32 0.00 406.00 4,200.00 34.81 4,075.43 170.96 484.4256.45 698,568.055,940,310.134,002.43 0.00 447.38 4,273.77 34.81 4,136.00 194.23 519.5256.45 698,602.525,940,334.324,063.00 0.00 477.90 SV1 4,300.00 34.81 4,157.54 202.51 532.0056.45 698,614.775,940,342.914,084.54 0.00 488.75 4,400.00 34.81 4,239.64 234.05 579.5756.45 698,661.505,940,375.704,166.64 0.00 530.12 4,500.00 34.81 4,321.75 265.60 627.1456.45 698,708.225,940,408.484,248.75 0.00 571.49 4,600.00 34.81 4,403.86 297.15 674.7256.45 698,754.955,940,441.274,330.86 0.00 612.87 4,700.00 34.81 4,485.96 328.70 722.2956.45 698,801.675,940,474.054,412.96 0.00 654.24 4,800.00 34.81 4,568.07 360.24 769.8656.45 698,848.405,940,506.844,495.07 0.00 695.61 4,900.00 34.81 4,650.18 391.79 817.4356.45 698,895.125,940,539.624,577.18 0.00 736.98 5,000.00 34.81 4,732.28 423.34 865.0156.45 698,941.855,940,572.414,659.28 0.00 778.35 5,100.00 34.81 4,814.39 454.88 912.5856.45 698,988.575,940,605.194,741.39 0.00 819.73 5,200.00 34.81 4,896.50 486.43 960.1556.45 699,035.305,940,637.974,823.50 0.00 861.10 5,254.20 34.81 4,941.00 503.53 985.9456.45 699,060.625,940,655.744,868.00 0.00 883.52 UG3 5,300.00 34.81 4,978.61 517.98 1,007.7356.45 699,082.025,940,670.764,905.61 0.00 902.47 5,400.00 34.81 5,060.71 549.53 1,055.3056.45 699,128.755,940,703.544,987.71 0.00 943.84 5,500.00 34.81 5,142.82 581.07 1,102.8756.45 699,175.475,940,736.335,069.82 0.00 985.21 5,600.00 34.81 5,224.93 612.62 1,150.4556.45 699,222.205,940,769.115,151.93 0.00 1,026.59 5,700.00 34.81 5,307.03 644.17 1,198.0256.45 699,268.925,940,801.905,234.03 0.00 1,067.96 5,800.00 34.81 5,389.14 675.72 1,245.5956.45 699,315.655,940,834.685,316.14 0.00 1,109.33 5,900.00 34.81 5,471.25 707.26 1,293.1656.45 699,362.375,940,867.475,398.25 0.00 1,150.70 6,000.00 34.81 5,553.36 738.81 1,340.7456.45 699,409.105,940,900.255,480.36 0.00 1,192.08 6,062.90 34.81 5,605.00 758.65 1,370.6656.45 699,438.495,940,920.875,532.00 0.00 1,218.10 UG1 6,100.00 34.81 5,635.46 770.36 1,388.3156.45 699,455.825,940,933.045,562.46 0.00 1,233.45 6,200.00 34.81 5,717.57 801.90 1,435.8856.45 699,502.555,940,965.825,644.57 0.00 1,274.82 6,300.00 34.81 5,799.68 833.45 1,483.4656.45 699,549.275,940,998.605,726.68 0.00 1,316.19 6,400.00 34.81 5,881.78 865.00 1,531.0356.45 699,596.005,941,031.395,808.78 0.00 1,357.56 6,500.00 34.81 5,963.89 896.55 1,578.6056.45 699,642.725,941,064.175,890.89 0.00 1,398.94 6,600.00 34.81 6,046.00 928.09 1,626.1856.45 699,689.455,941,096.965,973.00 0.00 1,440.31 6,700.00 34.81 6,128.11 959.64 1,673.7556.45 699,736.175,941,129.746,055.11 0.00 1,481.68 6,763.20 34.81 6,180.00 979.58 1,703.8256.45 699,765.715,941,150.466,107.00 0.00 1,507.83 WS2 6,800.00 34.81 6,210.21 991.19 1,721.3256.45 699,782.905,941,162.536,137.21 0.00 1,523.05 6,900.00 34.81 6,292.32 1,022.73 1,768.8956.45 699,829.625,941,195.316,219.32 0.00 1,564.43 7,000.00 34.81 6,374.43 1,054.28 1,816.4756.45 699,876.355,941,228.106,301.43 0.00 1,605.80 7,100.00 34.81 6,456.53 1,085.83 1,864.0456.45 699,923.075,941,260.886,383.53 0.00 1,647.17 7,132.23 34.81 6,483.00 1,096.00 1,879.3756.45 699,938.135,941,271.456,410.00 0.00 1,660.51 WS1 7,200.00 34.81 6,538.64 1,117.38 1,911.6156.45 699,969.805,941,293.676,465.64 0.00 1,688.54 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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 6,547.75 Vert Section 7,300.00 34.81 6,620.75 1,148.92 1,959.1956.45 700,016.525,941,326.456,547.75 0.00 1,729.91 7,400.00 34.81 6,702.86 1,180.47 2,006.7656.45 700,063.255,941,359.236,629.86 0.00 1,771.29 7,500.00 34.81 6,784.96 1,212.02 2,054.3356.45 700,109.975,941,392.026,711.96 0.00 1,812.66 7,540.24 34.81 6,818.00 1,224.71 2,073.4756.45 700,128.775,941,405.216,745.00 0.00 1,829.31 CM3 7,600.00 34.81 6,867.07 1,243.56 2,101.9156.45 700,156.705,941,424.806,794.07 0.00 1,854.03 7,700.00 34.81 6,949.18 1,275.11 2,149.4856.45 700,203.425,941,457.596,876.18 0.00 1,895.40 7,800.00 34.81 7,031.28 1,306.66 2,197.0556.45 700,250.155,941,490.376,958.28 0.00 1,936.78 7,900.00 34.81 7,113.39 1,338.21 2,244.6356.45 700,296.875,941,523.167,040.39 0.00 1,978.15 7,960.42 34.81 7,163.00 1,357.27 2,273.3756.45 700,325.115,941,542.967,090.00 0.00 2,003.14 CM2 8,000.00 34.81 7,195.50 1,369.75 2,292.2056.45 700,343.605,941,555.947,122.50 0.00 2,019.52 8,100.00 34.81 7,277.61 1,401.30 2,339.7756.45 700,390.325,941,588.737,204.61 0.00 2,060.89 8,200.00 34.81 7,359.71 1,432.85 2,387.3456.45 700,437.055,941,621.517,286.71 0.00 2,102.26 8,300.00 34.81 7,441.82 1,464.39 2,434.9256.45 700,483.785,941,654.297,368.82 0.00 2,143.64 8,400.00 34.81 7,523.93 1,495.94 2,482.4956.45 700,530.505,941,687.087,450.93 0.00 2,185.01 8,500.00 34.81 7,606.03 1,527.49 2,530.0656.45 700,577.235,941,719.867,533.03 0.00 2,226.38 8,600.00 34.81 7,688.14 1,559.04 2,577.6456.45 700,623.955,941,752.657,615.14 0.00 2,267.75 8,700.00 34.81 7,770.25 1,590.58 2,625.2156.45 700,670.685,941,785.437,697.25 0.00 2,309.12 8,780.08 34.81 7,836.00 1,615.85 2,663.3156.45 700,708.095,941,811.697,763.00 0.00 2,342.26 CM1 8,800.00 34.81 7,852.36 1,622.13 2,672.7856.45 700,717.405,941,818.227,779.36 0.00 2,350.50 8,900.00 34.81 7,934.46 1,653.68 2,720.3656.45 700,764.135,941,851.007,861.46 0.00 2,391.87 9,000.00 34.81 8,016.57 1,685.22 2,767.9356.45 700,810.855,941,883.797,943.57 0.00 2,433.24 9,100.00 34.81 8,098.68 1,716.77 2,815.5056.45 700,857.585,941,916.578,025.68 0.00 2,474.61 9,200.00 34.81 8,180.78 1,748.32 2,863.0756.45 700,904.305,941,949.368,107.78 0.00 2,515.99 9,225.84 34.81 8,202.00 1,756.47 2,875.3756.45 700,916.375,941,957.838,129.00 0.00 2,526.68 THRZ 9,300.00 34.81 8,262.89 1,779.87 2,910.6556.45 700,951.035,941,982.148,189.89 0.00 2,557.36 9,400.00 34.81 8,345.00 1,811.41 2,958.2256.45 700,997.755,942,014.928,272.00 0.00 2,598.73 9,460.90 34.81 8,395.00 1,830.62 2,987.1956.45 701,026.215,942,034.898,322.00 0.00 2,623.92 BHRZ 9,496.22 34.81 8,424.00 1,841.77 3,003.9956.45 701,042.715,942,046.478,351.00 0.00 2,638.54 LCU 9,500.00 34.81 8,427.11 1,842.96 3,005.7956.45 701,044.485,942,047.718,354.11 0.00 2,640.10 9,600.00 34.81 8,509.21 1,874.51 3,053.3756.45 701,091.205,942,080.498,436.21 0.00 2,681.47 9,627.75 34.81 8,532.00 1,883.26 3,066.5756.45 701,104.175,942,089.598,459.00 0.00 2,692.96 TSGR 9,632.72 34.81 8,536.08 1,884.83 3,068.9356.45 701,106.495,942,091.228,463.08 0.00 2,695.01 Start Dir 6º/100' : 9632.72' MD, 8536.08'TVD 9,638.00 35.02 8,540.41 1,886.49 3,071.4656.87 701,108.975,942,092.958,467.41 6.00 2,697.21 7" x 8 1/2" 9,650.00 35.49 8,550.21 1,890.23 3,077.2957.80 701,114.705,942,096.848,477.21 6.00 2,702.30 9,665.77 36.13 8,563.00 1,895.06 3,085.1559.00 701,122.435,942,101.888,490.00 6.00 2,709.20 TSHU 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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 8,517.39 Vert Section 9,700.00 37.56 8,590.39 1,905.25 3,102.9661.46 701,139.975,942,112.528,517.39 6.00 2,724.98 9,750.00 39.72 8,629.45 1,919.33 3,130.8164.79 701,167.445,942,127.348,556.45 6.00 2,749.96 9,754.62 39.92 8,633.00 1,920.59 3,133.4965.08 701,170.095,942,128.668,560.00 6.00 2,752.38 TSAD 9,800.00 41.97 8,667.27 1,932.45 3,160.7667.82 701,197.025,942,141.238,594.27 6.00 2,777.17 9,850.00 44.30 8,703.76 1,944.56 3,192.7170.60 701,228.655,942,154.188,630.76 6.00 2,806.54 9,900.00 46.68 8,738.81 1,955.64 3,226.6073.15 701,262.235,942,166.148,665.81 6.00 2,837.98 9,920.87 47.69 8,753.00 1,959.95 3,241.2974.16 701,276.805,942,170.838,680.00 6.00 2,851.71 T4A (42N) 9,950.00 49.12 8,772.34 1,965.64 3,262.3175.51 701,297.675,942,177.088,699.34 6.00 2,871.42 10,000.00 51.60 8,804.23 1,974.55 3,299.7777.69 701,334.875,942,186.978,731.23 6.00 2,906.76 10,020.80 52.65 8,817.00 1,977.93 3,315.8378.56 701,350.845,942,190.778,744.00 6.00 2,921.99 TZ3 (TCGL) 10,050.00 54.13 8,834.42 1,982.34 3,338.8579.73 701,373.745,942,195.798,761.42 6.00 2,943.90 10,100.00 56.68 8,862.81 1,988.99 3,379.4681.65 701,414.165,942,203.508,789.81 6.00 2,982.74 10,116.93 57.55 8,872.00 1,990.98 3,393.5482.27 701,428.185,942,205.868,799.00 6.00 2,996.26 T2C (BCGL) 10,150.00 59.26 8,889.32 1,994.48 3,421.4983.45 701,456.025,942,210.098,816.32 6.00 3,023.17 10,200.00 61.86 8,913.90 1,998.79 3,464.8185.16 701,499.215,942,215.548,840.90 6.00 3,065.09 10,250.00 64.49 8,936.46 2,001.92 3,509.3286.79 701,543.625,942,219.838,863.46 6.00 3,108.37 10,300.00 67.13 8,956.95 2,003.85 3,554.8888.34 701,589.115,942,222.968,883.95 6.00 3,152.91 10,343.39 69.44 8,973.00 2,004.55 3,595.1889.65 701,629.385,942,224.728,900.00 6.00 3,192.48 T2B (24N) 10,350.00 69.79 8,975.30 2,004.58 3,601.3889.84 701,635.575,942,224.918,902.30 6.00 3,198.57 10,400.00 72.46 8,991.48 2,004.10 3,648.6891.29 701,682.875,942,225.688,918.48 6.00 3,245.24 10,450.00 75.14 9,005.43 2,002.43 3,696.6692.70 701,730.875,942,225.278,932.43 6.00 3,292.78 10,500.00 77.82 9,017.12 1,999.56 3,745.1894.07 701,779.455,942,223.678,944.12 6.00 3,341.06 10,550.00 80.52 9,026.51 1,995.50 3,794.1295.41 701,828.475,942,220.908,953.51 6.00 3,389.96 10,565.81 81.37 9,029.00 1,993.97 3,809.6695.83 701,844.055,942,219.788,956.00 6.00 3,405.53 T2A (22P) 10,600.00 83.22 9,033.58 1,990.26 3,843.3396.73 701,877.815,942,216.968,960.58 6.00 3,439.34 10,650.00 85.92 9,038.32 1,983.86 3,892.6998.04 701,927.315,942,211.868,965.32 6.00 3,489.05 10,700.00 88.63 9,040.70 1,976.31 3,942.0599.34 701,976.855,942,205.618,967.70 6.00 3,538.98 10,725.41 90.00 9,041.00 1,972.05 3,967.09100.00 702,002.005,942,202.008,968.00 6.00 3,564.38 10,750.00 91.37 9,040.71 1,967.66 3,991.29100.54 702,026.305,942,198.258,967.71 6.00 3,588.97 10,800.00 94.16 9,038.29 1,958.05 4,040.29101.65 702,075.545,942,189.948,965.29 6.00 3,638.90 10,850.00 96.95 9,033.45 1,947.54 4,088.93102.76 702,124.435,942,180.708,960.45 6.00 3,688.62 10,900.00 99.74 9,026.19 1,936.14 4,137.06103.88 702,172.845,942,170.588,953.19 6.00 3,738.00 10,950.00 102.52 9,016.54 1,923.90 4,184.57105.03 702,220.655,942,159.598,943.54 6.00 3,786.91 11,000.00 105.30 9,004.53 1,910.85 4,231.30106.19 702,267.715,942,147.778,931.53 6.00 3,835.21 11,024.16 106.64 8,997.88 1,904.26 4,253.58106.77 702,290.155,942,141.778,924.88 6.00 3,858.29 End Dir : 11024.16' MD, 8997.88' TVD 11,100.00 106.64 8,976.17 1,883.29 4,323.15106.77 702,360.255,942,122.638,903.17 0.00 3,930.44 11,200.00 106.64 8,947.54 1,855.64 4,414.89106.77 702,452.685,942,097.418,874.54 0.00 4,025.59 11,300.00 106.64 8,918.91 1,828.00 4,506.63106.77 702,545.105,942,072.198,845.91 0.00 4,120.74 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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 8,817.28 Vert Section 11,400.00 106.64 8,890.28 1,800.35 4,598.37106.77 702,637.535,942,046.968,817.28 0.00 4,215.88 11,500.00 106.64 8,861.65 1,772.70 4,690.11106.77 702,729.965,942,021.748,788.65 0.00 4,311.03 11,600.00 106.64 8,833.02 1,745.06 4,781.85106.77 702,822.395,941,996.518,760.02 0.00 4,406.17 11,700.00 106.64 8,804.39 1,717.41 4,873.59106.77 702,914.825,941,971.298,731.39 0.00 4,501.32 11,800.00 106.64 8,775.76 1,689.77 4,965.33106.77 703,007.255,941,946.068,702.76 0.00 4,596.47 11,867.89 106.64 8,756.33 1,671.00 5,027.61106.77 703,070.005,941,928.948,683.33 0.00 4,661.06 Start Dir 6º/100' : 11867.89' MD, 8756.33'TVD 11,900.00 104.89 8,747.60 1,662.30 5,057.26105.92 703,099.875,941,921.028,674.60 6.00 4,691.77 11,950.00 102.17 8,735.91 1,649.50 5,104.15104.63 703,147.075,941,909.468,662.91 6.00 4,740.17 12,000.00 99.44 8,726.54 1,637.62 5,151.80103.36 703,195.025,941,898.848,653.54 6.00 4,789.16 12,050.00 96.70 8,719.52 1,626.71 5,200.08102.11 703,243.575,941,889.208,646.52 6.00 4,838.61 12,100.00 93.97 8,714.87 1,616.79 5,248.86100.88 703,292.595,941,880.578,641.87 6.00 4,888.37 12,135.90 92.00 8,713.00 1,610.30 5,284.12100.00 703,328.005,941,875.008,640.00 6.00 4,924.21 12,150.00 91.16 8,712.61 1,607.86 5,298.0099.87 703,341.945,941,872.938,639.61 6.00 4,938.31 12,200.00 88.20 8,712.89 1,599.48 5,347.2999.43 703,391.435,941,865.858,639.89 6.00 4,988.30 12,250.00 85.23 8,715.76 1,591.50 5,396.5698.98 703,440.895,941,859.178,642.76 6.00 5,038.21 12,300.00 82.26 8,721.20 1,583.94 5,445.6798.52 703,490.185,941,852.908,648.20 6.00 5,087.89 12,350.00 79.30 8,729.21 1,576.83 5,494.5198.06 703,539.195,941,847.078,656.21 6.00 5,137.22 12,400.00 76.33 8,739.76 1,570.17 5,542.9297.59 703,587.755,941,841.698,666.76 6.00 5,186.05 12,450.00 73.37 8,752.82 1,563.99 5,590.7897.11 703,635.765,941,836.778,679.82 6.00 5,234.26 12,464.87 72.49 8,757.19 1,562.25 5,604.8996.97 703,649.905,941,835.408,684.19 6.00 5,248.46 End Dir : 12464.87' MD, 8757.19' TVD 12,500.00 72.49 8,767.76 1,558.19 5,638.1496.97 703,683.255,941,832.218,694.76 0.00 5,281.91 12,600.00 72.49 8,797.84 1,546.62 5,732.8196.97 703,778.185,941,823.148,724.84 0.00 5,377.14 12,700.00 72.49 8,827.93 1,535.05 5,827.4796.97 703,873.115,941,814.068,754.93 0.00 5,472.38 12,800.00 72.49 8,858.02 1,523.48 5,922.1396.97 703,968.045,941,804.998,785.02 0.00 5,567.61 12,900.00 72.49 8,888.11 1,511.92 6,016.7996.97 704,062.975,941,795.918,815.11 0.00 5,662.84 12,940.94 72.49 8,900.42 1,507.18 6,055.5596.97 704,101.835,941,792.208,827.42 0.00 5,701.83 Start Dir 6º/100' : 12940.94' MD, 8900.42'TVD 12,950.00 72.99 8,903.11 1,506.15 6,064.1496.75 704,110.445,941,791.398,830.11 6.00 5,710.47 13,000.00 75.78 8,916.57 1,500.97 6,112.0195.59 704,158.435,941,787.478,843.57 6.00 5,758.51 13,050.00 78.57 8,927.67 1,496.71 6,160.5794.46 704,207.085,941,784.488,854.67 6.00 5,807.07 13,100.00 81.36 8,936.38 1,493.36 6,209.6893.35 704,256.275,941,782.438,863.38 6.00 5,856.02 13,150.00 84.16 8,942.68 1,490.93 6,259.2292.25 704,305.855,941,781.318,869.68 6.00 5,905.23 13,200.00 86.96 8,946.56 1,489.45 6,309.0491.17 704,355.695,941,781.138,873.56 6.00 5,954.55 13,254.35 90.00 8,948.00 1,488.89 6,363.3690.00 704,410.005,941,782.008,875.00 6.00 6,008.14 Start Dir 5º/100' : 13254.35' MD, 8948'TVD 13,300.00 92.10 8,947.16 1,489.25 6,409.0089.10 704,455.615,941,783.568,874.16 5.00 6,053.03 13,400.00 96.69 8,939.50 1,492.52 6,508.6287.12 704,555.115,941,789.458,866.50 5.00 6,150.56 13,500.00 101.28 8,923.88 1,499.20 6,607.1385.11 704,653.405,941,798.718,850.88 5.00 6,246.42 13,560.37 104.04 8,910.65 1,504.86 6,665.7683.86 704,711.865,941,805.908,837.65 5.00 6,303.17 End Dir : 13560.37' MD, 8910.65' TVD 13,600.00 104.04 8,901.03 1,508.97 6,703.9883.86 704,749.965,941,811.028,828.03 0.00 6,340.10 13,700.00 104.04 8,876.77 1,519.34 6,800.4483.86 704,846.105,941,823.928,803.77 0.00 6,433.29 13,800.00 104.04 8,852.50 1,529.71 6,896.8983.86 704,942.255,941,836.828,779.50 0.00 6,526.48 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 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 8,755.24 Vert Section 13,900.00 104.04 8,828.24 1,540.08 6,993.3583.86 705,038.395,941,849.728,755.24 0.00 6,619.67 14,000.00 104.04 8,803.97 1,550.45 7,089.8083.86 705,134.535,941,862.638,730.97 0.00 6,712.86 14,100.00 104.04 8,779.71 1,560.83 7,186.2683.86 705,230.685,941,875.538,706.71 0.00 6,806.05 14,200.00 104.04 8,755.44 1,571.20 7,282.7183.86 705,326.825,941,888.438,682.44 0.00 6,899.24 14,300.00 104.04 8,731.18 1,581.57 7,379.1783.86 705,422.975,941,901.338,658.18 0.00 6,992.43 14,374.92 104.04 8,713.00 1,589.34 7,451.4383.86 705,495.005,941,911.008,640.00 0.00 7,062.24 Total Depth : 14374.92' MD, 8713' TVD - 4 1/2" x 6 1/8" Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Targets Dip Angle (°) Dip Dir. (°) 01-12B wp09 tgt3 8,948.00 5,941,782.00 704,410.001,488.89 6,363.360.00 0.00 - plan hits target center - Circle (radius 150.00) 01-12B wp09 tgt2 8,713.00 5,941,875.00 703,328.001,610.30 5,284.120.00 0.00 - plan hits target center - Point 01-12B wp09 tgt1 9,041.00 5,942,202.00 702,002.001,972.05 3,967.090.00 0.00 - plan hits target center - Point 01-12B wp09 tgt4 8,713.00 5,941,911.00 705,495.001,589.34 7,451.440.00 0.00 - plan hits target center - Circle (radius 250.00) Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 7" x 8 1/2"8,540.419,638.00 78-1/2 4 1/2" x 6 1/8"8,713.0014,374.92 4-1/2 6-1/8 9 5/8" x 12 1/4" TOW2,900.592,901.00 9-5/8 12-1/4 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay 01 Standard Proposal Report Well: Wellbore: Plan: 01-12 Plan: 01-12B Survey Calculation Method:Minimum Curvature Kelly Bushing / Rotary Table @ 73.00usft (NORD Design:01-12B wp09 Database:Alaska MD Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORD North Reference: Well Plan: 01-12 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations Vertical Depth SS 10,565.81 9,029.00 T2A (22P) 9,627.75 8,532.00 TSGR 7,960.42 7,163.00 CM2 6,062.90 5,605.00 UG1 10,343.39 8,973.00 T2B (24N) 6,763.20 6,180.00 WS2 4,273.77 4,136.00 SV1 3,757.75 3,709.00 SV2 7,540.24 6,818.00 CM3 5,254.20 4,941.00 UG3 10,116.93 8,872.00 T2C (BCGL) 9,665.77 8,563.00 TSHU 9,754.62 8,633.00 TSAD 10,020.80 8,817.00 TZ3 (TCGL) 9,920.87 8,753.00 T4A (42N) 9,496.22 8,424.00 LCU 9,225.84 8,202.00 THRZ 8,780.08 7,836.00 CM1 9,460.90 8,395.00 BHRZ 3,533.40 3,509.00 SV3 7,132.23 6,483.00 WS1 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 2,900.01 2,899.60 -15.54 27.01 KOP : Start Dir 12.3º/100' : 2900' MD, 2899.59'TVD : 30° LT TF 2,917.00 2,916.55 -15.95 28.10 End Dir : 2917' MD, 2916.55' TVD 2,937.00 2,936.47 -16.42 29.75 Start Dir 4º/100' : 2937' MD, 2936.47'TVD 3,237.00 3,230.62 -22.62 85.54 Start Dir 3.5º/100' : 3237' MD, 3230.62'TVD 3,906.67 3,834.58 78.42 344.88 End Dir : 3906.67' MD, 3834.58' TVD 9,632.72 8,536.08 1,884.83 3,068.93 Start Dir 6º/100' : 9632.72' MD, 8536.08'TVD 11,024.16 8,997.88 1,904.26 4,253.58 End Dir : 11024.16' MD, 8997.88' TVD 11,867.89 8,756.33 1,671.00 5,027.61 Start Dir 6º/100' : 11867.89' MD, 8756.33'TVD 12,464.87 8,757.19 1,562.25 5,604.89 End Dir : 12464.87' MD, 8757.19' TVD 12,940.94 8,900.42 1,507.18 6,055.55 Start Dir 6º/100' : 12940.94' MD, 8900.42'TVD 13,254.35 8,948.00 1,488.89 6,363.36 Start Dir 5º/100' : 13254.35' MD, 8948'TVD 13,560.37 8,910.65 1,504.86 6,665.76 End Dir : 13560.37' MD, 8910.65' TVD 14,374.92 8,713.00 1,589.34 7,451.43 Total Depth : 14374.92' MD, 8713' TVD 1/22/2025 6:00:22PM COMPASS 5000.17 Build 04 Page 9 Clearance Summary Anticollision Report 22 January, 2025 Hilcorp North Slope, LLC Prudhoe Bay 01 Plan: 01-12 Plan: 01-12B 5002920269 01-12B wp09 Reference Design: 01 - Plan: 01-12 - Plan: 01-12B - 01-12B wp09 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Well Coordinates: 5,940,126.51 N, 698,088.31 E (70° 14' 25.93" N, 148° 24' 00.66" W) Datum Height: Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Scan Range: 2,900.00 to 14,374.92 usft. Measured Depth. Geodetic Scale Factor Applied Version: 5000.17 Build: 04 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft NO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type: Scan Type:25.00 Prudhoe Bay Hilcorp North Slope, LLC Anticollision Report for Plan: 01-12 - 01-12B wp09 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 2,900.00 to 14,374.92 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: 01 - Plan: 01-12 - Plan: 01-12B - 01-12B wp09 Measured Depth (usft) Summary Based on Minimum Separation Warning 01 01-01 - 01-01 - 01-01 360.02 5,324.53 284.37 5,014.27 4.7595,324.53 Centre Distance Pass - 01-01 - 01-01 - 01-01 360.20 5,350.00 284.17 5,037.02 4.7375,350.00 Ellipse Separation Pass - 01-01 - 01-01 - 01-01 388.81 5,650.00 304.62 5,305.58 4.6185,650.00 Clearance Factor Pass - 01-01A - 01-01A - 01-01A 465.81 13,887.92 -28.31 11,708.55 0.94313,887.92 Centre Distance FAIL - 01-01A - 01-01A - 01-01A 477.16 14,000.00 -51.83 11,751.77 0.90214,000.00 Clearance Factor FAIL - 01-01A - 01-01B - 01-01B 517.28 13,867.39 141.60 11,602.11 1.37713,867.39 Centre Distance Pass - 01-01A - 01-01B - 01-01B 526.75 13,975.00 131.51 11,641.07 1.33313,975.00 Ellipse Separation Pass - 01-01A - 01-01B - 01-01B 531.53 14,000.00 132.70 11,650.67 1.33314,000.00 Clearance Factor Pass - 01-01A - 01-01C - 01-01C 573.64 8,218.27 430.60 8,215.87 4.0108,218.27 Centre Distance Pass - 01-01A - 01-01C - 01-01C 573.95 8,250.00 430.17 8,242.62 3.9928,250.00 Ellipse Separation Pass - 01-01A - 01-01C - 01-01C 575.66 8,300.00 431.00 8,284.93 3.9808,300.00 Clearance Factor Pass - 01-02 - 01-02 - 01-02 300.99 4,202.60 235.77 4,121.86 4.6154,202.60 Clearance Factor Pass - 01-03 - 01-03 - 01-03 469.17 3,975.00 410.30 3,829.03 7.9703,975.00 Clearance Factor Pass - 01-03 - 01-03 - 01-03 467.02 4,025.00 408.60 3,852.09 7.9954,025.00 Ellipse Separation Pass - 01-03 - 01-03 - 01-03 467.01 4,026.70 408.62 3,852.87 7.9974,026.70 Centre Distance Pass - 01-03 - 01-03A - 01-03A 469.17 3,975.00 410.30 3,818.83 7.9703,975.00 Clearance Factor Pass - 01-03 - 01-03A - 01-03A 467.02 4,025.00 408.60 3,841.89 7.9954,025.00 Ellipse Separation Pass - 01-03 - 01-03A - 01-03A 467.01 4,026.70 408.62 3,842.67 7.9974,026.70 Centre Distance Pass - 01-04 - 01-04 - 01-04 116.71 4,598.06 54.55 4,384.25 1.8784,598.06 Centre Distance Pass - 01-04 - 01-04 - 01-04 116.72 4,600.00 54.54 4,385.85 1.8774,600.00 Clearance Factor Pass - 01-04 - 01-04A - 01-04A 116.71 4,598.06 54.40 4,384.25 1.8734,598.06 Centre Distance Pass - 01-04 - 01-04A - 01-04A 116.72 4,600.00 54.38 4,385.85 1.8724,600.00 Clearance Factor Pass - 01-04 - 01-04B - 01-04B 116.71 4,598.06 54.55 4,399.95 1.8784,598.06 Centre Distance Pass - 01-04 - 01-04B - 01-04B 116.72 4,600.00 54.54 4,401.55 1.8774,600.00 Clearance Factor Pass - 01-05 - 01-05 - 01-05 525.50 4,150.00 464.09 3,870.00 8.5584,150.00 Clearance Factor Pass - 01-05 - 01-05 - 01-05 524.30 4,175.00 464.09 3,870.00 8.7084,175.00 Ellipse Separation Pass - 01-05 - 01-05 - 01-05 524.14 4,187.72 464.59 3,870.00 8.8014,187.72 Centre Distance Pass - 01-05 - 01-05B - 01-05B 525.50 4,150.00 464.09 3,864.80 8.5574,150.00 Clearance Factor Pass - 22 January, 2025 - 18:09 COMPASSPage 2 of 8 Prudhoe Bay Hilcorp North Slope, LLC Anticollision Report for Plan: 01-12 - 01-12B wp09 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 2,900.00 to 14,374.92 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: 01 - Plan: 01-12 - Plan: 01-12B - 01-12B wp09 Measured Depth (usft) Summary Based on Minimum Separation Warning 01-05 - 01-05B - 01-05B 524.30 4,175.00 464.09 3,864.80 8.7084,175.00 Ellipse Separation Pass - 01-05 - 01-05B - 01-05B 524.14 4,187.72 464.59 3,864.80 8.8014,187.72 Centre Distance Pass - 01-05 - 01-05PB1 - 01-05PB1 525.50 4,150.00 464.09 3,870.00 8.5584,150.00 Clearance Factor Pass - 01-05 - 01-05PB1 - 01-05PB1 524.30 4,175.00 464.09 3,870.00 8.7084,175.00 Ellipse Separation Pass - 01-05 - 01-05PB1 - 01-05PB1 524.14 4,187.72 464.59 3,870.00 8.8014,187.72 Centre Distance Pass - 01-06 - 01-06 - 01-06 299.15 5,003.18 239.70 4,700.00 5.0325,003.18 Centre Distance Pass - 01-06 - 01-06 - 01-06 611.55 12,875.00 -39.90 11,389.25 0.93912,875.00 Clearance Factor FAIL - 01-06 - 01-06A - 01-06A 299.17 5,000.00 239.36 4,692.90 5.0025,000.00 Ellipse Separation Pass - 01-06 - 01-06A - 01-06A 299.15 5,003.18 239.71 4,692.90 5.0325,003.18 Centre Distance Pass - 01-06 - 01-06A - 01-06A 907.08 12,775.00 443.37 11,200.59 1.95612,775.00 Clearance Factor Pass - 01-07 - 01-07 - 01-07 443.24 3,749.63 383.08 3,732.08 7.3683,749.63 Centre Distance Pass - 01-07 - 01-07 - 01-07 443.24 3,750.00 383.08 3,732.27 7.3673,750.00 Ellipse Separation Pass - 01-07 - 01-07 - 01-07 443.87 3,775.00 383.55 3,744.78 7.3593,775.00 Clearance Factor Pass - 01-07 - 01-07A - 01-07A 443.24 3,749.63 383.08 3,732.08 7.3683,749.63 Centre Distance Pass - 01-07 - 01-07A - 01-07A 443.24 3,750.00 383.08 3,732.27 7.3673,750.00 Ellipse Separation Pass - 01-07 - 01-07A - 01-07A 443.87 3,775.00 383.55 3,744.78 7.3593,775.00 Clearance Factor Pass - 01-07 - 01-07APB1 - 01-07APB1 443.24 3,749.63 383.08 3,732.08 7.3683,749.63 Centre Distance Pass - 01-07 - 01-07APB1 - 01-07APB1 443.24 3,750.00 383.08 3,732.27 7.3673,750.00 Ellipse Separation Pass - 01-07 - 01-07APB1 - 01-07APB1 443.87 3,775.00 383.55 3,744.78 7.3593,775.00 Clearance Factor Pass - 01-08 - 01-08 - 01-08 787.58 14,350.00 427.78 12,096.56 2.18914,350.00 Clearance Factor Pass - 01-08 - 01-08A - 01-08A 136.82 3,615.09 93.24 3,819.32 3.1393,615.09 Centre Distance Pass - 01-08 - 01-08A - 01-08A 137.08 3,625.00 92.84 3,825.42 3.0993,625.00 Ellipse Separation Pass - 01-08 - 01-08A - 01-08A 140.04 3,650.00 94.45 3,840.46 3.0723,650.00 Clearance Factor Pass - 01-11 - 01-11 - 01-11 112.09 2,900.00 63.31 2,894.05 2.2982,900.00 Clearance Factor Pass - 01-13 - 01-13 - 01-13 119.86 3,076.22 69.75 3,088.99 2.3923,076.22 Centre Distance Pass - 01-13 - 01-13 - 01-13 120.05 3,100.00 69.73 3,112.68 2.3863,100.00 Clearance Factor Pass - 01-14 - 01-14 - 01-14 211.45 2,965.18 169.83 2,975.71 5.0812,965.18 Centre Distance Pass - 01-14 - 01-14 - 01-14 211.74 3,000.00 169.75 3,009.00 5.0433,000.00 Ellipse Separation Pass - 01-14 - 01-14 - 01-14 213.42 3,050.00 170.91 3,055.06 5.0203,050.00 Clearance Factor Pass - 01-14 - 01-14A - 01-14A 211.45 2,965.18 169.83 2,975.71 5.0812,965.18 Centre Distance Pass - 22 January, 2025 - 18:09 COMPASSPage 3 of 8 Prudhoe Bay Hilcorp North Slope, LLC Anticollision Report for Plan: 01-12 - 01-12B wp09 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 2,900.00 to 14,374.92 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: 01 - Plan: 01-12 - Plan: 01-12B - 01-12B wp09 Measured Depth (usft) Summary Based on Minimum Separation Warning 01-14 - 01-14A - 01-14A 211.74 3,000.00 169.75 3,009.00 5.0433,000.00 Ellipse Separation Pass - 01-14 - 01-14A - 01-14A 213.42 3,050.00 170.91 3,055.06 5.0203,050.00 Clearance Factor Pass - 01-15 - 01-15 - 01-15 369.50 2,900.00 320.04 2,901.67 7.4702,900.00 Ellipse Separation Pass - 01-15 - 01-15 - 01-15 411.44 3,675.00 353.70 3,642.03 7.1263,675.00 Clearance Factor Pass - 01-15 - 01-15A - 01-15A 369.50 2,900.00 320.04 2,893.87 7.4702,900.00 Ellipse Separation Pass - 01-15 - 01-15A - 01-15A 411.44 3,675.00 353.70 3,634.23 7.1263,675.00 Clearance Factor Pass - 01-15 - 01-15B - 01-15B 369.50 2,900.00 320.30 2,893.87 7.5112,900.00 Ellipse Separation Pass - 01-15 - 01-15B - 01-15B 411.44 3,675.00 353.86 3,634.23 7.1453,675.00 Clearance Factor Pass - 01-16 - 01-16 - 01-16 244.97 10,039.88 126.84 10,075.25 2.07410,039.88 Centre Distance Pass - 01-16 - 01-16 - 01-16 246.84 10,100.00 123.68 10,130.31 2.00410,100.00 Ellipse Separation Pass - 01-16 - 01-16 - 01-16 251.80 10,150.00 124.77 10,174.25 1.98210,150.00 Clearance Factor Pass - 01-18 - 01-18 - 01-18 399.95 2,900.00 363.35 2,795.16 10.9262,900.00 Clearance Factor Pass - 01-18 - 01-18A - 01-18A 399.95 2,900.00 363.46 2,791.01 10.9592,900.00 Clearance Factor Pass - 01-21 - 01-21PB1 - 01-21PB1 497.89 2,900.00 462.13 2,620.00 13.9262,900.00 Clearance Factor Pass - 01-22 - 01-22 - 01-22 354.94 2,900.00 305.96 2,908.28 7.2472,900.00 Ellipse Separation Pass - 01-22 - 01-22 - 01-22 1,485.43 9,775.00 957.90 9,821.26 2.8169,775.00 Clearance Factor Pass - 01-22 - 01-22A - 01-22A 354.94 2,900.00 305.96 2,908.28 7.2472,900.00 Ellipse Separation Pass - 01-22 - 01-22A - 01-22A 1,485.43 9,775.00 957.90 9,821.26 2.8169,775.00 Clearance Factor Pass - 01-22 - 01-22B - 01-22B 354.94 2,900.00 305.96 2,908.28 7.2472,900.00 Centre Distance Pass - 01-22 - 01-22B - 01-22B 671.70 10,025.00 244.96 11,877.00 1.57410,025.00 Ellipse Separation Pass - 01-22 - 01-22B - 01-22B 693.40 10,075.00 249.29 11,877.00 1.56110,075.00 Clearance Factor Pass - 01-23 - 01-23 - 01-23 259.69 2,900.00 221.25 2,879.46 6.7562,900.00 Clearance Factor Pass - 01-23 - 01-23A - 01-23A 259.69 2,900.00 221.25 2,879.46 6.7562,900.00 Clearance Factor Pass - 01-23 - 01-23APB1 - 01-23APB1 259.69 2,900.00 221.25 2,879.46 6.7562,900.00 Clearance Factor Pass - 01-24 - 01-24 - 01-24 231.16 2,900.00 134.50 2,872.00 2.3912,900.00 Clearance Factor Pass - 01-24 - 01-24A - 01-24A 231.16 2,900.00 134.50 2,872.00 2.3912,900.00 Clearance Factor Pass - 01-25 - 01-25 - 01-25 221.60 2,900.00 173.76 2,874.15 4.6322,900.00 Clearance Factor Pass - 01-26 - 01-26 - 01-26 256.19 2,900.00 207.53 2,900.61 5.2652,900.00 Ellipse Separation Pass - 01-26 - 01-26 - 01-26 3,451.48 13,025.00 2,710.14 10,974.79 4.65613,025.00 Clearance Factor Pass - 01-26 - 01-26A - 01-26A 256.19 2,900.00 207.53 2,894.56 5.2652,900.00 Ellipse Separation Pass - 22 January, 2025 - 18:09 COMPASSPage 4 of 8 Prudhoe Bay Hilcorp North Slope, LLC Anticollision Report for Plan: 01-12 - 01-12B wp09 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 2,900.00 to 14,374.92 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: 01 - Plan: 01-12 - Plan: 01-12B - 01-12B wp09 Measured Depth (usft) Summary Based on Minimum Separation Warning 01-26 - 01-26A - 01-26A 3,221.44 12,250.00 2,561.20 10,293.95 4.87912,250.00 Clearance Factor Pass - 01-26 - 01-26B - 01-26B 256.19 2,900.00 207.53 2,894.56 5.2652,900.00 Ellipse Separation Pass - 01-26 - 01-26B - 01-26B 3,221.44 12,250.00 2,561.20 10,293.95 4.87912,250.00 Clearance Factor Pass - 01-28 - 01-28 - 01-28 782.49 2,900.00 749.40 2,776.15 23.6512,900.00 Ellipse Separation Pass - 01-28 - 01-28 - 01-28 1,009.23 11,600.00 819.91 10,140.18 5.33111,600.00 Clearance Factor Pass - 01-28 - 01-28A - 01-28A 524.58 9,636.67 374.52 11,980.00 3.4969,636.67 Centre Distance Pass - 01-28 - 01-28A - 01-28A 525.80 9,675.00 372.40 11,980.00 3.4289,675.00 Ellipse Separation Pass - 01-28 - 01-28A - 01-28A 530.86 9,725.00 374.43 11,980.00 3.3949,725.00 Clearance Factor Pass - 01-28 - 01-28B - 01-28B 782.49 2,900.00 749.40 2,776.15 23.6512,900.00 Ellipse Separation Pass - 01-28 - 01-28B - 01-28B 1,034.46 11,475.00 907.61 10,002.39 8.15511,475.00 Clearance Factor Pass - 01-32 - 01-32 - 01-32 457.52 2,900.00 409.61 2,849.98 9.5492,900.00 Clearance Factor Pass - 01-32 - 01-32A - 01-32A 457.52 2,900.00 409.72 2,847.68 9.5702,900.00 Clearance Factor Pass - 01-33 - 01-33 - 01-33 303.82 2,900.00 255.46 2,880.37 6.2832,900.00 Clearance Factor Pass - 01-37 - 01-37 - 01-37 1,215.38 2,900.00 1,185.89 2,458.10 41.2102,900.00 Centre Distance Pass - 01-37 - 01-37 - 01-37 1,284.28 14,350.00 1,048.22 14,275.00 5.44114,350.00 Clearance Factor Pass - Plan: 01-12 - 01-12 - 01-12 0.00 2,902.69 -0.77 2,902.69 0.0052,902.69 Clearance Factor FAIL - Plan: 01-12 - 01-12A - 01-12A 0.00 2,902.69 -0.77 2,902.69 0.0052,902.69 Clearance Factor FAIL - Plan: 01-29 - 01-29 - 01-29 511.41 4,187.97 451.58 4,058.91 8.5484,187.97 Centre Distance Pass - Plan: 01-29 - 01-29 - 01-29 511.45 4,200.00 451.50 4,068.87 8.5314,200.00 Ellipse Separation Pass - Plan: 01-29 - 01-29 - 01-29 517.42 4,325.00 456.17 4,170.81 8.4484,325.00 Clearance Factor Pass - Plan: 01-29 - Plan: 01-29A - 01-29A wp04 511.41 4,187.97 451.69 4,058.91 8.5634,187.97 Centre Distance Pass - Plan: 01-29 - Plan: 01-29A - 01-29A wp04 511.45 4,200.00 451.61 4,068.87 8.5464,200.00 Ellipse Separation Pass - Plan: 01-29 - Plan: 01-29A - 01-29A wp04 517.42 4,325.00 456.28 4,170.81 8.4634,325.00 Clearance Factor Pass - 22 January, 2025 - 18:09 COMPASSPage 5 of 8 Prudhoe Bay Hilcorp North Slope, LLC Anticollision Report for Plan: 01-12 - 01-12B wp09 Survey tool program From (usft) To (usft) Survey/Plan Survey Tool 500.00 2,900.00 3_CB-Film-GMS 2,900.00 3,100.00 01-12B wp09 GYD_Quest GWD 3,100.00 9,637.00 01-12B wp09 3_MWD+IFR2+MS+Sag 9,637.00 14,374.92 01-12B wp09 3_MWD+IFR2+MS+Sag Ellipse 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. 22 January, 2025 - 18:09 COMPASSPage 6 of 8 0.00 1.00 2.00 3.00 4.00 Separation Factor3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 Measured Depth (1200 usft/in) 01-04A 01-01 01-02 01-11 01-01B 01-06 01-06A01-24A 01-24 01-16 01-22A 01-22B01-22 01-01A 01-01C 01-28A01-25 01-12A 01-13 01-08 01-08A 01-12 No-Go Zone - Stop Drilling Collision Avoidance Required Collision Risk Procedures Req. WELL DETAILS:Plan: 01-12 NAD 1927 (NADCON CONUS)Alaska Zone 04 Ground Level: 39.70 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5940126.51 698088.31 70° 14' 25.9320 N 148° 24' 0.6554 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: 01-12, True North Vertical (TVD) Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Measured Depth Reference:Kelly Bushing / Rotary Table @ 73.00usft (NORDIC 1) Calculation Method:Minimum Curvature SURVEY PROGRAM Date: 2024-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 500.00 2900.00 1 : Camera based gyro multisho (01-12) 3_CB-Film-GMS2900.00 3100.00 01-12B wp09 (Plan: 01-12B) GYD_Quest GWD3100.00 9637.00 01-12B wp09 (Plan: 01-12B) 3_MWD+IFR2+MS+Sag 9637.00 14374.92 01-12B wp09 (Plan: 01-12B) 3_MWD+IFR2+MS+Sag 0.00 30.00 60.00 90.00 120.00 150.00 180.00 Centre to Centre Separation (60.00 usft/in)3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 Measured Depth (1200 usft/in) 01-11 01-13 NO GLOBAL FILTER: Using user defined selection & filtering criteria 2900.00 To 14374.92 Project: Prudhoe Bay Site: 01 Well: Plan: 01-12 Wellbore: Plan: 01-12B Plan: 01-12B wp09 CASING DETAILS TVD TVDSS MD Size Name 2900.59 2827.59 2901.00 9-5/8 9 5/8" x 12 1/4" TOW 8540.41 8467.41 9638.00 7 7" x 8 1/2" 8713.00 8640.00 14374.92 4-1/2 4 1/2" x 6 1/8" 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. 223-090 PBU 01-12B PRUDHOE OILPRUDHOE BAY CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Jacob Thompson To:Lau, Jack J (OGC) Cc:Joseph Engel Subject:RE: [EXTERNAL] FW: PBU 01-12B PTD (223-090) Date:Monday, February 10, 2025 3:14:13 PM Attachments:4 in. 14.00# IU S-135 R2 DS38 (4.875 x 2.5625) - 10P.12.5B.pdf 5IN 19.5LB NC50.pdf Jack, See the responses below in Red. Let me know if you have any other questions. Thanks, Jacob Thompson Hilcorp Alaska, LLC Senior Drilling Engineer Jacob.Thompson@hilcorp.com Cell: 907-854-4377 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, February 10, 2025 1:25 PM To: Jacob Thompson <Jacob.Thompson@hilcorp.com> Subject: [EXTERNAL] FW: PBU 01-12B PTD (223-090) Jake, I didn’t realize Joe was out, here are my quick and easy questions regarding his PTD request for 01-12B. Jack From: Lau, Jack J (OGC) Sent: Friday, February 7, 2025 9:19 AM To: Joseph Engel <jengel@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: RE: PBU 01-12B PTD (223-090) Morning Joe, Following up on me questions. From: Lau, Jack J (OGC) Sent: Wednesday, February 5, 2025 2:20 PM To: Joseph Engel <jengel@hilcorp.com> Subject: PBU 01-12B PTD (223-090) Good afternoon Joe, I have a few questions about the PTD for 01-12B. Displacement for the liner cement job appears to be off a tad I calculate 353.12 bbls for the displacement which is pretty close. I believe this to be a fat finger. Very close though. Send me the specs for the 4” and 5” dp We are currently in the process of finalizing the rental agreement on the 4” DP, but it is planned to be 4” 14# HT-38 DP. The 5” 19.5# NC50. See Attached. How will you be freeze protecting? Freeze protection will be achieved by injecting ~52 bbls of diesel or dead crude into the 7” x 9-5/8” annulus after the 7” casing is landed and pack off installed. A hot oil truck usually performs this operation. With a MASP of 2700 psi what’s the basis of testing tubing to 3500 psi with 1000 psi on IA for 2500 psi equivalent? This is a good catch. The permit was worded incorrectly. The Tubing is to be pressure tested to 3,500 psi on top of the ball and rod. The IA is to be tested to 3500 psi while holding 1000 psi on the tubing. This is to ensure that the Shear valve in the GLM does not rupture prior to testing the IA. After the successful GLV shear the tubing pressure is bled off rapidly to rupture the shear valve so the freeze protect can be circulated in. Thanks Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell 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. 1 Dewhurst, Andrew D (OGC) From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent:Wednesday, 5 February, 2025 16:52 To:Dewhurst, Andrew D (OGC); Joseph Engel; Jacob Thompson; David Bjork Cc:Lau, Jack J (OGC); Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL] PBU 01-12B PTD (223-090) Andy, Sorry, I had meant to include a note with the PTD. I’d say a revised or replacement PTD is preferable to keep the API #’s as conventional (50-029-20269-02-00 for 01-12B). I can conƱrm that at this point no work has been performed to the PTD #223-090 submitted / approved in 2023. Appreciate your help and please let me know if you have any questions or need additional information. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, February 5, 2025 1:21 PM To: Joseph Engel <jengel@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL] PBU 01-12B PTD (223-090) Joe, We received (on 31 January 2024) a PTD applicaƟon for the PBU 01-12B well. Hilcorp already has an approved PTD (223- 090) for this well that was issued back in late 2023. Would you conĮrm that the program associated with PTD 223-090 was never executed? Assuming it was not, you have a couple opƟons: 1. You could request that we withdraw the PTD 223-090 and the applicaƟon we just received would receive a new PTD number and new API number. 2. You could request that the recent applicaƟon become a revision to the one from 2023. It comes down to the PTD and API numbers. Andy 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon 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. WELL PERMIT CHECKLIST Company Hilcorp North Slope, LLC Well Name:PRUDHOE BAY UNIT 01-12B Initial Class/Type / GeoArea 890 Unit 11650 On/Off Shore On ProgramField & Pool Well bore seg Annular DisposalPTD#:2230900 PRUDHOE BAY, PRUDHOE OIL - 640150 NA1 Permit fee attached Yes ADL028329 and ADL0283282 Lease number appropriate Yes3 Unique well name and number Yes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by 341J4 Well located in a defined pool Yes5 Well located proper distance from drilling unit boundary NA6 Well located proper distance from other wells Yes7 Sufficient acreage available in drilling unit Yes8 If deviated, is wellbore plat included Yes9 Operator only affected party Yes10 Operator has appropriate bond in force Yes11 Permit can be issued without conservation order Yes12 Permit can be issued without administrative approval Yes13 Can permit be approved before 15-day wait NA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For s NA15 All wells within 1/4 mile area of review identified (For service well only) NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only) NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) Yes18 Conductor string provided Yes19 Surface casing protects all known USDWs Yes20 CMT vol adequate to circulate on conductor & surf csg Yes21 CMT vol adequate to tie-in long string to surf csg Yes Fully cemented production liner. Parent well isolates the reservoir.22 CMT will cover all known productive horizons Yes23 Casing designs adequate for C, T, B & permafrost Yes24 Adequate tankage or reserve pit Yes25 If a re-drill, has a 10-403 for abandonment been approved Yes26 Adequate wellbore separation proposed Yes27 If diverter required, does it meet regulations Yes28 Drilling fluid program schematic & equip list adequate Yes29 BOPEs, do they meet regulation Yes30 BOPE press rating appropriate; test to (put psig in comments) Yes31 Choke manifold complies w/API RP-53 (May 84) Yes32 Work will occur without operation shutdown Yes33 Is presence of H2S gas probable NA34 Mechanical condition of wells within AOR verified (For service well only) No DS 01 wells are H2S-bearing. H2S measures are required. Max H2S recorded on DS 01-25: 900 ppm on 07/29/20235 Permit can be issued w/o hydrogen sulfide measures Yes Expected reservoir pressure is 7.2 ppg EMW; will be drilled using 8.4 ppg mud and MPD36 Data presented on potential overpressure zones NA37 Seismic analysis of shallow gas zones NA38 Seabed condition survey (if off-shore) NA39 Contact name/phone for weekly progress reports [exploratory only] Appr ADD Date 2/6/2025 Appr JJL Date 2/10/2025 Appr ADD Date 2/6/2025 Administration Engineering Geology Geologic Commissioner:Date:Engineering Commissioner:Date Public Commissioner Date ($8JLC 2/11/2025 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 Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil, PBU 01-12B Hilcorp Alaska, LLC Permit to Drill Number: 223-090 Surface Location: 780' FNL, 755' FWL, Sec 08, T10N, R15E, UM, AK Bottomhole Location: 2247' FSL, 1682' FWL, Sec 09, T10N, R15E, UM, AK Dear Mr. Myers: 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, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of October 2023. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.23 15:11:27 -08'00' 23 PBU 01-12B Drilling Manager 09/28/23 Monty M Myers By Grace Christianson at 11:25 am, Sep 29, 2023 223-090 A.Dewhurst 19OCT23 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented liner and all drilling done below the base of the PB oil pool confining zones. DSR-9/29/23 50-029-20269-02-00 MGR19OCT2023*&: Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.10.23 15:12:06 -08'00'10/23/23 10/23/23 RBDMS JSB 102423 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 28, 2023 Re:01-12B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 01-12A with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for 01-12B Producer: See 01-12A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. Service coil will mill the 3-1/2" CIBP and push to bottom. E-line will set a 3-1/4" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set the whipstock or mill window pre-rig, the rig will set the whipstock and/or mill a single string 2.74" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and land in Zone 2. The lateral will continue in Zone 2, 3 and back to 4 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in October 2023) x Reference 01-12B Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: 1. Service Coil : Mill 3-1/2" CIBP at 11,000' and push to bottom. 2. Slickline : Dummy WS drift and Caliper 3. E-Line : Set Whipstock* (if not possible, set with rig) 4. Fullbore : MIT-IA and MIT-T 5. Service Coil : Mill Window (if window not possible, mill with rig) 6. Valve Shop : Pre-CTD Tree Work 7. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in December 2023) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,415 psi). a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure. Kill well. 2. Mill 2.74” Window (only if not done pre-rig) a. Top of window (whipstock pinch point) at 11,112' MD. b. Single string exit (out of 3-1/4" liner) plus 10' of rathole. PTD 223-090 Sundry 323-537 3. Drill build section: 3.25" OH, ~245' (20 deg DLS planned). Drill production lateral: 3.25" OH, ~1305' (12 deg DLS planned). a. Drill with a constant bottom hole pressure for entire sidetrack b. Pressure deployment will be utilized c.Lay in completion/kill weight fluid in preparation for liner run after TD and on the last trip out of hole d. No flow test prior to laying down drilling BHA. Confirm well is dead prior to picking up liner. 4. Run 2-3/8” 13Cr solid liner Pump primary cement job: a. Have 2" safety joint with TIW valve ready to be picked up while running liner b. Swap well over to KCl c. Cement: 16 bbls, 15.3 ppg Class G, TOC at TOL*. d. Freeze protect well to a min 2,200' TVDss 3. RDMO * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2.Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~300’) and RPM. Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (big hole) & 2-3/8” (slim hole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (11,112' MD -8,711' TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4439 psi 4439 psi 9.8 B Annular friction - ECD (psi/ft)389 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3896 psi 3896 psi 8.6 B+C Mud + ECD Combined 4284 psi 3896 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 155 psi 544 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The reservoir pressure is expected to be 3295 psi at 8,800 TVD. (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,415 psi (from estimated reservoir pressure). Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 3.25" hole for the entirety of the production hole section. Liner Program: x 2-3/8", 4.6#, 13Cr / Solid: 10540' MD – 12662' MD (2122' liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 2,500 psi. x A X-over shall be made up to a 2" safety joint including a TIW valve for all tubulars ran in hole. x 2" safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre- installed TIW valve). When closing on a 2" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 109°. Inclination at kick off point is 67°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 29,985 ft x Distance to nearest well within pool – 200 ft Logging: x MWD directional and Gamma Ray will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x 300' perforated post rig – See future perf sundry (only if extended perforating is used). x 1.5" Perf Guns at 6 spf x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or service coil post rig under this PTD. x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. Anti-Collision Failures: x WP04 has one failure. Close approach is in the target reservoir. Plan to shut in failed wells or keep online with contingencies to have extra fluid on location and heightened awareness to shut well in if needed. i. 03-24B - Online Producing Hazards: x DS01 is an H2S pad. Last H2S reading on 01-12A: 14 ppm on 2/7/2023. x Max H2S recorded on 01-25: 900 ppm on 07/29/2023. x 1 fault crossings expected. x Medium lost circulation risk. 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" # $ %&' 1 0 2 8 ( 3 $) $ $) $) $) $) $) $) $) $)$) $) $) $)$) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $)$) $)$) $) $) $) $) $) $) $)! ! !!! ! !! !!! !!! !! !!! !!! !! ! ! !! ! !! !!! ! !!!! !! !!!! ! !! !!! !!! !! ! !!! !! ! ! ! !! ! !! ! ! ! !D $) Prudhoe Bay Unit 01-01 01-01C 01-04 01-04A 01-04B 01-05 01-06 01-06A 01-10 01-11 01-12 01-12A 01-15 01-15A 01-15B 01-16 01-21 01-21A 01-22 01-22A 01-22B 01-26 01-26A 01-26B 01-28 01-28A 01-29 01-30 01-31 01-32 01-32A 01-34 01-34A 01-36 03-22 03-22A 03-24 03-24A 03-24B 05-03 05-03A 05-03B 05-03C 05-04A 05-07 05-09A 05-20 05-20B 05-21 05-21A 05-27 05-27A 05-27B05-41A 11-03 11-03A 11-12 11-1511-22A 12-01 12-02 12-13 12-21 12-28 12-28A SAGR-01 Sec. 9 Sec. 4 Sec. 8 Sec. 17 Sec. 16 Sec. 5 Sec. 7 (612) Sec. 18 (615) Sec. 6 (609) U010N015E CH2MHILL BASE CAMP FLEET SHOP WARM STORAGE MCC WESTERN GECO CORPORATION NORGASCO HALIBURTON Airport Equipment Inc. NABORS DRILLING SHOP & WHAREHOUSES NC MACHINERY TARMAC CAMP U 11 PBOC DSM/CIC PAD (SOUTH HANGER) CATCO SCHLUMBERGER EQUIPMENT SERVICES PEAK BASE CAMP J PAD BAROID DRILLING FLUIDS DALTON PAD CROWLEY MARINE SERVICES COTU U 21 / PAD 9 PEAK EQUIPMENT PAD SCHLUMBERGER GUN SHOP ALSAKA CLEAN SEAS STAGING AREA - EXXON PAD PEAK STORAGE PAD DS1 ALASKA FRONTIERS CONSTRUCTORS ARCTIC OILFIELD HOTEL U 9 Gas Cap PA Oil Rim PA Lisburne PA 01-12B_SHL 01-12B_TPH 01-12B_BHL Map Date: 9/22/2023 Prudhoe Bay Unit 01-12B Well wp04 E0 1,000 2,000Feet Legend !01-12B_SHL D 01-12B_TPH $)01-12B_BHL T01_12B_wp04_well_track $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint Oil and Gas Unit Boundary CO - 341J Well located within AIO - 4G IPA Do c u m e n t P a t h : O : \ A W S \ G I S \ P r o d u c t s \ A l a s k a \ K E N \ E n v i r o n m e n t a l \ K E N A I G r o u n d W a t e r M o n i t o r i n g \ G r o u n d W a t e r R e p o r t A u g u s t 2 0 2 3 \ M X D s \ N or t h S l o p e _ P B U _ 0 1 - 1 2 B _ w p 0 4 . m x d Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PRUDHOE BAY X PRUDHOE OIL POOL 223-090 PBU 01-12B W E L L P E R M I T C H E C K L I S T Co m p a n y Hi l c o r p N o r t h S l o p e , L L C We l l N a m e : PR U D H O E B A Y U N I T 0 1 - 1 2 B In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t 11 6 5 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 0 9 0 0 PR U D H O E B A Y , P R U D H O E O I L - 6 4 0 1 5 0 NA 1 P e r m i t f e e a t t a c h e d Ye s A D L 0 2 8 3 2 9 a n d A D L 0 2 8 3 2 8 2 L e a s e n u m b e r a p p r o p r i a t e Ye s 3 U n i q u e w e l l n a m e a n d n u m b e r Ye s P R U D H O E B A Y , P R U D H O E O I L - 6 4 0 1 5 0 - g o v e r n e d b y 3 4 1 J 4 W e l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 S u f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 I f d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 O p e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 O p e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 P e r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 P e r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 C a n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r NA 15 A l l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 P r e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 N o n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 18 C o n d u c t o r s t r i n g p r o v i d e d Ye s A l l d r i l l i n g o n t h i s s i d e t r a c k w i l l b e l o w e x i s t i n g s u r f a c e c a s i n g s h o e . 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 20 C M T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 21 C M T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s F u l l y c e m e n t e d p r o d u c t i o n l i n e r . P a r e n t w e l l i s o l a t e s t h e r e s e r v o i r . 22 C M T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l . F u l l i n t e g r i t y a b o v e s i d e t r a c k . 23 C a s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s C D R 2 h a s a d e q u a t e t a n k a g e a n d g o o d t r u c k i n g s u p p o r t . 24 A d e q u a t e t a n k a g e o r r e s e r v e p i t Ye s S u n d r y 3 2 3 - 3 6 6 25 I f a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s H a l l i b u r t o n c o l l i s i o n s c a n i d e n t i f i e s n o c l o s e a p p r o a c h e s . 26 A d e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d Ye s A l l d r i l l i n g b e l o w t h e s u r f a c e c a s i n g s h o e . N o d i v e r t e r r e q u i r e d . 27 I f d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s M P D b u t r e s e r v o i r p r e s s u r e b e l o w w a t e r g r a d i e n t . 28 D r i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s C T P a c k o f f , f l o w c r o s s , a n n u l a r , b l i n d s h e a r , C T p i p e s l i p s , f l o w c r o s s , B H A p i p e s l i p s , C T p i p e s l i p s 29 B O P E s , d o t h e y m e e t r e g u l a t i o n Ye s 7 - 1 / 1 6 " 5 0 0 0 p s i s t a c k p r e s s u r e t e s t e d t o 3 5 0 0 p s i . 30 B O P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s F l a n g e d c h o k e a n d k i l l l i n e s b e t w e e n d u a l c o m b i ' s w r e m o t e c h o k e 31 C h o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 W o r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n Ye s P B U S - p a d i s a n H 2 S p a d > 1 0 0 p p m . M o n i t o r i n g w i l l b e r e q u i r e d . 33 I s p r e s e n c e o f H 2 S g a s p r o b a b l e NA T h i s i s a d e v e l o p m e n t w e l l . 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No D S 0 1 w e l l s a r e H 2 S - b e a r i n g . H 2 S m e a s u r e s a r e r e q u i r e d . M a x H 2 S r e c o r d e d o n D S 0 1 - 2 5 : 9 0 0 p p m o n 0 7 / 2 9 / 2 0 35 P e r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s E x p e c t e d r e s e r v o i r p r e s s u r e i s 7 . 2 p p g E M W ; w i l l b e d r i l l e d u s i n g 8 . 4 p p g m u d a n d M P D ( 9 . 8 p p g E M W ) . 36 D a t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 S e i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 S e a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 C o n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 10 / 1 9 / 2 0 2 3 Ap p r MG R Da t e 10 / 1 6 / 2 0 2 3 Ap p r AD D Da t e 10 / 1 9 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *& :