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Home My WebLink About225-128CAUTION: 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 L-287 (PTD: 225-128) FIT after kick off plug Date:Tuesday, January 6, 2026 3:14:39 PM Attachments:PBU L-287 9.625 FIT.pdf From: Joseph Engel <jengel@hilcorp.com> Sent: Tuesday, January 6, 2026 1:42 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: HAK PBU L-287 (PTD: 225-128) FIT after kick off plug Jack – Attached is the FIT for the 9-5/8” after the PH abandonment and kick off plug. Let me know if you have any questions. Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CASING AND LEAK-OFF FRACTURE TESTS Well Name:PPB W L -287 Date:1/5/2026 Csg Size/Wt/Grade:9.625" 47# L -80 Supervisor:L o tt/Dan i els Csg Setting Depth:2,184 TMD 1894 TVD Mud Weight:9.2 ppg LOT / FIT Press =320 psi LOT / FIT =12.45 ppg Hole Depth =2220 md Fluid Pumped=0.5 Bbls Volume Back =0.25 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here HHere Here HHere ->00 ->00 ->172 ->4 140 ->2 118 ->8 501 ->3 154 ->12 784 ->4 192 ->16 1110 ->5 218 ->20 1460 ->6 246 ->24 1864 ->7 265 ->28 2268 ->8 283 ->32 2672 ->9 298 ->33 2720 ->10 309 -> ->11 324 -> -> -> -> -> Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 324 ->0 2718 ->0.25 268 ->1 2711 ->0.5 259 ->2 2711 ->0.75 256 ->3 2709 ->1 252 ->4 2706 ->2 241 ->5 2704 ->3 231 ->10 2699 ->4 224 ->15 2692 ->5 217 ->20 2689 ->6 212 ->25 2683 ->7 205 ->30 2680 ->8 201 -> ->9 196 -> ->10 192 -> 0 1 2 3 4 5 6 7 8 9 10 11 0 4 8 12 16 20 24 28 32 33 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 010203040Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 324 268259256252241231224217212205201196192 271827112711270927062704 2699 2692 2689 2683 2680 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Schrader Bluff Oil, Orion Development Area, PBU L-287 Hilcorp Alaska, LLC Permit to Drill Number: 225-128 Surface Location: 2300' FSL, 4024' FEL, Sec 34, T12N, R11E, UM, AK Bottomhole Location: 690' FSL, 1808' FEL, Sec 30, T12N, R11E, UM, AK Dear Mr. McLaughlin: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, . Commissioner DATED this 22 nd day of December 2025. Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.11.25 10:25:54 - 09'00' Sean McLaughlin (4311) 225-128 By Grace Christianson at 10:50 am, Nov 25, 2025 * Casing tests & FIT digital data to AOGCC immediately upon performing FIT. J.Lau 12/16/25 SFD * BOPE test to 3000 psi. Annular to 2500 psi. * 24 hour notice to AOGCC to witness MIT-IA to 3500 psi. Well will be used only for injection. Production or pre-production are prohibited without an approved spacing exception. 50-029-23829-01-00 *DNR easement or equivalent required to pass through acreage within the KRU. DSR-11/25/25 * LWD gamma-ray and resistivity data to AOGCC promptly to confirm required location for TOC on 8-1/2" OH by 7" annulus. * *Injection limited to affected area of AIO 26C A.Dewhurst 22DEC25JLC 12/22/2025 12/22/25 12/22/25 24 November 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 L-287 Dear Sir/Madam, Hilcorp North Slope, LLC hereby applies for a Permit to Drill an onshore injector well from the L Pad in Prudhoe Bay, Alaska. L-287 is planned to be a horizontal injector targeting the Schrader Bluff Sands. The approximate spud date is anticipated to be December 21th, 2025, pending rig schedule. The Innovation rig will be used to drill this well. The directional plan is a two-hole section grassroots well, starting out of the pilot hole L-287PH1 surface casing. An 8-1/2 hole will be drilled to the OBd, 7 ran and cemented. A 6-1/8 hole section will be drilled in the OBd sand, and a 4-1/2 cemented liner will be ran, 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 starting out of the pilot hole L-287PH1 surface casing. All we lls in an d ne ar th e AO R all ap pe ar to be ad eq ua tel y iso lat Prudhoe Bay Unit (PBU) L-287 Version 1 11/16/2025 2 Prudhoe Bay L-287 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: Hole Section Hazards ................................................................................................ 16 Attachment 4: LOT / FIT Test Procedure .......................................................................................... 19 Attachment 5: Cement Summary ..................................................................................................... 20 Attachment 6: Prognosed Formation Tops ...................................................................................... 22 Attachment 7: Well Schematic ......................................................................................................... 23 Attachment 8: Formation Evaluation Program ................................................................................ 24 Attachment 9: Wellhead Diagram .................................................................................................... 25 Attachment 10: Management of Change ......................................................................................... 26 Attachment 11: Drill Pipe Specs ....................................................................................................... 27 Attachment 12: Kick Tolerance Calculations .................................................................................... 29 Attachment 13: Directional Plan ...................................................................................................... 31 3 Prudhoe Bay L-287 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 L-287. 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 2300' FSL, 4024' FEL, Sec 34, T12N, R11E, UM, AK NAD 27 Coordinate System X: 582,893.6 Y: 5,978,018.9 Innovation Rig KB Elevation 26.5 above GL Ground Level 47.1 above MSL Location at Top of Productive Interval - L-287 Reference to Government Section Lines 854' FSL, 2429' FEL, Sec 33, T12N, R11E, UM, AK NAD 27 Coordinate System X: 579,227.5 Y: 5,976,531.9 Measured Depth, Rig KB (MD) 6174.8 Total Vertical Depth, Rig KB (TVD) 4,338.8 Total vertical Depth, Subsea (TVDSS) 4,265 Location at Bottom of Productive Interval L-287 Reference to Government Section Lines 690' FSL, 1808' FEL, Sec 30, T12N, R11E, UM, AK NAD 27 Coordinate System X: 569,224.2 Y: 5,981,548.6 Measured Depth, Rig KB (MD) 17,394.4 Total Vertical Depth, Rig KB (TVD) 4,265.2 Total Vertical Depth, Subsea (TVDSS) 4,191.3 4 Prudhoe Bay L-287 (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 L-287 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 & 6-1/8 13-5/8 x 5M Control Technology Inc Annular BOP 13-5/8 x 5M Control Technology Inc Double Gate o Blind ram in bottom cavity Mud cross w/ 3 x 5M side outlets 13-5/8 x 5M Control Technology Single ram 3-1/8 x 5M Choke Line 3-1/8 x 5M Kill line 3-1/8 x 5M Choke manifold 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. 5 Prudhoe Bay L-287 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 Intermediate Hole Pressure Data Maximum anticipated BHP 2,071 psi in the Schrader OBc at 4,426 TVD Maximum surface pressure 1,638 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 12.4 ppg EMW FIT after drilling 20 of new hole outside of 9- 5/8 12.4 provides greater than 25 bbl based on 9.5 ppg MW, 8.46 ppg pore pressure 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 1,877 psi in the Schrader OBd at 4,265 TVD Maximum surface pressure 1,450 psi from the Schrader OBd (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 10.5 ppg EMW FIT after drilling 20 of new hole outside of 7 10.5 ppg provides greater than 25 bbl based on 9.4 ppg MW, 8.46 ppg pore pressure 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 OBd OBc 6 Prudhoe Bay L-287 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 TXP ~6,935 Surface ~6,935 / 4,473 6.125 4-1/2 3.958 12.6# L-80 H563 ~10,605 ~6,685 ~17,390 / 4,265 Tubing 4-1/2 3.958 12.6# L-80 JFEBEAR ~6,685 Surface ~6,685 / 4,451 Please refer to Attachment 5: Cement Summary for further details. 7 Prudhoe Bay L-287 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 this well 8. Drilling Fluid Program 20 AAC 25.005 (c) (8) A drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Intermediate Hole Production Hole Mud Type LSND 3% KCl BaraDril-N Mud Properties: Mud Weight PV YP HPHT Fluid Loss pH MBT 8.8-9.5 ppg 15-30 25-45 < 11.0 8.5-9.0 < 8 8.8 9.5 ppg 15-25 15-30 < 11 9-10 <8 A diagram of drilling fluid system on Innovation is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033 8 Prudhoe Bay L-287 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 L-287 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. 9 Prudhoe Bay L-287 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 L-287PH1 is listed below. Please refer to Attachments for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed Drilling Program Transfer from L-287PH1 PTD to L-287 PTD 1. Tag kick off plug and perform kick off a. After 20 of new hole, cbu and perform FIT t/ 12.4 ppg EMW 2. Drill 8.5 Intermediate hole to TD, called by geo 3. CBU and BROOH 4. LD BHA 5. RU and run 7 Intermediate casing to TD a. Circulate casing every ~2000 MD 6. Cement 7 casing as per cement program 7. Lay down landing joint and RILDS 8. Freeze protect 9-5/8 x 7 annulus 9. LD 5 DP 10. MU 6-1/8 cleanout BHA, TIH to top of 7 shoetrack 11. PT 7 casing to 3500 psi, chart test 12. Drill out 7 shoe track & drill 20 of new hole 13. Pull back into 7 shoe and perform FIT to 10.5 ppg EMW 14. POOH LD cleanout BHA 15. MU 6-1/8 RSS BHA, RIH to bottom 16. Drill 6-1/8 lateral as per geologist to TD 17. CBU and monitor well 18. BROOH to 7 shoe 19. CUB and POOH 20. LD BHA 21. RU and run 4-1/2 liner on 4 DP to TD 22. Set and release running tool, re engage running tool 23. Cement 4-1/2 liner as per plan 24. Set liner top packer, pooh with running tool 25. CBU to remove any cement above the liner to packer 26. RU and PT liner to packer / 7 annulus t. 1500 psi f/ 10 min, charted 27. POOH LD running tool 10 Prudhoe Bay L-287 28. RU E-line and perform CBL of 7 a. TOC Required: 500 MD Above Ugnu 4A, 3,053 MD (TBD based upon logs) b. ~ Liner top, 6,685 MD 29. Run 4-1/2 tubing as per tally 30. Land Hanger, RILDS 31. Install BPV, ND BOPE, NU Tree 32. PT tubing hanger void 500/5000 psi, PT tree to 250/5000psi 33. Spot CI Brine 34. Drop Ball & Rod, set tubing packer 35. 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 36. Bleed Pressure on tubing to 0 psi, spot freeze protect 37. RU jumper to allowed freeze protect to swap 38. RDMO perform CBL of 7 11 Prudhoe Bay L-287 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 OBD production interval at ~85 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 65 degrees is at ~6,000 MD. The X-nipple below the production packer will be set at ~6,100 MD / 4,310 TVD and the production packer will be ~70 MD above the X nipple which puts it at ~6,030 MD / ~4280 TVD. The intermediate casing shoe is planned at ~6,935 MD / ~4,473 TVD which means the planned packer depth is ~900 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. 12 Prudhoe Bay L-287 Attachment 1: Location & GIS Maps 13 Prudhoe Bay L-287 NOTE: A portion of the productive interval lies within a corner of the adjacent KRU. SFD 14 Prudhoe Bay L-287 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 15 Prudhoe Bay L-287 BOPE Configuration for each operation: Drill Intermediate / Run 7 13-5/8 Annular UPR: 2-7/8 x 5-1/2 VBR Blind Rams LPR: 7 Solid Body or 2-7/8 x 5-1/2 VBR Drill Production / Run Lower & Upper comp 13-5/8 Annular UPR: 2-7/8 x 5-1/2 VBR Blind Rams LPR: 2-7/8 x 5-1/2 VBR Innovation Rig Choke Manifold Schematic 16 Prudhoe Bay L-287 Attachment 3: Hole Section Hazards 8-1/2 Intermediate 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. Gas Hydrates/Free Gas Gas hydrates have been seen on PBU L Pad. Be prepared for them. They have been reported between 1800 and 3140 TVD across Prudhoe. MW has been chosen based upon successful trouble free penetrations of offset wells. Be prepared for gas hydrates o Keep mud temperature as cool as possible, Target 60-70*F o Dump and dilute as necessary to maintain temp, utilize cold water on the rig as well as cold premade mud on trucks ready o Drill through hydrate sands and quickly as possible, do not backream. Remember that hydrate gas behaves differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Isolate/dump contaminated fluid to remove hydrates from the system. Cretaceous Over Pressure: L-Pad does not have a history of over-pressure in the cretaceous interval (4500-5300 TVD). However, as a precaution ensure MW is above 9.0. Be prepared while drilling this interval. 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. Keep ECDs at a minimum to reduce risk of losses. 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. Anti-Collision 17 Prudhoe Bay L-287 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. 6-1/8 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. 18 Prudhoe Bay L-287 PBU L Pad has a history of H2S. Ensure detectors are tested and functioning. AOGCC to be notified withing 24 hours if H2S is encountered more than 20 ppm during drilling operations Rig will have fully functional automatic H2S detection equipment meeting the requirements of 20 AAC 25.066 In the event H2S is detected, well work will be suspended and personnel evacuated until a detailed mitigation procured can be developed. L-Pad H2S Data: 19 Prudhoe Bay L-287 Attachment 4: LOT / FIT Test Procedure 20 Prudhoe Bay L-287 Attachment 5: Cement Summary 7 Intermediate Casing Cement OH x CSG 8-1/2 OH x 7 Casing Basis Cement Vol Open hole volume + excess + 120 ft shoe track TOC Cement to 500 MD above Ugnu 4A 3,553 MD (to be confirmed by LWD log) Total Cement Volume Spacer 60 bbls of 11.0 ppg Tuned Spacer Cement Open Hole Excess 40% 15.8ppg Tail: 127.3 bbls, 714.2 ft3, 610.4 sks 1.17 cuft/sk BHST 88 deg F Displacement (6,935120) * .0383bpf = 261 bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 8.5" OH x 7" (6,935 - 3053)' x 0.0226 bpf x 1.4 = 122.8 688.9 7" Shoetrack 120' x 0.0382 bpf = 4.5 25.2 Total Tail 127.3 714.2 610.4 21 Prudhoe Bay L-287 4-1/2 Liner Cement OH x CSG 6-1/8 OH x 4-1/2 Liner Basis Cement Vol Open hole volume + excess TOC ~6935 MD, 7 shoe Total Cement Volume Spacer 60 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess, Single Slurry 15.0ppg: 230 bbls, 1290 ft3, 998.7 sks 1.292 cuft/sk BHST 85 deg F Displacement 6,685 * .0104 (4 DP Capacity) = 69.5 bbl 10,700 * .0152 bpf (4-1/2 Capacity) =162.6 bbl = 232.2 bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 6-1/8" OH x 4-1/2" (17385 - 6935)' x 0.0168 bpf x 1.3 = 228.2 1280.2 4-1/2" shoe track 120' x 0.0152 bpf = 1.8 10.1 Total Tail 230.0 1290.3 998.7 22 Prudhoe Bay L-287 Attachment 6: Prognosed Formation Tops All formations expected to be normally pressured. L Pad Permafrost is ~ 1,732 TVD Reference Plan: BPRF Sand / Silt / ICE Water 1,924 1,732.7 -1659 762 8.46 0.44 SV4 Sand / Silt / ICE Water 1,931 1,737.6 -1664 765 8.46 0.44 Surface Casing 2,200 1,902.0 -1828 837 8.46 0.44 SV3 Sand / Shale Gas Hydrates / Free Gas 2,480 2,085.7 -2012 918 8.46 0.44 SV2 Sand / Shale Gas Hydrates / Free Gas 2,726 2,242.4 -2168 987 8.46 0.44 SV1 Sand / Shale Gas Hydrates / Free Gas 3,151 2,513.3 -2439 1106 8.46 0.44 UG4 Sand / Coals Gas Hydrates / Free Gas 3,497 2,733.6 -2660 1203 8.46 0.44 UG4A Sand / Coals Heavy Oil / Water 3,553 2,769.1 -2695 1218 8.46 0.44 UG4B Sand / Coals Water 3,762 2,902.4 -2828 1277 8.46 0.44 UG3 Sand / Coals Water 4,096 3,114.8 -3041 1370 8.46 0.44 UG3A Sand / Coals Water 4,233 3,201.8 -3128 1409 8.46 0.44 UG2 Sand / Coals Water 4,471 3,353.3 -3279 1475 8.46 0.44 UG1 Sand / Coals Water 4,718 3,510.5 -3436 1545 8.46 0.44 TUZC Sand / Silts Heavy Oil 4,961 3,665.5 -3591 1613 8.46 0.44 MA Sand / Silts Heavy Oil 5,305 3,884.6 -3811 1709 8.46 0.44 MB Sand / Silts Heavy Oil 5,370 3,925.9 -3852 1727 8.46 0.44 MC Sand / Silts Heavy Oil 5,447 3,974.3 -3900 1749 8.46 0.44 NB Sand Oil 5,730 4,139.3 -4065 1940 9.01 0.47 OA Sand Oil 6,013 4,275.8 -4202 2000 9.00 0.47 OBA Sand Oil 6,175 4,338.9 -4265 2030 9.00 0.47 OBC Sand Oil 6,499 4,426.0 -4352 2071 9.00 0.47 OBD Sand Oil 6,939 4,473.5 -4400 1775 7.63 0.40 TD Siltstone Water 17,392 4,265.0 -4191 1877 8.46 0.44 L-287 wp03ANTICIPATED FORMATION TOPS & GEOHAZARDS TOP NAME LITHOLOGY EXPECTED FLUID Est. Pressure MD (FT) TVD (FT) TVDSS (FT)GradientEMW 23 Prudhoe Bay L-287 Attachment 7: Well Schematic 24 Prudhoe Bay L-287 Attachment 8: Formation Evaluation Program 8-1/2 Intermediate LWD Gamma Ray Resistivity 6-1/8 Production LWD Gamma Ray Resistivity Azimuthal Resistivity Mudlogging No mud logging is planned 25 Prudhoe Bay L-287 Attachment 9: Wellhead Diagram 26 Prudhoe Bay L-287 Attachment 10: Management of Change 27 Prudhoe Bay L-287 Attachment 11: Drill Pipe Specs 28 Prudhoe Bay L-287 29 Prudhoe Bay L-287 Attachment 12: Kick Tolerance Calculations 30 Prudhoe Bay L-287 31 Prudhoe Bay L-287 Attachment 13: Directional Plan L-287 wp03: Intermediate / Pilot Hole Section Offset Wells with CF < 1.0: L-287PH1 @ 2252 MD, L-287PH1 will be an plugged back hole section filled with cement, there is no risk Production Section Offset Wells with CF < 1.0: L-287PH1 @ 11,525 MD, L-287PH1 will be an plugged back hole section filled with cement, there is no risk 1 Dewhurst, Andrew D (OGC) From:Michael Schoetz <mschoetz@hilcorp.com> Sent:Monday, 15 December, 2025 14:00 To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Starns, Ted C (OGC); Aaron O'Quinn Subject:RE: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Attachments:2025-12-10_Decision_ADL 422668_.pdf Steve, Attached, please find a copy of DOGs Directors Decision approving of Hilcorps application for wellbore easement. The Entry Authorization is in the process of being fully executed (awaiting only DOGs execution). I would also like to confirm that Hilcorp understands that per 20 AAC 25.005(h) a Permit to Drill is not valid at a location where the applicant does not have a right to drill for oil and gas. It is understood that even with an approved PTD Hilcorp cannot drill the proposed wellbore across the KRU lease without an Entry Authorization in place with DOG. Thank you, Michael W. Schoetz, CPL Hilcorp North Slope, LLC Division Landman Main: (907) 777-8300 Office: (907) 777-8414 Mobile: (281) 685-0902 Email: mschoetz@hilcorp.com 3800 Centerpoint Dr., Suite 1400 | Anchorage, Alaska 99503 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, December 12, 2025 12:49 PM To: Michael Schoetz <mschoetz@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; Aaron O'Quinn <Aaron.Oquinn@hilcorp.com> Subject: RE: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Hello Michael, FYI: The only item for this Permit to Drill Application that I lack to complete my portion of the review is the DNR easement. Thanks for Your Help and Be Well, Steve Davies AOGCC CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain condential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without rst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (OGC) Sent: Wednesday, December 10, 2025 10:23 AM To: 'Michael Schoetz' <mschoetz@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; 'Aaron O'Quinn' <Aaron.Oquinn@hilcorp.com> Subject: RE: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Hello Michael, Any response from DNR regarding the wellbore easement for PBU L-287? Thanks for Your Help and Be Well, Steve Davies Senior Petroleum Geologist AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain condential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without rst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (OGC) Sent: Wednesday, December 3, 2025 9:56 AM To: Michael Schoetz <mschoetz@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; Aaron O'Quinn <Aaron.Oquinn@hilcorp.com> Subject: RE: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Thank you, Michael. I appreciate your help with this. Thanks Again and Be Well, Steve Davies Senior Petroleum Geologist AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain condential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without rst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 From: Michael Schoetz <mschoetz@hilcorp.com> Sent: Wednesday, December 3, 2025 9:21 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; Aaron O'Quinn <Aaron.Oquinn@hilcorp.com> Subject: RE: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Steve, Per our conversation this morning, the subject lease is located in both PBU and KRU and ownership on both sides does differ. That being said: 1. The proposed operations are for an injection well. There will not be any production or pre-production within 500ft of the boundary. In prior discussions with AOGCC it was conveyed that since the well will not be producing a spacing exception would not be required. 2. Hilcorp will be receiving a wellbore easement from DOG granting the authority to lay the wellbore across the portion of the lease within KRU. Hilcorp understands that even with an approved PTD it cannot drill the well across KRU lands without a wellbore easement or other approval from DOG. As discussed, I will provide a copy of the wellbore easement once received from DOG which should be in the next day or so. I will make myself available to discuss further at your convenience. Thank you, Michael W. Schoetz, CPL Hilcorp North Slope, LLC Division Landman Main: (907) 777-8300 Office: (907) 777-8414 Mobile: (281) 685-0902 Email: mschoetz@hilcorp.com 3800 Centerpoint Dr., Suite 1400 | Anchorage, Alaska 99503 From: Jamie Wilson <jamie.wilson@hilcorp.com> Sent: Tuesday, December 2, 2025 7:27 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Michael Schoetz <mschoetz@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: Re: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Steve, Michael Schoetz is our Landman who handles PBU. He will be able to help answer your questions. Thanks, Jamie 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. 4 Get Outlook for iOS From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, December 1, 2025 3:41:35 PM To: Jamie Wilson <jamie.wilson@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL] PBU_L-287 (PTD 225-128) - Question Hello Jamie, I'm reviewing Hilcorp's Permit to Drill Application for Prudhoe Bay Unit (PBU) L-287, and I have a question. Upon review, the land situation appears to be a bit complicated so perhaps you can help me. This planned well will be in leases ADL 28239 and ADL 47449. Part of the productive section will lie in lease ADL 47449, which according to DNR's Land Administration System Case File has the customer's name listed as Hilcorp North Slope, LLC. Lease ADL 47449 comprises four Sections: 29, 30, 31, and 32 of T12N, R11E. According to the Division of Oil and Gas's latest maps for the Kuparuk River Unit (KRU) and PBU, Sections 29, 30, and 32 lie within the PBU, while Section 31 lies within the KRU. As planned, part of the productive interval in PBU L-287 will cross into, and pass through, the northeastern corner of Section 31 within the KRU. Per 20 AAC 25.055(a)(1), a spacing exception is required for oil-related wells that lie within 500' of a property line if the owner or the landowner are not the same on both sides of that property line. The State of Alaska is the landowner for both affected leases ADL 28239 and ADL 47449, so no problem there. My question: Is there a change in owner companies or ownership percentage for Section 31 versus the three Sections located within the PBU? If so, what are the companies and the percentage interest for each company on both sides of that unit boundary line? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 5 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. 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 PRUDHOE BAY UNIT L-287 SCHRADER BLUFF OIL POOL, ORION DEVELOMENT AREA 225-128 WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT L-287Initial Class/TypeSER / PENDGeoArea890Unit11650On/Off ShoreOnProgram SERWell bore segAnnular DisposalPTD#:2251280Field & Pool:PRUDHOE BAY, SCHRADER BLUF OIL - 640135NA1 Permit fee attachedYes Surf Loc & Top Prod Int lie in ADL0028239; TD lies within ADL0047449.2 Lease number appropriateYes3 Unique well name and numberYes4 Well located in a defined poolNo DNR easement or equivalent required. Injection only unless a spacing exception is approved.5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedNo9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes AIO 26C, except for short section that traverses a corner of the KRU.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15 All wells within 1/4 mile area of review identified (For service well only)No Pre-production and production prohibited unwess a spacing exception is approved.16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes 5K30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes Highest H2S on pad L-110 160 ppm.33 Is presence of H2S gas probableYes34 Mechanical condition of wells within AOR verified (For service well only)No H2S measures are required as H2S is present at L-Pad.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure range is 0.396 to 0.468 psi/ft (7.6 to 9.0 ppg EMW). Operator's planned mud program36 Data presented on potential overpressure zonesNA appears sufficient to control anticipated pressures and maintain wellbore stability.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate18-Dec-25ApprJJLDate16-Dec-25ApprSFDDate03-Dec-25AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 12/22/2025