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HomeMy WebLinkAbout226-008CAUTION: 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:Dewhurst, Andrew D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NIK O-230 As Built (PTD 226-008) Date:Monday, February 2, 2026 10:42:32 AM Attachments:FRB25 OPP 02-00 Conductors As-Built-AS-BUILT O-230_Signed.pdf Sam, I recommend filing this email and the attachment in the well file. Andy From: Cody Dinger <cdinger@hilcorp.com> Sent: Monday, 2 February, 2026 10:39 To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Cc: Brad Gorham <Brad.Gorham@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Subject: NIK O-230 As Built Hello All, Attached is the as built surface plat for NIK O-230 (slot 32) for your records, no change to the permitted SHL. We are close to having these all surveyed in, so my hope is that near future permit to drill submittals include these and we go without these emails. Thank you! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Cody Dinger Sent: Friday, January 9, 2026 1:19 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; 'Dewhurst, Andrew D (OGC)' <andrew.dewhurst@alaska.gov>; 'Guhl, Meredith D (OGC)' <meredith.guhl@alaska.gov> Cc: Brad Gorham <Brad.Gorham@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Subject: NIK O-232 As Built Hello All, Attached is the as built surface plat for NIK O-232 (slot 30) for your records, slight 1’change from the east line to the permitted SHL. Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Cody Dinger Sent: Friday, January 2, 2026 8:18 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Cc: Brad Gorham <Brad.Gorham@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Subject: NIK O-233 As Built Hello All, Attached is the as built surface plat for NIK O-233 (slot 37) for your records, no change to the permitted SHL. Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Hilcorp Alaska Jan. 28, 2026 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-230 Hilcorp Alaska, LLC Permit to Drill Number: 226-008 Surface Location: 3086' FSL, 1779' FEL, Sec 5, T13N, R9E, UM, AK Bottomhole Location: 1295' FNL, 394' FEL, Sec 19, 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, . Commissioner DATED this 11 th day of February 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: 21,135' TVD: 3,871' 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-516497 y- 6036438 Zone-4 13.1' to Same Pool: 154' to OPI-02 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.5 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 129.5# X-52 Weld 160' Surface Surface 160' 160' 9-5/8" 47# L-80 TXP 2,500' Surface Surface 2,500' 2,093' 9-5/8" 40# L-80 Wdg 521 4,700' 2,500' 2,093' 7,200' 3,417' 5-1/2" 17# L-80 JFE BEAR 4,585' 7,050' 3,407' 11,635' 3,543' 4-1/2" 13.5# L-80 Wdg 625 9,500' 11,635' 3,543 21,135' 3,871' Tbg 3-1/2" 9.2# CR 13-80 JFE BEAR 7,050' Surface Surface 7,050' 3,407' 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 Brad Gorham for Sean Mclaughlin 12-1/4" 8-1/2"Uncemented Screens Liner Stg 1 L - 1505 ft3 / T - 458 ft3 Stg 2 L - 1615 ft3 / T - 313 ft3 Total Depth MD (ft): LengthCasing Size Commission Use Only See cover letter for other requirements. 18. Casing Program: Top - Setting Depth - Bottom Nikatichuq O-230 Nikaitchuq Unit Schrader Bluff Oil Pool (N Sands) Cement Quantity, c.f. or sacks 2/16/2026 620' to nearest unit boundary 620' FSL, 549' FEL, Sec 31, T14N, R9E, UM, AK 1295' FNL, 394' FEL, Sec 19, T14N, R9E, UM, AK LONS 05-007 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC 3086' FSL, 1779' FEL, Sec 5, T13N, R9E, UM, AK ADL355024, ADL 391283 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Specifications 1683 GL / BF Elevation above MSL (ft): Plugs (measured): (including stage data) 16 yds concrete Total Depth TVD (ft): 1300 Conductor/Structural Authorized Title: Authorized Signature: Authorized Name: Production Liner Intermediate 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): 907-263-3917 Uncemented Screens Liner Tubing / ESP Effect. Depth TVD (ft): 5580 Cement Volume MD Brad Gorham brad.gorham@hilcorp.com Effect. Depth MD (ft): 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) 226-008 By Grace Christianson at 2:37 pm, Jan 23, 2026 50-029-23834-00-00 Shut in OP 17-02 during close approach passby or submit adjusted directional survey and anti-colision scan to AOGCC and obtain approval before drilling by the close approach. Submit FIT/LOT data within 48 hrs of performing test. BOP test to 3000 psi. Annular test to 2500 psi. DSR-2/2/26SFD 1/28/2026BJM 2/10/26 Digitally signed by Brad Gorham (14309) DN: cn=Brad Gorham (14309) Date: 2026.01.23 13:34:46 - 09'00' Brad Gorham (14309) JLC 2/11/2026 02/11/26 02/11/26 Western North Slope NIK O-230 Final 1/23/2026 Oliktok Point O-230 SB NB Producer Table of Contents 1. Well Name......................................................................................................................................3 2. Location Summary..........................................................................................................................3 3. Blowout Prevention Equipment Information.................................................................................4 4. Drilling Hazards Information...........................................................................................................5 5. Procedure for Conducting Formation Integrity Tests.....................................................................6 6. Casing and Cementing Program.....................................................................................................6 7. Diverter System Information..........................................................................................................7 8. Drilling Fluid Program.....................................................................................................................7 9. Abnormally Pressured Formation Information ..............................................................................8 10. Seismic Analysis............................................................................................................................8 11. Seabed Condition Analysis............................................................................................................8 12. Evidence of Bonding.....................................................................................................................8 13. Proposed Drilling Program ...........................................................................................................9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal................................................11 15. Proposed Variance Request........................................................................................................11 Attachment 1: Location & GIS Maps................................................................................................12 Attachment 2: Doyon 14 BOPE Schematic.......................................................................................14 Attachment 3: Doyon 14 Choke Manifold Schematic......................................................................18 Attachment 4: Hole Section Hazards................................................................................................19 Attachment 5: LOT / FIT Test Procedure..........................................................................................22 Attachment 6: Cement Summary.....................................................................................................23 Attachment 7: Prognosed Formation Tops......................................................................................24 Attachment 8: Wellbore Schematic .................................................................................................25 Attachment 9: Formation Evaluation Program................................................................................26 Attachment 10: Wellhead Diagram..................................................................................................27 Attachment 11: Management of Change.........................................................................................28 Attachment 12: Drill Pipe Specs.......................................................................................................29 Attachment 13: Kick Tolerance Calculations....................................................................................30 Attachment 14: Directional Plan......................................................................................................31 Oliktok Point O-230 SB NB Producer As per 20 AAC 25.005 (c), an application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. 1. Well Name 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as O-230. 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 gvernmental 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 3086' FSL, 1789' FEL, Sec 5, T13N, R9E, UM, AK NAD 27 Coordinate System X= 516497 Y= 6036438 Doyon 14 Rig KB Elevation 33.7’ above GL Ground Level 13.1 ft Location at Top of Productive Interval Reference to Government Section Lines 620' FSL, 549' FEL, Sec 31, T14N, R9E, UM, AK NAD 27 Coordinate System X= 512437 Y= 6039243 Measured Depth, Rig KB (MD)7,200’ Total Vertical Depth, Rig KB (TVD)3,417’ Total vertical Depth, Subsea (TVDSS)3,370’ Location at Bottom of Productive Interval Reference to Government Section Lines 1295' FNL, 394' FEL, Sec 19, T14N, R9E, UM, AK NAD 27 Coordinate System X= 512518 Y= 6053167 Measured Depth, Rig KB (MD)21,135’ Total Vertical Depth, Rig KB (TVD)3,870’ Total Vertical Depth, Subsea (TVDSS)3,824’ 1779' FEL SFD Oliktok Point O-230 SB NB Producer (D) other information required by 20 AAC 25.050(b); 20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must: (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 1: Location Maps, Attachment 6: Formation Tops and Attachment 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 O-230 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 Doyon 14 BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 8-1/2” 13-5/8” x 5M Shaffer Annular BOP 13-5/8” x 5M Hydril Double Gate Blind ram in bottom cavity Mud cross w/ 3” x 5M side outlets 13-5/8” x 5M Hydril 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: NL Shaffer 6 station, 3,000 psi, 180 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. Oliktok Point O-230 SB NB Producer 4. Drilling Hazards Information 20 AAC 25.005 (c) (4) Information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure; 8.5” Production Hole Pressure Data Maximum anticipated BHP 1,683 psi in the Schrader NB Sand at 3,824’ TVD Maximum surface pressure 1,300 psi from the Schrader NB Sand (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 – 8.5” hole 12.0 ppg EMW FIT after drilling 20’ of new hole outside of 9- 5/8” 10.0 ppg FIT provides greater than 25 bbl based on 9.5 ppg MW, 8.5 ppg pore pressure 10.0 ppg minimum to drill ahead, 12.0 EMW for drilling ECDs 9.625” Casing Test 2,500 psi, chart for 30 min (See Variance requests) (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 Test to 2875 psi (50% of casing burst rating) -bjm Oliktok Point O-230 SB NB Producer 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (c) (5) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment: 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 12.25” 9.625” 8.525”47 L-80 TXP 2,500’Surface 2,500’ 9.625” 8.835”40 L-80 W521 3,592’ 2,500’ 7,200’ 8.5” 5.5” Screens 4.892 17.0 L-80 EZGO HT /JFE Bear 4,585’ 7,050’ 11,635’ 4.5” Screens 3.920 13.5 L-80 W625 9,500’ 11,635’ 21,135’ Tubing 3.5”2.992”9.2 13Cr80 JFE Bear 7,050’Surface 7,050’ Please refer to Attachment 5: Cement Summary for further details. Hole Section OD (in)ID (in)Drift (in) Conn OD (in) Wt (#/ft) Grade Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.25”- - - X-52 12-1/4”9-5/8” 8.681” 8.525” 10.625”47 L-80 6,870 4,750 1,086 9-5/8”8.835”8.679”10.625”40 L-80 5,750 3,090 916 8-1/2”5-1/2” 4.78” 4.78” 6.25”20 L-80 9,190 8,830 466 4-1/2” 3.960” 3.795” 4.714”13.5 L-80 9020 8540 279 Tubing 3-1/2” 2.992” 2.867” 4.500”9.3 L-80 9289 7399 163 Casing design factors for burst, collapse and tension from Brad Gathman email 2/10/26. -bjm Oliktok Point O-230 SB NB Producer 7. Diverter System Information 20 AAC 25.005 (c) (7) A diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Hole Section Equipment Test Pressure (psi) 12.25”21.25” 2M Hydril w/ 16” knife gate & diverter line Function Test Only 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 Surface Hole Production Hole Mud Type Spud Mud / LSND 3% KCl / Polymer Mud Properties: Mud Weight PV YP Fluid Loss pH MBT Temp 8.8 – 9.8 20 – 40 25 - 45 < 10 8.5 – 9.0 Visc: 75 – 175 < 70* 9.0 – 10.0 ppg 15-25 15-30 < 10 HPHT 8.5-9.0 <8 A diagram of drilling fluid system on Doyon 14 is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033 Oliktok Point O-230 SB NB Producer 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) (9) For an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A – Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis 20 AAC 25.005 (c) (10) For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A – Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis 20 AAC 25.005 (c) (11) For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); O-230 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. Hilcorp Alaska, LLC SFD Oliktok Point O-230 SB NB Producer 13. Proposed Drilling Program 20 AAC 25.005 (c) (13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to O-230 is listed below. Please refer to Attachments for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed Drilling Program O-230 1. MIRU Doyon 14 2. Install riser connection & test void to 1,000 psi for 15 minutes 3. NU Diverter & function test a. 24 hr notice to AOGCC for opportunity to witness 4. MU 12-1/4” Motor BHA and Drill Surface Hole to section TD, into Schrader Bluff NB Sand 5. CBU, BROOH 6. LD BHA 7. RU and RIH with 9-5/8” Surface Casing to TD, land hanger into landing ring 8. Perform 2-stage 9-5/8” Casing cement job per program while picked up off landing ring & oscillating 9. LD Landing joint, jet stack & install packoff per Vault spec, test to 3,800 psi for 15 minutes 10. ND Diverter, install wellhead and drilling adapter 11. NU BOPE & Test a. 24 hr notice to AOGCC for opportunity to witness b. BOPE tested to 3000 psi / Annular tested to 2500 psi 12. Pull test plug & install wear bushing 13. MU 8-1/2” cleanout assembly, TIH and drill through stage tool 14. POOH, LD cleanout BHA 15. PT 9-5/8” casing to 50% of casing burst pressure, 2500 psi, chart test a. See variance request for casing test pressure 16. MU 8-1/2” RSS BHA, RIH to bottom a. Install MPD RCD to be used to monitor wellbore conditions during connections 17. Drill out 9-5/8” shoe track & 20’ of new hole, circulate & condition mud 18. Pull back into 9-5/8” shoe, perform FIT t/ 12.0 ppg EMW a. Email casing test and FIT data to AOGCC 19. Drill 8-1/2” intermediate hole to section TD, in the SB NB 20. Perform clean up cycles w/SAPP sweeps, displace w/viscosifed brine, and BROOH 21. LD BHA, RU casing equipment 22. Run 5.5”x4.5” screen liner on 5” DP to TD a. Safety joints to be on rig floor while performing liner run operations Oliktok Point O-230 SB NB Producer 23. Set liner packer/hanger & perform release sequence 24. Test liner top to 1,500 psi for 10 minutes 25. POOH & LD running tool 26. Pull wear bushing 27. Run 3.5” upper completion as per tally 28. Reverse circulate corrosion inhibited brine & freeze protect 29. Land hanger. Land hanger. RILDs and test hanger. 30. MIT-IA to 1500 psi and test for 30 charted minutes. 31. Install BPV, ND BOPE. NU adapter flange. 32. Install TH adapter & test connection to 5,000 psi 33. Install TH, pull BPV & set TWC 34. Test tree to 5,000 psi 35. Pull TWC & set BPV, bullhead freeze protect 36. Secure tree, cellar, wellhouse 37. RDMO Post Rig Work 1. Tie into facility Note: This well will not be fracture stimulated. Oliktok Point O-230 SB NB Producer 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) (14) A general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. All cuttings and mud generated during drilling operations will be disposed of onsite at Oliktok Point or at MPU G&I. 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 request a variance to 20 AAC 25.030 (e) which states: A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show a stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1). Hilcorp is requesting to test the 9-5/8” casing to 2500 psi instead of the 2875 psi (50% of burst of 9-5/8” 40# casing). The selected lower test pressure of 2,500 psi is based on the need to avoid exceeding the most likely fracture gradient at the casing shoe (0.65 psi/ft) should the shoe leak or prove incompetent. This conservative limit ensures wellbore integrity while maintaining a margin of safety, as 2,500 psi remains significantly above the Maximum Anticipated Surface Pressure (MASP). The approach has been consistently applied and approved on wells drilled by Hilcorp in the Milne Point and Prudhoe Bay fields since at least 2015.Variance request is denied. Pressure test to 50% of burst rating per statewide regulations. -bjm Oliktok Point O-230 SB NB Producer Attachment 1: Location & GIS Maps Oliktok Point O-230 SB NB Producer Oliktok Point O-230 SB NB Producer Attachment 2: Doyon 14 BOPE Schematic Doyon 14 Diverter Schematic: Oliktok Point O-230 SB NB Producer O-230 Diverter Line Layout: Oliktok Point O-230 SB NB Producer Doyon 14 BOPE Schematic: Per 20 AAC 25.035(e)1.A Oliktok Point O-230 SB NB Producer 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 BOPE Configuration for each operation: Drill Production / Run 5.5” x 4.5” Liner & 3.5” Completion: 13-5/8” Annular UPR: 2-7/8” x 5” VBR Blind Rams LPR: 2-7/8” x 5” VBR Oliktok Point O-230 SB NB Producer Attachment 3: Doyon 14 Choke Manifold Schematic Oliktok Point O-230 SB NB Producer Attachment 4: Hole Section Hazards 12.25” Hole Section Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates/Free Gas Gas hydrates have been seen on Oliktok Point. Be prepared for them. They have been reported near the base of the permafrost. MW has been chosen based upon successful trouble-free penetrations of offset wells. 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. 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: Oliktok Point does not have a history of over-pressure to the SB NB sand. However, as a precaution to ensure MW is above 9.0. Be prepared while drilling this interval. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPM’s when CBU and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill ability to clean the hole. Anti-Collison: Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. OP17-02 and OP17-02PB1 are close approaches. The well will either be shut-in or the directional plan will be slightly modified prior to execution to get the CF above a 1.0. Wellbore stability (Permafrost, running sands and gravel) Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring The well will either be shut-in or the directional plan will be slightly modified prior to execution to get the CF above a 1.0. Oliktok Point does not have a history of over-pressure to the SB NB sand. Oliktok Point O-230 SB NB Producer the pumps on slowly after connections. Maintain mud parameters and increase MW to combat running sands and gravel formations. Stuck pipe, wood chunks over shakers and other hole stability issues. 8.5” Hole Section Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps and test effect of weighted high vis 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 or slower ROP 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. Casing Running Casing running issues have been noted on OPP, gravels, stability wood chunks, etc. Watch casing run, and ensure to condition hole prior to running casing, ex: backream trouble intervals. Gas Cut Mud Gas cut mud has been seen at OPP, ensure sufficient MW is used during hole section. Ensure gas detectors are always functioning. Watch swab effect. Anti-Collison: Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. OP19-T1N is P&A’d across the potential intersection depth. The risk of a collision is purely financial. H2S: Oliktok has no 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. Oliktok Point O-230 SB NB Producer Wells with over 100ppm H2S readings on Oliktok Point: There are no wells at OPP with H2S 100ppm or greater. Oliktok Point O-230 SB NB Producer Attachment 5: LOT / FIT Test Procedure Oliktok Point O-230 SB NB Producer Attachment 6: Cement Summary Both stages of the cement job will be displaced with surface hole mud with a density ranging from 8.8-9.8 ppg. Verified cement calcs. -bjm Oliktok Point O-230 SB NB Producer Attachment 7: Prognosed Formation Tops All formations expected to be normally pressured. ANTICIPATED FORMATION TOPS & GEOHAZARDS O-230 wp-04 TOP NAME LITHOLOGY EXPECTED FLUID MD (FT) TVDSS (FT) TVD (FT)Est. ML PP (psi)ML PP (ppg) Oliktok Point O-230 SB NB Producer Attachment 8: Wellbore Schematic Upper completion jewelry not accurately numbered. -bjm Oliktok Point O-230 SB NB Producer Attachment 9: Formation Evaluation Program 12.25” Surface Hole LWD Gamma Ray Resistivity 8.5” Production Hole LWD Gamma Ray Resistivity Azimuthal Resistivity Mudlogging No mudlogging is planned. Oliktok Point O-230 SB NB Producer Attachment 10: Wellhead Diagram Oliktok Point O-230 SB NB Producer Attachment 11: Management of Change and approved in advance. SFD Oliktok Point O-230 SB NB Producer Attachment 12: Drill Pipe Specs Hole Section OD (in)ID (in)TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension (k-lbs) Surface & Production 5”4.276”3.25”6.625”19.5 S-135 GPDS50 36,100 43,100 560 5”4.276”3.25”6.625”19.5 S-135 NC50 31,032 34,136 560 Oliktok Point O-230 SB NB Producer Attachment 13: Kick Tolerance Calculations Oliktok Point O-230 SB NB Producer Attachment 14: Directional Plan 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. 226-008 NIKAITCHUQ O-230 NIKAITCHUQ SCHRADER BLUFF OIL WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name: NIKAITCHUQ O-230Initial Class/TypeDEV / PENDGeoArea890Unit11400On/Off ShoreOnProgram DEVWell bore segAnnular DisposalPTD#:2260080Field & Pool:NIKAITCHUQ, SCHRADER BLUFF OIL - 561100NA1 Permit fee attachedYes Surface Location lies within ADL0355024; Top Prod Int & TD lie within ADL0391283.2 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 boundaryNA6 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) (For NA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgNA21 CMT vol adequate to tie-in long string to surf csgNo Surface casing is top set in reservoir and is fully cemented. Lower completion is uncemented screens & blanks22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes See close approach note in conditions of approval26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 1300 psi, BOP rated to 5k psi (BOP test to 3000 psi)30 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 shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes None expected. Rig has sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure is 0.439 psi/ft (8.5 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]ApprSFDDate1/28/2026ApprBJMDate2/10/2026ApprSFDDate1/28/2026AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 2/11/2026