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Home My WebLink About225-0111. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reset Packer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,800' N/A Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 5,410psi Liner 150 Screens 6,390psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Milne Point Ugnu Undefined Oil Pool N/A 3,642' 10,799' 3,642' 1,304 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MPU S-204 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12/1/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 & 380110 225-011 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23814-00-00 Hilcorp Alaska LLC N/A Length Size Proposed Pools: 160' 160' Slotted 4.6 / L-80 / Hydril 511 TVD Burst 10,648' 7,740psi MD N/A 7,240psi 6,870psi 5,750psi 2,062' 3,879' 3,867' 2,243' 4,921' 127' 20" 9-5/8" 9-5/8" 2,211' 7"4,692' 2,678' 10,800' Perforation Depth MD (ft): 4,723' See Schematic 6,085' See Schematic 2-3/8" 3,642'5-1/2" 6.5 / L-80 / EUE 8rd ryan.lewis@hilcorp.com 303-906-5178 3-1/2" 9.3/ L-80 / EUE-8rd 4,344' 2-7/8' 3-1/2" 9.3/ L-80 / EUE-8rd 4,373' 4,658' DLESP & Baker SLZXP LTP and N/A 4,350 MD/ 3,770 TVD & 4,715 MD/ 3,866 TVD and N/A Ryan Lewis Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:39 am, Nov 04, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.11.03 16:01:40 - 09'00' Taylor Wellman (2143) 325-678 10-404 DSR-11/6/25 * BOPE pressure test to 2000 psi. 24 hour notice to AOGCC. A.Dewhurst 04NOV25 MGR07NOV25JLC 11/7/2025 11/07/25 Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 Well Name:MPS-204 API Number:50-029-23814-00-00 Current Status:SI - JP Producer Rig:ASR-1 Estimated Start Date:12/01/2025 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:225-011 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,678 psi @ 3,744 TVD 9/8/25 (EMW = 8.7 ppg)KWF= 9.0 ppg Max Potential Surface Pressure: 1,304 psi Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU S-204 will be a new drill into the Ugnu formation. We will be running a downhole heater in this well. The packer on the upper completion failed after a week and has been shut in ever since. Objectives: We will need to pull the upper completion and replace the packer. RIH, land the completion, set the packer and pressure test the IA. Notes Regarding Wellbore Condition: - 5/24/25 Spud - 6/23/2025 MIT-IA to 3,700 psi. - 6/24/2025 Completed. Coil Tubing 1. Turn on the Salamander heater 1 day ahead of Coil rigging up. 2. MIRU CTU. PT PCE according to coil weekly BOP testing. 3. RIH 1.50 coil with dual BPV, coil disconnect, jet swirl nozzle down to 10,600 MD. 4. Close in the coil backside and bullhead hot water throughout the lateral. The goal is to fluff, string out and break up anything that might be in the 5-1/2 x 2-3/8 annulus. 5. TIH to Bullnose guide shoe at 10,648MD. 6. Continue pumping while TOOH. 7. RDMO Pumping & Well Support 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RD well house and flowlines. Clear and level area around well. 10. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 11. Pressure test lines to 3,000 psi. 12. Circulate at least one wellbore volume with 9.0# brine down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of 9.0# brine. 13. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 14. RD Little Red Services and reverse out skid. 15. Set BPV. ND tree. NU BOPE. Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 RWO Procedure (Sundried or Non-Sundried Work): MIRU/Test BOPE: 16. Turn on the Salamander heater 3 days ahead of ASR rigging up. 17. MIRU Hilcorp ASR #1 Rig, ancillary equipment and lines to 500 bbl returns tank 18. Check for pressure and if 0 psi, set CTS plug. If needed, bleed any residual pressure off tubing and casing. If needed, kill well with 9.0# brine prior to setting CTS. 19. Test BOPE to 250 psi Low / 2000 psi High, annular to 250 psi Low / 2000 psi High (hold each test of ram/valve for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform BOPE Test as per ASR 1 BOP Test Procedure b. Notify AOGCC 24-hrs in advance of BOPE test c. Confirm test pressure per the Sundry Conditions of Approval d. Test pipe rams on 2-7/8 and 3-½ test jts e. Submit completed 10-424 Blow-Out Preventer Equipment (BOPE) Test from within 5 days of BOPE test 20. Pull CTS plug. Bleed any pressure to the returns tank. Kill well w/9.0# brine as needed. Pull BPV. NOTE: If indications show pressure underneath BPV, lubricate out BPV. 21. Call out the Baker Spoolers, Salamander, GEO PSI rep, we will use the Hilcorp spooler to spool the ESP cable and GEO PSI tec line. 22. RU the spoolers to handle the #1 flat ESP cable and 1 tec line. 23.Screw in the landing joint, back out the lockdown pins 24. The packer is set to shear at 40K overpull. a. PUW was 103K, SOW was 60k, with a block weight of 40k. b. Work pipe up from 100 Klbs to 115 Klbs in 5 klbs increments. c. If pipe has not released at 115 klbs, contact engineer prior to working pipe any further. d. Note if the packer shears off and releases or just straight pulls indicating the packer released. 25. Confirm the hanger is free, lay down the tubing hanger. a. Treat everything that will have to be re-used with care to salvage what we can. 26. POOH and lay down the 3-1/2 tubing to the packer at 4,350 MD. a. Note any indications of leak point at the packer element or the penetrators in the daily report. 27. Pull the penetrators, lay down the packer. 28. Lay down the 2-7/8 equipment below the packer. 29. PU: Nipple, Brace, 2.813" XN with 2.75" No-Go, RHC-M Plug installed Crossover, 3-1/2", EUE 8rd pin x 3-1/2", Vam Top Box Viking packer 7 x 3-1/2 x 3/8 Vam Top Box x Pin 7.5KPSI Crossover, 3-1/2", EUE 8rd box x 3-1/2", Vam Top Pin Tubing, 3-1/2", 9.3#, L-80, EUE 8rd Box x Pin C Pup Joint, 3-1/2", 9.3#, L-80, EUE Box x Pin Gauge Carrier, GEOPSI 10K Gauge Pup Joint, 3-1/2", 9.3#, L-80, EUE Box x Pin C If indications show pressure underneath BPV, lubricate out BPV Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 Tubing, 3-1/2", 9.3#, L-80, EUE 8rd Box x Pin C Pup Joint, 3-1/2", 9.3#, L-80, EUE Box x Pin Sliding Sleeve, Viking, 2.813" X profile, covered ports for TEC wire bypass Re-use Pup Joint, 3-1/2", 9.3#, L-80, EUE Box x Pin C Tubing, 3-1/2", 9.3#, L-80, EUE 8rd Box x Pin C 30. If during the RIH we cannot get back down it would be necessary to land the completion, RD ASR and bring in coil tubing to drill the 2-3/8 bullnose guide shoe ,in the end of the tailpipe completion, and make a fluff and stuff run to TD. Then RU ASR and continue with the install. 31. RIH the new packer to landing depth 4,350 MD. Testing continuity on the Heater/ESP cable and tec line every 1000. 32. Terminate the ESP cable and make up the ESP penetrator to the ESP cable, and (1) ¼ BHP gauge tec line. 33. PU and MU the 3-1/2 tubing hanger. Make final splice of the DH gauge ensure any unused control line ports are dummied off. We may need to lay down 1 jt of 3-1/2 to have enough length to make the splice. 34. Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 35. Land the tubing hanger and RILDS. Lay down the landing joint. 36. Install 3-1/2 HP BPV. ND BOP. Install the plug off tool. 37. NU the tubing head adapter and NU the tree. 38. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 39. Pull the plug off tool and BPV. 40. Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500 MD. 41. Drop the ball & rod. 42. Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). 43. Bleed the tubing pressure to 2,000 psi and PT the IA to 3,700 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 44.Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 45. RDMO Attachments: 1. Schematic 2. Proposed Wellbore Schematic 3. Double BOP Drawing _____________________________________________________________________________________ Revised By: TDF 9/18/2025 SCHEMATIC Milne Point Unit Well: MPU S-204 Last Completed: 6/23/2025 PTD: 225-011 TD =10,800(MD) /TD =3,642 (TVD) 3 20 Orig. KB Elev.:70.21/ GL Elev.:36.5 74 5 9-5/8 1 2 See Screen/ Solid Liner Detail 6 PB1: 210 612 PBTD =10,799 (MD) /PBTD =3,642 (TVD) 9-5/8 Fidelis Cementer @ 2,225 MD PB2: 8025 10178 11 7&8 9 10 3-1/2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 160 N/A 9-5/8 Surface 47 / L-80 / TXP 8.681 Surface 2,243 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.835 2,243 4,921 0.0758 7 Tieback 26 / L-80 / TXP 6.276 Surface 4,723 0.0383 5-1/2 Liner 150 Screens 20x17 / L-80 / Hyd 625xJFEB 4.780 x 4.892 4,715 10,800 0.0221 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 4,344 0.0087 2-7/8 Tubing 6.5/L-80/EUE-8rd 2.441 4,344 4,373 0.0058 3-1/2 Tubing 9.3 / L-80 / EUE-8rd 2.992 4,373 4,658 0.0087 2-3/8 Slotted Tubing 4.7 / L-80 / H 511 1.995 4,657 10,648 0.0039 OPEN HOLE / CEMENT DETAIL 42x24 17 yds Concrete 12-1/4"Stg 1 Lead - 299 sx / Tail 400 sx Stg 2 Lead 706 sx / Tail 270 sx 8-1/2 Uncemented Screen Liner WELL INCLINATION DETAIL KOP @ 209 90° Hole Angle = @ 4,922 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V, Tubing Hanger, FMC TC-1A, 11 x 4-1/2 TC-II top x bottom, CIW H BPVT, 1 Control Line, 1 ESP Penetrator GENERAL WELL INFO API: 50-029-23814-00-00 Completion Date: 6/23/2025 JEWELRY DETAIL No. Top MD Item ID 1 4,236 Viking Sliding Sleeve 2.813 X Profile 2.813 2 4,289 GEOPSI Gauge Carrier (Gauge Installed) 2.992 3 4,350 7 x 2-7/8 DLESP Packer 2.390 4 4,360 Heater Cable to ESP Cable Splice N/A 5 4,371 2.875 XN Nipple w 2.205 No-Go 2.205 6 4,657 3-1/2 to 2-3/8 X-Over 1.995 Lower Completion 7 4,715 Baker SLZXP LTP w/ double grip slips (11.27 tieback sleeve) 6.190 8 4,723 7 Tieback Assy. 6.180 9 4,736 7 H563 x 5.5 JFEBear L-80 XO 4.870 10 10,648 2-3/8 Tubing Shoe 11 10,799 Shoe 5-1/2SCREEN LINER DETAIL # Top (MD) Top (TVD) Btm (MD) Btm (TVD) 20 4911 3879 8341 3712 17 8343 3712 10759 3645 _____________________________________________________________________________________ Revised By: TDF 9/18/2025 PROPOSED Milne Point Unit Well: MPU S-204 Last Completed: 6/23/2025 PTD: 225-011 TD =10,800(MD) /TD =3,642 (TVD) 3 20 Orig. KB Elev.:70.21/ GL Elev.:36.5 74 5 9-5/8 1 2 See Screen/ Solid Liner Detail 6 PB1: 210 612 PBTD =10,799 (MD) /PBTD =3,642 (TVD) 9-5/8 Fidelis Cementer @ 2,225 MD PB2: 8025 10178 11 7&8 9 10 3-1/2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 160 N/A 9-5/8 Surface 47 / L-80 / TXP 8.681 Surface 2,243 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.835 2,243 4,921 0.0758 7 Tieback 26 / L-80 / TXP 6.276 Surface 4,723 0.0383 5-1/2 Liner 150 Screens 20x17 / L-80 / Hyd 625xJFEB 4.780 x 4.892 4,715 10,800 0.0221 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface ±4,657 0.0087 2-3/8 Slotted Tubing 4.7 / L-80 / H 511 1.995 4,657 10,648 0.0039 WELL INCLINATION DETAIL KOP @ 209 90° Hole Angle = @ 4,922 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V, Tubing Hanger, FMC TC-1A, 11 x 4-1/2 TC-II top x bottom, CIW H BPVT, 1 Control Line, 1 ESP Penetrator GENERAL WELL INFO API: 50-029-23814-00-00 Completion Date: 6/23/2025 JEWELRY DETAIL No. Top MD Item ID 1 4,236 Viking Sliding Sleeve 2.813 X Profile 2.813 2 4,289 GEOPSI Gauge Carrier (Gauge Installed) 2.992 3 ±4,350 7 x 2-7/8 DLESP Packer 2.390 4 4,360 Heater Cable to ESP Cable Splice N/A 5 4,371 2.875 XN Nipple w 2.205 No-Go 2.205 6 4,657 3-1/2 to 2-3/8 X-Over 1.995 Lower Completion 7 4,715 Baker SLZXP LTP w/ double grip slips (11.27 tieback sleeve) 6.190 8 4,723 7 Tieback Assy. 6.180 9 4,736 7 H563 x 5.5 JFEBear L-80 XO 4.870 10 10,648 2-3/8 Tubing Shoe 11 10,799 Shoe 5-1/2 SCREEN LINER DETAIL # Top (MD) Top (TVD) Btm (MD) Btm (TVD) 20 4911 3879 8341 3712 17 8343 3712 10759 3645 OPEN HOLE / CEMENT DETAIL 42x24 17 yds Concrete 12-1/4"Stg 1 Lead - 299 sx / Tail 400 sx Stg 2 Lead 706 sx / Tail 270 sx 8-1/2 Uncemented Screen Liner Milne Point ASR Rig 1 BOPE 2025 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 Blin d11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8 x 5 VBR David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: RESUBMITTED DUE TO API NUMBER ERROR WELL: MPU S-204 + PB1 + PB2 PTD: 225-011 API: 50-029-23814-00-00 (MPU S-204) API: 50-029-23814-70-00 (MPU S-204PB1) API: 50-029-23814-71-00 (MPU S-204PB2) FINAL LWD FORMATION EVALUATION + GEOSTEERING (05/25/2025 to 06/08/2025) x EWR-M5, AGR, ABG, DGR, ADR Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Final Geosteering and EOW Report/Plots SFTP Transfer – Main Folders: FINAL LWD Subfolders: FINAL Geosteering Subfolders:g Please include current contact information if different from above. T40604 T40605 T40606 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.08 14:45:40 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov August 20, 2025 Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-25-034 Notice of Violation and Request for Information – Close-out BOPE Test Reporting Milne Point Unit S-204 (PTD 2250110) Ugnu Undefined Oil Pool Dear Mr. McLaughlin: The Alaska Oil and Gas Conservation Commission (AOGCC) has completed its review of Hilcorp Alaska LLC (Hilcorp)’s June 17, 2025, letter responding to the subject notice of violation and information request. Actions taken by Hilcorp should help to prevent recurrence of this violation. The AOGCC does not intend to pursue any further enforcement action regarding the missed test report. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Phoebe Brooks Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.20 14:43:00 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.20 17:57:09 -08'00' 06/17/2025 Commissioners – Jessie Chmielowski and Gregory Wilson Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Response to Docket Number: OTH-25-034, Notice of Violation – BOPE Test Reporting, Request for Information, Milne Point Unti S-204 (PTD 2250110) To: Commissioner Chmielowski and Commissioner Wilson On June 16, 2025, Hilcorp Alaska, LLC (Hilcorp) received a Notice of Violation from the AOGCC (Docket Number: OTH-25-034, Notice of Violation – BOPE Test Reporting, Request for Information, Milne Point Unti S-204 (PTD 2250110) (the “NOV”). Hilcorp has investigated the circumstances surrounding the matters described in the NOV and is hereby submitting this response to AOGCC to describe steps that have been taken or will be taken to prevent recurrence. Background On May 6, 2025, Hilcorp circulated an AOGCC awareness note to all Drill Site Managers (DSMs) with specific instructions that a BOPE test form must be completed and submitted to AOGCC within 5 days of performing a BOPE test. In accordance with 20 AAC 25.035, a BOPE test was completed for MPU S-204 at 10:00AM on the morning of June 3rd. The BOPE test form was last saved at 6:47PM that same day. See file time stamp below. However, the Drill Site Manager responsible for MPU S-204 failed to submit the BOPE test report by June 8, 2025 Actions to prevent recurrence The DSM is responsible for timely emailing the BOPE test report to AOGCC. Hilcorp is currently determining whether the failure to send the test report was clerical in nature (email stuck in outbox, or computer error), or whether the DSM simply failed to submit the test report. Based on such determination, Hilcorp will address the individual appropriately. Hilcorp Alaska, LLC Sean McLaughlin, Drilling Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 By Samantha Coldiron at 9:27 am, Jun 18, 2025 Additionally, Hilcorp shall take the following steps to prevent recurrence: x Communicate this incident (and repercussions) to all DSMs; x Remind all DSMs of the BOPE testing and reporting requirements under 20 AAC 25.035 (with a particular emphasis on the 5-day deadline) Sean McLaughlin Drilling Manager CC Jim Regg Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.06.18 09:20:48 - 08'00' Sean McLaughlin (4311) 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 June 16, 2025 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7017 2400 0000 5648 0602 Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Docket Number: OTH-25-034 Notice of Violation – BOPE Test Reporting Request for Information (RFI) Milne Point Unit S-204 (PTD 2250110) Ugnu Undefined Oil Pool Dear Mr. McLaughlin: Hilcorp Alaska LLC (Hilcorp) recently commenced drilling operations at Milne Point Unit (MPU) S-204 pursuant to Permit to Drill (PTD) 2250110, approved on April 4, 2025. The well is being drilled by Doyon Rig 14. During well drilling operations testing of blowout prevention equipment (BOPE) must be completed at intervals specified in 20 AAC 25.035(e)(10). Submittal of a BOPE Test Report to the Alaska Oil and Gas Conservation Commission (AOGCC) is required not later than five days after completion of a BOPE test pursuant to 20 AAC 25.035(e)(10)(g). The test submittal requirements (distribution and date due relative to the completion of the test) are also detailed at the top of the BOPE Test Report, Form 10-424. Failure to timely submit a BOPE test report is a violation of AOGCC regulations. For MPU S-204, Hilcorp submitted the Diverter test report on May 25, 2025 and notified AOGCC of the intent to perform the initial BOPE test on June 1, 2025 (test scheduled for June 2, 2025). Using the scheduled test date, the BOPE test report was due not later than June 7, 2025. AOGCC inquired about the about the report’s status on June 10, 2025. Within 7 days after receipt of this letter (next business day if the due date falls on a weekend or holiday), Hilcorp is requested to describe specific steps that have been or will be taken to prevent recurrence of this violation. Docket Number: OTH-25-034 Notice of Violation – BOPE Test Reporting June 16, 2025 Page 2 of 2 The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Phoebe Brooks (email) AOGCC Inspectors (email) Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.06.16 10:09:01 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.16 10:20:45 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well AL Explanation Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull & Replace Packer 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,970'N/A Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 5,410psi Liner 150҄ Screens 6,390psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng FHL Ret. & BOT SLZXP and N/A ~4,420 MD/ ~2,267 TVD & ~4,378 MD/ ~2,258 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 3-1/2" 9.3/ L-80 / EUE-8rd 4,770' 10,970' Perforation Depth MD (ft): 4,738' See Schematic 6,062' See Schematic 2-3/8" 3,743'5-1/2" 107' 20" 9-5/8" 9-5/8" 2,500' 7"4,738' 2,388' MD N/A 7,240psi 6,870psi 5,750psi 1,899' 2,374' 2,341' 2,500' 4,888' Length Size Proposed Pools: 107' 107' Slotted 4.7 / L-80 / W 511 TVD Burst 10,800' 7,740psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 & 380110 225-011 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23814-00-00 Hilcorp Alaska LLC N/A AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 6/27/2025 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MPU S-204 Milne Point Ugnu Undefined Oil Pool N/A 3,743' 10,970' 3,743' 787 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-393 By Gavin Gluyas at 3:17 pm, Jun 27, 2025 DSR-6/30/25 * Approved for reverse circulating jet pump. * IA High pressure trip not to exceed MIT-IA test pressure of 3700 psi. 787 SFD 6/30/2025 10-407 Completion ops to be included in original well completion report. MGR27JUN2025 Yes June 27, 2025 Mel Rixse *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.01 08:49:48 -08'00'07/01/25 RBDMS JSB 070225 Well:MPS-204 PTD: 225-011 API: 50-029-23814-00-00 Well Name: MPS-204 API Number: 50-029-23814-00-00 Current Status:New Drill Rig:Doyon 14 Esti mated Start Date: 6/27/2025 Est imated Durati on: 0 days Regul atory Contac t:Tom Fouts Permi t to Drill Number: 225-011 F irst Call Engineer:Ryan Lewis (303)906-5178 (M ) Second Call Engineer:Taylor Wellman (907) 777-8449 (O)(907) 947-9533 (M) Current Bottom Hole Pressure: 1,154 psi @ 3,670’ TVD S-203 BH gauge 8/23/24 (EMW = 6.1 ppg) Max Potenti al Surface Pressure: 787 psi Gas Column Gradient (0.1 psi /ft) Bri e f Well Summary: MPU S-204 will be a new drill into the Ugnu formation. This well will be a Reverse circula t ing JP tha t has a downhol e heater to reduce oil viscosi ty. Obj ect ives: Sundry of AL method. MPS-204 will be a reverse circulating JP. The SSV is installed in the vertic al run of the tree. The Pilot trips for the SSV: Low pressure shutdown will be set at 25% of flowing tubing pressure or 50% of f irst vessel pressure (whichever is greater). High Pressure shutdown will be set to 1100 psi . Power fluid pressure is +-3600 psi. The PF SSV low press ure shutdown is set grea ter than 50% of the power fluid pressure. The high-pressure shutdown w ill be set at 5,000 psi. Attac hments: 1.Proposed Wellbore Schematic 3700 psi. MIT-IA tested to 3700 psi. High pressure trip not to exceed test pressure. -mgr _____________________________________________________________________________________ Revised By:RJL 5/7/2025 PR O P O SED SCHE MATIC M ilne Point Uni t Well:M PU S-204 Last Compl eted:TBD PTD:TBD TD =10,970’(MD)/TD =3,743’(TVD) 3 20” Orig.KBElev.:70.0’/GL Elev.:36.5’ 7”4 5 9-5/8” 1 2 See Screen/ Solid Liner Detail 6 PBTD =10,970’(MD)/PBTD =3,743’(TVD) 9-5/8” ‘ES’ Cementer @ ~2,500’ MD 11 7&8 9 10 3-1/2” CASING DETAIL Size Type Wt/ Grade/Conn ID Top Btm BPF 20"Conductor 215 /X-52 / WeldN/ASurface 107’N/A 9-5/8”Surface47/L-80 /TXP 8.681 Surf ace2,500’0.0732 9-5/8"Surface40/L-80 /TXP 8.835 2,500’4,888’0.0758 7”Tieback 26 /L-80 /TXP 6.276 Surf ace4,738’0.0383 5-1/2”Liner 150μ Screens 17 /L-80 / Hyd 625 4.767 4,738’10,970’0.0221 TUBING DETAIL 3-1/2"Tubing 9.3/L-80 /EUE-8rd 2.992 Surface4,770’0.0087 2-3/8”Tubing Slotted 4.7/L-80 / W 511 1.995 4,770’10,800’0.0039 OPENHOLE /CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 –Le ad -241 sxEcono Cem /Tail –395 sx Sw if t Cem Stg 2 –Lead –673 sx Perm Cem /Tail –268 sx Class G 8-1/2”Uncemented Screen Liner WELL INCLINATION DETAIL KOP @250’ 90°HoleAngle =@5,200’ TREE &WELLHEAD Tree Cameron3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INF O API:TBD Completion Date:TBD 5-1/2”SOLID LINER DETAIL Jts Top (MD Top (TVD) Btm (MD) Btm (TVD) JEWELRY DETAIL No.Top MD Item ID 1 ~4,360’3.5”CMD Sliding Sleeve 2.813” 2 ~4,390’4.5”GaugeMandrel w/¼”Wire (IntakeGauge)2.875” 3 ~4,420’7”x 2.875”FHL Retrievable Packer 2.885” 4 ~4,425’Heater CabletoESP Cable SpliceN/A 5 ~4,450’2.875”XNNipple 2.205” 6 ~4,670’X-Over 1.995” Lower Completion 7 ~4,738’BOT SLZXP LT Pack er /LinerHanger 4-1/2”x 9-5/8”6.190” 8 ~4,738’7”Tieback Assy.6.151” 9 ~4,738’7”H563 x 5.5”625 L-80 XO4.767” 10 ~10,800’WLEG1.995” 11 10,970’Shoe 5-1/2”Screens LINER DETAIL Jts Top (MD)Top (TVD)Btm (MD)Btm (TVD) 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull & Replace Packer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,970'N/A Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 5,410psi Liner 150҄ Screens 6,390psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Milne Point Ugnu Undefined Oil Pool N/A 3,743' 10,970' 3,743' 787 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MPU S-204 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 6/17/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 & 380110 225-011 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23814-00-00 Hilcorp Alaska LLC N/A Length Size Proposed Pools: 107' 107' Slotted 4.7 / L-80 / W 511 TVD Burst 10,800' 7,740psi MD N/A 7,240psi 6,870psi 5,750psi 1,899' 2,374' 2,341' 2,500' 4,888' 107' 20" 9-5/8" 9-5/8" 2,500' 7"4,738' 2,388' 10,970' Perforation Depth MD (ft): 4,738' See Schematic 6,062' See Schematic 2-3/8" 3,743'5-1/2" FHL Ret. & BOT SLZXP and N/A ~4,420 MD/ ~2,267 TVD & ~4,378 MD/ ~2,258 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 3-1/2" 9.3/ L-80 / EUE-8rd 4,770' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:27 pm, Jun 17, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.06.17 14:00:48 - 08'00' Taylor Wellman (2143) 325-368 10-407 MGR17JUN2025 DSR-6/17/25A.Dewhurst 17JUN25 Yes * BOPE pressure test to 3000 psi. Annular to 2500 psi. 24 hour notice. 17-June-2025 Mel Rixse (original completion report) SJC for GCW 6/23/25 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.23 10:57:42 -08'00'06/23/25 RBDMS JSB 062325 Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 Well Name:MPS-204 API Number:50-029-23814-00-00 Current Status:New Drill Rig:Doyon 14 Estimated Start Date:6/17/2025 Estimated Duration:5days Regulatory Contact:Tom Fouts Permit to Drill Number:225-011 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,154 psi @ 3,670’ TVD S-203 BH gauge 8/23/24 (EMW = 6.1 ppg) Max Potential Surface Pressure: 787 psi Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU S-204 will be a new drill into the Ugnu formation. We will be running a downhole heater in this well. The upper completion landed, we set the packer and the IA test failed. We repeated the setting sequence and have the same results, the IA test failed. Objectives: We will need to pull the upper completion and replace the packer. RIH, land the completion, set the packer and pressure test the IA. Notes Regarding Wellbore Condition: - Spud 5/24/25. Slickine: 1.RU slickline. 2.Pull Ball and rod 3.Shift the sliding sleeve open. 4.Circulate out the Freeze Protect. 5.Close the sliding sleeve. Rigwork: 6.Set TWC. ND the production tree 7.NU NU 13-5/8” x 5M BOP as follows: xx BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13-5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 4-1/2” x 7” VBRs in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5” VBRs x NU bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 8.Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 a. Test 4-1/2” x 7” rams with 5” and 7” test joints b. Test 2-7/8” x 5” rams with the 3-1/2” and 5” test joints c. Confirm test pressures with PTD d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug e. Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 9.RD BOP test equipment 10.Call out the Baker Spoolers, we will use the Hilcorp spooler, Salamander 11.RU the spoolers to handle the #1 flat ESP cable and 3 tec lines. 12.Screw in the landing joint, back out the lockdown pins 13.The packer is set to shear at 40K overpull. a. PUW was 103K, SOW was 60k, with a block weight of 40k. b. Work pipe up from 100 Klbs to 115 Klbs in 5 klbs increments. c. If pipe has not released at 115 klbs, contact engineer prior to working pipe any further. 14.Confirm the hanger is free, lay down the tubing hanger. a. Treat everything that will have to be re-used with care to salvage what we can. 15.POOH and lay down the 3-1/2” tubing to the packer at 4,351’ MD. a. Note any indications of leak point at the packer element or the penetrators in the daily report. 16.Pull the penetrators, lay down the packer. 17.PU the new packer and RIH to landing depth 18.Terminate the ESP cable and make up the ESP penetrator to the ESP cable, (3) 1/8” tec lines and (1) ¼” BHP gauge tec line. 19.PU and MU the 3-1/2” tubing hanger. Make final splice of the 4 (3 TEC wire and 1 for DH gauge) ensure any unused control line ports are dummied off. 20.Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 21.Land the tubing hanger and RILDS. Lay down the landing joint. 22.Install 3-1/2” HP BPV. ND BOP. Install the plug off tool. 23.NU the tubing head adapter and NU the tree. 24.PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 25.Pull the plug off tool and BPV. 26.Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 27.Drop the ball & rod. 28.Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 29.Bleed the tubing pressure to 2,000 psi and PT the IA to 3,700 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 30.Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 31.RDMO Attachments: 1. Proposed Wellbore Schematic _____________________________________________________________________________________ Revised By: RJL 5/7/2025 PROPOSED SCHEMATIC Milne Point Unit Well: MPU S-204 Last Completed: TBD PTD: TBD TD =10,970’(MD) /TD =3,743’ (TVD) 3 20” Orig. KB Elev.: 70.0’/ GL Elev.:36.5’ 7”4 5 9-5/8” 1 2 See Screen/ Solid Liner Detail 6 PBTD =10,970’ (MD) / PBTD =3,743’ (TVD) 9-5/8” ‘ES’ Cementer @ ~2,500’ MD 11 7&8 9 10 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 107’ N/A 9-5/8” Surface 47 / L-80 / TXP 8.681 Surface 2,500’ 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.835 2,500’ 4,888’ 0.0758 7” Tieback 26 / L-80 / TXP 6.276 Surface 4,738’ 0.0383 5-1/2” Liner 150ђ Screens 17 / L-80 / Hyd 625 4.767 4,738’ 10,970’ 0.0221 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 4,770’ 0.0087 2-3/8” Tubing Slotted 4.7 / L-80 / W 511 1.995 4,770’ 10,800’ 0.0039 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 –Lead - 241 sx Econo Cem / Tail –395 sx Swift Cem Stg 2 – Lead – 673 sx Perm Cem / Tail – 268 sx Class G 8-1/2” Uncemented Screen Liner WELL INCLINATION DETAIL KOP @ 250’ 90° Hole Angle = @ 5,200’ TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INFO API: TBD Completion Date: TBD 5-1/2”SOLID LINER DETAIL Jts Top (MD Top (TVD) Btm (MD) Btm (TVD) JEWELRY DETAIL No. Top MD Item ID 1 ~4,360’ 3.5” CMD Sliding Sleeve 2.813” 2 ~4,390’ 4.5” Gauge Mandrel w/ ¼” Wire (Intake Gauge) 2.875” 3 ~4,420’ 7” x 2.875”FHL Retrievable Packer 2.885” 4 ~4,425’ Heater Cable to ESP Cable Splice N/A 5 ~4,450’2.875”XN Nipple 2.205” 6 ~4,670’ X-Over 1.995” Lower Completion 7 ~4,738’ BOT SLZXP LT Packer / Liner Hanger 4-1/2” x 9-5/8” 6.190” 8 ~4,738’ 7” Tieback Assy. 6.151” 9 ~4,738’ 7” H563 x 5.5” 625 L-80 XO 4.767” 10 ~10,800’ WLEG 1.995” 11 10,970’ Shoe 5-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) Originated: Delivered to:6-Jun-25Alaska Oil & Gas Conservation Commiss06Jun25-NR ,<)*(*$'''8:)*81&) :)*%$+ +*#61$!>> ''>+*#61>> ;A>:C:' :/A>:C:'.:=EWELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3T-730 501-03-20907-00-00 225-010 Kuparuk River WL TTiX HSD FINAL FIELD 27-May-253S-703 501-03-20913-00-00 225-035 Kuparuk River WL TTiX-IBC-CBL FINAL FIELD 31-May-253T-603 501-03-20887-00-00 224-074 Kuparuk River WL TTiX FSI FINAL FIELD 20-May-25Transmittal ReceiptFFFFFFFFFFFFFFFFFFFFFFFFFFFFFFFF 4FFFFFFFFFFFFFFFFFFFFFFFFFFFFFFFFF%)/ &6) )Please return via courier or sign/scan and email a copy to Schlumberger.!+*G!$28+#/&7<)#TRANSMITTAL DATETRANSMITTAL # $B +)!6)+#=/!)*)+6A2#E1$#1)+8C*!2+<8 *+60$$2*<$<<$<!)<<+#/B+)##+<!8 *+6H!+#))!*#)2=<2)!*#$<2!!/<)#+#))*2##)</<8D&+*$/26%)T40532T40533T405343T-730501-03-20907-00-00225-010Kuparuk RiverWLTTiX HSDFINAL FIELD27-May-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.06 13:07:43 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Upper Completion Change 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,970'N/A Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 5,410psi Liner 150҄ Screens 6,390psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng FHL Ret. & BOT SLZXP and N/A ~4,420 MD/ ~2,267 TVD & ~4,378 MD/ ~2,258 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 3-1/2" 9.3/ L-80 / EUE-8rd 4,770' 10,970' Perforation Depth MD (ft): 4,738' See Schematic 6,062' See Schematic 2-3/8" 3,743'5-1/2" 107' 20" 9-5/8" 9-5/8" 2,500' 7"4,738' 2,388' MD N/A 7,240psi 6,870psi 5,750psi 1,899' 2,374' 2,341' 2,500' 4,888' Length Size Proposed Pools: 107' 107' Slotted 4.7 / L-80 / W 511 TVD Burst 10,800' 7,740psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 & 380110 225-011 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23814-00-00 Hilcorp Alaska LLC N/A AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 5/24/2025 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MPU S-204 Milne Point Ugnu Undefined Oil Pool N/A 3,743' 10,970' 3,743' 787 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:00 pm, May 08, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.05.08 10:33:20 - 08'00' Taylor Wellman (2143) 325-289 * Approved for reverse circulating jet pump. Surface safety valve system requires a SSV on the production side and a SSV on the power fluid side, both tied to the safety valve system panel. * IA SSV high pressure trip pressure not to exceed 3650 psi. IA low pressure trip pressure not to be lower 50% of header pressure. * The prod tubing low-pressure trip will be set at least 50 percent of the separator inlet pressure or at least 25 percent of the flowing tubing pressure, whichever is greater. * SSV closure on IA will initiate closure within 2 minutes on SSV on production tubing and visa versa. * Compliance to CO 808 required.10-407 (original completion) SFD 5/14/2025 DSR-5/9/25 * BOPE pressure test to 3000 psi. Annular to 2500 psi. MGR14MAY25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.15 09:36:42 -08'00' 05/15/25 RBDMS JSB 051625 Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 Well Name:MPS-204 API Number:50-029-23814-00-00 Current Status:New Drill Rig:Doyon 14 Estimated Start Date:5/24/2025 Estimated Duration:25 days Regulatory Contact:Tom Fouts Permit to Drill Number:225-011 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,154 psi @ 3,670’ TVD S-203 BH gauge 8/23/24 (EMW = 6.1 ppg) Max Potential Surface Pressure: 787 psi Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU S-204 will be a new drill into the Ugnu formation. We will be running a downhole heater in this well and the only packer we could procure to accommodate the heater cable and the 3 tec lines for thermocouples to measure temperature along the lateral is a 2-7/8”. Objectives: Sundry the upper completion from a 3-1/2” packer and XN nipple to a 2-7/8” packer and XN nipple. Notes Regarding Wellbore Condition: - Est Spud 5/24/25. Run Upper Completion – Jet Pump 18.1 RU to run slotted 2-3/8” 4.44# L-80 W511 x 3-1/2”, 9.3#, L-80 EUE tubing. x Ensure wear bushing is pulled. x Ensure 2-3/8” 4.44# L-80 W511 x XT-39 and 3-1/2”, L-80, 12.6#, EUE x XT-39 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 18.2 PU, MU and RIH with the following 2-3/8” x 3-1/2” JP completion (confirm tally with Operations Engineer): x WLEG/Mule shoe x XX Joints, 2-3/8” 4.44# L-80 W511 x Attach cross collar clamps with 3 heater cables and 3 thermo couple 1/8” tec lines. x Crossover, 3-1/2”, EUE Box x 2-3/8” W511 Pin x XX joint, 3-1/2”, 9.3#, L-80 EUE x Crossover, 2-7/8”, EUE Box x 3-1/2”, EUE Pin Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 x Nipple, 2.313” XN profile (2.205” no-go), 2-7/8”, EUE (RHC plug body installed, Set at +-70 degrees) x Crossover, 3-1/2”, EUE Box x 2-7/8”, EUE Pin x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x Convert over from 3 heater cables to ESP Cable. x Make up packer penetrators for the ESP cable and 3 tec lines. x Crossover, 2-7/8”, EUE Box x 3-1/2”, EUE Pin x Retrievable Packer,Tri-point, 2-7/8”, 6.5#, L-80 EUE x Crossover, 3-1/2”, EUE Box x 2-7/8”, EUE Pin x Pup joint, 3-1/2”, 9.3#, L-80 EUE x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Crossover, 4-1/2”, EUE Box x 3-1/2”, EUE Pin x Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd x Crossover, 3-1/2”, EUE Box x 4-1/2”, EUE 8rd Pin x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x Sliding Sleeve, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x XXX joints, 3-1/2”, 9.3#, L-80 EUE 18.3 Terminate the ESP cable and make up the ESP penetrator to the ESP cable, (3) 1/8” tec lines and (1) ¼” BHP gauge tec line. 18.4 PU and MU the 3-1/2” tubing hanger. Make final splice of the 4 (3 TEC wire and 1 for DH gauge) ensure any unused control line ports are dummied off. 18.5 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.6 Land the tubing hanger and RILDS. Lay down the landing joint. 18.7 Install 3-1/2” HP BPV. ND BOP. Install the plug off tool. 18.8 NU the tubing head adapter and NU the tree. 18.9 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 18.10 Pull the plug off tool and BPV. 18.11 Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 18.12 Drop the ball & rod. Well: MPS-204 PTD: 225-011 API: 50-029-23814-00-00 18.13 Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). 18.14 Bleed the tubing pressure to 2,000 psi and PT the IA to 3,700 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 18.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.16 RDMO Attachments: 1. Proposed Wellbore Schematic _____________________________________________________________________________________ Revised By: RJL 5/7/2025 PROPOSED SCHEMATIC Milne Point Unit Well: MPU S-204 Last Completed: TBD PTD: TBD TD =10,970’(MD) /TD =3,743’ (TVD) 3 20” Orig. KB Elev.: 70.0’/ GL Elev.:36.5’ 7”4 5 9-5/8” 1 2 See Screen/ Solid Liner Detail 6 PBTD =10,970’ (MD) / PBTD =3,743’ (TVD) 9-5/8” ‘ES’ Cementer @ ~2,500’ MD 11 7&8 9 10 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 107’ N/A 9-5/8” Surface 47 / L-80 / TXP 8.681 Surface 2,500’ 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.835 2,500’ 4,888’ 0.0758 7” Tieback 26 / L-80 / TXP 6.276 Surface 4,738’ 0.0383 5-1/2” Liner 150ђ Screens 17 / L-80 / Hyd 625 4.767 4,738’ 10,970’ 0.0221 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 4,770’ 0.0087 2-3/8” Tubing Slotted 4.7 / L-80 / W 511 1.995 4,770’ 10,800’ 0.0039 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 –Lead - 241 sx Econo Cem / Tail –395 sx Swift Cem Stg 2 – Lead – 673 sx Perm Cem / Tail – 268 sx Class G 8-1/2” Uncemented Screen Liner WELL INCLINATION DETAIL KOP @ 250’ 90° Hole Angle = @ 5,200’ TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INFO API: TBD Completion Date: TBD 5-1/2”SOLID LINER DETAIL Jts Top (MD Top (TVD) Btm (MD) Btm (TVD) JEWELRY DETAIL No. Top MD Item ID 1 ~4,360’ 3.5” CMD Sliding Sleeve 2.813” 2 ~4,390’ 4.5” Gauge Mandrel w/ ¼” Wire (Intake Gauge) 2.875” 3 ~4,420’ 7” x 2.875”FHL Retrievable Packer 2.885” 4 ~4,425’ Heater Cable to ESP Cable Splice N/A 5 ~4,450’2.875”XN Nipple 2.205” 6 ~4,670’ X-Over 1.995” Lower Completion 7 ~4,738’ BOT SLZXP LT Packer / Liner Hanger 4-1/2” x 9-5/8” 6.190” 8 ~4,738’ 7” Tieback Assy. 6.151” 9 ~4,738’ 7” H563 x 5.5” 625 L-80 XO 4.767” 10 ~10,800’ WLEG 1.995” 11 10,970’ Shoe 5-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 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: Milne Point Unit, Ugnu Undefined Oil Pool, MPU S-204 Hilcorp Alaska, LLC Permit to Drill Number: 225-011 Surface Location: 3236' FSL, 474' FEL, Sec 12, T12N, R10E, UM, AK Bottomhole Location: 2474' FSL, 1601' FEL, Sec 11, T12N, R10E, 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 4th day of April 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.04 08:52:05 -08'00' By Gavin Gluyas at 8:18 am, Feb 06, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.02.05 17:00:40 - 09'00' Sean McLaughlin (4311) A.Dewhurst 28MAR25 50-029-23814-00-00 DSR-2/18/25 * BOPE test to 3000 psi. Annular to 2500 psi. * Email FIT and Casing test digital data to AOGCC immediately upon completion of FIT. * Additional 10-403 required prior to POP to describe jet pump configuration, power fluid pressures, tree variance request (if required) and SSVs w/ corresponding trip pressures. MGR18MAR2025 225-011 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.04 08:52:18 -08'00'04/04/25 04/04/25 rbdms jsb 040425 Milne Point Unit (MPU) S-204 Application for Permit to Drill Version 2 1/17/2025 Table of Contents 1.0 Well Summary .......................................................................................................................... 2 2.0 Management of Change Information ....................................................................................... 3 3.0 Tubular Program:..................................................................................................................... 4 4.0 Drill Pipe Information: ............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................ 5 6.0 Planned Wellbore Schematic .................................................................................................... 6 7.0 Drilling / Completion Summary ............................................................................................... 7 8.0 Mandatory Regulatory Compliance / Notifications ................................................................. 8 9.0 R/U and Preparatory Work .................................................................................................... 10 10.0 N/U Diverter System ............................................................................................................... 11 11.0 Drill 12-1/4” Hole Section ....................................................................................................... 13 12.0 Run 9-5/8” Surface Casing ..................................................................................................... 16 13.0 Cement 9-5/8” Surface Casing ................................................................................................ 22 14.0 ND Diverter, NU BOPE, & Test ............................................................................................. 27 15.0 Drill 8-1/2” Hole Section ......................................................................................................... 28 16.0 Run Screened Liner ................................................................................................................ 33 17.0 Run 7” Tieback ....................................................................................................................... 37 18.0 Run Upper Completion – Jet Pump ....................................................................................... 40 19.0 Doyon 14 Diverter Schematic ................................................................................................. 42 20.0 Doyon 14 BOP Schematic ....................................................................................................... 43 21.0 Wellhead Schematic ................................................................................................................ 44 22.0 Days Vs Depth ......................................................................................................................... 45 23.0 Formation Tops & Information.............................................................................................. 46 24.0 Anticipated Drilling Hazards ................................................................................................. 48 25.0 Doyon 14 Rig Layout .............................................................................................................. 51 26.0 FIT Procedure ......................................................................................................................... 52 27.0 Doyon 14 Rig Choke Manifold Schematic .............................................................................. 53 28.0 Casing Design .......................................................................................................................... 54 29.0 8-1/2” Hole Section MASP ...................................................................................................... 55 30.0 Spider Plot (NAD 27) (Governmental Sections) ..................................................................... 56 31.0 Surface Plat (As Built) (NAD 27) ............................................................................................ 57 Page 2 Milne Point Unit S-204 Ugnu Producer PTD Application 1.0 Well Summary Well MPU S-204 Pad Milne Point “S” Pad Planned Completion Type Jet Pump Target Reservoir(s) Ugnu MB Sand Planned Well TD, MD / TVD 10,970’ MD / 3,663’ TVD PBTD, MD / TVD 10,970’ MD / 3,663’ TVD Surface Location (Governmental) 3236’ FSL, 474’ FEL, Sec. 12, T12N, R10E, UM, AK Surface Location (NAD 27) X= 565537, Y=5999901 Top of Productive Horizon (Governmental)2389’ FSL, 814’ FEL, Sec. 12, T12N, R10E, UM, AK TPH Location (NAD 27) X= 565205, Y=5999051 BHL (Governmental) 2474' FSL, 1601' FEL, Sec 11, T12N, R10E, UM, AK BHL (NAD 27) X= 559138, Y= 5999085 AFE Drilling Days 17 AFE Completion Days 4 Maximum Anticipated Pressure (Surface) 1317 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1704 psig Work String 5” 19.5# S-135 NC 50 Doyon 14 KB Elevation above MSL: 33.7 ft + 36.3 ft = 70.0 ft GL Elevation above MSL: 36.3 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit S-204 Ugnu Producer PTD Application 2.0 Management of Change Information Page 4 Milne Point Unit S-204 Ugnu Producer PTD Application 3.0 Tubular Program: Hole Section OD (in)ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.25”---X-52Weld 12-1/4”9-5/8” 8.835” 8.679”10.625”40 L-80 TXP 5,750 3,090 916 9-5/8” 8.681” 8.525” 10.625” 47 L-80 TXP 6,870 4,750 1,086 Tieback 7” 6.276” 6.151” 7.656” 26 L-80 TXP 7,240 5,410 604 8-1/2”5-1/2” Screens 4.892” 4.767” 6.050” 17 L-80 BEAR HT 7,740 6,290 397 Tubing 4-1/2" 3.958” 3.833” 4.729” 12.6 L-80 TXP 8,430 7,500 288 4.0 Drill Pipe Information: 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 DS50 36,100 43,100 560klb 5”4.276” 3.25” 6.625” 19.5 S-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit S-204 Ugnu Producer PTD Application 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellView. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates x Submit a short operations update each work day to sean.mclaughlin@hilcorp.com, nathan.sperry@hilcorp.com, and joseph.lastufka@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Email Drilling Manager Sean Mclaughlin sean.mclaughlin@hilcorp.com Drilling Engineer Nate Sperry 907.777.8450 nathan.sperry@hilcorp.com Completion Engineer Ryan Lewis Ryan.lewis@hilcorp.com Geologist Patrick Boyle 907.564.4649 Patrick.boyle@hilcorp.com Drilling Env. Coordinator Adrian Kersten 907.564.4820 Adrian.kersten@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 Joseph.Lastufka@hilcorp.com Drilling Manager Sean Mclaughlin sean.mclaughlin@hilcorp.com _____________________________________________________________________________________ Revised By: JNL 2/5/2025 PROPOSED SCHEMATIC Milne Point Unit Well: MPU S-204 Last Completed: TBD PTD: TBD TD =10,970’(MD) /TD =3,663’ (TVD) 3 20” Orig. KB Elev.: 70.0’ / GL Elev.: 36.5’ 7”4 5 9-5/8” 1 2 See Screen/ Solid Liner Detail 6 PBTD =10,970’ (MD) /PBTD =3,663’ (TVD) 9-5/8” ‘ES’ Cementer @ ~2,500’ MD 11 7&8 9 10 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 107’ N/A 9-5/8” Surface 47 / L-80 / TXP 8.681 Surface 2,500’ 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.835 2,500’ 4,888’ 0.0758 7” Tieback 26 / L-80 / TXP 6.276 Surface 4,738’ 0.0383 5-1/2” Liner 150ђ Screens 17 / L-80 / Hyd 625 4.767 4,738’ 10,970’ 0.0221 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 4,770’ 0.0087 2-3/8” Tubing Slotted 4.7 / L-80 / W 511 1.995 4,770’ 10,800’ 0.0039 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead - 241 sx Econo Cem / Tail – 395 sx Swift Cem Stg 2 – Lead – 673 sx Perm Cem / Tail – 268 sx Class G 8-1/2” Uncemented Screen Liner WELL INCLINATION DETAIL KOP @ 250’ 90° Hole Angle = @ 5,200’ TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INFO API: TBD Completion Date: TBD 5-1/2”SOLID LINER DETAIL Jts Top (MD Top (TVD) Btm (MD) Btm (TVD) JEWELRY DETAIL No. Top MD Item ID 1 ~4,360’ 3.5” CMD Sliding Sleeve 2.813” 2 ~4,390’ 4.5” Gauge Mandrel w/ ¼” Wire (Intake Gauge) 2.875” 3 ~4,420’ 7” x 3.5” FHL Retrievable Packer 2.885” 4 ~4,425’ Heater Cable to ESP Cable Splice N/A 5 ~4,450’ 3.5” XN Nipple 2.750” 6 ~4,670’ X-Over 1.995” Lower Completion 7 ~4,738’ BOT SLZXP LT Packer / Liner Hanger 4-1/2” x 9-5/8” 6.190” 8 ~4,738’ 7” Tieback Assy. 6.151” 9 ~4,738’ 7” H563 x 5.5” 625 L-80 XO 4.767” 10 ~10,800’ WLEG 1.995” 11 10,970’ Shoe 5-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) Page 7 Milne Point Unit S-204 Ugnu Producer PTD Application 7.0 Drilling / Completion Summary MPU S-204 is a grassroots producer planned to be drilled in the Ugnu MB sand. The directional plan is 12-1/4” surface hole with 9-5/8” surface casing set in the top of the Ugnu MB sand. An 8-1/2” lateral section will be drilled and completed with a 5-1/2” liner. The well will be produced with a jet pump. Doyon 14 will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately April 5th, 2025, pending rig schedule. Surface casing will be run to 4,888’ MD / 3,873’ TVD and cemented to surface via a 2-stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations: 1. MIRU Doyon 14 2. N/U & Test 21-1/4” Diverter and 16” diverter line 3. Drill 12-1/4” hole to TD of surface hole section. Run and cement 9-5/8” surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8” 5M BOP & Test 5. Drill 8-1/2” lateral to well TD 6. Run 5-1/2” production liner 7. Run 7” tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface hole: No mud logging. Remote geologist. LWD: GR + Res 2. Production Hole: No mud logging. Remote geologist. LWD: GR + ADR (For geo-steering) Page 8 Milne Point Unit S-204 Ugnu Producer PTD Application 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that all drilling and completion operations comply with all applicable AOGCC regulations. Operations stated in this PTD application may be altered based on sound engineering judgement as wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from the AOGCC. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. x BOPs shall be tested at (2) week intervals during the drilling and completion of MPU S-204. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3,000 psi & subsequent tests of the BOP equipment will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial and subsequent tests).Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“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 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)”. AOGCC Regulation Variance Requests: x None Page 9 Milne Point Unit S-204 Ugnu Producer PTD Application Summary of BOP Equipment & Notifications Hole Section Equipment Test Pressure (psi) 12 1/4”x 21-1/4” 2M Diverter w/ 16” Diverter Line Function Test Only 8-1/2” x 13-5/8” x 5M Hydril “GK” Annular BOP x 13-5/8” x 5M Hydril MPL Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Hydril MPL Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3000 Subsequent Tests: 250/3000 Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov Test Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 Milne Point Unit S-204 Ugnu Producer PTD Application 9.0 R/U and Preparatory Work 9.1 S-204 will utilize a 20” conductor on S-pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Doyon 14. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80qF). Page 11 Milne Point Unit S-204 Ugnu Producer PTD Application 10.0 N/U Diverter System 10.1 N/U 21-1/4” Hydril MSP 2M Diverter System (Diverter Schematic attached to program). x N/U 16-3/4” 3M x 21-1/4” 2M DSA on 16-3/4” 3M wellhead. x N/U 21-1/4” diverter “T”. x Knife gate, 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source x Place drip berm at the end of diverter line. 10.2 Notify AOGCC. Function test diverter. x Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. x Ensure that the annular closes in less than 45 seconds (API Standard 64 3rd edition March 2018 section 12.6.2 for packing element ID greater than 20”) 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. Page 12 Milne Point Unit S-204 Ugnu Producer PTD Application 10.4 Rig & Diverter Orientation: x May change on location Page 13 Milne Point Unit S-204 Ugnu Producer PTD Application 11.0 Drill 12-1/4” Hole Section 11.1 P/U 12-1/4” directional drilling assembly: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x GWD will be the primary gyro tool. Take gyro surveys until MWD cleans up. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135. x Run a solid float in the surface hole section. 11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor. x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4” hole section to section TD in the Ugnu MB sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Do not out drill the hole cleaning capacity. Perform clean up cycles or reduce ROP if packoffs, increase in pump pressure, or changes in hookload are seen. x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). x Perform gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. x Be prepared for gas hydrates. In MPU they have been encountered typically around 2,100- 2,400’ TVD (just below permafrost). Be prepared for hydrates: x Gas hydrates can be identified by the gas detector and a decrease in MW or ECD x Monitor returns for hydrates, checking pressurized & non-pressurized scales Page 14 Milne Point Unit S-204 Ugnu Producer PTD Application x Do not stop to circulate out gas hydrates – this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. x Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 11.4 12-1/4” hole mud program summary: Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface – Base Permafrost 8.9+ Base Permafrost - TD 9.2+ MW can be cut once ~500’ below hydrate zone x Rheology: M-I gel should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC UL should be used for filtrate control. Background LCM (10 ppb total) nut plug fine & medium, M-I-X II fine & medium can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability:Additions of SCREENKLEEN are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X-CIDE 207 MUST be made to control bacterial action. x Casing Running:Reduce system YP with TANNATHIN / CF DESCO II as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Page 15 Milne Point Unit S-204 Ugnu Producer PTD Application System Type:8.8 – 9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 – 9.8 75-175 20 - 40 25-45 <10 8.5 – 9.0 70 F System Formulation: Gel + FW spud mud Product Concentration Fresh Water soda Ash M-I GEL caustic soda SCREENKLEEN MI WATE PAC-UL /DEXTRID LT ALDACIDE G 0.967 bbl 0.125 ppb 35 ppb 0.1 ppb (8.5 – 9.0 pH) as needed as required for 8.8 – 9.2 ppg if required for <10 FL 0.1 ppb 11.5 PU 2-3 stands off bottom to avoid washing out the hole at TD, CBU, pump tandem sweeps and drop viscosity. 11.6 RIH to bottom, proceed to BROOH to HWDP x Pump at full drill rate (400-600 gpm), and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program planned. Page 16 Milne Point Unit S-204 Ugnu Producer PTD Application 12.0 Run 9-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U 9-5/8” casing running equipment (CRT & Tongs) x Ensure 9-5/8” TXP x NC50 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 8.5” on the location prior to running. x Note that 47# drift is 8.525” x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8” TXP, 2 Centralizers 10’ from each end w/ stop rings 1 joint –9-5/8” TXP, 1 Centralizer mid joint w/ stop ring 9-5/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint –9-5/8” TXP, 1 Centralizer mid joint with stop ring 9-5/8” HES Baffle Adaptor x Ensure bypass baffle is correctly installed on top of float collar. x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment and stage tool components. This end up. Bypass Baffle Page 17 Milne Point Unit S-204 Ugnu Producer PTD Application 12.5 Float equipment and Stage tool equipment drawings: Page 18 Milne Point Unit S-204 Ugnu Producer PTD Application 12.6 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint to ~ 1000’ MD from shoe x 1 centralizer every 2 joints to ~2,000’ above shoe x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost. x Install centralizers over couplings on 5 joints below and 5 joints above stage tool. x Do not place tongs on ES cementer, this can cause damaged to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. 9-5/8” 40# L-80 TXP Make-Up Torques: Casing OD Minimum Optimum Maximum 9-5/8”18,860 ft-lbs 20,960 ft-lbs 23,060 ft-lbs 9-5/8” 47# L-80 TXP MUT: Casing OD Minimum Optimum Maximum 9-5/8”21,440 ft-lbs 23,820 ft-lbs 26,200 ft-lbs Page 19 Milne Point Unit S-204 Ugnu Producer PTD Application Page 20 Milne Point Unit S-204 Ugnu Producer PTD Application 12.8 Continue running 9-5/8” surface casing x Centralizers: 1 centralizer every 3rd joint to 200’ from surface x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Ensure the permafrost is covered with 9-5/8” 47# from BPRF to Surface x Ensure drifted to 8.525” Page 21 Milne Point Unit S-204 Ugnu Producer PTD Application 12.10 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.11 Slow in and out of slips. 12.12 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.13 Lower casing to setting depth. Confirm measurements. 12.14 Have slips staged in cellar, along with necessary equipment for the operation. 12.15 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 22 Milne Point Unit S-204 Ugnu Producer PTD Application 13.0 Cement 9-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Total Cement Volume: Page 23 Milne Point Unit S-204 Ugnu Producer PTD Application Cement Slurry Design (1st Stage Cement Job): 13.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 13.10 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.11 Ensure rig pump is used to displace cement. To operate the stage tool hydraulically, the plug must be bumped. 13.12 Displacement calculation is in step 13.8 above. 80 bbls of tuned spacer to be left on top of stage tool so that the first fluid through the ES cementer is tuned spacer to minimize the risk of flash setting cement 13.13 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. Lead Slurry Tail Slurry System EconoCem HalCem Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mix Water 13.92 gal/sk 4.98 gal/sk Page 24 Milne Point Unit S-204 Ugnu Producer PTD Application 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 25 Milne Point Unit S-204 Ugnu Producer PTD Application Second Stage Surface Cement Job: 13.18 Prepare for the 2 nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre-job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2 nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. Lead Slurry Tail Slurry System ArcticCem HalCem Density 10.7 lb/gal 15.8 lb/gal Yield 2.88 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk Page 26 Milne Point Unit S-204 Ugnu Producer PTD Application 13.26 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.27 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.28 Land closing plug on stage collar and pressure up to 1,000 – 1,500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips. 13.29 Make initial cut on 9-5/8” final joint. L/D cut joint. Make final cut on 9-5/8”. Dress off stump. Install 9-5/8” wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on WellView: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Milne Point Unit S-204 Ugnu Producer PTD Application 14.0 ND Diverter, NU BOPE, & Test 14.1 ND the diverter T, knife gate, diverter line & NU 11” x 13-5/8” 5M casing spool. 14.2 NU 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 4-1/2” x 7” VBRs in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5” VBRs x NU bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 14.3 RU MPD RCD and related equipment 14.4 Run 5” BOP test plug 14.5 Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. x Test 4-1/2” x 7” rams with 5” and 7” test joints x Test 2-7/8” x 5” rams with the 3-1/2” and 5” test joints x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 RD BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix 8.9 ppg FloPro fluid for production hole. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. Page 28 Milne Point Unit S-204 Ugnu Producer PTD Application 15.0 Drill 8-1/2” Hole Section 15.1 If necessary, MU 8-1/2” cleanout BHA (Milltooth Bit & 1.22° PDM) 15.2 TIH w/ 8-1/2” cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2,500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5,750 / 2 = ~2,875 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20’ of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. x 12.0 ppg desired to cover shoe strength for expected ECD’s. A 9.9 ppg FIT is the minimum required to drill ahead x 9.8 ppg provides >25 bbls based on 9.5ppg MW, 8.46ppg PP (swab kick at 9.5ppg BHP) 15.8 POOH and LD cleanout BHA 15.9 PU 8-1/2” directional BHA. x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5” 19.5# S-135 NC50. x Run a ported float in the production hole section. Ugnu Bit Jetting Guidelines Formation Jetting TFA MB 3 x 15, 3 x 16 1.1068 * Email casing test and FIT digital data to AOGCC upon completion of FIT. - mgr Page 29 Milne Point Unit S-204 Ugnu Producer PTD Application 15.10 8-1/2” hole section mud program summary: x Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. x Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. x Rheology: Keep viscosifier additions to a minimum. Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge continuously while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type:8.8 – 9.8 ppg FloPro drilling fluid Properties: Interval Density PV YP LSYP Total Solids MBT HPHT Hardness Production 8.8-9.8 15-25 - ALAP 15 - 30 4-6 <10% <8 <11.0 <100 System Formulation: Product- production ppb or (% liquids) Water 0.916 bbls/bbl Soda Ash 0.17 ppb FLO-VIS PLUS 0.5 –0.75 ppb FLO-TROL 6.0 ppb Potassium Chloride (KCl)10.7 ppb SCREENKLEEN 0.5% v/v SAFE-CARB 20 10 ppb SAFE-CARB 40 10 ppb SALT As needed Onyxide 200 2.1 gals/100 bbls Sodium Metabisulfite 0.25 ppb Page 30 Milne Point Unit S-204 Ugnu Producer PTD Application 15.11 TIH with 8-1/2” directional assembly to bottom 15.12 Install MPD RCD 15.13 Displace wellbore to 8.9 ppg FloPro drilling fluid 15.14 Begin drilling 8-1/2” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 15.14 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 350-550 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor torque and drag with pumps on every stand (confirm frequency with co-man) x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Use ADR to stay in section. Reservoir plan is to stay in MB sand. x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x MPU S-31 has a 0.450 clearance factor. MPU S-31 is an active water injector in the Schrader OA and OB sands. The close approach occurs >4,000’ into the lateral at 9,656’ MD. S-31 will be shut-in and pressure bled down prior to drilling by. 15.15 Reference:Halliburton has a procedure for Schrader OH sidetracks based on lessons learned and best practices. Ensure the DD is referencing their procedure. x Patience is key! Getting kicked off too quickly might have been the cause of failed liner runs on past wells. x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so we have a nice place to low side. x Attempt to lowside in a fast drilling interval where the wellbore is headed up. x Orient TF to low side and dig a trough with high flowrates for the first 30 feet, working string back and forth. Trough for approximately 30 minutes. Page 31 Milne Point Unit S-204 Ugnu Producer PTD Application x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + Liner volume with viscosified brine. x Proposed brine blend (aiming for an 8 on the 6 RPM reading) - KCl: 7.1bbp for 2% NaCl: As needed Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42 ppb Flo-Vis Plus: 1.25 ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 15.15 Monitor the returned fluids carefully while displacing to brine. After 1 (or more if needed) BU, Perform production screen test (PST). The brine has been properly conditioned when it will pass the production screen test (x3 350 ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure 15.19 BROOH with the drilling assembly to the 9-5/8” casing shoe x Circulate at full drill rate (less if losses are seen, 350 GPM minimum). x Rotate at maximum RPM that can be sustained. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions Page 32 Milne Point Unit S-204 Ugnu Producer PTD Application x When pulling across any OHST depths, turn pumps off and rotary off to minimize disturbance. Trip back in hole past OHST depth to ensure liner will stay in correct hole section, check with ABI compared to as drilled surveys 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 15.22 Monitor well for flow/pressure build up with MPD. Increase fluid weight if necessary. x If necessary, increase MW at shoe for any higher than expected pressure seen x Ensure fluid coming out of hole has passed a PST at the possum belly 15.23 POOH and LD BHA. 15.24 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 33 Milne Point Unit S-204 Ugnu Producer PTD Application 16.0 Run Screened Liner NOTE: If an open hole sidetrack was performed, drop the centralizers on the lowermost 2-3 joints and run them slick. 16.1 Well control preparedness: In the event of an influx of formation fluids while running the screened liner, the following well control response procedure will be followed: x P/U & M/U the safety joint (with 5-1/2” crossover installed on bottom, TIW valve in open position on top, 5-1/2” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 5-1/2” screened liner. x Slack off and with the safety joint across the BOP, shut in ram or annular on the safety joint. Close TIW. x Proceed with well kill operations. 16.2 R/U 5-1/2” liner running equipment. x Ensure 5-1/2” x NC50 crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.3 Run 5-1/2” screened production liner x Use API Modified thread compound. Dope pin end only w/ paint brush. Wipe off excess. Thread compound can plug the screens x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. x Fill 5-½” liner with PST passed mud (to keep from plugging screens with solids) (use 100 micron coupon if 150 micron coupon is not available) x Install screen joints as per the Running Order (From Completion Engineer post TD). o Do not place tongs or slips on screen joints o Screen placement ±40’ x If liner length exceeds surface casing length, ensure centralizers are placed 1/jt for each joint outside of the surface shoe. This is to mitigate difference sticking risk while running inner string. x Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10 and 20 rpm 5-1/2” 17.0# L-80 JFE Bear HT Torque OD Minimum Optimum Maximum 5-1/2 9,000 ft-lbs 10,000 ft-lbs 11,000 ft-lbs Page 34 Milne Point Unit S-204 Ugnu Producer PTD Application Page 35 Milne Point Unit S-204 Ugnu Producer PTD Application 16.6. Ensure to run enough liner to provide for approx 150’ overlap inside 9-5/8” casing. Ensure hanger/pkr will not be set in a 9-5/8” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8” connection. 16.7. Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. M/U Baker SLZXP liner top packer to liner. 16.9. Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH with liner no faster than 30 ft/min – this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. x Ensure 5” DP/HWDP has been drifted x There is no inner string planned to be run, as opposed to previous wells. The DP should auto fill. Monitor FL and if filling is required due to losses/surging. 16.11. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.12. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. Break circulation. Begin circulating at ~1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating.Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. Page 36 Milne Point Unit S-204 Ugnu Producer PTD Application 16.18. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.19. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool. 16.20. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 16.21. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 16.22. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. PU pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 16.24. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned, LD DP on the TOOH. Note: Once running tool is LD, swap to the completion AFE. Page 37 Milne Point Unit S-204 Ugnu Producer PTD Application 17.0 Run 7” Tieback 17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install 7” solid body casing rams in the upper ram cavity. RU testing equipment. PT to 250/3,000 psi with 7” test joint. RD testing equipment. 17.2 RU 7” casing handling equipment. x Ensure XO to DP made up to FOSV and ready on rig floor. x Rig up computer torque monitoring service. x String should stay full while running, RU fill up line and check as appropriate. 17.3 PU 7” tieback seal assembly and set in rotary table. Ensure 7” seal assembly has (4) 1” holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8” x 7” annulus. 17.4 MU first joint of 7” to seal assy. 17.6 Run 7”, 26#, L-80 TXP tieback tieback to position seal assembly two joints above tieback sleeve. Record PU and SO weights. 7”, 26#, L-80, TXP =Casing OD Torque (Min) Torque (Opt)Torque (Max)Torque (Operating) 7”13,280 ft-lbs 14,750 ft-lbs 16,230 ft-lbs 20,000 ft-lbs Page 38 Milne Point Unit S-204 Ugnu Producer PTD Application Page 39 Milne Point Unit S-204 Ugnu Producer PTD Application 17.7 MU 7” to DP crossover. 17.8 MU stand of DP to string, and MU top drive. 17.9 Break circulation at 1 BPM and begin lowering string. 17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off pressure. Leave standpipe bleed off valve open. 17.11 Continue lowering string and land out on no-go. Set down 5 – 10K and mark the pipe as “NO- GO DEPTH”. 17.12 PU string & remove unnecessary 7” joints. 17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing hanger is landed. Ensure one full joint is below the casing hanger. 17.14 PU and MU the 7” casing hanger. 17.15 Ensure circulation is possible through 7” string. 17.16 RU and circulate corrosion inhibited brine in the 9-5/8” x 7” annulus. 17.17 With seals stabbed into tieback sleeve, spot diesel freeze protection from 2,500’ TVD to surface in 9-5/8” x 7” annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent collapse of the 7” casing (verify collapse pressure of 7” tieback seal assembly). 17.18 SO and land hanger. Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning report. 17.19 Back out the landing joint. MU packoff running tool and install packoff on bottom of landing joint. Set casing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes. 17.20 RD casing running tools. 17.21 PT 9-5/8” x 7” annulus to 1,500 psi for 30 minutes charted. Page 40 Milne Point Unit S-204 Ugnu Producer PTD Application 18.0 Run Upper Completion – Jet Pump 18.1 RU to run slotted 2-3/8” 4.44# L-80 W511 x 3-1/2”, 9.3#, L-80 EUE tubing. x Ensure wear bushing is pulled. x Ensure 2-3/8” 4.44# L-80 W511 x XT-39 and 3-1/2”, L-80, 12.6#, EUE x XT-39 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 18.2 PU, MU and RIH with the following 2-3/8” x 3-1/2” JP completion (confirm tally with Operations Engineer): x WLEG/Mule shoe x XX Joints, 2-3/8” 4.44# L-80 W511 x Attach cross collar clamps with 3 heater cables and 3 thermo couple 1/8” tec lines. x Crossover, 3-1/2”, EUE Box x 2-3/8” W511 Pin x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x Nipple, 2.813” XN profile (2.750” no-go), 3-1/2”, EUE (RHC plug body installed,Set at +- 70 degrees) x Pup joint, 3-1/2”, 9.3#, L-80 EUE x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x Convert over from 3 heater cables to ESP Cable. x Make up packer penetrators for the ESP cable and 3 tec lines. x Retrievable Packer, Baker, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Crossover, 4-1/2”, EUE Box x 3-1/2”, EUE Pin x Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd x Crossover, 3-1/2”, EUE Box x 4-1/2”, EUE 8rd Pin x 1 joint, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE Page 41 Milne Point Unit S-204 Ugnu Producer PTD Application x Sliding Sleeve, 3-1/2”, 9.3#, L-80 EUE x Pup joint, 3-1/2”, 9.3#, L-80 EUE x XXX joints, 3-1/2”, 9.3#, L-80 EUE 18.3 Terminate the ESP cable and make up the ESP penetrator to the ESP cable, (3) 1/8” tec lines and (1) ¼” BHP gauge tec line. 18.4 PU and MU the 3-1/2” tubing hanger. Make final splice of the 4 (3 TEC wire and 1 for DH gauge) ensure any unused control line ports are dummied off. 18.5 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.6 Land the tubing hanger and RILDS. Lay down the landing joint. 18.7 Install 3-1/2” HP BPV. ND BOP. Install the plug off tool. 18.8 NU the tubing head adapter and NU the tree. 18.9 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 18.10 Pull the plug off tool and BPV. 18.11 Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 18.12 Drop the ball & rod. 18.13 Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). 18.14 Bleed the tubing pressure to 2,000 psi and PT the IA to 3,700 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 18.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.16 RDMO * Separate completion sundry required to POP this well with jet pump. - mgr Page 42 Milne Point Unit S-204 Ugnu Producer PTD Application 19.0 Doyon 14 Diverter Schematic Page 43 Milne Point Unit S-204 Ugnu Producer PTD Application 20.0 Doyon 14 BOP Schematic 2-7/8” x 5” VBR Page 44 Milne Point Unit S-204 Ugnu Producer PTD Application 21.0 Wellhead Schematic X 3 3 3 Page 45 Milne Point Unit S-204 Ugnu Producer PTD Application 22.0 Days Vs Depth Page 46 Milne Point Unit S-204 Ugnu Producer PTD Application 23.0 Formation Tops & Information TOP NAME MD (FT) TVD (FT) TVDSS (FT) Formation Pressure (psi) EMW (ppg) Base Permafrost 2,016 1,820 -1,750 801 8.46 SV1 2,613 2,350 -2,280 1034 8.46 UG4 3,032 2,752 -2,682 1211 8.46 UG_MB 4,890 3,873 -3,803 1704 8.46 Page 47 Milne Point Unit S-204 Ugnu Producer PTD Application S-Pad Data Sheet Formation Description Page 48 Milne Point Unit S-204 Ugnu Producer PTD Application 24.0 Anticipated Drilling Hazards 12-1/4” 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 Gas hydrates are generally not seen on S-pad. 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. 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 our ability to clean the hole. Anti-Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Well Specific A/C: x There are no wells with a clearance factor of <1.0 Wellbore stability (Permafrost, running sands and gravel, conductor broaching): 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 pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. Page 49 Milne Point Unit S-204 Ugnu Producer PTD Application H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 50 Milne Point Unit S-204 Ugnu Producer PTD Application 8-1/2” 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. Maint. circulation rate of > 300 gpm 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: There is 1 planned fault crossing for S-204. The expected throw for the fault is 20’. H2S: Treat every hole section as though it has the potential for H2S. Three samples containing H2S have been captured on MPU S-pad. S-08 had 50 ppm measured in 2012. S-12 had 28.9 ppm measured in 2012. S-39 had 2 ppm measured in 2014. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 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. Well Specific AC: x MPU S-31 has a 0.450 clearance factor. MPU S-31 is an active water injector in the Schrader OA and OB sands. The close approach occurs >4,000’ into the lateral at 9,656’ MD. S-31 will be shut-in and pressure bled down prior to drilling by. Page 51 Milne Point Unit S-204 Ugnu Producer PTD Application 25.0 Doyon 14 Rig Layout Page 52 Milne Point Unit S-204 Ugnu Producer PTD Application 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 53 Milne Point Unit S-204 Ugnu Producer PTD Application 27.0 Doyon 14 Rig Choke Manifold Schematic Page 54 Milne Point Unit S-204 Ugnu Producer PTD Application 28.0 Casing Design Page 55 Milne Point Unit S-204 Ugnu Producer PTD Application 29.0 8-1/2” Hole Section MASP Page 56 Milne Point Unit S-204 Ugnu Producer PTD Application 30.0 Spider Plot (NAD 27) (Governmental Sections) Page 57 Milne Point Unit S-204 Ugnu Producer PTD Application 31.0 Surface Plat (As Built) (NAD 27) Standard Proposal Report 03 February, 2025 Plan: MPU S-204 wp17 Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S-204 MPU S-204 0 425 850 1275 1700 2125 2550 2975 3400 3825True Vertical Depth (850 usft/in)-850 -425 0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 6800 7225 Vertical Section at 270.00° (850 usft/in) MPU S-204 wp12 tgt13 MPU S-204 wp12 tgt05 MPU S-204 wp12 tgt10 MPU S-204 wp12 tgt01 MPU S-204 wp12 tgt11 MPU S-204 wp12 tgt08 MPU S-204 wp12 tgt12MPU S-204 wp12 tgt04 MPU S-204 wp12 tgt07 MPU S-204 wp12 tgt02 MPU S-204 wp12 tgt03 MPU S-204 wp12 tgt06 MPU S-204 wp12 tgt09 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 500 1000 1500 2000 250 0 3000 3500 400045005000550060006500700075008000850090009500100001050010970MPU S-204 wp17 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 500' MD, 499.29'TVD Start Dir 4.5º/100' : 700' MD, 695.12'TVD Start Dir 5º/100' : 1000' MD, 972.74'TVD End Dir : 1696.83' MD, 1537.86' TVD Start Dir 5º/100' : 2512.99' MD, 2259.79'TVD End Dir : 4784.89' MD, 3869.71' TVD Begin Geosteering Fault 1 (10'-20' DTE) Fault 2A (10'-20' DTE)Fault 2B (10'-20' DTW)Total Depth : 10970.46' MD, 3663.01' SV6 SV4 Permafrost SV1 UG4A LA3 MB Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: MPU S-204 36.30+N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999900.83 565537.07 70° 24' 36.6398 N 149° 27' 58.8729 W SURVEY PROGRAM Date: 2022-10-28T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 33.70 1200.00 MPU S-204 wp17 (MPU S-204) GYD_Quest GWD 1200.00 4889.00 MPU S-204 wp17 (MPU S-204) 3_MWD+IFR2+MS+Sag 4889.00 10970.46 MPU S-204 wp17 (MPU S-204) 3_MWD+IFR2+MS+Sag REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-204, True North Vertical (TVD) Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Measured Depth Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Calculation Method: Minimum Curvature Project:Milne Point Site:M Pt S Pad Well:Plan: MPU S-204 Wellbore:MPU S-204 Design:MPU S-204 wp17 CASING DETAILS TVD TVDSS MD Size Name 3873.32 3803.32 4888.34 9-5/8 9 5/8" x 12 1/4" 3663.01 3593.01 10970.46 4-1/2 4 1/2" x 8 1/2" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 3 500.00 7.50 150.00 499.29 -14.15 8.17 3.00 150.00 -8.17 Start Dir 4º/100' : 500' MD, 499.29'TVD 4 700.00 15.49 147.40 695.12 -48.00 29.12 4.00 -5.00 -29.12 Start Dir 4.5º/100' : 700' MD, 695.12'TVD 5 1000.00 28.54 137.78 972.74 -135.21 99.18 4.50 -20.00 -99.18 Start Dir 5º/100' : 1000' MD, 972.74'TVD 6 1300.00 43.38 134.02 1214.92 -260.59 222.12 5.00 -10.00 -222.12 7 1696.83 27.80 112.36 1537.86 -391.81 407.57 5.00 -149.51 -407.57 End Dir : 1696.83' MD, 1537.86' TVD 8 2512.99 27.80 112.36 2259.79 -536.62 759.66 0.00 0.00 -759.66 Start Dir 5º/100' : 2512.99' MD, 2259.79'TVD 9 4784.89 88.00 270.00 3869.71 -847.28 -234.87 5.00 155.49 234.87 End Dir : 4784.89' MD, 3869.71' TVD 10 5074.89 88.00 270.00 3879.83 -847.28 -524.70 0.00 0.00 524.70 MPU S-204 wp12 tgt01 11 5378.12 96.90 271.87 3866.87 -842.36 -827.29 3.00 11.81 827.29 12 5613.56 96.90 271.87 3838.57 -834.74 -1060.90 0.00 0.00 1060.90 13 5777.48 92.00 271.50 3825.85 -829.94 -1224.20 3.00 -175.70 1224.20 14 5877.48 92.00 271.50 3822.36 -827.32 -1324.11 0.00 0.00 1324.11 MPU S-204 wp12 tgt03 15 5921.69 93.04 271.13 3820.42 -826.31 -1368.26 2.50 -19.78 1368.26 16 6430.48 93.04 271.13 3793.43 -816.33 -1876.24 0.00 0.00 1876.24 17 6468.68 92.80 270.20 3791.49 -815.89 -1914.39 2.50 -104.54 1914.39 18 6895.43 92.80 270.20 3770.64 -814.40 -2340.63 0.00 0.00 2340.63 MPU S-204 wp12 tgt05 19 6948.32 93.92 270.91 3767.54 -813.89 -2393.42 2.50 32.40 2393.42 20 7376.39 93.92 270.91 3738.31 -807.11 -2820.44 0.00 0.00 2820.44 21 7413.99 93.00 270.70 3736.04 -806.58 -2857.96 2.50 -167.10 2857.96 22 7913.99 93.00 270.70 3709.87 -800.48 -3357.24 0.00 0.00 3357.24 MPU S-204 wp12 tgt07 23 7961.76 91.81 270.85 3707.86 -799.84 -3404.96 2.50 172.89 3404.96 24 8422.52 91.81 270.85 3693.27 -793.02 -3865.44 0.00 0.00 3865.44 MPU S-204 wp12 tgt08 25 8714.09 91.39 279.59 3685.11 -766.54 -4155.41 3.00 92.69 4155.41 26 8798.60 91.39 279.59 3683.07 -752.47 -4238.71 0.00 0.00 4238.71 27 9193.62 88.90 268.00 3682.08 -726.38 -4632.17 3.00 -102.05 4632.17 28 9443.62 88.90 268.00 3686.88 -735.10 -4881.97 0.00 0.00 4881.97 MPU S-204 wp12 tgt10 29 9553.10 89.43 264.76 3688.48 -742.01 -4991.20 3.00 -80.73 4991.20 30 9765.20 89.43 264.76 3690.58 -761.39 -5202.41 0.00 0.00 5202.41 31 9982.18 92.50 270.50 3686.93 -770.36 -5419.06 3.00 61.84 5419.06 32 10462.18 92.50 270.50 3665.99 -766.18 -5898.58 0.00 0.00 5898.58 MPU S-204 wp12 tgt12 33 10540.80 90.15 270.75 3664.17 -765.32 -5977.16 3.00 173.98 5977.16 34 10970.46 90.15 270.75 3663.01 -759.72 -6406.79 0.00 0.00 6406.79 MPU S-204 wp12 tgt13Total Depth : 10970.46' MD, 3663.01' TVD FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 852.82 782.82 866.96 SV6 1603.38 1533.38 1770.90 SV4 1820.00 1750.00 2015.79 Permafrost 2350.42 2280.42 2613.46 SV1 2752.33 2682.33 3031.95 UG4A 3652.29 3582.29 4099.76 LA3 3873.36 3803.36 4889.50 MB -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 2000 2400 South(-)/North(+) (800 usft/in)-6400 -6000 -5600 -5200 -4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 400 800 West(-)/East(+) (800 usft/in) MPU S-204 wp12 tgt09 MPU S-204 wp12 tgt06 MPU S-204 wp12 tgt03 MPU S-204 wp12 tgt02MPU S-204 wp12 tgt07 MPU S-204 wp12 tgt04 MPU S-204 wp12 tgt12 MPU S-204 wp12 tgt08MPU S-204 wp12 tgt11 MPU S-204 wp12 tgt01 MPU S-204 wp12 tgt10 MPU S-204 wp12 tgt05MPU S-204 wp12 tgt13 9 5/8" x 12 1/4" 4 1/2" x 8 1/2"75010001250175022502750 3250350037503663MPU S-204 wp17 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 500' MD, 499.29'TVD Start Dir 4.5º/100' : 700' MD, 695.12'TVD Start Dir 5º/100' : 1000' MD, 972.74'TVD End Dir : 1696.83' MD, 1537.86' TVD Start Dir 5º/100' : 2512.99' MD, 2259.79'TVD End Dir : 4784.89' MD, 3869.71' TVD Begin Geosteering Fault 1 (10'-20' DTE)Fault 2A (10'-20' DTE) Fault 2B (10'-20' DTW) Total Depth : 10970.46' MD, 3663.01' TVD CASING DETAILS TVD TVDSS MD Size Name 3873.32 3803.32 4888.34 9-5/8 9 5/8" x 12 1/4" 3663.01 3593.01 10970.46 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-204 Wellbore: MPU S-204 Plan: MPU S-204 wp17 WELL DETAILS: Plan: MPU S-204 36.30 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999900.83 565537.07 70° 24' 36.6398 N 149° 27' 58.8729 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-204, True NorthVertical (TVD) Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Measured Depth Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev)Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: M Pt S Pad usft Map usft usft °0.51Slot Radius:"0 5,999,978.00 566,345.00 5.00 70° 24' 37.3286 N 149° 27' 35.1708 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPU S-204 usft usft 0.00 0.00 5,999,900.83 565,537.07 36.30Wellhead Elevation:usft0.50 70° 24' 36.6398 N 149° 27' 58.8729 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU S-204 Model NameMagnetics BGGM2024 4/28/2025 13.74 80.65 57,184.29233696 Phase:Version: Audit Notes: Design MPU S-204 wp17 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:33.70 270.000.000.0033.70 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.000.000.0033.700.000.0033.70 -36.30 0.000.000.000.000.000.00250.000.000.00250.00 180.00 150.000.003.003.008.17-14.15499.29150.007.50500.00 429.29 -5.00-1.303.994.0029.12-48.00695.12147.4015.49700.00 625.12 -20.00-3.214.354.5099.18-135.21972.74137.7828.541,000.00 902.74 -10.00-1.254.955.00222.12-260.591,214.92134.0243.381,300.00 1,144.92 -149.51-5.46-3.935.00407.57-391.811,537.86112.3627.801,696.83 1,467.86 0.000.000.000.00759.66-536.622,259.79112.3627.802,512.99 2,189.79 155.496.942.655.00-234.87-847.283,869.71270.0088.004,784.89 3,799.71 0.000.000.000.00-524.70-847.283,879.83270.0088.005,074.89 3,809.83 11.810.622.943.00-827.29-842.363,866.87271.8796.905,378.12 3,796.87 0.000.000.000.00-1,060.90-834.743,838.57271.8796.905,613.56 3,768.57 -175.70-0.22-2.993.00-1,224.20-829.943,825.85271.5092.005,777.48 3,755.85 0.000.000.000.00-1,324.11-827.323,822.36271.5092.005,877.48 3,752.36 -19.78-0.852.352.50-1,368.26-826.313,820.42271.1393.045,921.69 3,750.42 0.000.000.000.00-1,876.24-816.333,793.43271.1393.046,430.48 3,723.43 -104.54-2.42-0.632.50-1,914.39-815.893,791.49270.2092.806,468.68 3,721.49 0.000.000.000.00-2,340.63-814.403,770.64270.2092.806,895.43 3,700.64 32.401.342.112.50-2,393.42-813.893,767.54270.9193.926,948.32 3,697.54 0.000.000.000.00-2,820.44-807.113,738.31270.9193.927,376.39 3,668.31 -167.10-0.56-2.442.50-2,857.96-806.583,736.04270.7093.007,413.99 3,666.04 0.000.000.000.00-3,357.24-800.483,709.87270.7093.007,913.99 3,639.87 172.890.31-2.482.50-3,404.96-799.843,707.86270.8591.817,961.76 3,637.86 0.000.000.000.00-3,865.44-793.023,693.27270.8591.818,422.52 3,623.27 92.693.00-0.153.00-4,155.41-766.543,685.11279.5991.398,714.09 3,615.11 0.000.000.000.00-4,238.71-752.473,683.07279.5991.398,798.60 3,613.07 -102.05-2.93-0.633.00-4,632.17-726.383,682.08268.0088.909,193.62 3,612.08 0.000.000.000.00-4,881.97-735.103,686.88268.0088.909,443.62 3,616.88 -80.73-2.960.483.00-4,991.20-742.013,688.48264.7689.439,553.10 3,618.48 0.000.000.000.00-5,202.41-761.393,690.58264.7689.439,765.20 3,620.58 61.842.651.413.00-5,419.06-770.363,686.93270.5092.509,982.18 3,616.93 0.000.000.000.00-5,898.58-766.183,665.99270.5092.5010,462.18 3,595.99 173.980.31-2.983.00-5,977.16-765.323,664.17270.7590.1510,540.80 3,594.17 0.000.000.000.00-6,406.79-759.723,663.01270.7590.1510,970.46 3,593.01 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -36.30 Vert Section 33.70 0.00 33.70 0.00 0.000.00 565,537.075,999,900.83-36.30 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 565,537.075,999,900.8330.00 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 565,537.075,999,900.83130.00 0.00 0.00 250.00 0.00 250.00 0.00 0.000.00 565,537.075,999,900.83180.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 300.00 1.50 299.99 -0.57 0.33150.00 565,537.405,999,900.27229.99 3.00 -0.33 400.00 4.50 399.85 -5.10 2.94150.00 565,540.065,999,895.76329.85 3.00 -2.94 500.00 7.50 499.29 -14.15 8.17150.00 565,545.365,999,886.75429.29 3.00 -8.17 Start Dir 4º/100' : 500' MD, 499.29'TVD 600.00 11.49 597.90 -28.28 16.68148.25 565,553.995,999,872.70527.90 4.00 -16.68 700.00 15.49 695.12 -48.00 29.12147.40 565,566.605,999,853.09625.12 4.00 -29.12 Start Dir 4.5º/100' : 700' MD, 695.12'TVD 800.00 19.77 790.41 -72.74 46.53142.85 565,584.245,999,828.51720.41 4.50 -46.53 866.96 22.69 852.82 -91.77 61.55140.74 565,599.425,999,809.61782.82 4.50 -61.55 SV6 900.00 24.13 883.13 -101.87 69.94139.88 565,607.895,999,799.59813.13 4.50 -69.94 1,000.00 28.54 972.74 -135.21 99.18137.78 565,637.425,999,766.51902.74 4.50 -99.18 Start Dir 5º/100' : 1000' MD, 972.74'TVD 1,100.00 33.47 1,058.42 -172.82 134.34136.20 565,672.915,999,729.21988.42 5.00 -134.34 1,200.00 38.42 1,139.36 -214.72 175.42134.99 565,714.365,999,687.671,069.36 5.00 -175.42 1,300.00 43.38 1,214.92 -260.59 222.12134.02 565,761.455,999,642.231,144.92 5.00 -222.12 1,400.00 39.14 1,290.08 -304.77 271.02130.01 565,810.735,999,598.481,220.08 5.00 -271.02 1,500.00 35.06 1,369.84 -341.64 318.70125.20 565,858.725,999,562.031,299.84 5.00 -318.70 1,600.00 31.22 1,453.58 -370.92 364.79119.34 565,905.065,999,533.161,383.58 5.00 -364.79 1,696.83 27.80 1,537.86 -391.81 407.57112.36 565,948.025,999,512.641,467.86 5.00 -407.57 End Dir : 1696.83' MD, 1537.86' TVD 1,700.00 27.80 1,540.67 -392.38 408.94112.36 565,949.405,999,512.091,470.67 0.00 -408.94 1,770.90 27.80 1,603.38 -404.95 439.52112.36 565,980.095,999,499.791,533.38 0.00 -439.52 SV4 1,800.00 27.80 1,629.12 -410.12 452.08112.36 565,992.695,999,494.731,559.12 0.00 -452.08 1,900.00 27.80 1,717.58 -427.86 495.22112.36 566,035.985,999,477.371,647.58 0.00 -495.22 2,000.00 27.80 1,806.03 -445.60 538.36112.36 566,079.275,999,460.011,736.03 0.00 -538.36 2,015.79 27.80 1,820.00 -448.40 545.17112.36 566,086.105,999,457.271,750.00 0.00 -545.17 Permafrost 2,100.00 27.80 1,894.48 -463.34 581.50112.36 566,122.565,999,442.651,824.48 0.00 -581.50 2,200.00 27.80 1,982.94 -481.09 624.64112.36 566,165.855,999,425.291,912.94 0.00 -624.64 2,300.00 27.80 2,071.39 -498.83 667.78112.36 566,209.145,999,407.932,001.39 0.00 -667.78 2,400.00 27.80 2,159.85 -516.57 710.92112.36 566,252.435,999,390.572,089.85 0.00 -710.92 2,500.00 27.80 2,248.30 -534.31 754.06112.36 566,295.725,999,373.202,178.30 0.00 -754.06 2,512.99 27.80 2,259.79 -536.62 759.66112.36 566,301.345,999,370.952,189.79 0.00 -759.66 Start Dir 5º/100' : 2512.99' MD, 2259.79'TVD 2,600.00 23.91 2,338.08 -552.30 794.19116.81 566,335.995,999,355.582,268.08 5.00 -794.19 2,613.46 23.32 2,350.42 -554.76 798.98117.62 566,340.815,999,353.152,280.42 5.00 -798.98 SV1 2,700.00 19.65 2,430.94 -570.83 826.25123.92 566,368.215,999,337.332,360.94 5.00 -826.25 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 2,456.19 Vert Section 2,800.00 15.82 2,526.19 -589.78 849.93134.52 566,392.065,999,318.592,456.19 5.00 -849.93 2,900.00 12.78 2,623.12 -609.00 865.07150.75 566,407.365,999,299.502,553.12 5.00 -865.07 3,000.00 11.23 2,720.99 -628.35 871.53173.79 566,413.995,999,280.212,650.99 5.00 -871.53 3,031.95 11.16 2,752.33 -634.53 871.76182.02 566,414.285,999,274.032,682.33 5.00 -871.76 UG4A 3,100.00 11.75 2,819.05 -647.67 869.27198.95 566,411.915,999,260.872,749.05 5.00 -869.27 3,200.00 14.12 2,916.55 -666.82 858.31218.79 566,401.125,999,241.632,846.55 5.00 -858.31 3,300.00 17.61 3,012.75 -685.66 838.74231.99 566,381.715,999,222.622,942.75 5.00 -838.74 3,400.00 21.69 3,106.93 -704.04 810.69240.66 566,353.835,999,203.993,036.93 5.00 -810.69 3,500.00 26.07 3,198.36 -721.83 774.39246.62 566,317.695,999,185.903,128.36 5.00 -774.39 3,600.00 30.64 3,286.35 -738.87 730.11250.94 566,273.565,999,168.463,216.35 5.00 -730.11 3,700.00 35.31 3,370.23 -755.06 678.18254.23 566,221.795,999,151.823,300.23 5.00 -678.18 3,800.00 40.05 3,449.36 -770.26 619.01256.82 566,162.765,999,136.113,379.36 5.00 -619.01 3,900.00 44.84 3,523.13 -784.35 553.04258.96 566,096.925,999,121.433,453.13 5.00 -553.04 4,000.00 49.66 3,591.00 -797.24 480.78260.75 566,024.785,999,107.923,521.00 5.00 -480.78 4,099.76 54.50 3,652.29 -808.79 402.97262.31 565,947.085,999,095.683,582.29 5.00 -402.97 LA3 4,100.00 54.51 3,652.43 -808.82 402.77262.31 565,946.885,999,095.653,582.43 5.00 -402.77 4,200.00 59.37 3,706.97 -819.00 319.61263.69 565,863.825,999,084.743,636.97 5.00 -319.61 4,300.00 64.25 3,754.19 -827.71 231.93264.94 565,776.235,999,075.263,684.19 5.00 -231.93 4,400.00 69.14 3,793.75 -834.88 140.40266.08 565,684.775,999,067.293,723.75 5.00 -140.40 4,500.00 74.03 3,825.33 -840.46 45.71267.16 565,590.155,999,060.893,755.33 5.00 -45.71 4,600.00 78.93 3,848.69 -844.40 -51.41268.18 565,493.085,999,056.093,778.69 5.00 51.41 4,700.00 83.84 3,863.67 -846.67 -150.22269.17 565,394.305,999,052.963,793.67 5.00 150.22 4,784.89 88.00 3,869.71 -847.28 -234.87270.00 565,309.665,999,051.603,799.71 5.00 234.87 End Dir : 4784.89' MD, 3869.71' TVD 4,800.00 88.00 3,870.24 -847.28 -249.97270.00 565,294.565,999,051.473,800.24 0.00 249.97 4,888.34 88.00 3,873.32 -847.28 -338.26270.00 565,206.295,999,050.703,803.32 0.00 338.26 9 5/8" x 12 1/4" 4,889.10 88.00 3,873.35 -847.28 -339.02270.00 565,205.535,999,050.693,803.35 0.00 339.02 Begin Geosteering 4,889.50 88.00 3,873.36 -847.28 -339.42270.00 565,205.135,999,050.693,803.36 0.00 339.42 MB 4,900.00 88.00 3,873.73 -847.28 -349.91270.00 565,194.645,999,050.593,803.73 0.00 349.91 4,928.00 88.00 3,874.70 -847.28 -377.90270.00 565,166.665,999,050.353,804.70 0.00 377.90 Fault 1 (10'-20' DTE) 5,000.00 88.00 3,877.22 -847.28 -449.85270.00 565,094.715,999,049.723,807.22 0.00 449.85 5,074.89 88.00 3,879.83 -847.28 -524.70270.00 565,019.885,999,049.063,809.83 0.00 524.70 5,100.00 88.74 3,880.54 -847.24 -549.80270.15 564,994.785,999,048.873,810.54 3.00 549.80 5,200.00 91.67 3,880.19 -846.44 -649.78270.77 564,894.805,999,048.803,810.19 3.00 649.78 5,300.00 94.61 3,874.71 -844.57 -749.60271.38 564,794.985,999,049.803,804.71 3.00 749.60 5,378.12 96.90 3,866.87 -842.36 -827.29271.87 564,717.285,999,051.323,796.87 3.00 827.29 5,400.00 96.90 3,864.24 -841.65 -849.00271.87 564,695.575,999,051.843,794.24 0.00 849.00 5,500.00 96.90 3,852.22 -838.41 -948.22271.87 564,596.335,999,054.213,782.22 0.00 948.22 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,779.52 Vert Section 5,522.50 96.90 3,849.52 -837.69 -970.55271.87 564,574.005,999,054.743,779.52 0.00 970.55 Fault 2A (10'-20' DTE) 5,600.00 96.90 3,840.20 -835.18 -1,047.45271.87 564,497.095,999,056.573,770.20 0.00 1,047.45 5,613.56 96.90 3,838.57 -834.74 -1,060.90271.87 564,483.635,999,056.893,768.57 0.00 1,060.90 5,700.00 94.32 3,830.12 -832.08 -1,146.88271.67 564,397.655,999,058.803,760.12 3.00 1,146.88 5,777.48 92.00 3,825.85 -829.94 -1,224.20271.50 564,320.315,999,060.263,755.85 3.00 1,224.20 5,800.00 92.00 3,825.06 -829.35 -1,246.70271.50 564,297.815,999,060.653,755.06 0.00 1,246.70 5,877.48 92.00 3,822.36 -827.32 -1,324.11271.50 564,220.405,999,062.003,752.36 0.00 1,324.11 5,900.00 92.53 3,821.47 -826.77 -1,346.61271.31 564,197.905,999,062.353,751.47 2.50 1,346.61 5,921.69 93.04 3,820.42 -826.31 -1,368.26271.13 564,176.245,999,062.623,750.42 2.50 1,368.26 6,000.00 93.04 3,816.26 -824.77 -1,446.45271.13 564,098.055,999,063.473,746.26 0.00 1,446.45 6,100.00 93.04 3,810.96 -822.81 -1,546.29271.13 563,998.215,999,064.563,740.96 0.00 1,546.29 6,200.00 93.04 3,805.66 -820.85 -1,646.13271.13 563,898.365,999,065.643,735.66 0.00 1,646.13 6,300.00 93.04 3,800.35 -818.89 -1,745.97271.13 563,798.525,999,066.733,730.35 0.00 1,745.97 6,400.00 93.04 3,795.05 -816.93 -1,845.81271.13 563,698.685,999,067.813,725.05 0.00 1,845.81 6,430.48 93.04 3,793.43 -816.33 -1,876.24271.13 563,668.245,999,068.153,723.43 0.00 1,876.24 6,468.68 92.80 3,791.49 -815.89 -1,914.39270.20 563,630.105,999,068.253,721.49 2.50 1,914.39 6,500.00 92.80 3,789.96 -815.78 -1,945.67270.20 563,598.825,999,068.093,719.96 0.00 1,945.67 6,600.00 92.80 3,785.07 -815.43 -2,045.55270.20 563,498.955,999,067.563,715.07 0.00 2,045.55 6,700.00 92.80 3,780.19 -815.08 -2,145.43270.20 563,399.085,999,067.033,710.19 0.00 2,145.43 6,800.00 92.80 3,775.30 -814.73 -2,245.31270.20 563,299.215,999,066.503,705.30 0.00 2,245.31 6,895.43 92.80 3,770.64 -814.40 -2,340.63270.20 563,203.905,999,066.003,700.64 0.00 2,340.63 6,900.00 92.90 3,770.41 -814.38 -2,345.19270.26 563,199.345,999,065.983,700.41 2.50 2,345.19 6,948.32 93.92 3,767.54 -813.89 -2,393.42270.91 563,151.115,999,066.053,697.54 2.50 2,393.42 7,000.00 93.92 3,764.01 -813.07 -2,444.97270.91 563,099.565,999,066.413,694.01 0.00 2,444.97 7,100.00 93.92 3,757.18 -811.49 -2,544.73270.91 562,999.805,999,067.123,687.18 0.00 2,544.73 7,200.00 93.92 3,750.35 -809.90 -2,644.48270.91 562,900.055,999,067.833,680.35 0.00 2,644.48 7,300.00 93.92 3,743.52 -808.32 -2,744.24270.91 562,800.295,999,068.543,673.52 0.00 2,744.24 7,376.39 93.92 3,738.31 -807.11 -2,820.44270.91 562,724.095,999,069.083,668.31 0.00 2,820.44 7,400.00 93.34 3,736.81 -806.76 -2,844.00270.78 562,700.535,999,069.223,666.81 2.50 2,844.00 7,413.99 93.00 3,736.04 -806.58 -2,857.96270.70 562,686.565,999,069.283,666.04 2.50 2,857.96 7,500.00 93.00 3,731.54 -805.53 -2,943.85270.70 562,600.685,999,069.583,661.54 0.00 2,943.85 7,600.00 93.00 3,726.30 -804.31 -3,043.71270.70 562,500.835,999,069.923,656.30 0.00 3,043.71 7,700.00 93.00 3,721.07 -803.09 -3,143.56270.70 562,400.975,999,070.263,651.07 0.00 3,143.56 7,800.00 93.00 3,715.84 -801.87 -3,243.42270.70 562,301.125,999,070.613,645.84 0.00 3,243.42 7,900.00 93.00 3,710.60 -800.65 -3,343.27270.70 562,201.275,999,070.953,640.60 0.00 3,343.27 7,913.99 93.00 3,709.87 -800.48 -3,357.24270.70 562,187.305,999,071.003,639.87 0.00 3,357.24 7,961.76 91.81 3,707.86 -799.84 -3,404.96270.85 562,139.585,999,071.233,637.86 2.50 3,404.96 8,000.00 91.81 3,706.65 -799.27 -3,443.18270.85 562,101.365,999,071.463,636.65 0.00 3,443.18 8,100.00 91.81 3,703.48 -797.79 -3,543.12270.85 562,001.425,999,072.063,633.48 0.00 3,543.12 8,200.00 91.81 3,700.32 -796.31 -3,643.06270.85 561,901.485,999,072.663,630.32 0.00 3,643.06 8,300.00 91.81 3,697.15 -794.83 -3,743.00270.85 561,801.555,999,073.263,627.15 0.00 3,743.00 8,400.00 91.81 3,693.98 -793.35 -3,842.94270.85 561,701.615,999,073.863,623.98 0.00 3,842.94 8,422.52 91.81 3,693.27 -793.02 -3,865.44270.85 561,679.105,999,074.003,623.27 0.00 3,865.44 8,500.00 91.70 3,690.89 -790.31 -3,942.83273.17 561,601.705,999,076.043,620.89 3.00 3,942.83 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,618.04 Vert Section 8,600.00 91.56 3,688.04 -782.17 -4,042.45276.17 561,502.025,999,083.303,618.04 3.00 4,042.45 8,700.00 91.41 3,685.46 -768.83 -4,141.51279.17 561,402.865,999,095.763,615.46 3.00 4,141.51 8,714.09 91.39 3,685.11 -766.54 -4,155.41279.59 561,388.945,999,097.943,615.11 3.00 4,155.41 8,798.60 91.39 3,683.07 -752.47 -4,238.71279.59 561,305.535,999,111.273,613.07 0.00 4,238.71 8,800.00 91.38 3,683.03 -752.23 -4,240.09279.55 561,304.145,999,111.493,613.03 3.00 4,240.09 8,900.00 90.75 3,681.18 -738.18 -4,339.07276.61 561,205.055,999,124.683,611.18 3.00 4,339.07 9,000.00 90.12 3,680.42 -729.21 -4,438.66273.68 561,105.405,999,132.773,610.42 3.00 4,438.66 9,100.00 89.49 3,680.76 -725.35 -4,538.57270.75 561,005.475,999,135.753,610.76 3.00 4,538.57 9,193.62 88.90 3,682.08 -726.38 -4,632.17268.00 560,911.905,999,133.913,612.08 3.00 4,632.17 9,200.00 88.90 3,682.20 -726.60 -4,638.54268.00 560,905.525,999,133.633,612.20 0.00 4,638.54 9,300.00 88.90 3,684.12 -730.09 -4,738.46268.00 560,805.655,999,129.263,614.12 0.00 4,738.46 9,400.00 88.90 3,686.04 -733.58 -4,838.38268.00 560,705.775,999,124.903,616.04 0.00 4,838.38 9,443.62 88.90 3,686.88 -735.10 -4,881.97268.00 560,662.215,999,122.993,616.88 0.00 4,881.97 9,495.00 89.15 3,687.76 -737.57 -4,933.28266.48 560,610.925,999,120.073,617.76 3.00 4,933.28 Fault 2B (10'-20' DTW) 9,500.00 89.17 3,687.83 -737.89 -4,938.27266.33 560,605.945,999,119.713,617.83 3.00 4,938.27 9,553.10 89.43 3,688.48 -742.01 -4,991.20264.76 560,553.055,999,115.123,618.48 3.00 4,991.20 9,600.00 89.43 3,688.94 -746.30 -5,037.90264.76 560,506.395,999,110.433,618.94 0.00 5,037.90 9,700.00 89.43 3,689.94 -755.43 -5,137.48264.76 560,406.905,999,100.423,619.94 0.00 5,137.48 9,765.20 89.43 3,690.58 -761.39 -5,202.41264.76 560,342.045,999,093.903,620.58 0.00 5,202.41 9,800.00 89.92 3,690.78 -764.29 -5,237.08265.68 560,307.395,999,090.693,620.78 3.00 5,237.08 9,900.00 91.34 3,689.68 -769.52 -5,336.93268.32 560,207.615,999,084.593,619.68 3.00 5,336.93 9,982.18 92.50 3,686.93 -770.36 -5,419.06270.50 560,125.505,999,083.023,616.93 3.00 5,419.06 10,000.00 92.50 3,686.15 -770.21 -5,436.85270.50 560,107.705,999,083.023,616.15 0.00 5,436.85 10,100.00 92.50 3,681.79 -769.34 -5,536.75270.50 560,007.815,999,083.023,611.79 0.00 5,536.75 10,200.00 92.50 3,677.43 -768.46 -5,636.66270.50 559,907.915,999,083.013,607.43 0.00 5,636.66 10,300.00 92.50 3,673.06 -767.59 -5,736.56270.50 559,808.015,999,083.013,603.06 0.00 5,736.56 10,400.00 92.50 3,668.70 -766.72 -5,836.46270.50 559,708.125,999,083.003,598.70 0.00 5,836.46 10,462.18 92.50 3,665.99 -766.18 -5,898.58270.50 559,646.005,999,083.003,595.99 0.00 5,898.58 10,500.00 91.37 3,664.71 -765.81 -5,936.37270.62 559,608.215,999,083.043,594.71 3.00 5,936.37 10,540.80 90.15 3,664.17 -765.32 -5,977.16270.75 559,567.425,999,083.173,594.17 3.00 5,977.16 10,600.00 90.15 3,664.01 -764.55 -6,036.36270.75 559,508.225,999,083.423,594.01 0.00 6,036.36 10,700.00 90.15 3,663.74 -763.25 -6,136.35270.75 559,408.245,999,083.853,593.74 0.00 6,136.35 10,800.00 90.15 3,663.47 -761.94 -6,236.34270.75 559,308.255,999,084.273,593.47 0.00 6,236.34 10,900.00 90.15 3,663.20 -760.64 -6,336.33270.75 559,208.265,999,084.703,593.20 0.00 6,336.33 10,970.46 90.15 3,663.01 -759.72 -6,406.79270.75 559,137.805,999,085.003,593.01 0.00 6,406.79 Total Depth : 10970.46' MD, 3663.01' TVD - 4 1/2" x 8 1/2" 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Targets Dip Angle (°) Dip Dir. (°) MPU S-204 wp12 tgt13 3,663.01 5,999,085.00 559,137.80-759.72 -6,406.790.00 0.00 - plan hits target center - Point MPU S-204 wp12 tgt05 3,770.64 5,999,066.00 563,203.90-814.40 -2,340.630.00 0.00 - plan hits target center - Point MPU S-204 wp12 tgt10 3,686.88 5,999,078.00 560,662.60-780.10 -4,881.970.00 0.00 - plan misses target center by 44.98usft at 9445.79usft MD (3686.92 TVD, -735.18 N, -4884.13 E) - Point MPU S-204 wp12 tgt01 3,879.83 5,999,059.00 564,986.30-837.04 -558.190.00 0.00 - plan misses target center by 10.21usft at 5108.48usft MD (3880.71 TVD, -847.22 N, -558.27 E) - Point MPU S-204 wp12 tgt11 3,688.29 5,999,081.00 560,154.30-772.64 -5,390.270.00 0.00 - plan misses target center by 2.23usft at 9953.39usft MD (3688.08 TVD, -770.42 N, -5390.29 E) - Point MPU S-204 wp12 tgt08 3,693.27 5,999,074.00 561,679.10-793.02 -3,865.440.00 0.00 - plan hits target center - Point MPU S-204 wp12 tgt12 3,665.99 5,999,083.00 559,646.00-766.18 -5,898.580.00 0.00 - plan hits target center - Point MPU S-204 wp12 tgt04 3,794.74 5,999,064.00 563,712.10-820.86 -1,832.420.00 0.00 - plan misses target center by 3.81usft at 6386.57usft MD (3795.76 TVD, -817.19 N, -1832.40 E) - Point MPU S-204 wp12 tgt07 3,709.87 5,999,071.00 562,187.30-800.48 -3,357.240.00 0.00 - plan hits target center - Point MPU S-204 wp12 tgt02 3,860.54 5,999,059.00 564,728.60-834.78 -815.900.00 0.00 - plan misses target center by 10.99usft at 5367.64usft MD (3868.10 TVD, -842.69 N, -816.89 E) - Point MPU S-204 wp12 tgt03 3,822.36 5,999,062.00 564,220.40-827.32 -1,324.110.00 0.00 - plan hits target center - Point MPU S-204 wp12 tgt06 3,736.47 5,999,069.00 562,695.60-806.94 -2,848.930.00 0.00 - plan misses target center by 0.25usft at 7404.94usft MD (3736.53 TVD, -806.69 N, -2848.93 E) - Point MPU S-204 wp12 tgt09 3,676.62 5,999,076.00 561,170.80-786.56 -4,373.760.00 0.00 - plan misses target center by 52.00usft at 8930.24usft MD (3680.83 TVD, -734.93 N, -4369.14 E) - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 9 5/8" x 12 1/4"3,873.324,888.34 9-5/8 12-1/4 4 1/2" x 8 1/2"3,663.0110,970.46 4-1/2 8-1/2 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Standard Proposal Report Well: Wellbore: Plan: MPU S-204 MPU S-204 Survey Calculation Method:Minimum Curvature MPU S-204 as built RKB @ 70.00usft (Original W Design:MPU S-204 wp17 Database:Alaska MD Reference:MPU S-204 as built RKB @ 70.00usft (Original W North Reference: Well Plan: MPU S-204 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations Vertical Depth SS 2,613.46 2,350.42 SV1 0.00 2,015.79 1,820.00 Permafrost 0.00 4,889.50 3,873.36 MB 3,031.95 2,752.33 UG4A 0.00 866.96 852.82 SV6 0.00 4,099.76 3,652.29 LA3 0.00 1,770.90 1,603.38 SV4 0.00 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 250.00 250.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 500.00 499.29 -14.15 8.17 Start Dir 4º/100' : 500' MD, 499.29'TVD 700.00 695.12 -48.00 29.12 Start Dir 4.5º/100' : 700' MD, 695.12'TVD 1,000.00 972.74 -135.21 99.18 Start Dir 5º/100' : 1000' MD, 972.74'TVD 1,696.83 1,537.86 -391.81 407.57 End Dir : 1696.83' MD, 1537.86' TVD 2,512.99 2,259.79 -536.62 759.66 Start Dir 5º/100' : 2512.99' MD, 2259.79'TVD 4,784.89 3,869.71 -847.28 -234.87 End Dir : 4784.89' MD, 3869.71' TVD 4,889.10 3,873.35 -847.28 -339.02 Begin Geosteering 4,928.00 3,874.70 -847.28 -377.90 Fault 1 (10'-20' DTE) 5,522.50 3,849.52 -837.69 -970.55 Fault 2A (10'-20' DTE) 9,495.00 3,687.76 -737.57 -4,933.28 Fault 2B (10'-20' DTW) 10,970.46 3,663.01 -759.72 -6,406.79 Total Depth : 10970.46' MD, 3663.01' TVD 2/3/2025 12:49:18PM COMPASS 5000.17 Build 04 Page 9 Clearance Summary Anticollision Report 03 February, 2025 Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S-204 MPU S-204 5002923738 MPU S-204 wp17 Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Well Coordinates: 5,999,900.83 N, 565,537.07 E (70° 24' 36.64" N, 149° 27' 58.87" W) Datum Height: MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Geodetic Scale Factor Applied Version: 5000.17 Build: 04 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft NO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type: Scan Type:25.00 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning M Pt S Pad MPS-06 - MPS-06 - MPS-06 344.06 1,850.70 328.86 1,821.32 22.6351,850.70 Centre Distance Pass - MPS-06 - MPS-06 - MPS-06 344.08 1,858.70 328.82 1,827.84 22.5381,858.70 Ellipse Separation Pass - MPS-06 - MPS-06 - MPS-06 687.90 4,889.00 641.06 4,020.47 14.6884,889.00 Clearance Factor Pass - MPS-08 - MPS-08 - MPS-08 256.64 1,753.64 241.47 1,746.58 16.9171,753.64 Centre Distance Pass - MPS-08 - MPS-08 - MPS-08 256.66 1,758.70 241.44 1,750.35 16.8621,758.70 Ellipse Separation Pass - MPS-08 - MPS-08 - MPS-08 665.05 4,458.70 622.86 4,099.85 15.7624,458.70 Clearance Factor Pass - MPS-08 - MPS-08PB1 - MPS-08PB1 256.64 1,753.64 241.47 1,746.58 16.9171,753.64 Centre Distance Pass - MPS-08 - MPS-08PB1 - MPS-08PB1 256.66 1,758.70 241.44 1,750.35 16.8621,758.70 Ellipse Separation Pass - MPS-08 - MPS-08PB1 - MPS-08PB1 665.05 4,458.70 622.86 4,099.85 15.7624,458.70 Clearance Factor Pass - MPS-09 - MPS-09 - MPS-09 224.10 2,292.47 197.25 2,156.60 8.3452,292.47 Ellipse Separation Pass - MPS-09 - MPS-09 - MPS-09 224.22 2,308.70 197.33 2,170.30 8.3392,308.70 Clearance Factor Pass - MPS-11 - MPS-11 - MPS-11 133.55 2,508.70 103.81 2,415.75 4.4902,508.70 Clearance Factor Pass - MPS-11 - MPS-11 - MPS-11 132.53 2,533.70 103.53 2,437.04 4.5712,533.70 Ellipse Separation Pass - MPS-11 - MPS-11 - MPS-11 132.51 2,536.60 103.63 2,439.49 4.5872,536.60 Centre Distance Pass - MPS-13 - MPS-13 - MPS-13 244.68 1,319.17 233.85 1,304.55 22.5821,319.17 Centre Distance Pass - MPS-13 - MPS-13 - MPS-13 269.76 4,889.00 217.27 4,082.53 5.1404,889.00 Clearance Factor Pass - MPS-14 - MPS-14 - MPS-14 208.21 1,133.11 195.50 1,162.79 16.3841,133.11 Centre Distance Pass - MPS-14 - MPS-14 - MPS-14 208.21 1,133.70 195.50 1,163.22 16.3781,133.70 Ellipse Separation Pass - MPS-14 - MPS-14 - MPS-14 211.63 1,183.70 198.54 1,198.19 16.1701,183.70 Clearance Factor Pass - MPS-20 - MPS-20 - MPS-20 253.03 803.51 245.11 793.71 31.940803.51 Centre Distance Pass - MPS-20 - MPS-20 - MPS-20 253.22 833.70 244.99 822.31 30.776833.70 Ellipse Separation Pass - MPS-20 - MPS-20 - MPS-20 273.32 1,033.70 263.19 987.09 26.9921,033.70 Clearance Factor Pass - MPS-21 - MPS-21 - MPS-21 248.28 612.67 243.39 611.75 50.808612.67 Centre Distance Pass - MPS-21 - MPS-21 - MPS-21 248.42 633.70 243.35 630.35 49.059633.70 Ellipse Separation Pass - MPS-21 - MPS-21 - MPS-21 289.62 933.70 281.90 879.71 37.518933.70 Clearance Factor Pass - MPS-22 - MPS-22 - MPS-22 182.97 1,011.35 172.91 1,017.93 18.1971,011.35 Ellipse Separation Pass - MPS-22 - MPS-22 - MPS-22 185.69 1,058.70 175.22 1,052.53 17.7261,058.70 Clearance Factor Pass - MPS-23 - MPS-23 - MPS-23 217.87 824.03 211.53 811.90 34.370824.03 Centre Distance Pass - 03 February, 2025 - 12:58 COMPASSPage 2 of 10 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-23 - MPS-23 - MPS-23 217.88 833.70 211.47 821.07 33.954833.70 Ellipse Separation Pass - MPS-23 - MPS-23 - MPS-23 1,188.79 4,889.00 1,146.63 6,179.58 28.2004,889.00 Clearance Factor Pass - MPS-23 - MPS-23L1 - MPS-23L1 217.87 824.03 211.53 811.90 34.370824.03 Centre Distance Pass - MPS-23 - MPS-23L1 - MPS-23L1 217.88 833.70 211.47 821.07 33.954833.70 Ellipse Separation Pass - MPS-23 - MPS-23L1 - MPS-23L1 1,145.20 4,889.00 1,104.55 6,115.70 28.1754,889.00 Clearance Factor Pass - MPS-24 - MPS-24 - MPS-24 198.68 772.26 190.46 768.91 24.185772.26 Centre Distance Pass - MPS-24 - MPS-24 - MPS-24 198.70 783.70 190.43 779.73 24.009783.70 Ellipse Separation Pass - MPS-24 - MPS-24 - MPS-24 207.57 933.70 198.43 916.19 22.705933.70 Clearance Factor Pass - MPS-24 - MPS-24PB1 - MPS-24PB1 198.68 772.26 190.46 768.91 24.185772.26 Centre Distance Pass - MPS-24 - MPS-24PB1 - MPS-24PB1 198.70 783.70 190.43 779.73 24.009783.70 Ellipse Separation Pass - MPS-24 - MPS-24PB1 - MPS-24PB1 207.57 933.70 198.43 916.19 22.705933.70 Clearance Factor Pass - MPS-24 - MPS-24PB2 - MPS-24PB2 198.68 772.26 190.46 768.91 24.185772.26 Centre Distance Pass - MPS-24 - MPS-24PB2 - MPS-24PB2 198.70 783.70 190.43 779.73 24.009783.70 Ellipse Separation Pass - MPS-24 - MPS-24PB2 - MPS-24PB2 207.57 933.70 198.43 916.19 22.705933.70 Clearance Factor Pass - MPS-25 - MPS-25 - MPS-25 191.46 609.95 186.59 601.82 39.301609.95 Centre Distance Pass - MPS-25 - MPS-25 - MPS-25 191.61 633.70 186.55 623.80 37.889633.70 Ellipse Separation Pass - MPS-25 - MPS-25 - MPS-25 220.11 883.70 213.04 843.74 31.161883.70 Clearance Factor Pass - MPS-25 - MPS-25L1 - MPS-25L1 191.46 609.95 186.59 601.82 39.300609.95 Centre Distance Pass - MPS-25 - MPS-25L1 - MPS-25L1 191.61 633.70 186.55 623.80 37.889633.70 Ellipse Separation Pass - MPS-25 - MPS-25L1 - MPS-25L1 220.11 883.70 213.04 843.74 31.161883.70 Clearance Factor Pass - MPS-26 - MPS-26 - MPS-26 105.51 1,038.53 96.85 1,054.22 12.1791,038.53 Ellipse Separation Pass - MPS-26 - MPS-26 - MPS-26 106.07 1,058.70 97.27 1,072.01 12.0571,058.70 Clearance Factor Pass - MPS-27 - MPS-27 - MPS-27 164.27 690.17 158.77 684.82 29.883690.17 Centre Distance Pass - MPS-27 - MPS-27 - MPS-27 164.35 708.70 158.70 703.09 29.109708.70 Ellipse Separation Pass - MPS-27 - MPS-27 - MPS-27 180.89 908.70 173.64 884.34 24.948908.70 Clearance Factor Pass - MPS-27 - MPS-27L1 - MPS-27L1 164.27 690.17 158.77 684.82 29.883690.17 Centre Distance Pass - MPS-27 - MPS-27L1 - MPS-27L1 164.35 708.70 158.70 703.09 29.109708.70 Ellipse Separation Pass - MPS-27 - MPS-27L1 - MPS-27L1 180.89 908.70 173.64 884.34 24.949908.70 Clearance Factor Pass - MPS-27 - MPS-27PB1 - MPS-27PB1 164.27 690.17 158.23 684.82 27.202690.17 Centre Distance Pass - MPS-27 - MPS-27PB1 - MPS-27PB1 164.35 708.70 158.16 703.09 26.560708.70 Ellipse Separation Pass - 03 February, 2025 - 12:58 COMPASSPage 3 of 10 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-27 - MPS-27PB1 - MPS-27PB1 176.16 883.70 168.56 863.88 23.176883.70 Clearance Factor Pass - MPS-28 - MPS-28 - MPS-28 146.74 648.48 139.17 649.63 19.385648.48 Centre Distance Pass - MPS-28 - MPS-28 - MPS-28 146.93 683.70 139.06 684.72 18.655683.70 Ellipse Separation Pass - MPS-28 - MPS-28 - MPS-28 152.46 808.70 143.69 805.54 17.377808.70 Clearance Factor Pass - MPS-28 - MPS-28PB1 - MPS-28PB1 146.74 648.48 139.17 649.63 19.385648.48 Centre Distance Pass - MPS-28 - MPS-28PB1 - MPS-28PB1 146.93 683.70 139.06 684.72 18.655683.70 Ellipse Separation Pass - MPS-28 - MPS-28PB1 - MPS-28PB1 152.46 808.70 143.69 805.54 17.377808.70 Clearance Factor Pass - MPS-28 - MPS-28PB2 - MPS-28PB2 146.74 648.48 139.17 649.63 19.385648.48 Centre Distance Pass - MPS-28 - MPS-28PB2 - MPS-28PB2 146.93 683.70 139.06 684.72 18.655683.70 Ellipse Separation Pass - MPS-28 - MPS-28PB2 - MPS-28PB2 152.46 808.70 143.69 805.54 17.377808.70 Clearance Factor Pass - MPS-29 - MPS-29 - MPS-29 132.08 538.60 128.00 535.57 32.345538.60 Centre Distance Pass - MPS-29 - MPS-29 - MPS-29 132.19 558.70 127.96 554.96 31.238558.70 Ellipse Separation Pass - MPS-29 - MPS-29 - MPS-29 148.72 733.70 143.12 714.35 26.560733.70 Clearance Factor Pass - MPS-29 - MPS-29L1 - MPS-29L1 132.08 538.60 128.00 535.57 32.345538.60 Centre Distance Pass - MPS-29 - MPS-29L1 - MPS-29L1 132.19 558.70 127.96 554.96 31.238558.70 Ellipse Separation Pass - MPS-29 - MPS-29L1 - MPS-29L1 148.72 733.70 143.12 714.35 26.560733.70 Clearance Factor Pass - MPS-30 - MPS-30 - MPS-30 113.96 663.75 105.14 665.03 12.915663.75 Centre Distance Pass - MPS-30 - MPS-30 - MPS-30 114.13 683.70 105.05 684.01 12.576683.70 Ellipse Separation Pass - MPS-30 - MPS-30 - MPS-30 117.93 758.70 108.19 754.48 12.108758.70 Clearance Factor Pass - MPS-31 - MPS-31 - MPS-31 94.91 741.87 89.15 747.68 16.482741.87 Centre Distance Pass - MPS-31 - MPS-31 - MPS-31 95.02 758.70 89.13 764.09 16.141758.70 Ellipse Separation Pass - MPS-31 - MPS-31 - MPS-31 98.98 833.70 92.53 836.07 15.353833.70 Clearance Factor Pass - MPS-32 - MPS-32 - MPS-32 91.78 467.45 86.06 468.68 16.069467.45 Centre Distance Pass - MPS-32 - MPS-32 - MPS-32 92.10 533.70 85.55 534.93 14.076533.70 Ellipse Separation Pass - MPS-32 - MPS-32 - MPS-32 97.66 633.70 89.88 629.66 12.553633.70 Clearance Factor Pass - MPS-33 - MPS-33 - MPS-33 75.87 529.41 71.49 524.16 17.313529.41 Centre Distance Pass - MPS-33 - MPS-33 - MPS-33 75.99 558.70 71.42 553.10 16.656558.70 Ellipse Separation Pass - MPS-33 - MPS-33 - MPS-33 83.64 708.70 78.10 700.23 15.083708.70 Clearance Factor Pass - MPS-33 - MPS-33A - MPS-33A 75.87 529.41 71.49 530.47 17.313529.41 Centre Distance Pass - MPS-33 - MPS-33A - MPS-33A 75.99 558.70 71.42 559.41 16.656558.70 Ellipse Separation Pass - MPS-33 - MPS-33A - MPS-33A 83.64 708.70 78.10 706.54 15.083708.70 Clearance Factor Pass - 03 February, 2025 - 12:58 COMPASSPage 4 of 10 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-34 - MPS-34 - MPS-34 57.89 507.82 53.36 511.68 12.759507.82 Centre Distance Pass - MPS-34 - MPS-34 - MPS-34 57.90 508.70 53.35 512.53 12.745508.70 Ellipse Separation Pass - MPS-34 - MPS-34 - MPS-34 59.62 558.70 54.77 560.48 12.313558.70 Clearance Factor Pass - MPS-34 - MPS-34L1 - MPS-34L1 57.89 507.82 53.36 511.68 12.759507.82 Centre Distance Pass - MPS-34 - MPS-34L1 - MPS-34L1 57.90 508.70 53.35 512.53 12.745508.70 Ellipse Separation Pass - MPS-34 - MPS-34L1 - MPS-34L1 59.62 558.70 54.77 560.48 12.313558.70 Clearance Factor Pass - MPS-34 - MPS-34L2 - MPS-34L2 57.89 507.82 53.36 511.68 12.759507.82 Centre Distance Pass - MPS-34 - MPS-34L2 - MPS-34L2 57.90 508.70 53.35 512.53 12.745508.70 Ellipse Separation Pass - MPS-34 - MPS-34L2 - MPS-34L2 59.62 558.70 54.77 560.48 12.313558.70 Clearance Factor Pass - MPS-35 - MPS-35 - MPS-35 35.99 477.59 30.22 480.38 6.245477.59 Centre Distance Pass - MPS-35 - MPS-35 - MPS-35 36.01 483.70 30.20 486.38 6.196483.70 Ellipse Separation Pass - MPS-35 - MPS-35 - MPS-35 36.63 508.70 30.62 510.82 6.091508.70 Clearance Factor Pass - MPS-35 - MPS-35PB1 - MPS-35PB1 35.99 477.59 30.22 480.38 6.245477.59 Centre Distance Pass - MPS-35 - MPS-35PB1 - MPS-35PB1 36.01 483.70 30.20 486.38 6.196483.70 Ellipse Separation Pass - MPS-35 - MPS-35PB1 - MPS-35PB1 36.63 508.70 30.62 510.82 6.091508.70 Clearance Factor Pass - MPS-35 - MPS-35PB2 - MPS-35PB2 35.99 477.59 30.22 480.38 6.245477.59 Centre Distance Pass - MPS-35 - MPS-35PB2 - MPS-35PB2 36.01 483.70 30.20 486.38 6.196483.70 Ellipse Separation Pass - MPS-35 - MPS-35PB2 - MPS-35PB2 36.63 508.70 30.62 510.82 6.091508.70 Clearance Factor Pass - MPS-37 - MPS-37 - MPS-37 14.38 121.26 12.45 123.15 7.473121.26 Centre Distance Pass - MPS-37 - MPS-37 - MPS-37 14.82 483.70 9.91 484.78 3.017483.70 Ellipse Separation Pass - MPS-37 - MPS-37 - MPS-37 15.69 533.70 10.32 534.51 2.923533.70 Clearance Factor Pass - MPS-39 - MPS-39 - MPS-39 14.59 665.00 8.00 660.29 2.213665.00 Centre Distance Pass - MPS-39 - MPS-39 - MPS-39 14.86 708.70 7.87 703.99 2.125708.70 Clearance Factor Pass - MPS-41 - MPS-41 - MPS-41 45.47 33.70 44.05 35.23 32.06033.70 Centre Distance Pass - MPS-41 - MPS-41 - MPS-41 46.50 283.70 42.56 284.89 11.805283.70 Ellipse Separation Pass - MPS-41 - MPS-41 - MPS-41 54.04 508.70 47.67 510.08 8.481508.70 Clearance Factor Pass - MPS-41 - MPS-41A - MPS-41A 45.47 33.70 44.05 35.23 32.06033.70 Centre Distance Pass - MPS-41 - MPS-41A - MPS-41A 46.50 283.70 42.56 284.89 11.805283.70 Ellipse Separation Pass - MPS-41 - MPS-41A - MPS-41A 54.04 508.70 47.67 510.08 8.481508.70 Clearance Factor Pass - MPS-41 - MPS-41APB1 - MPS-41APB1 45.47 33.70 44.05 35.23 32.06033.70 Centre Distance Pass - 03 February, 2025 - 12:58 COMPASSPage 5 of 10 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-41 - MPS-41APB1 - MPS-41APB1 46.50 283.70 42.56 284.89 11.805283.70 Ellipse Separation Pass - MPS-41 - MPS-41APB1 - MPS-41APB1 54.04 508.70 47.67 510.08 8.481508.70 Clearance Factor Pass - MPS-41 - MPS-41APB2 - MPS-41APB2 45.47 33.70 44.05 35.23 32.06033.70 Centre Distance Pass - MPS-41 - MPS-41APB2 - MPS-41APB2 46.50 283.70 42.56 284.89 11.805283.70 Ellipse Separation Pass - MPS-41 - MPS-41APB2 - MPS-41APB2 54.04 508.70 47.67 510.08 8.481508.70 Clearance Factor Pass - MPS-43 - MPS-43 - MPS-43 55.79 708.70 46.30 711.11 5.882708.70 Centre Distance Pass - MPS-43 - MPS-43 - MPS-43 55.97 733.70 46.23 735.52 5.747733.70 Ellipse Separation Pass - MPS-43 - MPS-43 - MPS-43 57.27 783.70 47.12 784.57 5.647783.70 Clearance Factor Pass - MPU S-203 - MPU S-203 - MPU S-203 17.25 760.42 10.27 759.04 2.469760.42 Centre Distance Pass - MPU S-203 - MPU S-203 - MPU S-203 17.36 783.70 10.19 782.48 2.422783.70 Ellipse Separation Pass - MPU S-203 - MPU S-203 - MPU S-203 17.69 808.70 10.32 807.63 2.401808.70 Clearance Factor Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 17.25 760.42 10.27 759.04 2.469760.42 Centre Distance Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 17.36 783.70 10.19 782.48 2.422783.70 Ellipse Separation Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 17.69 808.70 10.32 807.63 2.401808.70 Clearance Factor Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 17.25 760.42 10.27 759.04 2.469760.42 Centre Distance Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 17.36 783.70 10.19 782.48 2.422783.70 Ellipse Separation Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 17.69 808.70 10.32 807.63 2.401808.70 Clearance Factor Pass - MPU S-44i - MPU S-44i - MPU S-44i 43.71 4,620.57 22.69 4,229.71 2.0794,620.57 Centre Distance Pass - MPU S-44i - MPU S-44i - MPU S-44i 45.42 4,633.70 22.46 4,233.39 1.9784,633.70 Ellipse Separation Pass - MPU S-44i - MPU S-44i - MPU S-44i 56.57 4,658.70 25.88 4,240.25 1.8434,658.70 Clearance Factor Pass - MPU S-45 - MPU S-45 - MPU S-45 165.26 33.70 163.35 27.20 86.45833.70 Centre Distance Pass - MPU S-45 - MPU S-45 - MPU S-45 165.41 258.70 162.85 251.76 64.744258.70 Ellipse Separation Pass - MPU S-45 - MPU S-45 - MPU S-45 707.43 4,889.00 647.32 5,137.09 11.7704,889.00 Clearance Factor Pass - MPU S-46i - MPU S-46i - MPU S-46i 195.34 33.70 193.43 27.70 102.19633.70 Centre Distance Pass - MPU S-46i - MPU S-46i - MPU S-46i 195.36 58.70 193.39 52.53 99.42258.70 Ellipse Separation Pass - MPU S-46i - MPU S-46i - MPU S-46i 1,202.73 4,889.00 1,160.91 3,914.33 28.7554,889.00 Clearance Factor Pass - MPU S-46i - MPU S-46PB1 - MPU S-46PB1 195.34 33.70 193.43 27.70 102.19633.70 Centre Distance Pass - MPU S-46i - MPU S-46PB1 - MPU S-46PB1 195.36 58.70 193.39 52.53 99.42258.70 Ellipse Separation Pass - MPU S-46i - MPU S-46PB1 - MPU S-46PB1 1,202.73 4,889.00 1,160.91 3,914.33 28.7554,889.00 Clearance Factor Pass - MPU S-47 - MPU S-47 - MPU S-47 225.26 33.70 223.35 28.28 117.84633.70 Centre Distance Pass - 03 February, 2025 - 12:58 COMPASSPage 6 of 10 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 33.70 to 4,889.00 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPU S-47 - MPU S-47 - MPU S-47 225.46 208.70 223.14 202.38 97.415208.70 Ellipse Separation Pass - MPU S-47 - MPU S-47 - MPU S-47 275.53 733.70 269.91 687.35 49.054733.70 Clearance Factor Pass - MPU S-47 - MPU S-47PB1 - MPU S-47PB1 225.26 33.70 223.35 28.28 117.84633.70 Centre Distance Pass - MPU S-47 - MPU S-47PB1 - MPU S-47PB1 225.46 208.70 223.14 202.38 97.415208.70 Ellipse Separation Pass - MPU S-47 - MPU S-47PB1 - MPU S-47PB1 275.53 733.70 269.91 687.35 49.054733.70 Clearance Factor Pass - MPU S-48i - MPU S-48i - MPU S-48i 254.85 214.55 252.52 209.17 109.693214.55 Centre Distance Pass - MPU S-48i - MPU S-48i - MPU S-48i 254.91 233.70 252.50 226.62 105.635233.70 Ellipse Separation Pass - MPU S-48i - MPU S-48i - MPU S-48i 328.91 733.70 323.30 658.87 58.565733.70 Clearance Factor Pass - MPU S-48i - MPU S-48PB1 - MPU S-48PB1 254.85 214.55 252.52 209.17 109.693214.55 Centre Distance Pass - MPU S-48i - MPU S-48PB1 - MPU S-48PB1 254.91 233.70 252.50 226.62 105.635233.70 Ellipse Separation Pass - MPU S-48i - MPU S-48PB1 - MPU S-48PB1 328.91 733.70 323.30 658.87 58.565733.70 Clearance Factor Pass - MPU S-56i - MPU S-56PB1 - MPU S-56PB1 59.41 292.10 56.65 285.98 21.463292.10 Centre Distance Pass - MPU S-56i - MPU S-56PB1 - MPU S-56PB1 59.51 333.70 56.52 327.71 19.899333.70 Ellipse Separation Pass - MPU S-56i - MPU S-56PB1 - MPU S-56PB1 71.03 608.70 66.42 604.29 15.400608.70 Clearance Factor Pass - MPU S-57 - MPU S-57 - MPU S-57 31.67 33.70 29.76 27.19 16.56733.70 Centre Distance Pass - MPU S-57 - MPU S-57 - MPU S-57 31.89 183.70 29.68 177.08 14.373183.70 Ellipse Separation Pass - MPU S-57 - MPU S-57 - MPU S-57 205.32 4,889.00 162.08 4,567.70 4.7484,889.00 Clearance Factor Pass - Plan: MPU S-53 - MPU S-53 - MPU S-53 wp15 120.52 233.70 117.84 234.10 44.993233.70 Centre Distance Pass - Plan: MPU S-53 - MPU S-53 - MPU S-53 wp15 120.62 283.70 117.65 283.92 40.577283.70 Ellipse Separation Pass - Plan: MPU S-53 - MPU S-53 - MPU S-53 wp15 1,033.24 3,983.70 967.13 10,565.59 15.6293,983.70 Clearance Factor Pass - Plan: MPU S-54 - MPU S-54 - MPU S-54 wp09 104.43 508.70 99.92 512.83 23.176508.70 Centre Distance Pass - Plan: MPU S-54 - MPU S-54 - MPU S-54 wp09 104.54 533.70 99.84 537.80 22.251533.70 Ellipse Separation Pass - Plan: MPU S-54 - MPU S-54 - MPU S-54 wp09 149.77 1,033.70 140.33 1,037.28 15.8561,033.70 Clearance Factor Pass - Plan: MPU S-55 - MPU S-55 - MPU S-55 wp05 88.78 673.59 83.01 682.55 15.395673.59 Centre Distance Pass - Plan: MPU S-55 - MPU S-55 - MPU S-55 wp05 88.84 708.70 82.78 718.48 14.665708.70 Ellipse Separation Pass - Plan: MPU S-55 - MPU S-55 - MPU S-55 wp05 118.36 1,133.70 108.06 1,154.50 11.4891,133.70 Clearance Factor Pass - 03 February, 2025 - 12:58 COMPASSPage 7 of 10 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Survey tool program From (usft) To (usft) Survey/Plan Survey Tool 33.70 1,200.00 MPU S-204 wp17 GYD_Quest GWD 1,200.00 4,889.00 MPU S-204 wp17 3_MWD+IFR2+MS+Sag 4,889.00 10,970.46 MPU S-204 wp17 3_MWD+IFR2+MS+Sag Ellipse error terms are correlated across survey tool tie-on points. Separation is the actual distance between ellipsoids. Calculated ellipses incorporate surface errors. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). Distance Between centres is the straight line distance between wellbore centres. All station coordinates were calculated using the Minimum Curvature method. 03 February, 2025 - 12:58 COMPASSPage 8 of 10 0.00 1.00 2.00 3.00 4.00 Separation Factor0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225 Measured Depth (550 usft/in) MPS-37MPS-11 MPU S-44i MPU S-203 MPS-39 No-Go Zone - Stop Drilling Collision Avoidance Required Collision Risk Procedures Req. WELL DETAILS:Plan: MPU S-204 NAD 1927 (NADCON CONUS)Alaska Zone 04 36.30+N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999900.83 565537.07 70° 24' 36.6398 N 149° 27' 58.8729 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-204, True North Vertical (TVD) Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Measured Depth Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Calculation Method:Minimum Curvature SURVEY PROGRAM Date: 2022-10-28T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 33.70 1200.00 MPU S-204 wp17 (MPU S-204) GYD_Quest GWD 1200.00 4889.00 MPU S-204 wp17 (MPU S-204) 3_MWD+IFR2+MS+Sag 4889.00 10970.46 MPU S-204 wp17 (MPU S-204) 3_MWD+IFR2+MS+Sag 0.00 30.00 60.00 90.00 120.00 150.00 180.00 Centre to Centre Separation (60.00 usft/in)0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225 Measured Depth (550 usft/in) MPS-33 MPS-41 MPS-31 MPS-34 MPU S-45 MPS-32 MPS-11 MPS-43 MPU S-56PB1 MPU S-44i MPS-30 MPU S-57 MPU S-55 wp05 MPU S-53 wp15 MPU S-203 MPS-39 MPS-39 MPU S-54 wp09 NO GLOBAL FILTER: Using user defined selection & filtering criteria 33.70 To 10970.46 Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-204 Wellbore: MPU S-204 Plan: MPU S-204 wp17 Ladder / S.F. Plots 1 of 2 CASING DETAILS TVD MD Name Size 3873.32 4888.34 9 5/8" x 12 1/4" 9-5/8 3663.01 10970.46 4 1/2" x 8 1/2" 4-1/2 Clearance Summary Anticollision Report 03 February, 2025 Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S-204 MPU S-204 5002923738 MPU S-204 wp17 Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Well Coordinates: 5,999,900.83 N, 565,537.07 E (70° 24' 36.64" N, 149° 27' 58.87" W) Datum Height: MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Scan Range: 4,889.00 to 10,970.46 usft. Measured Depth. Geodetic Scale Factor Applied Version: 5000.17 Build: 04 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft NO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type: Scan Type:25.00 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 4,889.00 to 10,970.46 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning M Pt S Pad MPS-06 - MPS-06 - MPS-06 687.90 4,889.00 641.06 4,020.47 14.6884,889.00 Ellipse Separation Pass - MPS-06 - MPS-06 - MPS-06 818.10 5,339.00 746.27 4,193.61 11.3905,339.00 Clearance Factor Pass - MPS-08 - MPS-08 - MPS-08 831.99 4,889.00 785.39 3,942.14 17.8534,889.00 Clearance Factor Pass - MPS-08 - MPS-08PB1 - MPS-08PB1 831.99 4,889.00 785.39 3,942.14 17.8534,889.00 Clearance Factor Pass - MPS-09 - MPS-09 - MPS-09 2,152.29 4,889.00 2,122.18 2,717.64 71.4824,889.00 Clearance Factor Pass - MPS-11 - MPS-11 - MPS-11 1,990.29 4,889.00 1,957.67 2,959.44 61.0094,889.00 Clearance Factor Pass - MPS-13 - MPS-13 - MPS-13 269.76 4,889.00 217.27 4,082.53 5.1404,889.00 Centre Distance Pass - MPS-13 - MPS-13 - MPS-13 271.01 4,914.00 215.66 4,089.35 4.8964,914.00 Ellipse Separation Pass - MPS-13 - MPS-13 - MPS-13 287.10 4,989.00 224.75 4,109.77 4.6054,989.00 Clearance Factor Pass - MPS-14 - MPS-14 - MPS-14 964.31 7,652.38 799.17 5,435.97 5.8397,652.38 Centre Distance Pass - MPS-14 - MPS-14 - MPS-14 976.74 8,239.00 777.99 6,036.84 4.9148,239.00 Ellipse Separation Pass - MPS-14 - MPS-14 - MPS-14 1,003.97 8,839.00 790.13 6,537.48 4.6958,839.00 Clearance Factor Pass - MPS-20 - MPS-20 - MPS-20 2,174.76 4,889.00 2,140.13 2,525.00 62.8064,889.00 Ellipse Separation Pass - MPS-20 - MPS-20 - MPS-20 4,046.84 8,939.00 3,922.02 5,000.00 32.4208,939.00 Clearance Factor Pass - MPS-21 - MPS-21 - MPS-21 2,428.98 4,914.00 2,386.18 2,499.88 56.7484,914.00 Centre Distance Pass - MPS-21 - MPS-21 - MPS-21 2,429.66 4,964.00 2,385.52 2,527.22 55.0534,964.00 Ellipse Separation Pass - MPS-21 - MPS-21 - MPS-21 4,118.65 10,970.46 3,705.87 7,287.46 9.97810,970.46 Clearance Factor Pass - MPS-22 - MPS-22 - MPS-22 26.40 7,058.03 1.70 5,238.52 1.0697,058.03 Clearance Factor Pass - MPS-23 - MPS-23 - MPS-23 398.99 6,011.24 368.79 6,229.68 13.2116,011.24 Centre Distance Pass - MPS-23 - MPS-23 - MPS-23 399.00 6,014.00 368.74 6,229.81 13.1846,014.00 Ellipse Separation Pass - MPS-23 - MPS-23 - MPS-23 447.47 6,214.00 410.05 6,238.53 11.9596,214.00 Clearance Factor Pass - MPS-23 - MPS-23L1 - MPS-23L1 356.87 5,984.78 332.35 6,196.78 14.5535,984.78 Centre Distance Pass - MPS-23 - MPS-23L1 - MPS-23L1 356.89 5,989.00 332.30 6,197.40 14.5135,989.00 Ellipse Separation Pass - MPS-23 - MPS-23L1 - MPS-23L1 436.66 6,239.00 401.14 6,234.21 12.2946,239.00 Clearance Factor Pass - MPS-24 - MPS-24 - MPS-24 232.79 6,786.78 206.59 5,760.01 8.8856,786.78 Centre Distance Pass - MPS-24 - MPS-24 - MPS-24 232.80 6,789.00 206.58 5,761.45 8.8786,789.00 Ellipse Separation Pass - MPS-24 - MPS-24 - MPS-24 412.10 7,214.00 337.76 6,046.66 5.5437,214.00 Clearance Factor Pass - MPS-24 - MPS-24PB1 - MPS-24PB1 643.15 6,264.00 541.45 5,033.00 6.3246,264.00 Clearance Factor Pass - 03 February, 2025 - 12:59 COMPASSPage 2 of 9 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 4,889.00 to 10,970.46 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-24 - MPS-24PB1 - MPS-24PB1 639.35 6,314.00 538.75 5,033.00 6.3556,314.00 Ellipse Separation Pass - MPS-24 - MPS-24PB1 - MPS-24PB1 638.91 6,337.72 538.98 5,033.00 6.3946,337.72 Centre Distance Pass - MPS-24 - MPS-24PB2 - MPS-24PB2 232.79 6,786.78 206.44 5,760.01 8.8346,786.78 Centre Distance Pass - MPS-24 - MPS-24PB2 - MPS-24PB2 232.80 6,789.00 206.42 5,761.45 8.8286,789.00 Ellipse Separation Pass - MPS-24 - MPS-24PB2 - MPS-24PB2 412.10 7,214.00 337.60 6,046.66 5.5327,214.00 Clearance Factor Pass - MPS-25 - MPS-25 - MPS-25 423.19 8,289.00 362.47 8,437.73 6.9698,289.00 Centre Distance Pass - MPS-25 - MPS-25 - MPS-25 423.92 8,314.00 362.21 8,437.24 6.8708,314.00 Ellipse Separation Pass - MPS-25 - MPS-25 - MPS-25 434.80 8,389.00 370.13 8,435.76 6.7238,389.00 Clearance Factor Pass - MPS-25 - MPS-25L1 - MPS-25L1 385.40 8,272.32 336.88 8,350.12 7.9438,272.32 Centre Distance Pass - MPS-25 - MPS-25L1 - MPS-25L1 385.76 8,289.00 336.66 8,349.85 7.8588,289.00 Ellipse Separation Pass - MPS-25 - MPS-25L1 - MPS-25L1 402.67 8,389.00 349.60 8,348.23 7.5888,389.00 Clearance Factor Pass - MPS-26 - MPS-26 - MPS-26 755.09 6,204.30 679.05 4,382.61 9.9296,204.30 Centre Distance Pass - MPS-26 - MPS-26 - MPS-26 757.91 6,289.00 675.58 4,435.53 9.2066,289.00 Ellipse Separation Pass - MPS-26 - MPS-26 - MPS-26 861.92 6,764.00 750.51 4,755.23 7.7376,764.00 Clearance Factor Pass - MPS-27 - MPS-27 - MPS-27 1,214.69 10,970.46 964.28 11,186.00 4.85110,970.46 Clearance Factor Pass - MPS-27 - MPS-27L1 - MPS-27L1 1,122.93 10,970.46 876.17 11,255.00 4.55110,970.46 Clearance Factor Pass - MPS-27 - MPS-27PB1 - MPS-27PB1 2,101.64 5,567.10 2,051.19 2,835.28 41.6555,567.10 Centre Distance Pass - MPS-27 - MPS-27PB1 - MPS-27PB1 2,101.76 5,589.00 2,050.99 2,835.28 41.4015,589.00 Ellipse Separation Pass - MPS-27 - MPS-27PB1 - MPS-27PB1 3,891.13 10,289.00 3,595.86 7,569.00 13.17810,289.00 Clearance Factor Pass - MPS-28 - MPS-28 - MPS-28 1,567.28 6,144.02 1,477.59 4,023.15 17.4756,144.02 Centre Distance Pass - MPS-28 - MPS-28 - MPS-28 1,568.48 6,214.00 1,476.38 4,053.03 17.0316,214.00 Ellipse Separation Pass - MPS-28 - MPS-28 - MPS-28 1,716.00 6,914.00 1,605.94 4,305.12 15.5936,914.00 Clearance Factor Pass - MPS-28 - MPS-28PB1 - MPS-28PB1 1,567.28 6,144.02 1,477.59 4,023.15 17.4756,144.02 Centre Distance Pass - MPS-28 - MPS-28PB1 - MPS-28PB1 1,568.48 6,214.00 1,476.38 4,053.03 17.0316,214.00 Ellipse Separation Pass - MPS-28 - MPS-28PB1 - MPS-28PB1 1,716.00 6,914.00 1,605.94 4,305.12 15.5936,914.00 Clearance Factor Pass - MPS-28 - MPS-28PB2 - MPS-28PB2 1,567.28 6,144.02 1,477.59 4,023.15 17.4756,144.02 Centre Distance Pass - MPS-28 - MPS-28PB2 - MPS-28PB2 1,568.48 6,214.00 1,476.38 4,053.03 17.0316,214.00 Ellipse Separation Pass - MPS-28 - MPS-28PB2 - MPS-28PB2 1,716.00 6,914.00 1,605.94 4,305.12 15.5936,914.00 Clearance Factor Pass - MPS-29 - MPS-29 - MPS-29 2,366.38 4,889.00 2,330.75 2,431.77 66.4104,889.00 Ellipse Separation Pass - MPS-29 - MPS-29 - MPS-29 5,749.13 10,589.00 5,592.88 4,486.27 36.79510,589.00 Clearance Factor Pass - 03 February, 2025 - 12:59 COMPASSPage 3 of 9 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 4,889.00 to 10,970.46 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-29 - MPS-29L1 - MPS-29L1 2,366.38 4,889.00 2,330.75 2,431.77 66.4104,889.00 Ellipse Separation Pass - MPS-29 - MPS-29L1 - MPS-29L1 5,749.13 10,589.00 5,592.88 4,486.27 36.79510,589.00 Clearance Factor Pass - MPS-30 - MPS-30 - MPS-30 1,584.76 7,006.63 1,462.34 4,510.41 12.9467,006.63 Centre Distance Pass - MPS-30 - MPS-30 - MPS-30 1,594.47 7,314.00 1,455.80 4,755.88 11.4987,314.00 Ellipse Separation Pass - MPS-30 - MPS-30 - MPS-30 1,802.88 9,239.00 1,567.98 6,499.21 7.6759,239.00 Clearance Factor Pass - MPS-31 - MPS-31 - MPS-31 101.18 9,656.78 -123.46 7,353.16 0.4509,656.78 Clearance Factor FAIL - MPS-32 - MPS-32 - MPS-32 1,206.75 10,970.46 929.49 10,679.00 4.35210,970.46 Clearance Factor Pass - MPS-33 - MPS-33 - MPS-33 1,083.20 6,487.97 977.69 4,380.80 10.2666,487.97 Centre Distance Pass - MPS-33 - MPS-33 - MPS-33 1,084.72 6,564.00 976.33 4,431.27 10.0086,564.00 Ellipse Separation Pass - MPS-33 - MPS-33 - MPS-33 1,120.79 6,864.00 1,004.28 4,620.77 9.6196,864.00 Clearance Factor Pass - MPS-33 - MPS-33A - MPS-33A 653.93 6,888.54 539.83 4,870.92 5.7316,888.54 Centre Distance Pass - MPS-33 - MPS-33A - MPS-33A 653.93 6,889.00 539.83 4,871.19 5.7316,889.00 Ellipse Separation Pass - MPS-33 - MPS-33A - MPS-33A 654.26 6,914.00 540.03 4,879.67 5.7286,914.00 Clearance Factor Pass - MPS-34 - MPS-34 - MPS-34 2,180.14 5,796.82 2,128.69 2,759.26 42.3765,796.82 Centre Distance Pass - MPS-34 - MPS-34 - MPS-34 2,182.67 5,964.00 2,125.92 2,865.61 38.4595,964.00 Ellipse Separation Pass - MPS-34 - MPS-34 - MPS-34 3,289.99 10,464.00 3,025.97 6,792.46 12.46110,464.00 Clearance Factor Pass - MPS-34 - MPS-34L1 - MPS-34L1 2,180.14 5,796.82 2,128.69 2,759.26 42.3765,796.82 Centre Distance Pass - MPS-34 - MPS-34L1 - MPS-34L1 2,182.67 5,964.00 2,125.92 2,865.61 38.4585,964.00 Ellipse Separation Pass - MPS-34 - MPS-34L1 - MPS-34L1 3,289.99 10,464.00 3,025.98 6,792.46 12.46110,464.00 Clearance Factor Pass - MPS-34 - MPS-34L2 - MPS-34L2 2,180.14 5,796.82 2,128.69 2,759.26 42.3755,796.82 Centre Distance Pass - MPS-34 - MPS-34L2 - MPS-34L2 2,182.67 5,964.00 2,125.92 2,865.61 38.4585,964.00 Ellipse Separation Pass - MPS-34 - MPS-34L2 - MPS-34L2 3,289.99 10,464.00 3,025.97 6,792.46 12.46110,464.00 Clearance Factor Pass - MPS-35 - MPS-35 - MPS-35 2,127.42 6,111.15 2,071.24 2,889.31 37.8676,111.15 Centre Distance Pass - MPS-35 - MPS-35 - MPS-35 2,130.25 6,289.00 2,067.92 3,010.60 34.1746,289.00 Ellipse Separation Pass - MPS-35 - MPS-35 - MPS-35 3,230.49 10,970.46 2,927.30 7,113.82 10.65510,970.46 Clearance Factor Pass - MPS-35 - MPS-35PB1 - MPS-35PB1 2,127.42 6,111.15 2,071.24 2,889.31 37.8676,111.15 Centre Distance Pass - MPS-35 - MPS-35PB1 - MPS-35PB1 2,130.25 6,289.00 2,067.92 3,010.60 34.1746,289.00 Ellipse Separation Pass - MPS-35 - MPS-35PB1 - MPS-35PB1 3,230.49 10,970.46 2,927.30 7,113.82 10.65510,970.46 Clearance Factor Pass - MPS-35 - MPS-35PB2 - MPS-35PB2 2,127.42 6,111.15 2,071.24 2,889.31 37.8676,111.15 Centre Distance Pass - MPS-35 - MPS-35PB2 - MPS-35PB2 2,130.25 6,289.00 2,067.92 3,010.60 34.1746,289.00 Ellipse Separation Pass - 03 February, 2025 - 12:59 COMPASSPage 4 of 9 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 4,889.00 to 10,970.46 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPS-35 - MPS-35PB2 - MPS-35PB2 3,230.49 10,970.46 2,927.30 7,113.82 10.65510,970.46 Clearance Factor Pass - MPS-37 - MPS-37 - MPS-37 1,461.26 4,889.00 1,430.45 3,829.10 47.4384,889.00 Clearance Factor Pass - MPS-39 - MPS-39 - MPS-39 1,908.78 4,889.00 1,882.46 3,059.85 72.5004,889.00 Clearance Factor Pass - MPS-41 - MPS-41 - MPS-41 1,172.60 4,889.00 1,139.45 3,497.19 35.3814,889.00 Clearance Factor Pass - MPS-41 - MPS-41A - MPS-41A 1,172.60 4,889.00 1,139.45 3,497.19 35.3814,889.00 Clearance Factor Pass - MPS-41 - MPS-41APB1 - MPS-41APB1 1,172.60 4,889.00 1,139.45 3,497.19 35.3814,889.00 Clearance Factor Pass - MPS-41 - MPS-41APB2 - MPS-41APB2 1,172.60 4,889.00 1,139.45 3,497.19 35.3814,889.00 Clearance Factor Pass - MPS-43 - MPS-43 - MPS-43 1,504.57 4,889.00 1,464.64 3,577.14 37.6854,889.00 Clearance Factor Pass - MPU S-203 - MPU S-203 - MPU S-203 503.74 6,228.55 427.40 5,890.12 6.5986,228.55 Centre Distance Pass - MPU S-203 - MPU S-203 - MPU S-203 516.09 10,114.00 304.03 9,762.77 2.43410,114.00 Ellipse Separation Pass - MPU S-203 - MPU S-203 - MPU S-203 555.52 10,970.46 325.42 10,605.98 2.41410,970.46 Clearance Factor Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 503.74 6,228.55 427.40 5,890.12 6.5986,228.55 Centre Distance Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 564.34 10,139.00 310.01 9,785.98 2.21910,139.00 Ellipse Separation Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 565.06 10,164.00 310.37 9,787.00 2.21910,164.00 Clearance Factor Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 503.74 6,228.55 427.40 5,890.12 6.5986,228.55 Centre Distance Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 579.86 10,970.46 330.16 10,625.17 2.32210,970.46 Clearance Factor Pass - MPU S-44i - MPU S-44i - MPU S-44i 259.41 4,889.00 219.22 4,297.63 6.4554,889.00 Clearance Factor Pass - MPU S-45 - MPU S-45 - MPU S-45 275.68 5,489.00 227.04 5,572.70 5.6685,489.00 Clearance Factor Pass - MPU S-45 - MPU S-45 - MPU S-45 215.05 5,664.00 188.68 5,661.44 8.1535,664.00 Ellipse Separation Pass - MPU S-45 - MPU S-45 - MPU S-45 212.87 5,702.12 189.20 5,680.10 8.9915,702.12 Centre Distance Pass - MPU S-46i - MPU S-46i - MPU S-46i 384.42 7,139.00 318.61 6,428.64 5.8427,139.00 Clearance Factor Pass - MPU S-46i - MPU S-46i - MPU S-46i 239.52 7,550.75 209.27 6,743.64 7.9177,550.75 Centre Distance Pass - MPU S-46i - MPU S-46i - MPU S-46i 239.77 7,564.00 209.17 6,751.11 7.8367,564.00 Ellipse Separation Pass - MPU S-46i - MPU S-46PB1 - MPU S-46PB1 384.42 7,139.00 318.61 6,428.64 5.8427,139.00 Clearance Factor Pass - MPU S-46i - MPU S-46PB1 - MPU S-46PB1 239.52 7,550.75 209.27 6,743.64 7.9177,550.75 Centre Distance Pass - MPU S-46i - MPU S-46PB1 - MPU S-46PB1 239.77 7,564.00 209.17 6,751.11 7.8367,564.00 Ellipse Separation Pass - MPU S-47 - MPU S-47 - MPU S-47 231.77 9,172.07 190.64 7,824.11 5.6349,172.07 Centre Distance Pass - MPU S-47 - MPU S-47 - MPU S-47 232.17 9,189.00 190.27 7,833.94 5.5419,189.00 Ellipse Separation Pass - MPU S-47 - MPU S-47 - MPU S-47 304.50 9,414.00 236.86 7,957.15 4.5019,414.00 Clearance Factor Pass - MPU S-47 - MPU S-47PB1 - MPU S-47PB1 231.77 9,172.07 190.42 7,824.11 5.6059,172.07 Centre Distance Pass - 03 February, 2025 - 12:59 COMPASSPage 5 of 9 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Comparison Well Name - Wellbore Name - Design @Measured Depth (usft) Minimum Distance (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Site Name Scan Range: 4,889.00 to 10,970.46 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-204 - MPU S-204 - MPU S-204 wp17 Measured Depth (usft) Summary Based on Minimum Separation Warning MPU S-47 - MPU S-47PB1 - MPU S-47PB1 232.17 9,189.00 190.06 7,833.94 5.5139,189.00 Ellipse Separation Pass - MPU S-47 - MPU S-47PB1 - MPU S-47PB1 304.50 9,414.00 236.64 7,957.15 4.4879,414.00 Clearance Factor Pass - MPU S-48i - MPU S-48i - MPU S-48i 209.57 10,692.48 157.69 9,233.19 4.04010,692.48 Centre Distance Pass - MPU S-48i - MPU S-48i - MPU S-48i 210.30 10,714.00 157.58 9,245.74 3.98810,714.00 Ellipse Separation Pass - MPU S-48i - MPU S-48i - MPU S-48i 264.81 10,889.00 190.90 9,340.30 3.58310,889.00 Clearance Factor Pass - MPU S-48i - MPU S-48PB1 - MPU S-48PB1 209.57 10,692.48 157.52 9,233.19 4.02710,692.48 Centre Distance Pass - MPU S-48i - MPU S-48PB1 - MPU S-48PB1 210.30 10,714.00 157.41 9,245.74 3.97610,714.00 Ellipse Separation Pass - MPU S-48i - MPU S-48PB1 - MPU S-48PB1 264.81 10,889.00 190.74 9,340.30 3.57510,889.00 Clearance Factor Pass - MPU S-56i - MPU S-56PB1 - MPU S-56PB1 268.19 6,385.38 245.51 6,254.49 11.8256,385.38 Centre Distance Pass - MPU S-56i - MPU S-56PB1 - MPU S-56PB1 268.20 6,389.00 245.47 6,256.79 11.7996,389.00 Ellipse Separation Pass - MPU S-56i - MPU S-56PB1 - MPU S-56PB1 388.02 6,739.00 338.33 6,455.81 7.8096,739.00 Clearance Factor Pass - MPU S-57 - MPU S-57 - MPU S-57 196.09 4,914.00 154.50 4,587.71 4.7154,914.00 Clearance Factor Pass - MPU S-57 - MPU S-57 - MPU S-57 172.05 5,014.00 140.95 4,664.20 5.5325,014.00 Ellipse Separation Pass - MPU S-57 - MPU S-57 - MPU S-57 169.87 5,052.96 143.21 4,693.42 6.3725,052.96 Centre Distance Pass - Plan: MPU S-53 - MPU S-53 - MPU S-53 wp15 1,777.57 4,889.00 1,703.51 10,489.74 24.0034,889.00 Clearance Factor Pass - Plan: MPU S-54 - MPU S-54 - MPU S-54 wp09 2,228.10 4,889.00 2,211.10 2,451.98 131.0294,889.00 Clearance Factor Pass - Plan: MPU S-55 - MPU S-55 - MPU S-55 wp05 2,265.12 4,889.00 2,248.72 2,375.03 138.1614,889.00 Clearance Factor Pass - Survey tool program From (usft) To (usft) Survey/Plan Survey Tool 33.70 1,200.00 MPU S-204 wp17 GYD_Quest GWD 1,200.00 4,889.00 MPU S-204 wp17 3_MWD+IFR2+MS+Sag 4,889.00 10,970.46 MPU S-204 wp17 3_MWD+IFR2+MS+Sag 03 February, 2025 - 12:59 COMPASSPage 6 of 9 Milne Point Hilcorp Alaska, LLC Anticollision Report for Plan: MPU S-204 - MPU S-204 wp17 Ellipse error terms are correlated across survey tool tie-on points. Separation is the actual distance between ellipsoids. Calculated ellipses incorporate surface errors. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). Distance Between centres is the straight line distance between wellbore centres. All station coordinates were calculated using the Minimum Curvature method. 03 February, 2025 - 12:59 COMPASSPage 7 of 9 0.00 1.00 2.00 3.00 4.00 Separation Factor4900 5250 5600 5950 6300 6650 7000 7350 7700 8050 8400 8750 9100 9450 9800 10150 10500 10850 11200 11550 Measured Depth (700 usft/in) MPU S-48i MPU S-48PB1 MPS-13 MPS-31 MPS-27L1 MPU S-44i MPU S-47 MPU S-203 MPU S-203PB1 MPU S-203PB2 MPS-22 No-Go Zone - Stop Drilling Collision Avoidance Required Collision Risk Procedures Req. WELL DETAILS:Plan: MPU S-204 NAD 1927 (NADCON CONUS)Alaska Zone 04 36.30+N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999900.83 565537.07 70° 24' 36.6398 N 149° 27' 58.8729 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-204, True North Vertical (TVD) Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Measured Depth Reference:MPU S-204 as built RKB @ 70.00usft (Original Well Elev) Calculation Method:Minimum Curvature SURVEY PROGRAM Date: 2022-10-28T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 33.70 1200.00 MPU S-204 wp17 (MPU S-204) GYD_Quest GWD 1200.00 4889.00 MPU S-204 wp17 (MPU S-204) 3_MWD+IFR2+MS+Sag 4889.00 10970.46 MPU S-204 wp17 (MPU S-204) 3_MWD+IFR2+MS+Sag 0.00 30.00 60.00 90.00 120.00 150.00 180.00 Centre to Centre Separation (60.00 usft/in)4900 5250 5600 5950 6300 6650 7000 7350 7700 8050 8400 8750 9100 9450 9800 10150 10500 10850 11200 11550 Measured Depth (700 usft/in) MPU S-57 NO GLOBAL FILTER: Using user defined selection & filtering criteria 33.70 To 10970.46 Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-204 Wellbore: MPU S-204 Plan: MPU S-204 wp17 Ladder / S.F. Plots 2 of 2 CASING DETAILS TVD MD Name Size 3873.32 4888.34 9 5/8" x 12 1/4" 9-5/8 3663.01 10970.46 4 1/2" x 8 1/2" 4-1/2 Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. MILNE POINT UGNU UNDEFINED OIL 225-011 MPU S-204 WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:MILNE PT UNIT S-204Initial Class/TypeDEV / PENDGeoArea890Unit11328On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2250110MILNE POINT, UGNU UNDEFINE OIL - 525160NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes ADL0380109 and ADL3801102 Lease number appropriateYes3 Unique well name and numberYes MILNE POINT, UGNU UNDEFINE OIL - 525160 - governed by Statewide Regs4 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) (ForNA15 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)Yes 20" 129.5# X-52 grouted to 126'18 Conductor string providedYes 9-5/8" L-80 47# to BOPF, 9-5/8" L-80 40# to SB reservoir19 Surface casing protects all known USDWsYes 9-5/8" fully cemented from reservoir to surface. Two stage cement job through ported collar.20 CMT vol adequate to circulate on conductor & surf csgNo 9-5/8" fully cemented from reservoir to surface. Two stage cement job through ported collar.21 CMT vol adequate to tie-in long string to surf csgYes 9-5/8" fully cemented from reservoir to surface. Two stage cement job through ported collar.22 CMT will cover all known productive horizonsYes 9-5/8" L-80 47# to BOPF, 9-5/8" L-80 40 to SB reservoir23 Casing designs adequate for C, T, B & permafrostYes Doyon 14 rig 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 scan shows one close approach near TD. Offset injector will be shut in.26 Adequate wellbore separation proposedYes 16" Diverter27 If diverter required, does it meet regulationsYes All fluids overbalanced to expected pore pressure.28 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)Yes Doyon 14 has 14 x 3-1/8" manual gate valves, 1 x 3-1/8" manual choke and 1 x 3-1/16" remote hydraulic choke.31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo 50 ppm max on MPU S pad. Monitoring will be required.33 Is presence of H2S gas probableNA This well is a Oil Development well.34 Mechanical condition of wells within AOR verified (For service well only)Yes No H2S anticipated35 Permit can be issued w/o hydrogen sulfide measuresYes All formations anticipated to be normally pressured.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]ApprADDDate3/28/2025ApprMGRDate3/18/2025ApprADDDate3/28/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 4/4/2025