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Home My WebLink About225-076MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-35A PRUDHOE BAY UNIT W-35A Jim Regg OperatorSrc: W-35A G SPT 4725 2250760 1500 1641 1645 1644 1642 21 198 201 199 Initial Test Pass Initial MIT-IA after Rotary Sidetrack 30 MinPretestInitial15 Min Type Test Notes: Interval P/F Well Type Inj TVD PTD Test psi Tubing OA Packer Depth 506 2403 2344 2335IA 45 Min 60 Min 50-029-21799-02-00 225-076-0 Bob Noble 11/2/2025 Well Name Permit Number: API Well Number Inspector Name:PRUDHOE BAY UNIT W-35A Inspection Date:Insp Num: Rel Insp Num: MITOP000011339 mitRCN251103154523 BBL Pumped:3 BBL Returned:3 Friday, January 16, 2026 Page 1 of 1           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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Injector W-35A (PTD #2250760) MIT-IA will be executed in November Date:Monday, November 3, 2025 9:38:38 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, November 1, 2025 10:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Injector W-35A (PTD #2250760) MIT-IA will be executed in November Mr. Wallace, Injector W-35A (PTD # 2250760) was POI on 10/29/25. The AOGCC witnessed MIT-IA is currently scheduled for 11/02 to allow for injection to stabilize. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 10/24/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251024 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BR 11-86 (REVISED) 50733207370000 225057 8/1/2025 HALLIBURTON RMT3D BRU 241-34T 50283201810000 220052 9/23/2025 AK E-LINE Perf END 2-36 50029220140000 190024 10/13/2025 READ Caliper Survey MPI 2-72 50029237810000 224016 10/2/2025 AK E-LINE Patch MPU I-01 50029220650000 190090 9/25/2025 AK E-LINE Punch MPU J-08A 50029224970100 199117 10/22/2025 HALLIBURTON COILFLAG MPU R-109 50029238220000 225073 9/24/2025 YELLOWJACKET SCBL NCIU A-06A 50883200260100 225071 9/25/2025 AK E-LINE CBL NCIU A-06A 50883200260100 225071 9/26/2025 AK E-LINE Perf PBU A-24B 50029207430200 225067 10/20/2025 HALLIBURTON RBT PBU GC-2E 50029227400000 197018 10/21/2025 HALLIBURTON TEMP PBU W-35A 50029217990200 225076 10/10/2025 HALLIBURTON RBT SP-03-NE2 50629236390000 219089 9/25/2025 AK E-LINE Caliper Please include current contact information if different from above. T41022 T41023 T41024 T41025 T41026 T41027 T41028 T41029 T41029 T41030 T41031 T41032 T41033 PBU W-35A 50029217990200 225076 10/10/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.24 13:32:55 -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:Clint Montague - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Michael Menapace - (C); Tyson Shriver; PB Wells Integrity Subject:PBU W-35A 10-426 Date:Friday, September 19, 2025 10:22:10 AM Attachments:PBU W-35A 10-426.xlsx Attached is the 10-426 form for PBU W-35A, conducted on the rig directly after running completion. If you have any questions please let me know. Thanks! Clint Montague Hilcorp DSM Innovation 907-670-3094 Office 907-394-0776 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. 3%8:$ 37' OPERATOR:FIELD / UNIT / PAD:DATE:OPERATOR REP:AOGCC REP:2250760 Type Inj N Tubing 0 3722 3638 3614 Type Te 4735 BBL Pump 2.2 IA 0 110 121 124 Interva 3500 BBL Return 2.2 OA 70 70 70 70 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2250760 Type Inj N Tubing 0 570 583 584 Type Te 4725 BBL Pump 6.5 IA 0 3719 3669 3661 Interva 3500 BBL Return 6.5 OA 70 90 90 90 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resu Witness waived by Kam StJohn Witness waived by Kam StJohn PBU W-35A 9 9 9 9 999 9 9 9 99 99 9 9 99 0,77 0,7,$ 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: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -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: 10/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: Well: PBU W-35A PTD: 225-076 API: 50-029-21799-02-00 FINAL LWD FORMATION EVALUATION + GEOSTEERING (08/16/2025 to 09/12/2025) x ROP, BaseStar and DGR Gamma Ray, EWR-P4, ADR and StrataStar Resistivity, ALD, CTN x Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Geosteering and EOW Report SFTP Transfer – Main Folders: LWD Subfolders: Geosteering Subfolders: Please include current contact information if different from above. 225-076 T40964 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.07 15:11:24 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Unit Field, Schrader Bluff Oil, PBU W-35A Hilcorp Alaska, LLC Permit to Drill Number: 225-076 Surface Location: 4029' FSL, 1451' FEL, Sec. 21, T11N, R12E, UM, AK Bottomhole Location: 2131 FSL, 671' FEL, Sec.06, T11N, R12E, UM, AK Dear Mr. McLaughlin: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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 8WK day of August 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.08 11:36:26 -08'00' By Grace Christianson at 9:53 am, Jul 14, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.07.14 09:29:03 - 08'00' Sean McLaughlin (4311) 15,500 *AOGCC witnessed BOP test to 3000 psi, Annular to 2500 psi. *Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FITs. *Witnessed MITIA on rig. Witnessed MITIA post injection *CBL required for casing cement through confining interval per 25.412 (d). Send CBL to AOGCC. * W-241 shut in during production hole drilling. JJL 7/18/25 225-076 A.Dewhurst 08AUG25 DSR-7/16/25 50-029-21799-02-00 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.08 11:36:38 -08'00'08/08/25 08/08/25 RBDMS JSB 081225 56 87 161718 21 56 87 161718 21 CHEV181112 K071112PB1 K091112 MP00151112 W-02 W-03W-03A W W W-16 W-18 W-19 W-19B W-20 W-200 W-200PB1 W-204 W-204L1 W-21 W-213 W W W- W-22 W-23 W-24 W-25 W-26 W-27 W-29 W-30 W-31W-31A W-32 W-34 W-39W-40 W-42 W-44 W-51 W-56 W-59W-59PB1 WETW Z-03 Z-06 Z-100 Z-102 Z-103 Z-113PB1 Z-114 Z-115 Z-116 Z-19A Z-210 Z-210PB1 Z-34 5PB1 Z-39 Z-40 Z-50 Z-61 Z-65 Z-68 Z-69 Z-220PB1 Z-220 Z-228 Z-229 Z-222 Z-223 W-241 W-26B Z-234 Z-235 Z-235PB1 W-235 WP W-35A WP HILCORP NORTH SLOPE Greater Prudhoe Bay SCHRADER BLUFF W-35A Area of Review FEET 0 1,000 2,000 3,000 POSTED WELL DATA Well Label WELL SYMBOLS Location INJ Well (Water Flood) P&A Oil/Gas J&A Temporarily Abandoned Plugback Active Oil Injector Location Producer Location Shut in Injector REMARKS Quarter Mile Radius highlighted with well symbols posted at OBC top By: BTR May 22, 2025 PETRA 5/22/2025 2:42:00 PM Well Name PTD API Distance / StatusTop of Oil Pool (SB OBc, MD)Top of Oil Pool (SB OBc, TVDss)Top of Cmt (MD)Top of Cmt (TVDss)Zonal IsolationCommentsPBU W-26 189-080 50-029-21964-00-001275' / Abandoned6392' 4933' 4974' 3892'ClosedSingle stage cement job, 9-5/8". Pumped 997 sx 13.5 ppg Class 'G' cement followed by 500 sx 15.6 ppg Class 'G' cement (total cement volume of 2398 cu ft). No losses reported. Plugs did not bump and cement was found inside the 9-5/8" casing at 11,201' MD. A USIT log run 9/18/1999 during an Ivishak rotary sidetrack shows the presence of cement up to the top of logged interval at 4974' MD. The 9-5/8" casing was later abandonded for a second sidetrack in 12/2022.PBU W-26B 222-151 50-029-21964-02-00567' / Producer8196' 4833' 6393' 4130'ClosedTwo stage cement job, 9-5/8". First stage pumped 281 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. No returns during first stage. ES Cementer opened at 2234' MD. Second stage cement job pumped 200 bbls 10.7 ppg ArcticCem followed by 58 bbls 15.8 ppg Class 'G' cement. No losses noted throughout second stage with a total of 200 bbls cement circulated to surface. CAST CBL 12/31/2022 shows first stage TOC at 6393' MD. Schrader Bluff OBd producer, not open to Schrader Bluff OBc.Passing MIT-IA to 3500 psi 1/8/2023.PBU W-241 222-154 50-029-23741-00-00175' / Injector7358' 4871' 6386' 4482'ClosedSingle stage cement job, 7". Pumped 47 bbls 15.8 ppg cement. No losses noted during job. Including shoe track volume, volumetric calculations place TOC in the 7" x 8-1/2" annulus at 6386' MD when accounting for 30% washout. Schrader Buff OBd injector, not open to Schrader Bluff OBc.Passing MIT-IA to 2321 psi 2/25/2023.PBU Z-228 222-055 50-029-23718-00-001148' / Producer6742' 4719' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 300 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. Full returns throughout first stage. ES Cementer opened at 2315' MD. 14 bbls of cement was circulated out to surface. Second stage cement job pumped 315 bbls 10.7 ppg ArcticCem followed by 56 bbls 15.8 ppg Type I/II cement. No losses noted throughout second stage with a total of 185 bbls cement circulated to surface. Schrader Bluff OBD producer, not open to Schrader Bluff OBc.Passing MIT-IA to 2430 psi 9/11/2023.Area of Review PBU W-35A Well Name PTD API Distance / StatusTop of Oil Pool (SB OBc, MD)Top of Oil Pool (SB OBc, TVDss)Top of Cmt (MD)Top of Cmt (TVDss)Zonal IsolationCommentsPBU W-26 189-080 50-029-21964-00-001275' / Abandoned6392' 4933' 4974' 3892'ClosedSingle stage cement job, 9-5/8". Pumped 997 sx 13.5 ppg Class 'G' cement followed by 500 sx 15.6 ppg Class 'G' cement (total cement volume of 2398 cu ft). No losses reported. Plugs did not bump and cement was found inside the 9-5/8" casing at 11,201' MD. A USIT log run 9/18/1999 during an Ivishak rotary sidetrack shows the presence of cement up to the top of logged interval at 4974' MD. The 9-5/8" casing was later abandonded for a second sidetrack in 12/2022.PBU W-26B 222-151 50-029-21964-02-00567' / Producer8196' 4833' 6393' 4130'ClosedTwo stage cement job, 9-5/8". First stage pumped 281 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. No returns during first stage. ES Cementer opened at 2234' MD. Second stage cement job pumped 200 bbls 10.7 ppg ArcticCem followed by 58 bbls 15.8 ppg Class 'G' cement. No losses noted throughout second stage with a total of 200 bbls cement circulated to surface. CAST CBL 12/31/2022 shows first stage TOC at 6393' MD. Schrader Bluff OBd producer, not open to Schrader Bluff OBc.Passing MIT-IA to 3500 psi 1/8/2023.PBU W-241 222-154 50-029-23741-00-00175' / Injector7358' 4871' 6386' 4482'ClosedSingle stage cement job, 7". Pumped 47 bbls 15.8 ppg cement. No losses noted during job. Including shoe track volume, volumetric calculations place TOC in the 7" x 8-1/2" annulus at 6386' MD when accounting for 30% washout. Schrader Buff OBd injector, not open to Schrader Bluff OBc.Passing MIT-IA to 2321 psi 2/25/2023.PBU Z-223 222-080 50-029-23720-00-001318' / Injector6135' 4609' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 213 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. 10 bbls lost throughout first stage. ES Cementer opened at 2282' MD. 64 bbls of cement was circulated out to surface. Second stage cement job pumped 359 bbls 10.7 ppg ArcticCem followed by 56 bbls 15.8 ppg Type I/II cement. No losses noted throughout second stage with a total of 269 bbls cement circulated to surface. Schrader Bluff OBc injector.Passing MIT-IA to 3076 psi 10/6/2024.PBU Z-229 222-104 50-029-23726-00-001316' / Producer7360' 4770' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 290 bbls 12.0 ppg VariCem, followed by 82 bbls 15.8 ppg Type I/II cement. Full returns throughout first stage. ES Cementer opened at 2313' MD. 30 bbls of cement was circulated out to surface. Second stage cement job pumped 427 bbls 10.7 ppg ArcticCem followed by 54 bbls 15.8 ppg Class 'G' cement. No losses noted throughout second stage with a total of 330 bbls cement circulated to surface. Schrader Bluff OBc producer.Passing MIT-IA to 3500 psi 10/25/2022.PBU Z-235 223-055 50-029-23760-00-001547' / Injector7978' 4808' Surface SurfaceClosedTwo stage cement job, 9-5/8". First stage pumped 334 bbls 12.0 ppg Type I/II, followed by 82 bbls 15.8 ppg Type I/II cement. Full returns throughout first stage. ES Cementer opened at 2449' MD. 104 bbls of cement was circulated out to surface. Second stage cement job pumped 442 bbls 10.7 ppg ArcticCem followed by 56 bbls 15.8 ppg Type I/II cement. No losses noted throughout second stage with a total of 248 bbls cement circulated to surface. Schrader Bluff OBc injector.Passing MIT-IA to 2430 psi 9/11/2023.Area of Review PBU W-35ASuperseded by revised AOR well list. -A.Dewhurst 08AUG25 07 June 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill Hilcorp North Slope, LLC W-35A Dear Sir/Madam, Hilcorp North Slope, LLC hereby applies for a Permit to Drill an onshore injector well from the W Pad in Prudhoe Bay, Alaska. W-35A is planned to be a lateral well targeting the Schrader Bluff Sands. W-35A is a continuation of the development lateral portion of W-35APH1, which was submitted on a prior PTD. The approximate spud date is anticipated to be August 20th, 2025, pending rig schedule. The Innovation rig will be used to drill this well. The directional plan is a continuation of the development injection lateral started in W-35APH1 wellbore. An 8-1/2” BHA will be used to perform an OHST at ~15,500’ MD and drill to TD in the OBc sand. 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 Area of Review Prudhoe Bay Unit (PBU) W-35A Version 1 7/2/2025 Prudhoe Bay W-35A Table of Contents 1. Well Name ...................................................................................................................................... 3 2. Location Summary .......................................................................................................................... 3 3. Blowout Prevention Equipment Information ................................................................................. 4 4. Drilling Hazards Information........................................................................................................... 5 5. Procedure for Conducting Formation Integrity Tests ..................................................................... 6 6. Casing and Cementing Program ..................................................................................................... 6 7. Diverter System Information .......................................................................................................... 7 8. Drilling Fluid Program ..................................................................................................................... 7 9. Abnormally Pressured Formation Information .............................................................................. 8 10. Seismic Analysis ............................................................................................................................ 8 11. Seabed Condition Analysis............................................................................................................ 8 12. Evidence of Bonding ..................................................................................................................... 8 13. Proposed Drilling Program ........................................................................................................... 9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ................................................ 11 15. Proposed Variance Request........................................................................................................ 11 Attachment 1: Location & GIS Maps ................................................................................................ 12 Attachment 2: BOPE Equipment ...................................................................................................... 15 Attachment 3: Hole Section Hazards ................................................................................................ 17 Attachment 4: LOT / FIT Test Procedure .......................................................................................... 19 Attachment 5: Cement Summary ..................................................................................................... 20 Attachment 6: Prognosed Formation Tops ...................................................................................... 2 1 Attachment 7: Well Schematic ......................................................................................................... 22 Attachment 8: Formation Evaluation Program ................................................................................ 23 Attachment 9: Wellhead Diagram .................................................................................................... 24 Attachment 10: Management of Change ......................................................................................... 2 5 Attachment 11: Drill Pipe Specs ....................................................................................................... 26 Attachment 12: Kick Tolerance Calculations .................................................................................... 27 Attachment 13: Directional Plan ...................................................................................................... 28 Prudhoe Bay W-35A As per 20 AAC 25.005 (c), an application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. 1. Well Name 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as W-35A.This will be a development production well. 2. Location Summary 20 AAC 25.005 (c) (2) A plat identifying the property and the property's owners and showing: (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth Location at Surface Reference to Government Section Lines 4,029' FSL, 1,451' FEL, Sec 21, T11N, R12E, UM, AK NAD 27 Coordinate System X: 611,789.02 Y: 5,959,002.08 Innovation Rig KB Elevation 26.5’ above GL Ground Level 53.2’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 1814' FSL, 275' FWL, Sec 16, T11N, R12E, UM, AK NAD 27 Coordinate System X: 608,182.7 Y: 5,962,013.9 Measured Depth, Rig KB (MD) 7900’ Total Vertical Depth, Rig KB (TVD) 4,966.3’ Total vertical Depth, Subsea (TVDSS) 4,886.7’ Location at Bottom of Productive Interval –W-35A Reference to Government Section Lines 2131' FSL, 671' FEL, Sec 6, T11N, R12E, UM, AK NAD 27 Coordinate System X: 601,771.3 Y: 5,972,801.3 Measured Depth, Rig KB (MD) 20,456’ Total Vertical Depth, Rig KB (TVD) 4,959’ Total Vertical Depth, Subsea (TVDSS) 4,879.5’ Prudhoe Bay W-35A (D) other information required by 20 AAC 25.050(b); 20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must: (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 1: Location Maps, Attachment 6: Formation Tops and Attachment 13: Directional Plan for further details. (2) for all wells within 200 feet of the proposed wellbore: (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The applicant is the only affected owner. 3. Blowout Prevention Equipment Information 20 AAC 25.005 (c) (3) A diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; BOP test frequency for W-35A will be 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 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in bottom cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc. Initial Test: 250/3000 (Annular 2500 psi) Subsequent Tests: 250/3000 (Annular 2500 psi) Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are in the doghouse and on accumulator unit. Please refer to Attachment 2: BOPE Equipment for further details. Prudhoe Bay W-35A 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” Production Hole Pressure Data Maximum anticipated BHP 2,190 psi in the Schrader OBc at 4,977’ TVD Maximum surface pressure 1,692 psi from the Schrader OBc (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,000 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 8-1/2” hole 12.0 ppg EMW FIT after drilling 20’ of new hole outside of 9- 5/8” 12.0 provides greater than 25 bbl based on 9.3 ppg MW, 8.44 ppg pore pressure 9.5 ppg minimum to drill ahead, 10.5 EMW for drilling ECDs 9-5/8” Casing Test 2,500 psi, chart for 30 min (Test pressure driven by 50% of Casing Burst) (B) data on potential gas zones; and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please refer to Attachment 3: Hole Section Hazards Prudhoe Bay W-35A 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 8.5” 7” 6.276” 26# L-80 H563 ~1,530 ~6,500 8,026’ / 4,975’ 4-1/2” Solid 3.958” 12.6# L-80 H563 ~12,426 ~8,026’ 20,456’ / 4,959’ Tubing 4-1/2” Solid 3.958” 12.6# L-80 JFEBear ~8,000 Surface ~8,000 / 4,973’ Please refer to Attachment 5: Cement Summary for further details. Prudhoe Bay W-35A 7. Diverter System Information 20 AAC 25.005 (c) (7) A diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Diverter system is not applicable to a sidetrack well. 8. Drilling Fluid Program 20 AAC 25.005 (c) (8) A drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Production Hole Mud Type 3% KCl BaraDril-N Mud Properties: Mud Weight PV YP HPHT Fluid Loss pH MBT 8.8 – 9.5 ppg 15-25 15-30 < 11 9-10 <8 A diagram of drilling fluid system on Innovation is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033 Prudhoe Bay W-35A 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) (9) For an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A – Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis 20 AAC 25.005 (c) (10) For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A – Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis 20 AAC 25.005 (c) (11) For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); The W-35A is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) (12) Evidence showing that the requirements of 20 AAC 25.025 have been met; Evidence of bonding for Hilcorp North Slope, LLC is on file with the Commission. Prudhoe Bay W-35A 13. Proposed Drilling Program 20 AAC 25.005 (c) (13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to W-35A is listed below. Please refer to Attachments for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed Drilling Program Transfer from W-35APH1 PTD to W-35A PTD 1. CBU, and POOH to OHST depth of ~15,500’ 2. Perform OHST 3. Drill 8-1/2” lateral as per directional plan and geo to TD, ~ 20,455’ MD 4. CBU and monitor well 5. BROOH t/ 9-5/8” shoe 6. CBU and POOH 7. LD BHA 8. RU and run 7” x 4-1/2” Liner on 5” DP to TD 9. Set and release liner hanger 10. Cement 4-1/2” Liner as per plan 11. Set liner top packer, pooh with running tool 12. CBU to remove any cement above liner top packer 13. RU and PT liner to packer / 7” annulus t. 1500 psi f/ 10 min, charted 14. POOH LD running tool 15. RU E-line and perform CBL of 9-5/8” a. TOC Required: 500’ MD Above Ugnu MA, 5,647’ MD b. ~ Liner top, 6,500’ MD 16. Run 4-1/2” tubing as per tally 17. Land Hanger, RILDS 18. Install BPV, ND BOPE, NU Tree 19. PT tubing hanger void 500/5000 psi, PT tree to 250/5000psi 20. Spot CI Brine 21. Drop Ball & Rod, set tubing packer 22. PT Tubing 3500 psi with 1000psi on IA, bleed tubing to 2000 psi & PT IA to 3500 psi a. All tests 30 min, charted b. Notify AOGCC 24hrs prior to test for opportunity to witness 23. Bleed Pressure on tubing to 0 psi, spot freeze protect 24. RU jumper to allowed freeze protect to swap 25. RDMO *Intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above all significant hydrocarbon zones and abnormally geo-pressured strata - JJL Prudhoe Bay W-35A Post Rig Work 1. Wireline: Pull ball and rod, RHC Plug 2. CTU: Shift injection sleeves 3. Well Tie In 4. Put Well on injection Note: This well will not be fracture stimulated or pre produced Prudhoe Bay W-35A 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) (14) A general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. All cuttings and mud generated during drilling operations will be hauled to Prudhoe G&I on Pad 4. Drilling mud and cuttings will be hauled offsite as it is generated via truck. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. 15. Proposed Variance Request Hilcorp would like to request a variance from 20 AAC 25.412.(b) which states: “A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone.” To effectively produce this fault block, the current well plan has the intermediate casing shoe landing at the OBc production interval at ~87 degrees inclination. To make the ball and rod we land to set the production packer slickline accessible, the X nipple in the tubing tail must be landed at less than 70 degrees inclination. The MD we currently have planned for 70 degrees is at ~6,900’ MD. The X-nipple below the production packer will be set at ~6,800’ MD / 4,770’ TVD and the production packer will be ~50’ MD above the X nipple which puts it at ~6,750’ MD / ~4750’ TVD. The intermediate casing shoe is planned at ~8030’ MD / ~4,974’ TVD which means the planned packer depth is ~1,280’ MD away. From a TVD standpoint, the production tubing packer is ~200’ TVD from the intermediate casing shoe. With the intermediate casing set in the Schrader Bluff sand, and the injection packer set inside the intermediate casing, injection fluids will be confined to the Schrader bluff sands. Prudhoe Bay W-35A Attachment 1: Location & GIS Maps Prudhoe Bay W-35A Prudhoe Bay W-35A Prudhoe Bay W-35A Attachment 2: BOPE Equipment Innovation Rig BOPE Schematic Per 20 AAC 25.035(e)1.A For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) (iii) one annular type Prudhoe Bay W-35A BOPE Configuration for each operation: Drill Production / Run 4-1/2” Liner & Completion: x 13-5/8” Annular x UPR: 2-7/8” x 5-1/2” VBR x Blind Rams x LPR: 7” solid body rams Innovation Rig Choke Manifold Schematic Prudhoe Bay W-35A Attachment 3: Hole Section Hazards 8-1/2” Production Hole Section Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Prudhoe Bay W-35A PBU W Pad has a history of H2S. Ensure detectors are tested and functioning. x AOGCC to be notified withing 24 hours if H2S is encountered more than 20 ppm during drilling operations x Rig will have fully functional automatic H2S detection equipment meeting the requirements of 20 AAC 25.066 x In the event H2S is detected, well work will be suspended and personnel evacuated until a detailed mitigation procured can be developed. Wells with over 100ppm H2S readings on W Pad: There are no wells with H2S 100ppm or greater Prudhoe Bay W-35A Attachment 4: LOT / FIT Test Procedure Prudhoe Bay W-35A Attachment 5: Cement Summary 4-1/2” Liner Cement OH x CSG 8-1/2” OH x 4-1/2” Liner Basis Cement Vol CH volume (1526’ 7” Liner Lap) + (OH volume x 30%) + 120’ ft shoe track TOC Liner Top, ~ 6,500’ MD Total Cement Volume Spacer 30 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess 15ppg: 860.8 bbls, 4829 ft3, 2759 sks 1.75 cuft/sk BHST 100 deg F Displacement 6500’ x .0171bpf (5” dp capacity) = 111.15 bbl 1526’ x .0058bpf (2-7/8” liner running tool extension) = 8.6bbl 12,310’ x .0152bpf (4-1/2” capacity) = 187.1bbl =306.9bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 9-5/8" CH x 7" (8,026-6,500) x .0282 = 43.0 241.2 8-1/2" OH x 4-1/2" (20,456 - 8,026)' x 0.0505 bpf x 1.3 = 816.0 4577.8 4-1/2" Shoetrack 120' x 0.0152 bpf = 1.8 10.1 Total Tail 860.8 4829.1 2759.5Tail Prudhoe Bay W-35A Attachment 6: Prognosed Formation Tops ANTICIPATED FORMATION TOPS & GEOHAZARDS Reference Plan: w-35A wp08 Obc Top Oil 8001.98 4,891 -4890.93 2,152 0.44 TD Oil 20455.9 4,959 -4879.48 2,182 0.44 TOP NAME EXPECTED FLUID MD (FT) TVD (FT) TVDSS (FT)Est. Pressure Gradient Top OBc at is 7868’ MD. See attached emails. -A.Dewhurst 08AUG25 Prudhoe Bay W-35A Attachment 7: Well Schematic Prudhoe Bay W-35A Attachment 8: Formation Evaluation Program 8-1/2” Production Hole LWD Gamma Ray Resistivity Azimuthal Resistivity Density Neutron Mudlogging No mudlogging is planned. Prudhoe Bay W-35A Attachment 9: Wellhead Diagram Prudhoe Bay W-35A Attachment 10: Management of Change Prudhoe Bay W-35A Attachment 11: Drill Pipe Specs Prudhoe Bay W-35A Attachment 12: Kick Tolerance Calculations Prudhoe Bay W-35A Attachment 13: Directional Plan Production Section Offset Wells with CF < 1.0: x W-35APH1 Plan, this is an uncompleted pilot hole, there is no collision risk x W-241: CF .9+, This well is a Schrader Bluff OBd lateral injector, separated from the OBc by silt, we will have geologic separation from the well. W-241 will be shut in during production hole drilling. Standard Proposal Report 16 June, 2025 Plan: W-35A wp08 Hilcorp North Slope, LLC Prudhoe Bay W Plan: W-35 Plan: W-35A 1900285038004750570066507600True Vertical Depth (1900 usft/in)0 950 1900 2850 3800 4750 5700 6650 7600 8550 9500 10450 11400 12350 13300 14250 15200 16150 17100 18050Vertical Section at 324.87° (1900 usft/in)W-35A wp03 tgt031500200025003000350040004500500055006000650070007500800085009000W-3520002500300035004000450050005500600065007000750080008500 9000 9500 10000 10500 11000 115 00 12000 12500 13000 13500 14000 14500 15000 15500 16000 1 65 0 0 17000 1 7 50 0 1 8 000 1 8 11 4W-35A PH1 wp0815500 16000 16500 17000 17500 18000 18500 19000 19500 20000 20456W-35A wp08Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TFEnd Dir : 1855' MD, 1854.98' TVDStart Dir 4.04º/100' : 1885' MD, 1884.96'TVDStart Dir 4.5º/100' : 2085' MD, 2083.64'TVDEnd Dir : 3361.67' MD, 3111.14' TVDStart Dir 3º/100' : 6448.14' MD, 4618.01'TVDEnd Dir : 7582.4' MD, 4944.1' TVDStart Dir 3º/100' : 7982.4' MD, 4972'TVDEnd Dir : 8121.73' MD, 4976.64' TVDStart Dir 1.5º/100' : 13621.74' MD, 4959.36'TVDEnd Dir : 13855.38' MD, 4959' TVDTotal Depth : 20455.99' MD, 4959' THilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: W-35Ground Level: 53.02+N/-S+E/-WNorthingEastingLatittudeLongitude0.000.005959002.08611789.02 70° 17' 49.0154 N 149° 5' 41.0699 WSURVEY PROGRAMDate: 2025-05-12T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool88.75 1830.00 W-35 Srvy 1 BOSS-GYRO (W-35) 3_Gyro-SR-GMS1830.00 2230.00 W-35A PH1 wp08 (Plan: W-35A PH1) GYD_Quest GWD2230.00 8026.00 W-35A PH1 wp08 (Plan: W-35A PH1) 3_MWD+IFR2+MS+Sag8026.00 15500.00 W-35A PH1 wp08 (Plan: W-35A PH1) 3_MWD+IFR2+MS+Sag15500.00 20455.99 W-35A wp08 (Plan: W-35A) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: W-35, True NorthVertical (TVD) Reference:W-35A planned RKB @ 79.52usftMeasured Depth Reference:W-35A planned RKB @ 79.52usftCalculation Method: Minimum CurvatureProject:Prudhoe BaySite:WWell:Plan: W-35Wellbore:Plan: W-35ADesign:W-35A wp08CASING DETAILSTVD TVDSS MD SizeName4959.00 4879.48 20455.99 7 7" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 15500.00 90.00 328.50 4959.00 9722.21 -7222.67 0.00 0.00 12107.442 20455.99 90.00 328.50 4959.00 13947.88 -9812.17 0.00 0.00 17053.51 W-35A wp03 tgt03 Total Depth : 20455.99' MD, 4959' TVD -800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 13600 South(-)/North(+) (1600 usft/in)-11200 -10400 -9600 -8800 -8000 -7200 -6400 -5600 -4800 -4000 -3200 -2400 -1600 -800 0 West(-)/East(+) (1600 usft/in) W-35A wp03 tgt03 22503 2 5 04 0 0 0 4 5 005 00 0 5 5 0 060 006500700075008000850087509205W-35 275032503500375040004250450047504565W-35A PH1 wp08 7" x 8 1/2"4959 W -3 5A wp08 Start Dir 8.6º/100' : 1830' MD, 1829.98'TVD : 109.65° RT TF End Dir : 1855' MD, 1854.98' TVD Start Dir 4.04º/100' : 1885' MD, 1884.96'TVD Start Dir 4.5º/100' : 2085' MD, 2083.64'TVD End Dir : 3361.67' MD, 3111.14' TVD Start Dir 3º/100' : 6448.14' MD, 4618.01'TVD End Dir : 7582.4' MD, 4944.1' TVD Start Dir 3º/100' : 7982.4' MD, 4972'TVD End Dir : 8121.73' MD, 4976.64' TVD Start Dir 1.5º/100' : 13621.74' MD, 4959.36'TVD End Dir : 13855.38' MD, 4959' TVD Total Depth : 20455.99' MD, 4959' TVD CASING DETAILS TVD TVDSS MD Size Name 4959.00 4879.48 20455.99 7 7" x 8 1/2" Project: Prudhoe Bay Site: W Well: Plan: W-35 Wellbore: Plan: W-35A Plan: W-35A wp08 WELL DETAILS: Plan: W-35 Ground Level: 53.02 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5959002.08 611789.02 70° 17' 49.0154 N 149° 5' 41.0699 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: W-35, True North Vertical (TVD) Reference: W-35A planned RKB @ 79.52usft Measured Depth Reference:W-35A planned RKB @ 79.52usft Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Prudhoe Bay, North Slope, UNITED STATES Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: W, TR-11-12 usft Map usft usft °0.84Slot Radius:"0 5,957,194.18 609,919.18 5.00 70° 17' 31.5064 N 149° 6' 36.3426 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: W-35, W-35 usft usft 0.00 0.00 5,959,002.08 611,789.02 53.20Wellhead Elevation:usft0.00 70° 17' 49.0154 N 149° 5' 41.0699 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Plan: W-35A Model NameMagnetics BGGM2025 11/11/2025 13.69 80.58 57,064.99509143 Phase:Version: Audit Notes: Design W-35A wp08 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:15,500.00 324.870.000.0026.50 Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.00-7,222.679,722.214,959.00328.5090.0015,500.00 4,879.48 0.000.000.000.00-9,812.1713,947.884,959.00328.5090.0020,455.99 4,879.48 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -53.02 Vert Section 26.50 0.00 26.50 0.00 0.000.00 611,789.025,959,002.08-53.02 0.00 0.00 88.75 0.23 88.75 0.06 -0.11296.31 611,788.915,959,002.139.23 0.37 0.11 188.75 0.17 188.75 0.22 -0.42300.50 611,788.605,959,002.29109.23 0.06 0.42 288.75 0.17 288.75 0.37 -0.67302.31 611,788.345,959,002.44209.23 0.01 0.69 388.75 0.17 388.75 0.57 -0.89323.31 611,788.125,959,002.64309.23 0.06 0.98 488.75 0.12 488.75 0.79 -1.00349.20 611,788.015,959,002.86409.23 0.08 1.22 588.75 0.62 588.75 1.25 -1.43310.61 611,787.585,959,003.31509.23 0.53 1.84 688.75 0.60 688.74 1.81 -2.32293.40 611,786.685,959,003.85609.22 0.18 2.81 788.75 0.15 788.74 2.04 -2.93278.20 611,786.065,959,004.07709.22 0.46 3.35 888.75 0.12 888.74 2.11 -2.9758.10 611,786.025,959,004.15809.22 0.25 3.43 988.75 0.43 988.74 2.39 -3.18306.20 611,785.805,959,004.42909.22 0.49 3.78 1,088.75 0.27 1,088.74 2.77 -3.3146.10 611,785.665,959,004.801,009.22 0.55 4.17 1,188.75 0.03 1,188.74 2.94 -3.1271.39 611,785.865,959,004.981,109.22 0.24 4.20 1,288.75 0.33 1,288.73 3.11 -3.33303.70 611,785.645,959,005.141,209.21 0.35 4.46 1,388.75 0.27 1,388.73 3.17 -3.79243.89 611,785.195,959,005.191,309.21 0.30 4.77 1,488.75 0.13 1,488.73 3.01 -3.90119.20 611,785.085,959,005.031,409.21 0.36 4.70 1,588.75 0.23 1,588.73 3.06 -3.97301.20 611,785.005,959,005.081,509.21 0.36 4.79 1,688.75 0.30 1,688.73 2.93 -4.26206.10 611,784.725,959,004.941,609.21 0.39 4.84 1,788.75 0.22 1,788.73 2.60 -4.20116.81 611,784.785,959,004.621,709.21 0.37 4.55 1,830.00 0.15 1,829.98 2.53 -4.09134.10 611,784.895,959,004.551,750.46 0.21 4.42 1,830.10 0.15 1,830.08 2.53 -4.09134.10 611,784.895,959,004.551,750.56 0.00 4.42 13-3/8" x 17 1/2" TOW 1,850.00 1.67 1,849.98 2.36 -4.32238.76 611,784.665,959,004.381,770.46 8.64 4.42 1,855.00 2.10 1,854.98 2.28 -4.46239.78 611,784.525,959,004.291,775.46 8.60 4.43 1,885.00 2.10 1,884.96 1.72 -5.41239.78 611,783.585,959,003.721,805.44 0.00 4.52 1,900.00 2.71 1,899.94 1.40 -5.96239.78 611,783.045,959,003.401,820.42 4.04 4.58 2,000.00 6.75 1,999.58 -2.74 -13.08239.78 611,775.985,958,999.141,920.06 4.04 5.28 2,085.00 10.18 2,083.64 -9.04 -23.89239.78 611,765.275,958,992.692,004.12 4.04 6.35 2,100.00 10.39 2,098.40 -10.31 -26.25243.38 611,762.935,958,991.382,018.88 4.50 6.67 2,200.00 12.63 2,196.42 -15.66 -45.17263.14 611,744.095,958,985.752,116.90 4.50 13.18 2,300.00 15.84 2,293.36 -15.53 -69.61276.04 611,719.655,958,985.512,213.84 4.50 27.35 2,400.00 19.56 2,388.63 -9.93 -99.42284.42 611,689.775,958,990.682,309.11 4.50 49.08 2,500.00 23.55 2,481.62 1.13 -134.41290.14 611,654.625,959,001.212,402.10 4.50 78.25 2,600.00 27.68 2,571.78 17.55 -174.36294.25 611,614.435,959,017.042,492.26 4.50 114.68 2,700.00 31.91 2,658.55 39.25 -219.03297.36 611,569.445,959,038.072,579.03 4.50 158.13 2,800.00 36.20 2,741.38 66.10 -268.15299.81 611,519.945,959,064.182,661.86 4.50 208.35 2,900.00 40.53 2,819.78 97.92 -321.41301.80 611,466.215,959,095.202,740.26 4.50 265.02 3,000.00 44.88 2,893.25 134.51 -378.49303.47 611,408.615,959,130.942,813.73 4.50 327.79 3,100.00 49.26 2,961.34 175.66 -439.02304.90 611,347.475,959,171.182,881.82 4.50 396.28 3,200.00 53.65 3,023.64 221.11 -502.65306.15 611,283.185,959,215.672,944.12 4.50 470.06 3,300.00 58.06 3,079.76 270.58 -568.97307.26 611,216.145,959,264.153,000.24 4.50 548.68 3,361.67 60.78 3,111.14 302.96 -611.04307.90 611,173.605,959,295.903,031.62 4.50 599.37 3,400.00 60.78 3,129.85 323.51 -637.43307.90 611,146.905,959,316.053,050.33 0.00 631.36 3,500.00 60.78 3,178.67 377.12 -706.29307.90 611,077.255,959,368.623,099.15 0.00 714.83 3,600.00 60.78 3,227.49 430.73 -775.16307.90 611,007.615,959,421.203,147.97 0.00 798.30 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,196.80 Vert Section 3,700.00 60.78 3,276.32 484.34 -844.02307.90 610,937.965,959,473.773,196.80 0.00 881.77 3,800.00 60.78 3,325.14 537.95 -912.89307.90 610,868.315,959,526.353,245.62 0.00 965.24 3,900.00 60.78 3,373.96 591.56 -981.75307.90 610,798.665,959,578.933,294.44 0.00 1,048.71 4,000.00 60.78 3,422.78 645.17 -1,050.62307.90 610,729.015,959,631.503,343.26 0.00 1,132.18 4,100.00 60.78 3,471.60 698.78 -1,119.48307.90 610,659.365,959,684.083,392.08 0.00 1,215.65 4,200.00 60.78 3,520.43 752.40 -1,188.35307.90 610,589.725,959,736.653,440.91 0.00 1,299.12 4,300.00 60.78 3,569.25 806.01 -1,257.21307.90 610,520.075,959,789.233,489.73 0.00 1,382.59 4,400.00 60.78 3,618.07 859.62 -1,326.08307.90 610,450.425,959,841.803,538.55 0.00 1,466.06 4,500.00 60.78 3,666.89 913.23 -1,394.94307.90 610,380.775,959,894.383,587.37 0.00 1,549.53 4,600.00 60.78 3,715.71 966.84 -1,463.81307.90 610,311.125,959,946.963,636.19 0.00 1,633.00 4,700.00 60.78 3,764.54 1,020.45 -1,532.67307.90 610,241.475,959,999.533,685.02 0.00 1,716.47 4,800.00 60.78 3,813.36 1,074.06 -1,601.53307.90 610,171.835,960,052.113,733.84 0.00 1,799.94 4,900.00 60.78 3,862.18 1,127.67 -1,670.40307.90 610,102.185,960,104.683,782.66 0.00 1,883.41 5,000.00 60.78 3,911.00 1,181.28 -1,739.26307.90 610,032.535,960,157.263,831.48 0.00 1,966.89 5,100.00 60.78 3,959.82 1,234.89 -1,808.13307.90 609,962.885,960,209.833,880.30 0.00 2,050.36 5,200.00 60.78 4,008.65 1,288.50 -1,876.99307.90 609,893.235,960,262.413,929.13 0.00 2,133.83 5,300.00 60.78 4,057.47 1,342.11 -1,945.86307.90 609,823.585,960,314.993,977.95 0.00 2,217.30 5,400.00 60.78 4,106.29 1,395.72 -2,014.72307.90 609,753.935,960,367.564,026.77 0.00 2,300.77 5,500.00 60.78 4,155.11 1,449.33 -2,083.59307.90 609,684.295,960,420.144,075.59 0.00 2,384.24 5,600.00 60.78 4,203.93 1,502.94 -2,152.45307.90 609,614.645,960,472.714,124.41 0.00 2,467.71 5,700.00 60.78 4,252.75 1,556.55 -2,221.32307.90 609,544.995,960,525.294,173.23 0.00 2,551.18 5,800.00 60.78 4,301.58 1,610.16 -2,290.18307.90 609,475.345,960,577.864,222.06 0.00 2,634.65 5,900.00 60.78 4,350.40 1,663.77 -2,359.04307.90 609,405.695,960,630.444,270.88 0.00 2,718.12 6,000.00 60.78 4,399.22 1,717.38 -2,427.91307.90 609,336.045,960,683.024,319.70 0.00 2,801.59 6,100.00 60.78 4,448.04 1,770.99 -2,496.77307.90 609,266.405,960,735.594,368.52 0.00 2,885.06 6,200.00 60.78 4,496.86 1,824.61 -2,565.64307.90 609,196.755,960,788.174,417.34 0.00 2,968.53 6,300.00 60.78 4,545.69 1,878.22 -2,634.50307.90 609,127.105,960,840.744,466.17 0.00 3,052.00 6,400.00 60.78 4,594.51 1,931.83 -2,703.37307.90 609,057.455,960,893.324,514.99 0.00 3,135.47 6,448.14 60.78 4,618.01 1,957.64 -2,736.52307.90 609,023.925,960,918.634,538.49 0.00 3,175.66 6,500.00 61.85 4,642.91 1,985.98 -2,772.10309.18 608,987.935,960,946.444,563.39 3.00 3,219.31 6,600.00 63.95 4,688.46 2,043.67 -2,839.88311.59 608,919.305,961,003.114,608.94 3.00 3,305.49 6,700.00 66.09 4,730.70 2,105.20 -2,906.42313.91 608,851.855,961,063.644,651.18 3.00 3,394.11 6,800.00 68.26 4,769.49 2,170.41 -2,971.54316.15 608,785.785,961,127.874,689.97 3.00 3,484.91 6,900.00 70.47 4,804.73 2,239.12 -3,035.06318.33 608,721.255,961,195.624,725.21 3.00 3,577.66 7,000.00 72.69 4,836.33 2,311.15 -3,096.80320.45 608,658.455,961,266.714,756.81 3.00 3,672.09 7,100.00 74.94 4,864.19 2,386.29 -3,156.60322.51 608,597.555,961,340.954,784.67 3.00 3,767.95 7,200.00 77.21 4,888.25 2,464.33 -3,214.28324.54 608,538.725,961,418.124,808.73 3.00 3,864.97 7,300.00 79.50 4,908.44 2,545.07 -3,269.70326.52 608,482.115,961,498.024,828.92 3.00 3,962.89 7,400.00 81.79 4,924.70 2,628.29 -3,322.70328.48 608,427.885,961,580.434,845.18 3.00 4,061.45 7,500.00 84.10 4,936.98 2,713.74 -3,373.13330.42 608,376.195,961,665.124,857.46 3.00 4,160.36 7,582.40 86.00 4,944.10 2,785.68 -3,412.66332.00 608,335.595,961,736.464,864.58 3.00 4,241.94 7,600.00 86.00 4,945.33 2,801.19 -3,420.91332.00 608,327.125,961,751.844,865.81 0.00 4,259.37 7,700.00 86.00 4,952.30 2,889.27 -3,467.74332.00 608,278.995,961,839.204,872.78 0.00 4,358.35 7,800.00 86.00 4,959.28 2,977.35 -3,514.57332.00 608,230.855,961,926.574,879.76 0.00 4,457.34 7,900.00 86.00 4,966.25 3,065.43 -3,561.41332.00 608,182.725,962,013.934,886.73 0.00 4,556.32 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,892.48 Vert Section 7,982.40 86.00 4,972.00 3,138.00 -3,599.99332.00 608,143.065,962,085.924,892.48 0.00 4,637.89 8,000.00 86.53 4,973.15 3,153.51 -3,608.24332.00 608,134.585,962,101.304,893.63 3.00 4,655.32 8,026.00 87.31 4,974.54 3,176.43 -3,620.43332.00 608,122.065,962,124.044,895.02 3.00 4,681.08 9-5/8" x 12 1/4" 8,100.00 89.53 4,976.59 3,241.74 -3,655.16332.00 608,086.375,962,188.824,897.07 3.00 4,754.47 8,121.73 90.18 4,976.64 3,260.93 -3,665.36332.00 608,075.885,962,207.854,897.12 3.00 4,776.04 8,200.00 90.18 4,976.40 3,330.04 -3,702.10332.00 608,038.125,962,276.404,896.88 0.00 4,853.70 8,300.00 90.18 4,976.08 3,418.33 -3,749.05332.00 607,989.875,962,363.984,896.56 0.00 4,952.93 8,400.00 90.18 4,975.77 3,506.63 -3,796.00332.00 607,941.615,962,451.564,896.25 0.00 5,052.15 8,500.00 90.18 4,975.45 3,594.92 -3,842.94332.00 607,893.365,962,539.144,895.93 0.00 5,151.38 8,600.00 90.18 4,975.14 3,683.21 -3,889.89332.00 607,845.115,962,626.714,895.62 0.00 5,250.61 8,700.00 90.18 4,974.83 3,771.51 -3,936.84332.00 607,796.865,962,714.294,895.31 0.00 5,349.84 8,800.00 90.18 4,974.51 3,859.80 -3,983.78332.00 607,748.615,962,801.874,894.99 0.00 5,449.06 8,900.00 90.18 4,974.20 3,948.10 -4,030.73332.00 607,700.365,962,889.454,894.68 0.00 5,548.29 9,000.00 90.18 4,973.88 4,036.39 -4,077.68332.00 607,652.115,962,977.034,894.36 0.00 5,647.52 9,100.00 90.18 4,973.57 4,124.69 -4,124.62332.00 607,603.865,963,064.614,894.05 0.00 5,746.74 9,200.00 90.18 4,973.26 4,212.98 -4,171.57332.00 607,555.615,963,152.194,893.74 0.00 5,845.97 9,300.00 90.18 4,972.94 4,301.27 -4,218.52332.00 607,507.365,963,239.774,893.42 0.00 5,945.20 9,400.00 90.18 4,972.63 4,389.57 -4,265.47332.00 607,459.115,963,327.344,893.11 0.00 6,044.43 9,500.00 90.18 4,972.31 4,477.86 -4,312.41332.00 607,410.855,963,414.924,892.79 0.00 6,143.65 9,600.00 90.18 4,972.00 4,566.16 -4,359.36332.00 607,362.605,963,502.504,892.48 0.00 6,242.88 9,700.00 90.18 4,971.68 4,654.45 -4,406.31332.00 607,314.355,963,590.084,892.16 0.00 6,342.11 9,800.00 90.18 4,971.37 4,742.75 -4,453.25332.00 607,266.105,963,677.664,891.85 0.00 6,441.33 9,900.00 90.18 4,971.06 4,831.04 -4,500.20332.00 607,217.855,963,765.244,891.54 0.00 6,540.56 10,000.00 90.18 4,970.74 4,919.33 -4,547.15332.00 607,169.605,963,852.824,891.22 0.00 6,639.79 10,100.00 90.18 4,970.43 5,007.63 -4,594.09332.00 607,121.355,963,940.404,890.91 0.00 6,739.02 10,200.00 90.18 4,970.11 5,095.92 -4,641.04332.00 607,073.105,964,027.974,890.59 0.00 6,838.24 10,300.00 90.18 4,969.80 5,184.22 -4,687.99332.00 607,024.855,964,115.554,890.28 0.00 6,937.47 10,400.00 90.18 4,969.49 5,272.51 -4,734.93332.00 606,976.605,964,203.134,889.97 0.00 7,036.70 10,500.00 90.18 4,969.17 5,360.81 -4,781.88332.00 606,928.345,964,290.714,889.65 0.00 7,135.92 10,600.00 90.18 4,968.86 5,449.10 -4,828.83332.00 606,880.095,964,378.294,889.34 0.00 7,235.15 10,700.00 90.18 4,968.54 5,537.39 -4,875.78332.00 606,831.845,964,465.874,889.02 0.00 7,334.38 10,800.00 90.18 4,968.23 5,625.69 -4,922.72332.00 606,783.595,964,553.454,888.71 0.00 7,433.61 10,900.00 90.18 4,967.91 5,713.98 -4,969.67332.00 606,735.345,964,641.034,888.39 0.00 7,532.83 11,000.00 90.18 4,967.60 5,802.28 -5,016.62332.00 606,687.095,964,728.604,888.08 0.00 7,632.06 11,100.00 90.18 4,967.29 5,890.57 -5,063.56332.00 606,638.845,964,816.184,887.77 0.00 7,731.29 11,200.00 90.18 4,966.97 5,978.87 -5,110.51332.00 606,590.595,964,903.764,887.45 0.00 7,830.51 11,300.00 90.18 4,966.66 6,067.16 -5,157.46332.00 606,542.345,964,991.344,887.14 0.00 7,929.74 11,400.00 90.18 4,966.34 6,155.45 -5,204.40332.00 606,494.095,965,078.924,886.82 0.00 8,028.97 11,500.00 90.18 4,966.03 6,243.75 -5,251.35332.00 606,445.845,965,166.504,886.51 0.00 8,128.19 11,600.00 90.18 4,965.72 6,332.04 -5,298.30332.00 606,397.585,965,254.084,886.20 0.00 8,227.42 11,700.00 90.18 4,965.40 6,420.34 -5,345.24332.00 606,349.335,965,341.664,885.88 0.00 8,326.65 11,800.00 90.18 4,965.09 6,508.63 -5,392.19332.00 606,301.085,965,429.234,885.57 0.00 8,425.88 11,900.00 90.18 4,964.77 6,596.93 -5,439.14332.00 606,252.835,965,516.814,885.25 0.00 8,525.10 12,000.00 90.18 4,964.46 6,685.22 -5,486.09332.00 606,204.585,965,604.394,884.94 0.00 8,624.33 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,884.62 Vert Section 12,100.00 90.18 4,964.14 6,773.52 -5,533.03332.00 606,156.335,965,691.974,884.62 0.00 8,723.56 12,200.00 90.18 4,963.83 6,861.81 -5,579.98332.00 606,108.085,965,779.554,884.31 0.00 8,822.78 12,300.00 90.18 4,963.52 6,950.10 -5,626.93332.00 606,059.835,965,867.134,884.00 0.00 8,922.01 12,400.00 90.18 4,963.20 7,038.40 -5,673.87332.00 606,011.585,965,954.714,883.68 0.00 9,021.24 12,500.00 90.18 4,962.89 7,126.69 -5,720.82332.00 605,963.335,966,042.294,883.37 0.00 9,120.47 12,600.00 90.18 4,962.57 7,214.99 -5,767.77332.00 605,915.085,966,129.864,883.05 0.00 9,219.69 12,700.00 90.18 4,962.26 7,303.28 -5,814.71332.00 605,866.825,966,217.444,882.74 0.00 9,318.92 12,800.00 90.18 4,961.95 7,391.58 -5,861.66332.00 605,818.575,966,305.024,882.43 0.00 9,418.15 12,900.00 90.18 4,961.63 7,479.87 -5,908.61332.00 605,770.325,966,392.604,882.11 0.00 9,517.37 13,000.00 90.18 4,961.32 7,568.16 -5,955.55332.00 605,722.075,966,480.184,881.80 0.00 9,616.60 13,100.00 90.18 4,961.00 7,656.46 -6,002.50332.00 605,673.825,966,567.764,881.48 0.00 9,715.83 13,200.00 90.18 4,960.69 7,744.75 -6,049.45332.00 605,625.575,966,655.344,881.17 0.00 9,815.06 13,300.00 90.18 4,960.37 7,833.05 -6,096.40332.00 605,577.325,966,742.924,880.85 0.00 9,914.28 13,400.00 90.18 4,960.06 7,921.34 -6,143.34332.00 605,529.075,966,830.494,880.54 0.00 10,013.51 13,500.00 90.18 4,959.75 8,009.64 -6,190.29332.00 605,480.825,966,918.074,880.23 0.00 10,112.74 13,600.00 90.18 4,959.43 8,097.93 -6,237.24332.00 605,432.575,967,005.654,879.91 0.00 10,211.96 13,621.74 90.18 4,959.36 8,117.13 -6,247.44332.00 605,422.085,967,024.694,879.84 0.00 10,233.54 13,700.00 90.12 4,959.16 8,185.84 -6,284.89330.83 605,383.625,967,092.844,879.64 1.50 10,311.28 13,800.00 90.04 4,959.02 8,272.51 -6,334.77329.33 605,332.465,967,178.754,879.50 1.50 10,410.87 13,855.38 90.00 4,959.00 8,319.94 -6,363.36328.50 605,303.165,967,225.744,879.48 1.50 10,466.11 13,900.00 90.00 4,959.00 8,357.98 -6,386.67328.50 605,279.295,967,263.434,879.48 0.00 10,510.64 14,000.00 90.00 4,959.00 8,443.25 -6,438.92328.50 605,225.785,967,347.904,879.48 0.00 10,610.44 14,100.00 90.00 4,959.00 8,528.51 -6,491.17328.50 605,172.275,967,432.374,879.48 0.00 10,710.24 14,200.00 90.00 4,959.00 8,613.78 -6,543.42328.50 605,118.775,967,516.844,879.48 0.00 10,810.04 14,300.00 90.00 4,959.00 8,699.04 -6,595.67328.50 605,065.265,967,601.314,879.48 0.00 10,909.84 14,400.00 90.00 4,959.00 8,784.30 -6,647.92328.50 605,011.755,967,685.784,879.48 0.00 11,009.64 14,500.00 90.00 4,959.00 8,869.57 -6,700.17328.50 604,958.245,967,770.254,879.48 0.00 11,109.44 14,600.00 90.00 4,959.00 8,954.83 -6,752.42328.50 604,904.745,967,854.724,879.48 0.00 11,209.24 14,700.00 90.00 4,959.00 9,040.10 -6,804.67328.50 604,851.235,967,939.194,879.48 0.00 11,309.04 14,800.00 90.00 4,959.00 9,125.36 -6,856.92328.50 604,797.725,968,023.664,879.48 0.00 11,408.84 14,900.00 90.00 4,959.00 9,210.62 -6,909.17328.50 604,744.215,968,108.134,879.48 0.00 11,508.64 15,000.00 90.00 4,959.00 9,295.89 -6,961.42328.50 604,690.705,968,192.604,879.48 0.00 11,608.44 15,100.00 90.00 4,959.00 9,381.15 -7,013.67328.50 604,637.205,968,277.074,879.48 0.00 11,708.24 15,200.00 90.00 4,959.00 9,466.42 -7,065.92328.50 604,583.695,968,361.544,879.48 0.00 11,808.04 15,300.00 90.00 4,959.00 9,551.68 -7,118.17328.50 604,530.185,968,446.014,879.48 0.00 11,907.84 15,400.00 90.00 4,959.00 9,636.94 -7,170.42328.50 604,476.675,968,530.484,879.48 0.00 12,007.64 15,500.00 90.00 4,959.00 9,722.21 -7,222.67328.50 604,423.165,968,614.954,879.48 0.00 12,107.44 15,600.00 90.00 4,959.00 9,807.47 -7,274.92328.50 604,369.665,968,699.424,879.48 0.00 12,207.24 15,700.00 90.00 4,959.00 9,892.74 -7,327.17328.50 604,316.155,968,783.894,879.48 0.00 12,307.04 15,800.00 90.00 4,959.00 9,978.00 -7,379.42328.50 604,262.645,968,868.364,879.48 0.00 12,406.84 15,900.00 90.00 4,959.00 10,063.26 -7,431.67328.50 604,209.135,968,952.834,879.48 0.00 12,506.64 16,000.00 90.00 4,959.00 10,148.53 -7,483.92328.50 604,155.635,969,037.304,879.48 0.00 12,606.44 16,100.00 90.00 4,959.00 10,233.79 -7,536.17328.50 604,102.125,969,121.774,879.48 0.00 12,706.24 16,200.00 90.00 4,959.00 10,319.06 -7,588.42328.50 604,048.615,969,206.244,879.48 0.00 12,806.04 16,300.00 90.00 4,959.00 10,404.32 -7,640.67328.50 603,995.105,969,290.714,879.48 0.00 12,905.84 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,879.48 Vert Section 16,400.00 90.00 4,959.00 10,489.58 -7,692.92328.50 603,941.605,969,375.184,879.48 0.00 13,005.64 16,500.00 90.00 4,959.00 10,574.85 -7,745.17328.50 603,888.095,969,459.654,879.48 0.00 13,105.44 16,600.00 90.00 4,959.00 10,660.11 -7,797.42328.50 603,834.585,969,544.134,879.48 0.00 13,205.24 16,700.00 90.00 4,959.00 10,745.38 -7,849.67328.50 603,781.075,969,628.604,879.48 0.00 13,305.04 16,800.00 90.00 4,959.00 10,830.64 -7,901.92328.50 603,727.565,969,713.074,879.48 0.00 13,404.84 16,900.00 90.00 4,959.00 10,915.90 -7,954.17328.50 603,674.065,969,797.544,879.48 0.00 13,504.64 17,000.00 90.00 4,959.00 11,001.17 -8,006.42328.50 603,620.555,969,882.014,879.48 0.00 13,604.44 17,100.00 90.00 4,959.00 11,086.43 -8,058.67328.50 603,567.045,969,966.484,879.48 0.00 13,704.24 17,200.00 90.00 4,959.00 11,171.70 -8,110.92328.50 603,513.535,970,050.954,879.48 0.00 13,804.04 17,300.00 90.00 4,959.00 11,256.96 -8,163.17328.50 603,460.035,970,135.424,879.48 0.00 13,903.84 17,400.00 90.00 4,959.00 11,342.22 -8,215.42328.50 603,406.525,970,219.894,879.48 0.00 14,003.64 17,500.00 90.00 4,959.00 11,427.49 -8,267.67328.50 603,353.015,970,304.364,879.48 0.00 14,103.44 17,600.00 90.00 4,959.00 11,512.75 -8,319.92328.50 603,299.505,970,388.834,879.48 0.00 14,203.24 17,700.00 90.00 4,959.00 11,598.02 -8,372.17328.50 603,245.995,970,473.304,879.48 0.00 14,303.04 17,800.00 90.00 4,959.00 11,683.28 -8,424.42328.50 603,192.495,970,557.774,879.48 0.00 14,402.84 17,900.00 90.00 4,959.00 11,768.54 -8,476.67328.50 603,138.985,970,642.244,879.48 0.00 14,502.64 18,000.00 90.00 4,959.00 11,853.81 -8,528.92328.50 603,085.475,970,726.714,879.48 0.00 14,602.44 18,100.00 90.00 4,959.00 11,939.07 -8,581.17328.50 603,031.965,970,811.184,879.48 0.00 14,702.23 18,200.00 90.00 4,959.00 12,024.34 -8,633.42328.50 602,978.465,970,895.654,879.48 0.00 14,802.03 18,300.00 90.00 4,959.00 12,109.60 -8,685.67328.50 602,924.955,970,980.124,879.48 0.00 14,901.83 18,400.00 90.00 4,959.00 12,194.86 -8,737.92328.50 602,871.445,971,064.594,879.48 0.00 15,001.63 18,500.00 90.00 4,959.00 12,280.13 -8,790.17328.50 602,817.935,971,149.064,879.48 0.00 15,101.43 18,600.00 90.00 4,959.00 12,365.39 -8,842.42328.50 602,764.425,971,233.534,879.48 0.00 15,201.23 18,700.00 90.00 4,959.00 12,450.66 -8,894.67328.50 602,710.925,971,318.004,879.48 0.00 15,301.03 18,800.00 90.00 4,959.00 12,535.92 -8,946.92328.50 602,657.415,971,402.474,879.48 0.00 15,400.83 18,900.00 90.00 4,959.00 12,621.18 -8,999.17328.50 602,603.905,971,486.944,879.48 0.00 15,500.63 19,000.00 90.00 4,959.00 12,706.45 -9,051.42328.50 602,550.395,971,571.414,879.48 0.00 15,600.43 19,100.00 90.00 4,959.00 12,791.71 -9,103.67328.50 602,496.895,971,655.884,879.48 0.00 15,700.23 19,200.00 90.00 4,959.00 12,876.98 -9,155.92328.50 602,443.385,971,740.354,879.48 0.00 15,800.03 19,300.00 90.00 4,959.00 12,962.24 -9,208.17328.50 602,389.875,971,824.824,879.48 0.00 15,899.83 19,400.00 90.00 4,959.00 13,047.50 -9,260.42328.50 602,336.365,971,909.294,879.48 0.00 15,999.63 19,500.00 90.00 4,959.00 13,132.77 -9,312.67328.50 602,282.865,971,993.764,879.48 0.00 16,099.43 19,600.00 90.00 4,959.00 13,218.03 -9,364.92328.50 602,229.355,972,078.234,879.48 0.00 16,199.23 19,700.00 90.00 4,959.00 13,303.30 -9,417.17328.50 602,175.845,972,162.704,879.48 0.00 16,299.03 19,800.00 90.00 4,959.00 13,388.56 -9,469.42328.50 602,122.335,972,247.174,879.48 0.00 16,398.83 19,900.00 90.00 4,959.00 13,473.82 -9,521.67328.50 602,068.825,972,331.644,879.48 0.00 16,498.63 20,000.00 90.00 4,959.00 13,559.09 -9,573.92328.50 602,015.325,972,416.114,879.48 0.00 16,598.43 20,100.00 90.00 4,959.00 13,644.35 -9,626.17328.50 601,961.815,972,500.584,879.48 0.00 16,698.23 20,200.00 90.00 4,959.00 13,729.62 -9,678.42328.50 601,908.305,972,585.054,879.48 0.00 16,798.03 20,300.00 90.00 4,959.00 13,814.88 -9,730.67328.50 601,854.795,972,669.524,879.48 0.00 16,897.83 20,400.00 90.00 4,959.00 13,900.14 -9,782.92328.50 601,801.295,972,753.994,879.48 0.00 16,997.63 20,455.99 90.00 4,959.00 13,947.88 -9,812.17328.50 601,771.335,972,801.284,879.48 0.00 17,053.51 Total Depth : 20455.99' MD, 4959' TVD 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Prudhoe Bay W Standard Proposal Report Well: Wellbore: Plan: W-35 Plan: W-35A Survey Calculation Method:Minimum Curvature W-35A planned RKB @ 79.52usft Design:W-35A wp08 Database:Alaska MD Reference:W-35A planned RKB @ 79.52usft North Reference: Well Plan: W-35 True Target Name - hit/miss target -Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Targets Dip Angle (°) Dip Dir. (°) W-35A wp03 tgt03 4,959.00 5,972,801.28 601,771.3213,947.88 -9,812.180.00 0.00 - plan misses target center by 0.01usft at 20455.99usft MD (4959.00 TVD, 13947.88 N, -9812.17 E) - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 7" x 8 1/2"20,455.99 78-1/2 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 20,455.99 4,959.00 13,947.88 -9,812.17 Total Depth : 20455.99' MD, 4959' TVD 6/16/2025 4:50:14PM COMPASS 5000.17 Build 04 Page 8 Clearance SummaryAnticollision Report16 June, 2025Hilcorp North Slope, LLCPrudhoe BayWPlan: W-35Plan: W-35A5002921799W-35A wp08Reference Design: W - Plan: W-35 - Plan: W-35A - W-35A wp08Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 5,959,002.08 N, 611,789.02 E (70° 17' 49.02" N, 149° 05' 41.07" W)Datum Height: W-35A planned RKB @ 79.52usftScan Range: 15,500.00 to 20,455.99 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.17 Build: 04Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 15,500.00 to 20,455.99 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: W - Plan: W-35 - Plan: W-35A - W-35A wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningWPlan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp080.0015,502.78-1.0815,502.780.00315,502.78Clearance FactorFAIL - Plan: W-35 - Plan: W-35A PH1 - W-35A PH1 wp080.2715,525.00-1.5615,525.000.14915,525.00Ellipse SeparationFAIL - W-241 - W-241 - W-24169.7216,679.47-1.7515,610.250.97516,679.47Centre DistanceFAIL - W-241 - W-241 - W-241107.4217,000.00-6.7015,914.900.94117,000.00Clearance FactorFAIL - W-241 - W-241 - W-241113.7017,025.00-6.9615,937.800.94217,025.00Ellipse SeparationFAIL - W-241 - W-241PB1 - W-241PB1 1,373.48 15,500.00 1,292.73 13,046.00 17.01015,500.00Clearance Factor Pass - W-26 - W-26 - W-26 6,431.06 15,500.00 6,345.23 12,030.00 74.93115,500.00Clearance Factor Pass - W-26 - W-26A - W-26A 6,138.12 15,500.00 6,043.83 12,620.00 65.09715,500.00Clearance Factor Pass - W-26 - W-26AL1 - W-26AL1 6,264.48 15,500.00 6,183.92 12,440.14 77.75615,500.00Clearance Factor Pass - W-26 - W-26B - W-26B 920.69 15,500.00 555.34 14,904.63 2.52015,500.00Clearance Factor Pass - W-29 - W-29 - W-29 8,131.55 15,500.00 8,049.27 10,950.00 98.82615,500.00Clearance Factor Pass - W-59 - W-59 - W-59 7,367.93 15,500.00 7,288.11 12,459.00 92.30815,500.00Clearance Factor Pass - ZZ-116 - Z-116 - Z-116 2,128.86 15,600.00 1,956.11 14,559.05 12.32315,600.00Ellipse Separation Pass - Z-116 - Z-116 - Z-116 2,128.34 15,647.03 1,957.52 14,559.05 12.45915,647.03Centre Distance Pass - Z-116 - Z-116 - Z-116 2,466.99 19,200.00 2,194.03 17,641.65 9.03819,200.00Clearance Factor Pass - Z-116 - Z-116PB1 - Z-116PB1 2,868.71 15,500.00 2,673.15 12,831.83 14.66915,500.00Clearance Factor Pass - Z-116 - Z-116PB2 - Z-116PB2 2,051.02 15,500.00 1,902.94 14,356.28 13.85115,500.00Ellipse Separation Pass - Z-116 - Z-116PB2 - Z-116PB2 2,133.14 16,525.00 1,962.59 15,335.00 12.50716,525.00Clearance Factor Pass - Z-220 - Z-220 - Z-220 1,481.40 17,050.00 1,190.58 17,691.00 5.09417,050.00Clearance Factor Pass - Z-220 - Z-220 - Z-220 1,470.63 17,175.00 1,183.82 17,691.00 5.12817,175.00Ellipse Separation Pass - Z-220 - Z-220 - Z-220 1,469.21 17,239.69 1,185.30 17,691.00 5.17517,239.69Centre Distance Pass - Z-221 - Z-221 - Z-221 1,304.71 15,500.00 1,004.38 17,186.00 4.34415,500.00Clearance Factor Pass - Z-221 - Z-221 - Z-221 1,290.45 15,625.00 996.05 17,186.00 4.38315,625.00Ellipse Separation Pass - Z-221 - Z-221 - Z-221 1,287.61 15,710.55 999.07 17,186.00 4.46215,710.55Centre Distance Pass - Z-222 - Z-222 - Z-222 1,419.58 16,950.00 1,105.29 17,618.00 4.51716,950.00Clearance Factor Pass - Z-222 - Z-222 - Z-222 1,403.91 17,100.00 1,096.34 17,618.00 4.56417,100.00Ellipse Separation Pass - 16 June, 2025 - 16:49COMPASSPage 2 of 5 Prudhoe BayHilcorp North Slope, LLCAnticollision Report for Plan: W-35 - W-35A wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 15,500.00 to 20,455.99 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: W - Plan: W-35 - Plan: W-35A - W-35A wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningZ-222 - Z-222 - Z-222 1,402.04 17,172.45 1,099.09 17,618.00 4.62817,172.45Centre Distance Pass - Z-223 - Z-223 - Z-223 1,365.98 15,500.00 1,078.41 16,855.00 4.75015,500.00Clearance Factor Pass - Z-228 - Z-228 - Z-228 1,961.74 15,500.00 1,767.97 13,725.00 10.12415,500.00Clearance Factor Pass - Z-229 - Z-229 - Z-229 2,102.84 15,500.00 1,907.84 13,305.00 10.78415,500.00Clearance Factor Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool88.75 1,830.003_Gyro-SR-GMS1,830.00 2,230.00GYD_Quest GWD2,230.00 8,026.003_MWD+IFR2+MS+Sag8,026.00 15,500.003_MWD+IFR2+MS+Sag15,500.00 20,455.99 W-35A wp08 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.16 June, 2025 - 16:49COMPASSPage 3 of 5 0.001.002.003.004.00Separation Factor15500 15750 16000 16250 16500 16750 17000 17250 17500 17750 18000 18250 18500 18750 19000 19250 19500 19750 20000 20250Measured Depth (500 usft/in)Z-222W-241W-35A PH1 wp08W-26BNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: W-35 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 53.02+N/-S +E/-W Northing Easting Latittude Longitude0.000.005959002.08611789.0270° 17' 49.0154 N149° 5' 41.0699 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: W-35, True NorthVertical (TVD) Reference:W-35A planned RKB @ 79.52usftMeasured Depth Reference:W-35A planned RKB @ 79.52usftCalculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2025-05-12T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool88.75 1830.00 W-35 Srvy 1 BOSS-GYRO (W-35) 3_Gyro-SR-GMS1830.00 2230.00 W-35A PH1 wp08 (Plan: W-35A PH1) GYD_Quest GWD2230.00 8026.00 W-35A PH1 wp08 (Plan: W-35A PH1) 3_MWD+IFR2+MS+Sag8026.00 15500.00 W-35A PH1 wp08 (Plan: W-35A PH1) 3_MWD+IFR2+MS+Sag15500.00 20455.99 W-35A wp08 (Plan: W-35A) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)15500 15750 16000 16250 16500 16750 17000 17250 17500 17750 18000 18250 18500 18750 19000 19250 19500 19750 20000 20250Measured Depth (500 usft/in)W-241NO GLOBAL FILTER: Using user defined selection & filtering criteria15500.00 To 20455.99Project: Prudhoe BaySite: WWell: Plan: W-35Wellbore: Plan: W-35APlan: W-35A wp08CASING DETAILSTVD TVDSS MD Size Name4959.00 4879.48 20455.99 7 7" x 8 1/2" 1 Dewhurst, Andrew D (OGC) From:Joseph Engel <jengel@hilcorp.com> Sent:Thursday, 7 August, 2025 18:21 To:Dewhurst, Andrew D (OGC) Cc:Lau, Jack J (OGC); Joseph Lastufka Subject:RE: [EXTERNAL] PBU W-35A (PTD 225-076): Questions Attachments:AOR for W-35Ai_REV1_08.05.2025.pdf Andy – Below are the answers to your questions for W-35A PTD •Yes, planned OH KOP is 15500’ MD. This will be performed in the OBc sand after tagging the top of the OH P&A kit of W-35A PH1. •Prog top OBC is 7868’ MD, the 8002’ depth was from an older well plan iteration. Apologies for the confusion. •Yes, the PH1 open hole section will be plugged back and not injected in to. The AOR is not applicable to the pilot hole. o As per our previous discussions/emails, PH1 plugging will be include a cemented sacriƱcial liner and inƲatable packer (OH P&A kit) to ensure proper isolation of the sands. •Upon further review of the AOR, geologist and team have updated the AOR to include Z-228 and removed the other wells. Updated AOR Attached. •Prior emails and discussions have addressed the plugging of W-35APH1. Please let me know if you have any more questions. Thank you for your time. -Joe From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, August 4, 2025 6:15 PM To: Joseph Engel <jengel@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: [EXTERNAL] PBU W-35A (PTD 225-076): Questions Joe, Here is the follow up email for W-35A. I am completing my review of the PBU W-35APB1 PTD and have a few questions. •Would you conƱrm the planned KOP is 15,500’ MD? 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. PH1 2 •Would you conƱrm the prognosed top of the OBc? The top is prognosed at 7,868’ MD in W- 35APB1. How does that depth relate to the 8,002’ MD in the W-35A prog? Is this a repeat occurrence? •Would you conƱrm that the portion of the pilot hole that will be plugged back will not be injecting? I just want to conƱrm that the AOR is not applicable to the pilot hole. I have drawn the cartoon below (with API suƯix) with my understanding of the Ʊnal conƱguration. If this is correct, only the W-35A needs the AOR. •On a related note, would you double-check the AOR wells? I am not showing that the PBU Z-223, Z-229, or Z-235 wells are within the 1/4-mile radius. But I am showing that the PBU Z-228 is close. •As we discussed today, I should know more about the proposed abandonment of W-35APB1 tomorrow. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. 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PH1 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 nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PBU W-35A 225-076 PRUDHOE BAY SCHRADER BLUFF OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT W-35AInitial Class/TypeSER / PENDGeoArea890Unit11650On/Off ShoreOnProgramSERWell bore segAnnular DisposalPTD#:2250760Field & Pool:PRUDHOE BAY, SCHRADER BLUF OIL - 640135NA1Permit fee attachedYesADL028263, ADL028262, and ADL0474502Lease number appropriateYes3Unique well name and numberYesPRUDHOE BAY, SCHRADER BLUF OIL - 640135 - governed by CO 505B, 505B.0044Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesAIO 26C14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15All wells within 1/4 mile area of review identified (For service well only)No16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18Conductor string providedYes19Surface casing protects all known USDWsYes20CMT vol adequate to circulate on conductor & surf csgYes21CMT vol adequate to tie-in long string to surf csgYes22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitYes25If a re-drill, has a 10-403 for abandonment been approvedYesW-241 will be shut in during production hole26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYes28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYes5000 psi30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesPBU W Pad has a history of H2S. Ensure detectors are tested and functioning.33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures required.35Permit can be issued w/o hydrogen sulfide measuresYesAnticipating pore pressure of 7.1 ppg EMW. Though there is offset WAG injection.36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate08-Aug-25ApprJJLDate06-Aug-25ApprADDDate04-Aug-25AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 8/8/2025