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Home My WebLink About225-142CAUTION: 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. You don't often get email from brad.gorham@hilcorp.com. Learn why this is important From:McLellan, Bryan J (OGC) To:Brad Gorham Cc:Cody Dinger; Rixse, Melvin G (OGC) Subject:RE: NIK O-232 (PTD# 225-142) Follow-Up Question Date:Wednesday, January 28, 2026 3:39:00 PM Attachments:image003.png Hi Brad, This variance request is denied. Almost every casing test in the state will exceed the fracture pressure if the shoe leaks. Additionally, 2500 psi casing test will still exceed the fracture pressure in O-232 if the shoe leaks, so dropping test pressure below the regulatory minimum doesn’t solve that issue. Hilcorp’s Schrader Bluff wells are not unique in this case and Hilcorp should follow the regulations by testing to 50% of casing burst, 2875 psi in the case of 9-5/8” 40# L-80 casing, per 20 AAC 25.030(e). Hilcorp should plan casing tests to be compliant with 20 AAC 25.030(e) in future PTD applications. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brad Gorham <brad.gorham@hilcorp.com> Sent: Tuesday, January 27, 2026 9:51 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com> Subject: NIK O-232 (PTD# 225-142) Follow-Up Question Bryan, I had a question on the O-232 approved PTD. In the permit Hilcorp asked for a variance to reduce the casing pressure test below: However, I did not see any mention of the variance approval within the COA’s or in the verbiage above. I just wanted to confirm if we have approval to test the casing to the lower pressure of 2,500 psi? Thanks, Brad Gorham Drilling Engineer Hilcorp Alaska, LLC Office: 907-263-3917 Cell: 907-250-3209 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 youare 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 strictlyprohibited. 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 andpermanently 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 useof 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 carryout such virus and other checks as it considers appropriate. 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: Nikaitchuq Field, Schrader Bluff Oil Pool, NIK O-232 Hilcorp Alaska, LLC Permit to Drill Number: 225-142 Surface Location: 3097' FSL, 1757' FEL, Sec 5, T13N, R9E, UM, AK Bottomhole Location: 1312' FNL, 706' FWL, Sec 20, T14N, R9E, UM, AK Dear Mr. McLaughlin: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this 23rd day of January 2026. 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 19,791' TVD: 3,904' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 46.8' 15. Distance to Nearest Well Open Surface: x-516518 y- 6036450 Zone-4 13.1' to Same Pool: 893' to OPI-02 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 129.5# X-52 Weld 80' Surface Surface 80' 80' 9-5/8" 47# L-80 TXP 2,500' Surface Surface 2,500' 2,039' 9-5/8" 40# L-80 Wdg 521 3,592' 2,500' 2,039' 6,092' 3,456' 5-1/2" 17# L-80 JFE BEAR 4,529' 5,942' 3,443' 10,471' 3,591' 4-1/2" 13.5# L-80 Wdg 625 9,500' 10,471' 3,591' 19,971' 3,904' Tbg 3-1/2" 9.2# CR 13-80 JFE BEAR 5,942' Surface Surface 5,942' 3,443 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number: Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4974 Cement Volume MD Brad Gorham brad.gorham@hilcorp.com Effect. Depth MD (ft): 907-263-3917 Uncemented Screens Liner Tubing / ESP Effect. Depth TVD (ft): Drilling Manager Sean Mclaughlin 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft):Perforation Depth MD (ft): Conductor/Structural Authorized Title: Authorized Signature: Authorized Name: Production Liner Intermediate Specifications 1718 GL / BF Elevation above MSL (ft): Plugs (measured): (including stage data) 16 yds concrete Total Depth TVD (ft): 1327 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 18. Casing Program: Top - Setting Depth - Bottom Nikatichuq O-232 Nikaitchuq Unit Schrader Bluff Oil Pool (N Sands) Cement Quantity, c.f. or sacks 1/21/2026 657' to nearest unit boundary 657' FSL, 575' FWL, Sec 32, T14N, R9E, UM, AK 1312' FNL, 706' FWL, Sec 20, T14N, R9E, UM, AK LONS 05-007 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC 3097' FSL, 1757' FEL, Sec 5, T13N, R9E, UM, AK ADL355024, ADL 390616, ADL 388583 Commission Use Only See cover letter for other requirements. Brad Gorham for Sean Mclaughlin 12-1/4" 8-1/2"Uncemented Screens Liner Stg 1 L - 1054 ft3 / T - 458 ft3 Stg 2 L - 1615 ft3 / T - 313 ft3 Total Depth MD (ft): LengthCasing Size s N ype of W L l R L 1b S Class: os N s No s N o Dr s s sDr 84 o : well is p G S S 2 S S S s Nos No S G y E S s No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Digitally signed by Brad Gorham (14309) DN: cn=Brad Gorham (14309) Date: 2025.12.23 10:30:17 - 09'00' Brad Gorham (14309) By Grace Christianson at 10:40 am, Dec 23, 2025 MGR21JAN2026 TS 12/31/25 225-142 * See following page for conditions of approval. 19,971' DSR-12/29/25 50-029-23832-00-00 01/23/26 01/23/26 Conditions if Approval PTD 225-142 Nikaitchuq O-232 1. AOGCC inspection of diverter layout and diverter function test. 24-hour notice to AOGCC. a. Not approved for 45° bends in diverter line. b. Clearly marked warning zone on each side and ahead of the vent line tip c. Prohibition on vehicle parking d. Restriction of tra ic to essential foot or vehicle tra ic only 2. AOGCC to witness BOPE test to 3000 psi. Annular to 2500 psi. 24-hour notice to AOGCC. 3. Changes to casing described on form 10-401, including: weight, diameters, drifts or connections to be communicated and approved by AOGCC. 4. All planned casings strings to be utilized in well construction to include engineering modeling for worst case tension, worst case collapse, worst case burst. 5. A 10-407 initial well completion report to be returned to AOGCC 30 days from rig release. 6. 9-5/8 surface/production casing to be drifted to casing speci cations drift ID. 7. Tuned spacers for cement to be of su icient density to always assure well bore pressure to remain above pore pressure. 8. Safety joint with FOSV to be on the rig oor with crossover to casing and slotted liner while performing casing running operations. 9. Email casing test and FIT digital data to AOGCC. If questionable uid volume returned from formation upon bleed back, do not proceed until noti cation AOGCC for intervention plans. 10. Shoe track length is de ned as: length of casing from casing shoe to landing collar that will be left lled with cement after primary surface/production casing cementing operations. For shoe track length calculations identi ed in this permit: ~120, or 3 full joints of casing. Western North Slope NK O-232 Final 12/22/2025 Oliktok Point O-232 SB NB Producer Table of Contents Oliktok Point O-232 SB NB Producer Reference to Government Section Lines 3097' FSL, 1757' FEL, Sec 5, T13N, R9E, UM, AK NAD 27 Coordinate System X= 516519 Y= 6036450 Doyon 14 Rig KB Elevation 33.7 above GL Ground Level 13.1 ft Reference to Government Section Lines 657' FSL, 575' FWL, Sec 32, T14N, R9E, UM, AK NAD 27 Coordinate System X= 513560 Y= 6039282 Measured Depth, Rig KB (MD)6,091 Total Vertical Depth, Rig KB (TVD)3,456 Total vertical Depth, Subsea (TVDSS)3,409 Reference to Government Section Lines 1312' FNL, 706' FWL, Sec 20, T14N, R9E, UM, AK NAD 27 Coordinate System X= 513618 Y= 6053152 Measured Depth, Rig KB (MD)19,971 Total Vertical Depth, Rig KB (TVD)3,903 Total Vertical Depth, Subsea (TVDSS)3,857 Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer 8.681" Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer All fluids statically overbalance to pore pressure. - mgr /Production Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Attachment 2: Doyon 14 Diverter and BOPE Schematics Oliktok Point O-232 SB NB Producer 20 AAC 25.035. Secondary well control -Diverter (c)(3) a clearly marked "warning zone" must be established on each side and ahead of the vent line tip, and the following restrictions must be in effect within the warning zone, beginning with the function test of the diverter system immediately before drilling operations begin and ending with diverter system rig-down: (A) a prohibition on vehicle parking; (B) a prohibition on ignition sources or running equipment; (C) a prohibition on staged equipment or materials; (D) the restriction of traffic to essential foot or vehicle traffic only; (4) the commission will, in its discretion, inspect the diverter system for compliance with the requirements of this subsection and require the operator to test the system to ensure proper operation. Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok PointO-232 SB NB Producer Oliktok Point O-232 SB NB Producer Be prepared for gas hydrates. Keep mud temperature as cool as possible, Target 60-70°F, use lake water Dump and dilute as necessary to maintain temp, utilize cold water on the rig as well as cold premade mud on trucks ready Drill through hydrate sands and quickly as possible, do not backream. Oliktok Point O-232 SB NB Producer 3 abandoned wells fail Hilcorp/Halliburton anticollision rules. - No HSE risk. - mgr Oliktok Point O-232 SB NB Producer Date Facility Sample Location Temp, F H2S ppm Note 5/3/2024 OPP OPP Well 74.6 0.1 OP12-01 5/4/2024 OPP OPP Well 74.1 0.1 OP16-03 5/4/2024 OPP OPP Well 69.0 0.1 OP17-02 5/4/2024 OPP OPP Well 73.3 0.3 OP14-S3 5/4/2024 OPP OPP Well 74.2 0.1 OP03-05 5/4/2024 OPP OPP Well 79.9 0.3 OP04-07 5/4/2024 OPP OPP Well 80.1 0.1 OP08-04 5/5/2024 OPP OPP Well 68.5 0.0 OP05-06 5/6/2024 OPP OPP Well 69.5 0.1 OP10-09 Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer ANTICIPATED FORMATION TOPS & GEOHAZARDS O-232 wp-06 TOP NAME LITHOLOGY EXPECTED FLUID MD (FT) TVDSS (FT) TVD (FT)Est. ML PP (psi)ML PP (ppg) SV4 (Sand)Water 1343 1264 1311 579 SV1 (Sand)Water 1839 1648 1695 749 BPRF (Sand)Water 1940 1711 1758 777 UG4 Ugnu (Sand)Water 2316 1904 1951 862 UG COAL2 COAL Water 3388 2416 2462 1088 UG LA3 Ugnu (Sand)Water 3989 2703 2749 1215 UG MB Ugnu (Sand)Water 4726 3053 3099 1370 UG MF Ugnu (Sand)Water 5343 3287 3334 1473 SB NA Schrader (Sand)Water 5664 3362 3409 1507 SB NB Schrader (Sand)Oil 5975 3400 3446 1523 8.50 9 5/8" shoe Schrader (Sand)Oil 6092 3410 3456 1528 8.50 Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer Oliktok Point O-232 SB NB Producer / Pro duct ion - mgr /Production 1 McLellan, Bryan J (OGC) From:Brad Gorham <brad.gorham@hilcorp.com> Sent:Friday, January 23, 2026 12:46 PM To:McLellan, Bryan J (OGC) Cc:Joseph Engel; Cody Dinger Subject:RE: [EXTERNAL] RE: NIK O-232 PTD (#225-142) Bryan, I have called twice in an e ort to reach you to discuss your ques on below. Your ques on is ambiguous and thus I am unsure of exactly what you are looking for. As stated in previous email, the speci c casing design factors for O-232 exceed the Hilcorp minimum design factors. These are calculated based upon the well speci c parameters already included in the PTD (casing weight/grade, formation pressure, MASP, MW, Cement weight, directional pro le, etc) In casing design, calculated design factors are based upon the load case (well opera on or condi on) that simulates the most severe condi ons the casing may encounter related to collapse, burst, and tension. The minimum design factors are safety margins that ensure the casing strength exceeds expected loads, accoun ng for uncertain es in manufacturing and design es ma on. The minimum design factor for collapse, assumes that you have evacuated surface casing for your internal pro le with wet cement for your external pro le. For burst, you are assuming that you have a column of gas to surface (MASP) for your internal pro le and have forma on gradient for your external pro le. Tension assumes the non-buoyed weight of the pipe as you run it in the hole. The calcula on assumes the well is ver cal, which these are not, and thus is a very conserva ve load case. These are standard industry well operations and conditions, and all formations for O-232 are normally pressured. To process this permit to drill, the speci c design factors for 0-232 are below and far exceed Hilcorp minimums. Thanks, You don't often get email from brad.gorham@hilcorp.com.Learn why this is important 2 Brad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, January 22, 2026 5:14 PM To: Brad Gorham <brad.gorham@hilcorp.com> Subject: [EXTERNAL] RE: NIK O-232 PTD (#225-142) Brad, What are the load cases for these minimum design factors? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brad Gorham <brad.gorham@hilcorp.com> Sent: Thursday, January 22, 2026 4:02 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: NIK O-232 PTD (#225-142) Bryan, Thanks for the phone call earlier, sounds like a formal response is forthcoming to the RFI. In an e ort to progress the O-232 and O-234A PTDs Hilcorps minimum casing design safety factors to support safe well construc on and delivery are outlined below: Hilcorp General Casing Design Safety Factors: Tension: 1.2 Collapse: 1.1 Burst: 1.1 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. You don't often get email from brad.gorham@hilcorp.com. Learn why this is important 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. 3 The design safety factors for both O-232 and O-234A exceed the minimum values listed above. Please let me know if this is su cient or if further discussion is needed. Appreciate your me, Thanks, Brad Gorham Drilling Engineer Hilcorp Alaska, LLC O ce: 907-263-3917 Cell: 907-250-3209 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. 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. SCHRADER BLUFF OIL 225-142 NIKAITCHUQ O-232 NIKAITCHUQ WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:NIKAITCHUQ 0-232Initial Class/TypeDEV / PENDGeoArea890Unit11400On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2251420Field & Pool:NIKAITCHUQ, SCHRADER BLUFF OIL - 561100NA1 Permit fee attachedYes ADL355024, ADL390616, ADL3885832 Lease number appropriateYes3 Unique well name and numberYes NIKAITCHUQ, SCHRADER BLUFF OIL - 561100 - governed by CO 477B4 Well located in a defined poolYes5 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 includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)No16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)No17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 20" 129.5# X-52 driven to 80' from pad level18 Conductor string providedYes Surface/Production casing from surface to SB reservoir19 Surface casing protects all known USDWsYes Surface/Production casing fully cemented from reservoir to surface 2 stage20 CMT vol adequate to circulate on conductor & surf csgYes Surface/Production casing fully cemented from reservoir to surface 2 stage21 CMT vol adequate to tie-in long string to surf csgYes Surface/Production casing fully cemented from reservoir to surface 2 stages - Screens in SB reservoir22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes Doyon 14 has adequate tankage and good trucking support24 Adequate tankage or reserve pitNA This is a grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scans identifies 3 abandoned well bores - no HSE risk26 Adequate wellbore separation proposedYes 16" diverter27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes 1 annular, 3 ram stack tested to 3000 psi.29 BOPEs, do they meet regulationYes 13-5/8" , 5000 psi stack tested to 3000 psi.30 BOPE press rating appropriate; test to (put psig in comments)No Doyon 14 has 3-1/16" Remote Choke, 3-1/8" Manual Choke, 14 3-1/8" 5M manual gate valves.31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo No H2S events at Nikaitchuq. Monitoring will be utilized.33 Is presence of H2S gas probableNA This is a producer.34 Mechanical condition of wells within AOR verified (For service well only)Yes35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure is 0.442 psi/ft (8.5 ppg EMW)36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprTCSDate12/30/2025ApprMGRDate1/2/2026ApprTCSDate12/30/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 1/23/2026