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Home My WebLink About225-111Originated: Delivered to:TRANSMITTAL DATE29-Jan-26Alaska Oil & Gas Conservation CommissionTRANSMITTAL #29JAN26-AP01ATTN: Gavin Gluyas !"# !"%&'(WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCOLOR PRINTS e-TRANS DATE/ CD3T-609 50-103-20929-00-00 225-111 KUPARUK RIVER MWD/LWD/DD VISION Service FINAL FIELD 11-Jan-26 1Path .PDF-Qty .LAS-Qty .DLIS-Qty .PPT-Qty .TXT-Qty.CSV -QtyData from M/LWD Tools)* + ,*$#-) + ,*.,, % /00+-) % " " /00+,$# -) % /00+ + + + + ,* 5,,)Anchorage, Alaska 99501-3539Data Description1#$2 , $)$,,$$3444+ + + Transmittal Receipt66666666666666666666666666666666 766666666666666666666666666666666666666666666.$+# $ )Please return via courier or sign/scan and email a copy to Schlumberger. 83,9:#-; 4$ 3#$,$*3$ '$#3*< 9( ,*:!39$ 443'*< 9 $'$4##4$49 :3*$'$')34=4*5*$3#5#5 9 $'$4'33> ,$5, ,$3*$:?-;.$ 225-111T41297Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.01.30 11:01:44 -09'00' 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: ___________________ 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: Kuparuk River Field Torok Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): Casing Collapse Structural Conductor Surface 2470 Intermediate Production Liner 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:Matt Smith Matt Smith Contact Email: Contact Phone: 907-263-4324 Authorized Title: 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 ADL025528 / ADL393883 KRU 3T-609 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska Inc. 225-111 P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20929-00-00 Will perfs require a spacing exception due to property boundaries? Current Pools: Proposed Pools: PRESENT WELL CONDITION SUMMARY MPSP (psi): Plugs (MD): Length Size MD TVD Burst 80 20 120 120 2571 10.75 2611 2492 5210 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): matt.smith2@conocophillips.com Drilling Engineer 1/5/2026 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: AOGCC USE ONLY Suspension Expiration Date: Subsequent Form Required:N P s 2 6 5 6 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-002 By Grace Christianson at 12:10 pm, Jan 05, 2026 10-404 Approved 10-403 for change of drilling rig required before drilling resumes. DSR-1/7/26 20 AAC 25.072. Temporary shutdown of drilling or completion operations. (b) The operator shall file with the commission, within 30 days after operation shutdown, a complete well record on a Report of Sundry Well Operations (Form 10-404), including a summary of daily well operations as described in 20 AAC 25.070 X VTL 1/6/2026 SFD 1/05/2026 BOP test to 4000 psig, annular preventer to 2500 psig. All conditions approved in original PTD in affect. 01/07/26 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 5, 2026 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry to Temporarily Shut Down Operations on 3T-609 (PTD#: 225-111) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Temporarily Shut Down Operations on 3T-609 (PTD#: 225-111) an onshore Moraine Producer well from the 3T drilling pad. The approximate intended work date is 1/05/2025. The surface section of 3T-609 was drilled to 2,616 MD / 2,492 TVD, and 10 3/4 casing run and cemented to surface. The wellhead was nippled up and TA cap installed, in preparation of moving to WNS to execute the winter season work scope. The remainder of the well as outlined in PTD 225-111 will be completed by Doyon 25 upon returning to Kuparuk after the exploration season. If you have any questions or require further information, please contact Matt Smith at 907-263-4324 (matt.smith2@conocophillips.com) or Justin Cremer at 907-263-4314. Sincerely, cc: 3T-609 Well File / Jenna Taylor ATO 1560 Will Earhart ATO 1552 Matt Smith Justin Cremer ATO 1548 Drilling Engineer Jenny Doherty ATO 1410 Sincerely, MaMMMMMMMtt Smith 3T-609 Sundry Page 1 3T-609 (PTD#: 225-111) Application for Sundry to Temporarily Shut Down Operations 1.Completed Operations 1. MIRU Doyon 142 onto 3T-609 2. Rig up and test surface riser, dewater cellar as needed. 3. Drilled 13 1/2 hole to TD at 2,616 MD / 2,492 TVD. 4. Ran and cemented 10 3/4 surface casing to surface, with 165 bbls cement returned to surface. Displaced with NAF fluid to act as freeze protect fluid. 5. Nipple up wellhead and TA Cap. Chart casing pressure test to 3000 psi for 30 min. 6. Secure well. Rig down and move out. Please note The remainder of the well will be completed by Doyon 25 upon return to Kuparuk after exploration season, in accordance with originally approved PTD (# 225-111) 2.Current As-Drilled Schematic 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 Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Torok Oil Pool, KRU 3T-609 Conoco Phillips Alaska, Inc. Permit to Drill Number: 225-111 Surface Location: 1932' FSL, 579' FWL, NWSW S1, T12N, R7E, UM Bottomhole Location: 4753' FSL, 2099' FWL, NENW S22, T13N, R7E, UM Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Commissioner DATED this 18 th day of December 2025. 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 22,733 TVD: 5081 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1/2/2025 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 526' to ADL355036 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 51 15. Distance to Nearest Well Open Surface: x-467790 y- 6003658 Zone- 4 12 to Same Pool: 2275' to 3T-617 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H-40 Welded 81 39 39 120 120 13.5" 10.75" 45.5 L80 Hyd563 2561 39 39 2600 2483 9.875" 7.625" 29.7 L80 Hyd563 5051 39 39 5090 4876 9.875" 7.625" 33.7 P110-S Hyd563 800 5090 4876 5890 4992 6.5" 4.5" 12.6 P110-S Hyd563 16993 5740 5008 22733 5081 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Matt Smith Chris Brillon Contact Email:matt.smith2@conocophillips.com Wells Engineering Manager Contact Phone:907-263-4324 Date: Permit to Drill API Number: Permit Approval Number: Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): Perforation Depth TVD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature: Commission Use Only See cover letter for other requirements. Intermediate Production Liner Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Surface Conductor/Structural Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks 2020sks 15.3ppg Casing Length Size Cement Volume MD Total Depth MD (ft): Total Depth TVD (ft): 1130sks 11ppg, 280sks 15.8ppg 180sks 14ppg, 280sks 15.3ppg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc. 59-52-180 KRU 3T-609 10 yds P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field Torok Oil Pool 1932' FSL, 579' FWL, NWSW S1 T12N R7E ADL025528 / ADL393883 (including stage data) 4258' FSL, 4642' FWL, NENE S2 T12N R7E LONS 01-013 4753' FSL, 2099' FWL, NENW S22 T13N R7E 2560 / 5760 GL / BF Elevation above MSL (ft): 2272 1764 18. Casing Program: Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 1/2/2026 225-111 By Grace Christianson at 1:46 pm, Oct 20, 2025 Requested variance of the diverter requirement under 20 AAC 25.035(h)(2) is approved. X VTL 12/17/2025 SFD 10/31/2025 DSR-10/30/25 Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig Annular preventer test to 2500 psig BOPE testing on a 21-day interval is approved with the attached conditions Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available Cement logs must be reviewed with the AOGCC as soon as available and prior to running the production liner 50-103-20929-00-00 JLC 12/17/2025 12/18/25 12/18/25 Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. CPAIs request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 17, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 3T-609 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Producer well from the 3T drilling pad. The intended spud date for this well is 1/2/2025. It is intended that Doyon 142 be used to drill the well. 3T-609 will utilize a 13 1/2 surface hole drilled to TD and 10 3/4 casing will be set and cemented to surface. As noted in section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will be sized for the intermediate casing string. The 9 7/8 intermediate hole will be drilled and set in the Moraine reservoir. A 7 5/8 casing string will be set and cemented from TD to secure the shoe and cover 250 TVD above any hydrocarbon-bearing zones (Coyote). The production interval will be comprised of a 6 1/2 horizontal hole that will be landed and geo-steered in the Moraine formation. The well will be completed as a fracture stimulated Producer with 4 1/2 liner and frac sleeves, cemented from TD to the liner top. The upper completion will include a production packer with GLMs and a downhole guage tied back to surface. A variance is requested for a BOPE test interval of 21 days for this project. Doyon 142 is a strong participant in the CPAI BOPE between well maintenance program, reflected by low failure rates in BOP tests since its entry into the CPAI fleet. The variance allows effective drilling and completion of problematic zones, or longer intervals during the well construction. It is also requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 3T-609. At 3T, there has not been any significant indication of shallow gas hydreates to date through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Matt Smith at 907-263-4324 (matt.smith2@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: 3T-609 Well File / Jenna Taylor ATO 1560 Will Earhart ATO 1552 Matt Smith Chris Brillon ATO 1548 Drilling Engineer Jenny Doherty ATO 1410 erely, S i h 1/2/2026 Recommend approving requested variance for diverter. SFD variance of the diverter requirement p completed as a fracture stimulated Producer 3T-609 PTD Page 1 3T-609 Application for Permit to Drill Document Table of Contents 1. Well Name .............................................................................................................................................................. 2 2. Location Summary ................................................................................................................................................... 2 3.Proposed Drilling Program..................................................................................................................................... 4 4.Blowout Prevention Equipment ............................................................................................................................. 4 5.Diverter System ..................................................................................................................................................... 5 6.MASP Calculations ................................................................................................................................................ 5 7.Procedure for Conducting Formation Integrity Tests ............................................................................................. 6 8.Casing and Cementing Program ........................................................................................................................... 6 9.Drilling Fluid Program ............................................................................................................................................ 7 10.Abnormally Pressured Formation Information ................................................................................................... 8 11.Seismic Analysis ................................................................................................................................................ 8 12.Seabed Condition Analysis ................................................................................................................................ 8 13.Evidence of Bonding .......................................................................................................................................... 8 14.Discussion of Mud and Cuttings Disposal and Annular Disposal ...................................................................... 8 15.Drilling Hazards Summary ................................................................................................................................. 8 16.Proposed Completion Schematic ..................................................................................................................... 10 3T-609 PTD Page 2 1. Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 3T-609 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface 1,932 FSL, 579 FWL, NWSW S1 T12N R7E, UM NAD 1927 Northings: 6003658 Eastings:467790 RKB Elevation 51AMSL Pad Elevation 12AMSL Top of Productive Horizon (Heel) 4258 FSL, 4642 FWL, NENE S2 T12N R7E, UM NAD 1927 Northings: 6005989 Eastings: 466581 Measured Depth, RKB: 5,890 Total Vertical Depth, RKB:4,992 Total Vertical Depth, SS:4,941 Total Depth (Toe) 4753 FSL, 2099 FWL, NENW S22 T13N R7E, UM NAD 1927 Northings: 6022342 Eastings: 462510 Measured Depth, RKB:22,733 Total Vertical Depth, RKB:5,081 Total Vertical Depth, SS:5,030 Pad Layout 3T-609 PTD Page 3 Well Plat 3T-609 PTD Page 4 3. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) 1. MIRU Doyon 142 onto 3T-609 2. Rig up and test surface riser, dewater cellar as needed. 3. Drill 13 1/2 hole to the surface casing point as per the directional plan. 4. Run and cement 10 3/4 surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice). 7. Pick up and run in hole with 9 7/8 drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3,000 psi for 30 minutes. 9. Drill out 20 of new hole and perform FIT/LOT. Maximum LOT to 18.0 ppg. Minimum LOT required to drill ahead is 11.0 ppg EMW. 10. Drill 9 7/8 hole to section TD, setting pipe 5-10 TVD in the Moraine Reservoir using near-bit GR. (LWD Program: GR/RES, near-bit GR). 11. Run 7 5/8 casing and cement to a minimum of 250 TVD above any hydrocarbon bearing zones (cementing schematic attached). Pressure test casing if possible on plug bump to 4000 psi. 12. Freeze protect down the Outer Annulus (10 3/4 surface casing x 7 5/8 intermediate casing annulus). 13. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice). 14. Pick up and run in hole with 6 1/2 drilling BHA. Log top of cement with sonic tool. 15. Chart casing pressure test to 4,000 psi for 30 minutes if not tested on plug bump. 16. Drill out shoe track and 20 feet of new formation. Perform FIT/LOT to a maximum of 16 ppg. Minimum required leak-off value is 11.0 ppg EMW. 17. Drill 6 1/2 hole to section TD (LWD Program: GR/RES/Den/Neu/Sonic). 18. Pull out of hole with drilling BHA. Review intermediate cement job details and sonic log TOC. 19. Run 4 1/2 liner with toe valve, frac sleeves and liner hanger and packer to 22,733 MD. 20. Cement 4 1/2 liner from TD to liner top. Pressure test 4 1/2 liner and liner hanger packer for 30 minutes. 21. Run 4 1/2 upper completion with glass plug, production packer and gas lift mandrels. Space out and land tubing hanger. 22. Pressure test hanger seals to 5,000 psi. 23. Pressure test against the glass plug to set production packer, test tubing to 4,200 psi, chart test. 24. Bleed tubing pressure to 2,200 psi and test IA to 3,850 psi, chart test. 25. Install HP-BPV. 26. Nipple down BOP. 27. Install tubing head adapter assembly. N/U frac tree and test to 10,000 psi/5 minutes. 28. Freeze protect down tubing and annulus. 29. Secure well. Rig down and move out. Please note This well will be fracd 4.Blowout Prevention Equipment Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP schematics on file for Doyon 142. Log top of cement with sonic tool. MPD equipment sonic log TOC 3T-609 PTD Page 5 Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 7 5/8 solid body rams, blind/shear rams and variable rams while drilling and running casing in the intermediate section of 3T-609. 3T-609 has a MASP of 1,764 psi in the intermediate hole section using the methodology in section 6 MASP calculations. With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2. Per 20AAC 25.035.e.a.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sixed to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Intermediate Drilling/Casing Production Proposed Configuration: Proposed Configuration: Annular Preventer (iii) Annular Preventer 7 5/8 fixed rams during drilling Intermediate VBRs in Upper Cavity Blind/Shear Rams (ii) Blind/Shear Rams VBRs (i) VBRs in Lower Cavity 5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) A diverter waiver is requested, as there have been no indications of hydrates on 3T pad, with 3T-608, 612, 613, 614 and 617 surface shoes within 500 of the 3T-609. 6. MASP Calculations Requirements of 20 AAC 25.005(c)(4) (A) maximum downhole pressure and maximum potential surface pressure; Method 1: no indications of hydrates on 3T pad, with 3T-608, 612, 613, 614 and 617 q , surface shoes within 500 of the 3T-609.Recommend approving requested waiver: Reviewed Daily Operations Summaries for nearby 3T-608, 3T-613, 3T-617, and 3T-731, and none reported gas while drilling through permafrost and to surface hole TD. AOGCC previously granted diverter variances for 3T-613, 3T-617, and 3T-731. SFD 3T-609 PTD Page 6 Method 2: Method 1 Method 2 = [( × 0.052 ) ] × = ( ) × Where: FG Fracture gradient at the casing seat in lb/gal 0.052 Conversion from lb/gal to psi/ft Gas Gradient 0.1 psi/ft TVD True Vertical Depth of casing seat in ft RKB Where: FPP Formation Pore Pressure at the next casing point Gas Gradient 0.1 psi/ft Section Hole Size Previous CSG Section TD MPSP psi MPSP MPSP Size MD TVD FG ppg Pore Pressure ppg | psi MD TVD Pore Pressure ppg | psi Method 1 psi Method 2 psi SURF 13 1/2 20 119 119 10.9 8.6 53 2,600 2,483 8.6 2,233 56 56 862 INTRM 9 7/8 10 3/4 2,600 2,483 13.0 8.6 1,110 5,890 4,992 8.6 2,233 1,495 1,495 1,734 PROD 6 1/2 7 5/8 5,890 4,992 13.0 8.6 2,233 22,733 5,081 8.6 2,233 1,764 2,876 1,764 (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 7. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with the Commission. 8. Casing and Cementing Program Requirements of 20 AAC 25.005 (c)(6) Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H40 Welded Cemented to surface with 10 yds slurry 10 3/4 13 1/2 45.5 L80 Hyd563 Cement to Surface 7 5/8 9 7/8 29.7 33.7 L80 P110-S Hyd563 250 TVD or 500 MD, whichever is greater, above upper most producing zone (Coyote) 4 1/2 6 1/2 12.6 P110-S Hyd563 Cemented liner with frac sleeves 3T-609 PTD Page 7 Cementing Calculations 10 3/4 Surface Casing run to 2,600 MD / 2,483 TVD Cement 2,600 MD to 2,100 (500 of tail) with Class G + Add's@ 15.8 PPG, and from 2,100' to surface with 11 ppg Arctic Lite Crete. Assume 225% excess annular volume in permafrost and 50% excess below the permafrost (1,568 MD), zero excess in 20 conductor. 7 5/8 Intermediate Casing run to 5890 MD / 4,992 TVD Top of slurry is designed to be at 4,032 MD, which is 250 TVD above the prognosis shallowest hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2-stage cement job will be performed to isolate this zone. Assume 50% excess annular volume. 4 1/2 Production Liner run from 5,890 MD / 4,992 TVD to 22,733 MD / 5,081 TVD Cement the liner from TD to the liner top using a 15.3 ppg Class G + Add's cement. Assume 30% excess annular volume in the open hole, and 0% excess in the 7 5/8 intermediate casing. 9. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13 1/2 9 7/8 6 1/2 Casing Size in. 10 3/4 7 5/8 4 1/2 Density PPG 8.6 9.8 9.0 9.6 9.0 10 PV cP 20-50 <22 <20 YP lb./100 ft2 50 - 80 20 - 30 15 - 30 Funnel Viscosity s/qt. 250 300 40-60 35-50 Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10 10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15 API Fluid Loss cc/30 min. N.C. 8.0 < 10.0 < 6.0 HPHT Fluid Loss cc/30 min. N/A < 10.0 < 10.0 pH 8.5-9.5 9-10 9-10 Surface Hole: A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain proper specifications The mud weight will be maintained at 9.8 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.6 ppg for formation stability and be prepared to add loss circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important. The mud will be weighted up to 9.5 ppg before pulling out of the hole. 3T-609 PTD Page 8 Production Hole: The horizontal production interval will be drilled with a Non-Aqueous Fluid (NAF) mud system weighted to 9.0 10 ppg. MPD will be utilized to add back pressure during connections to minimize pressure cycling. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 10. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. 12. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. 13. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Drilling Hazards Summary 13 1/2" Hole / 10 3/4 Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Follow real time surveys very closely, gyro survey as needed to ensure survey accuracy. Gas Hydrates Low If observed control drill, reduce pump rates and circulating time, reduce mud temperatures Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Running sands and gravels Low Maintain planned mud properties, increase mud weight, use weighted sweeps Lost Circulation Moderate Monitor ECDs for signs of packoff before losses occur. Keep hole clean and utilize LCM sweeps to regain circulation. 3T-609 PTD Page 9 9 7/8 Hole /7 5/8 Casing Interval Event Risk Level Mitigation Strategy Sloughing shale / Tight hole / Stuck Pipe Low Good hole cleaning, pre-treatment with LCM, stabilized BHA, maintain planned mud weights and adjust as needed, real time equivalent circulating density (ECD) monitoring Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure (Coyote / K3) Low Well control drills, check for flow during connections, increase mud weight if necessary. 6 1/2 Hole / 4 1/2 Liner - Horizontal Production Interval Event Risk Level Mitigation Strategy Lost circulation Moderate Reduce pump rates, real time ECD monitoring, maintain mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform clean out run if necessary, utilize super sliders for weight transfer if needed, monitor T&D real time Well Proximity Risks: 3T is a multi-well pad. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Unlikely to encounter any abnormal pressure, however, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. The overburden logs will be evaluated to ensure no hydrocarbon bearing zones are above the known Coyote. If identified, the primary intermediate cement job will be replanned to cover the zone as per the agency regulations. Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 3T-609 PTD Page 10 16. Proposed Completion Schematic 3T-609 wp08.1 Plan Summary 0 3 0 3500 7000 10500 14000 17500 21000 Measured Depth 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 30.0 30.0 60.0 60.0 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 14769 NDST-02 39100200300400500600700800900999 1099 1198 1298 3T-608 391002003004005006007007998999991099119812981398149815981698179818981999210022012302 3T-611 wp14.1 39100200300400500600700800 3T-612 39100200300400500600700 3T-606 wp08 39100200300400500600700 801 901 3T-607 wp05 39100200300400500600700 800 901 1001 1101 1202 1302 1403 3T-610 wp05 0 2750 0 1000 2000 3000 4000 5000 6000 7000 Vertical Section at 343.97° 10-3/4" Surface Casing 7-5/8" Intermediate Casing 15 30 45 Centre to Centre Separation0 400 800 1200 1600 2000 2400 2800 Measured Depth DDI 7.110 SURVEY PROGRAM Date: 2019-07-03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.00 1450.00 3T-609 wp08.1 (3T-609) r.5 SDI_URSA1 1450.00 2590.00 3T-609 wp08.1 (3T-609) MWD+IFR2+SAG+MS 2590.00 5880.00 3T-609 wp08.1 (3T-609) MWD+IFR2+SAG+MS 5880.00 22733.37 3T-609 wp08.1 (3T-609) MWD+IFR2+SAG+MS Ground / 12.00 CASING DETAILS TVD MD Name 2483.00 2600.25 10-3/4" Surface Casing 4992.00 5889.33 7-5/8" Intermediate Casing5081.00 22733.37 4-1/2" Production Liner Mag Model & Date: BGGM2025 01-May-26 Magnetic North is 13.26° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.58° 57129.71nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00 3 600.00 2.00 330.00 599.96 3.02 -1.75 1.00 330.00 3.39 Start Build 1.50 4 1514.09 15.71 330.00 1501.00 124.60 -71.94 1.50 0.00 139.62 Start 103.88 hold at 1514.09 MD 5 1617.97 15.71 330.00 1601.00 148.96 -86.00 0.00 0.00 166.92 Start Build 2.00 6 2684.52 37.04 330.00 2551.00 556.95 -321.56 2.00 0.00 624.09 Start 20.00 hold at 2684.52 MD 7 2704.52 37.04 330.00 2566.96 567.38 -327.58 0.00 0.00 635.78 Start DLS 2.50 TFO 176.26 8 2813.83 34.32 330.32 2655.75 622.68 -359.31 2.50 176.26 697.69 Start 1848.00 hold at 2813.83 MD 9 4661.84 34.32 330.32 4182.10 1527.78 -875.23 0.00 0.00 1710.06 Start DLS 3.00 TFO 19.51 10 5169.42 48.90 337.00 4560.79 1829.90 -1021.67 3.00 19.51 2040.87 Start 300.00 hold at 5169.42 MD 11 5469.42 48.90 337.00 4758.00 2038.00 -1110.00 0.00 0.00 2265.27 Start DLS 3.52 TFO 16.38 12 6521.76 84.94 346.83 5164.60 2945.21 -1394.32 3.52 16.38 3215.71 Start 7.93 hold at 6521.76 MD 13 6529.69 84.94 346.83 5165.30 2952.89 -1396.12 0.00 0.00 3223.60 Start DLS 3.50 TFO -18.12 14 6622.20 88.00 345.83 5171.00 3042.60 -1417.94 3.50 -18.12 3315.84 3T Deserted T01 090925 Start DLS 1.50 TFO 0.04 15 6759.96 90.07 345.83 5173.32 3176.15 -1451.65 1.50 0.04 3453.51 Start 1977.66 hold at 6759.96 MD 16 8737.62 90.07 345.83 5171.03 5093.65 -1935.74 0.00 0.00 5430.12 Start DLS 1.00 TFO -0.63 17 8750.98 90.20 345.83 5171.00 5106.60 -1939.01 1.00 -0.63 5443.47 3T Deserted T02 090925 Start DLS 1.00 TFO -1.93 18 8761.90 90.31 345.83 5170.95 5117.18 -1941.68 1.00 -1.93 5454.39 Start 5541.11 hold at 8761.90 MD 1914303.01 90.31 345.83 5141.06 10489.53 -3298.47 0.00 0.0010992.51 Start DLS 1.00 TFO 2.32 2014312.10 90.40 345.83 5141.00 10498.35 -3300.69 1.00 2.3211001.60 3T Deserted T03 090925 Start DLS 1.00 TFO 2.47 21 14320.07 90.48 345.83 5140.94 10506.07 -3302.64 1.00 2.4711009.56 Start 3574.65 hold at 14320.07 MD 2217894.72 90.48 345.83 5111.02 13971.89 -4177.48 0.00 0.0014582.19 Start DLS 1.00 TFO -170.08 2317896.71 90.46 345.83 5111.00 13973.82 -4177.97 1.00 -170.0814584.18 3T Deserted T04 090925 Start DLS 1.00 TFO 175.32 2417898.60 90.44 345.83 5110.99 13975.66 -4178.43 1.00 175.3214586.08 Start 2587.67 hold at 17898.60 MD 25 20486.27 90.44 345.83 5091.06 16484.54 -4811.80 0.00 0.0017172.31 Start DLS 1.00 TFO -179.03 26 20495.39 90.35 345.83 5091.00 16493.37 -4814.03 1.00 -179.0317181.41 3T Deserted T05 090925 Start DLS 1.00 TFO -177.07 27 20504.82 90.26 345.83 5090.95 16502.52 -4816.34 1.00 -177.0717190.84 Start 2228.55 hold at 20504.82 MD 28 22733.37 90.26 345.83 5081.00 18663.19 -5362.07 0.00 0.0019418.20 3T Deserted T06 090925 TD at 22733.37 FORMATION TOP DETAILS TVDPath Formation 1344.88 Top Ugnu C 1553.00 Base Perm 1964.00 Top West Sak 2368.00 Base West Sak 2581.00 C-80 3713.00 C-35 4075.00 Coyote 4186.00 Coyote Base 4980.00 Moraine 5155.00 Lower Moraine By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan 12+39 @ 51.00usft (D142) -25000250050007500True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500 20000Vertical Section at 343.97°10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner100060007000 8000 9000 10 00 0 11 000 12 00 0 13 00 0 14 00 0 1 500 0 1 6 000 17 00 0 18 000 1 90 00 20000 21000 22000 22734 0°49°90°90° 90 ° 9 0° 90 ° 90 ° 3T-609 wp08.1 Top Ugnu CBase PermTop West SakBase West SakC-80C-35CoyoteCoyote BaseMoraineLower Moraine3T-609 wp08.113:03, October 16 2025Section View 035007000105001400017500South(-)/North(+)-14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+)10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner5001000150020002500300035004000500050813T-609 wp08.13T-609 wp08.1While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.13:07, October 16 2025 0.000.501.001.502.002.503.003.504.004.505.005.50Separation Factor0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 16250 17500 18750 20000 21250 22500Measured Depth (2500 usft/in)3S-6113S-626ODST-473T-6083T-611 wp14.13T-6173T-617A wp023T-607 wp053T-610 wp05STOP DrillingTake Immediate ActionCaution - Monitor CloselyNormal OperationsProject: Kuparuk River Unit_2Site: Kuparuk 3T PadWell: 3T-609Wellbore: 3T-609Design: 3T-609 wp08.1 0 30 60 Centre to Centre Separation0 500 1000 1500 2000 2500 Partial Measured Depth Equivalent Magnetic Distance 3T-609 wp08.1 Ladder View 0 150 300 Centre to Centre Separation0 3500 7000 10500 14000 17500 21000 Measured Depth Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.00 1450.00 3T-609 wp08.1 (3T-609) r.5 SDI_URSA1 1450.00 2590.00 3T-609 wp08.1 (3T-609) MWD+IFR2+SAG+MS 2590.00 5880.00 3T-609 wp08.1 (3T-609) MWD+IFR2+SAG+MS 5880.00 22733.37 3T-609 wp08.1 (3T-609) MWD+IFR2+SAG+MS 13:27, October 16 2025 CASING DETAILS TVD MD Name 2483.00 2600.25 10-3/4" Surface Casing 4992.00 5889.33 7-5/8" Intermediate Casing 5081.00 22733.37 4-1/2" Production Liner 3T-609 wp08.1 TC View 30 30 60 60 90 90 120 120 150 150 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 144561450114546145901463514680147251476914814148591490414949149941503815083NDST-02 3950100150200 2503003504004505005495996496997497998498993T-603 39501001502002503003504004505005506006507007508008498999499981048109711461195124412923T-605 395010015020025030035040045050055060065070075080085090095099910491099114911981248129813471397144714961546 1595 16441694174417931842189219413T-608 39501001502002503003504004505005506006507007507998498999499991049 109911481198124812981348139814481498154815981648169817481798184818981949199920492100215022012251230223522403245425042555260626572707275628042853 2902 2951 3000 3049 3097 3145 31933T-611 wp14.1 3950100150200250 3003504004505005506006507007508008498999499991048109811471197124612961345139414431492154115901640168917383T-612 39 501001502002503003504004505005506006507007508008509009501000105011011151120112511301135214021452150315531602165317041755180618573T-613 395010015020025030035040045050055060065070075080085090095010001050110011501200125013011351140114511502155216013T-614 50100150200250300350400450500550600650700750800850900950100010501100115012011251130113511402145215021552160116523T-614 wp14 3950100150200250300350400449499 548 598 646 6953T-616 3950100150200250300350400449499 548 598 646 6953T-616PB1 3950100150200250300350400449499 548 598 646 6953T-616PB2 3950100150200250300350400450500550600650699749799850900950 3T-617 3950100150200250300350400450500550600650699749799850900950 3T-617A wp02 39501001502002503003504004505005506006503T-601 wp05 v5 3950100150200250300350400450 5005506006506997483T-602 wp05 v5 3950100150200250300350400450500550600650700750800849899948 9973T-604 wp05 v5 3950100150200250300350400450500550600650700750799 84989894899710461094114311911238 12863T-606 wp08 3950100150200250300350400450500550600650700751801851901951100110501100115012001250 1300 1350 1400 14491499 1549 1598 16473T-607 wp05 395010015020025030035040045050055060065070075080085190195110011051110111511202125213021352 1403 1453 1503 1553 1603 1653 1704 1755 1806 1858 1909 1960 2012 2063 2115 2166 2218 22703T-610 wp05 3950100150200250300350400450500550600650700750800850900950100010501100115012001251130113513T-615 wp09.1 SURVEY PROGRAM Date: 2019-07-03T00:00:00 Validated: Yes Version: From To Tool 39.00 1450.00 r.5 SDI_URSA1 1450.00 2590.00 MWD+IFR2+SAG+MS 2590.00 5880.00 MWD+IFR2+SAG+MS 5880.00 22733.37 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2483.00 2600.25 10-3/4" Surface Casing 4992.00 5889.33 7-5/8" Intermediate Casing 5081.00 22733.37 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00 3 600.00 2.00 330.00 599.96 3.02 -1.75 1.00 330.00 3.39 Start Build 1.50 4 1514.09 15.71 330.00 1501.00 124.60 -71.94 1.50 0.00 139.62 Start 103.88 hold at 1514.09 MD 5 1617.97 15.71 330.00 1601.00 148.96 -86.00 0.00 0.00 166.92 Start Build 2.00 6 2684.52 37.04 330.00 2551.00 556.95 -321.56 2.00 0.00 624.09 Start 20.00 hold at 2684.52 MD 7 2704.52 37.04 330.00 2566.96 567.38 -327.58 0.00 0.00 635.78 Start DLS 2.50 TFO 176.26 8 2813.83 34.32 330.32 2655.75 622.68 -359.31 2.50 176.26 697.69 Start 1848.00 hold at 2813.83 MD 9 4661.84 34.32 330.32 4182.10 1527.78 -875.23 0.00 0.00 1710.06 Start DLS 3.00 TFO 19.51 10 5169.42 48.90 337.00 4560.79 1829.90 -1021.67 3.00 19.51 2040.87 Start 300.00 hold at 5169.42 MD 11 5469.42 48.90 337.00 4758.00 2038.00 -1110.00 0.00 0.00 2265.27 Start DLS 3.52 TFO 16.38 12 6521.76 84.94 346.83 5164.60 2945.21 -1394.32 3.52 16.38 3215.71 Start 7.93 hold at 6521.76 MD 13 6529.69 84.94 346.83 5165.30 2952.89 -1396.12 0.00 0.00 3223.60 Start DLS 3.50 TFO -18.12 14 6622.20 88.00 345.83 5171.00 3042.60 -1417.94 3.50 -18.12 3315.84 3T Deserted T01 090925 Start DLS 1.50 TFO 0.04 15 6759.96 90.07 345.83 5173.32 3176.15 -1451.65 1.50 0.04 3453.51 Start 1977.66 hold at 6759.96 MD 16 8737.62 90.07 345.83 5171.03 5093.65 -1935.74 0.00 0.00 5430.12 Start DLS 1.00 TFO -0.63 17 8750.98 90.20 345.83 5171.00 5106.60 -1939.01 1.00 -0.63 5443.47 3T Deserted T02 090925 Start DLS 1.00 TFO -1.93 18 8761.90 90.31 345.83 5170.95 5117.18 -1941.68 1.00 -1.93 5454.39 Start 5541.11 hold at 8761.90 MD 1914303.01 90.31 345.83 5141.06 10489.53 -3298.47 0.00 0.0010992.51 Start DLS 1.00 TFO 2.32 2014312.10 90.40 345.83 5141.00 10498.35 -3300.69 1.00 2.3211001.60 3T Deserted T03 090925 Start DLS 1.00 TFO 2.47 21 14320.07 90.48 345.83 5140.94 10506.07 -3302.64 1.00 2.4711009.56 Start 3574.65 hold at 14320.07 MD 2217894.72 90.48 345.83 5111.02 13971.89 -4177.48 0.00 0.0014582.19 Start DLS 1.00 TFO -170.08 2317896.71 90.46 345.83 5111.00 13973.82 -4177.97 1.00 -170.0814584.18 3T Deserted T04 090925 Start DLS 1.00 TFO 175.32 2417898.60 90.44 345.83 5110.99 13975.66 -4178.43 1.00 175.3214586.08 Start 2587.67 hold at 17898.60 MD 25 20486.27 90.44 345.83 5091.06 16484.54 -4811.80 0.00 0.0017172.31 Start DLS 1.00 TFO -179.03 26 20495.39 90.35 345.83 5091.00 16493.37 -4814.03 1.00 -179.0317181.41 3T Deserted T05 090925 Start DLS 1.00 TFO -177.07 27 20504.82 90.26 345.83 5090.95 16502.52 -4816.34 1.00 -177.0717190.84 Start 2228.55 hold at 20504.82 MD 28 22733.37 90.26 345.83 5081.00 18663.19 -5362.07 0.00 0.0019418.20 3T Deserted T06 090925 TD at 22733.37 3T-609 wp08.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 1450.00 r.5 SDI_URSA11450.00 2590.00 MWD+IFR2+SAG+MS2590.00 5880.00 MWD+IFR2+SAG+MS5880.00 22733.37 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2483.00 2600.2510-3/4" Surface Casing4992.00 5889.33 7-5/8" Intermediate Casing5081.00 22733.37 4-1/2" Production Liner10102020303040405050606070700901802703021060240 120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]39501001502002503003504004505005506006507007508008509009509991049109911491198124812983T-608395010015020025030035040045050055060065070075079984989994999910491099114811981248129813481398144814981548159816481698174817981848189819491999204921002150220122512302235224033T-611 wp14.139501001502002503003504004505005506006507007508008498993T-61239501001502002503003504004505005506006507007507993T-606 wp0839501001502002503003504004505005506006507007518018519019513T-607 wp053950100150200250300350400450500550600650700750800851901951100110511101115112021252130213521403145315033T-610 wp05From Colour To MD39.00 To 2700.00MD Azi TFace39.00 0.00 0.00400.00 0.00 0.00600.00 330.00 330.001514.09 330.00 0.001617.97 330.00 0.002684.52 330.00 0.002704.52 330.00 0.002813.83 330.32 176.264661.84 330.32 0.005169.42 337.00 19.515469.42 337.00 0.006521.76 346.83 16.386529.69 346.83 0.006622.20 345.83 -18.126759.96 345.83 0.048737.62 345.83 0.008750.98 345.83 -0.638761.90 345.83 -1.9314303.01 345.83 0.0014312.10 345.83 2.3214320.07 345.83 2.4717894.72 345.83 0.0017896.71 345.83 -170.0817898.60 345.83 175.3220486.27 345.83 0.0020495.39 345.83 -179.0320504.82 345.83 -177.0722733.37 345.83 0.00 3T-609 wp08.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 1450.00 r.5 SDI_URSA11450.00 2590.00 MWD+IFR2+SAG+MS2590.00 5880.00 MWD+IFR2+SAG+MS5880.00 22733.37 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2483.00 2600.2510-3/4" Surface Casing4992.00 5889.33 7-5/8" Intermediate Casing5081.00 22733.37 4-1/2" Production Liner3030606090901201201501501801802102100901802703021060240 120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]2606265727072756280428532902295130003049309731453193324032873T-611 wp14.1From Colour To MD2600.00 To 5900.00MD Azi TFace39.00 0.00 0.00400.00 0.00 0.00600.00 330.00 330.001514.09 330.00 0.001617.97 330.00 0.002684.52 330.00 0.002704.52 330.00 0.002813.83 330.32 176.264661.84 330.32 0.005169.42 337.00 19.515469.42 337.00 0.006521.76 346.83 16.386529.69 346.83 0.006622.20 345.83 -18.126759.96 345.83 0.048737.62 345.83 0.008750.98 345.83 -0.638761.90 345.83 -1.9314303.01 345.83 0.0014312.10 345.83 2.3214320.07 345.83 2.4717894.72 345.83 0.0017896.71 345.83 -170.0817898.60 345.83 175.3220486.27 345.83 0.0020495.39 345.83 -179.0320504.82 345.83 -177.0722733.37 345.83 0.00 3T-609 wp08.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 1450.00 r.5 SDI_URSA11450.00 2590.00 MWD+IFR2+SAG+MS2590.00 5880.00 MWD+IFR2+SAG+MS5880.00 22733.37 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2483.00 2600.2510-3/4" Surface Casing4992.00 5889.33 7-5/8" Intermediate Casing5081.00 22733.37 4-1/2" Production Liner3030606090901201201501501801802102100901802703021060240 120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]14367144111445614501145461459014635146801472514769148141485914904149491499415038150831512715172NDST-02From Colour To MD5800.00 To 22734.00MD Azi TFace39.00 0.00 0.00400.00 0.00 0.00600.00 330.00 330.001514.09 330.00 0.001617.97 330.00 0.002684.52 330.00 0.002704.52 330.00 0.002813.83 330.32 176.264661.84 330.32 0.005169.42 337.00 19.515469.42 337.00 0.006521.76 346.83 16.386529.69 346.83 0.006622.20 345.83 -18.126759.96 345.83 0.048737.62 345.83 0.008750.98 345.83 -0.638761.90 345.83 -1.9314303.01 345.83 0.0014312.10 345.83 2.3214320.07 345.83 2.4717894.72 345.83 0.0017896.71 345.83 -170.0817898.60 345.83 175.3220486.27 345.83 0.0020495.39 345.83 -179.0320504.82 345.83 -177.0722733.37 345.83 0.00 3T-609 wp08.1Spider Plot13:46, October 16 202539.00 To 22733.98Northing (8000 usft/in)Easting (8000 usft/in)3545453540455035404550354040404540503540455040455040354045503540453540453540453540455035404550354550354550 404550403 54045 3 5 4 0 4 550 35404550354045354045354 0 354 0 455035404 5 5035404 5 50354045503540455035404 5 50354045503 5 40 4 5 503540455035403540354035404550 3T-609 wp08.1Spider Plot13:46, October 16 202539.00 To 22733.98Northing (1500 usft/in)Easting (1500 usft/in)35454540404540503540455040455040354045503540455035404550354550354550 404550403 5 4 0 3 5 4 0 35404550354045354045354 0 354 0 455035404 5 35403540453540455035403 5 4 03540 454550 3T-609 wp08.1Spider Plot13:52, October 16 202539.00 To 22733.98Northing (150 usft/in)Easting (150 usft/in)46810121646810121641618468101620222410121418222426 121418202426246812161822212162461618202468141624681416246814162681012141620222681012141620222681012141618202424 68141828 12142022242468101214182022242 6 28261012161822242 62830 3438261012161822242 62830 3438246810121424 8 10 1 2 268101214161824610121416182024681012161820224182101214161820222424681012141820242461822248101214161820222468101214161820222468101216182024624681012141618202224681012141618202224810246810242421224681012141618202224 3T-609 wp08.1NDST-02NDST-02PB1ODST-473S-6113S-6263T-6033T-6053T-6083T-611 wp14.13T-6123T-6133T-6143T-6163T-616PB13T-616PB23T-6173T-617A wp023T-6193T-6213T-6223T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-606 wp083T-607 wp053T-610 wp053T-624 wp05 v53T-625 wp07.13T-628 wp063T-629 wp05 v53-D View3T-609 wp08.114:08, October 16 2025 3T-609 wp08.1NDST-02NDST-02PB1ODST-473S-6113S-6263T-6033T-6053T-6083T-611 wp14.13T-6123T-6143T-614 wp143T-6163T-616PB13T-616PB23T-6173T-617A wp023T-6213T-6223T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-606 wp083T-607 wp053T-610 wp053T-615 wp09.13T-618 w3T-624 wp05 v53T-625 wp07.13T-628 wp063T-629 wp05 v53-D View3T-609 wp08.114:10, October 16 2025 035007000105001400017500South(-)/North(+) (3500 usft/in)-17500 -14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+) (3500 usft/in)50505100NDST-02505051005150NDST-02PB15150505051003T-60350505150510051503T-608510051503T-611 wp14.1505051503T-612505051003T-614 wp143T-616PB151003T-6195 0 5 051005150 3 T-6 2 1 505051003T-7303T-731A wp0251505100505051005150505051005050515050505100515051005100505050503T-624 wp05 v55100505050503T-628 wp0610-3/4" Surface Casing7-5/8" Intermediate Casing510051503T-609 wp08.13T-609 wp08.1Quarter Mile View13:58, October 16 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Deserted T01 090925 5171.00 Circle (Radius: 100.00)3T Deserted T02 090925 5171.00 Circle (Radius: 100.00)3T Deserted T03 090925 5141.00 Circle (Radius: 100.00)3T Deserted T04 090925 5111.00 Circle (Radius: 100.00)3T Deserted T05 090925 5091.00 Circle (Radius: 100.00)3T Deserted T06 090925 5081.00 Circle (Radius: 100.00)3T-609 T01 QM 5171.00 Circle (Radius: 1320.00)3T-609 T03 QM 5141.00 Circle (Radius: 1320.00)3T-609 T06 QM 5081.00 Circle (Radius: 1320.00) 035007000105001400017500South(-)/North(+) (3500 usft/in)-17500 -14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+) (3500 usft/in)50505100NDST-02505051005150NDST-02PB110-3/4" Surface Casing7-5/8" Intermediate Casing510051503T-609 wp08.13T-609 wp08.1Quarter Mile View14:03, October 16 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Deserted T01 090925 5171.00 Circle (Radius: 100.00)3T Deserted T02 090925 5171.00 Circle (Radius: 100.00)3T Deserted T03 090925 5141.00 Circle (Radius: 100.00)3T Deserted T04 090925 5111.00 Circle (Radius: 100.00)3T Deserted T05 090925 5091.00 Circle (Radius: 100.00)3T Deserted T06 090925 5081.00 Circle (Radius: 100.00)3T-609 T01 QM 5171.00 Circle (Radius: 1320.00)3T-609 T03 QM 5141.00 Circle (Radius: 1320.00)3T-609 T06 QM 5081.00 Circle (Radius: 1320.00) 02004006008001000South(-)/North(+) (200 usft/in)-1000 -800 -600 -400 -200 0 200 400 600West(-)/East(+) (200 usft/in)NDST-023T-60324833T-60824833T-611 wp14.124833T-612248324833T-614248324833T-6193 T-6 21 2 4 8 3 3T-7302 4 8 310-3/4" Surface Casing24833T-609 wp08.13T-609 wp08.1 15:23, October 15 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Deserted T01 090925 5171.00 Circle (Radius: 100.00)3T Deserted T02 090925 5171.00 Circle (Radius: 100.00)3T Deserted T03 090925 5141.00 Circle (Radius: 100.00)3T Deserted T04 090925 5111.00 Circle (Radius: 100.00)3T Deserted T05 090925 5091.00 Circle (Radius: 100.00)3T Deserted T06 090925 5081.00 Circle (Radius: 100.00)3T-609 Srf Csg 2483.00 Circle (Radius: 500.00) 3T-609 wp08.1 Surface Location 3T-609 wp08.1 Surface Location # Schlumberger-Confidential 3T-609 wp08.1 Surface Casing 3T-609 wp08.1 Surface Casing # Schlumberger-Confidential 3T-609 wp08.1 Top Moraine 3T-609 wp08.1 Top Moraine # Schlumberger-Confidential 3T-609 wp08.1 Intermediate Csg 3T-609 wp08.1 Intermediate Csg # Schlumberger-Confidential 3T-609 wp08.1 TD 3T-609 wp08.1 TD # Schlumberger-Confidential Certificate Of Completion Envelope Id: 3C3B93F4-207B-4164-9897-7C62ECEC389D Status: Completed Subject: Complete with Docusign: 3T-609 Permit Submission.pdf Source Envelope: Document Pages: 61 Signatures: 1 Envelope Originator: Certificate Pages: 4 Initials: 0 Matt Smith AutoNav: Enabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 925 N Eldridge Pkwy Houston, TX 77079 Matt.Smith2@conocophillips.com IP Address: 20.236.201.103 Record Tracking Status: Original 10/17/2025 10:51:09 AM Holder: Matt Smith Matt.Smith2@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Chris Brillon chris.l.brillon@cop.com Security Level: Email, Account Authentication (None) Signature Adoption: Pre-selected Style Using IP Address: 138.32.8.5 Sent: 10/17/2025 10:55:58 AM Viewed: 10/17/2025 4:31:32 PM Signed: 10/17/2025 4:37:04 PM Electronic Record and Signature Disclosure: Accepted: 10/17/2025 4:31:32 PM ID: 769361ca-df09-4fd2-a5a2-633474278b72 In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 10/17/2025 10:55:58 AM Certified Delivered Security Checked 10/17/2025 4:31:32 PM Signing Complete Security Checked 10/17/2025 4:37:04 PM Completed Security Checked 10/17/2025 4:37:04 PM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. 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Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. KUPARUK RIVER 225-111 KUPARUK RIVER, TOROK OIL KRU 3T-609 WELL PERMIT CHECKLISTCompany ConocoPhillips Alaska, Inc.Well Name: KUPARUK RIVER UNIT 3T-609Initial Class/TypeDEV / PENDGeoArea890 Unit 11160On/Off ShoreOnProgram DEVWell bore segAnnular DisposalPTD#:2251110Field & Pool:KUPARUK RIVER, TOROK OIL - 490169NA1 Permit fee attachedYes Surf Loc & Top Prod Int lie in ADL0025528; TD lies within ADL0393883.2 Lease number appropriateYes3 Unique well name and numberYes KUPARUK RIVER, TOROK OIL - 490169 - governed by CO 725A4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14Well 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)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 81' conductor18 Conductor string providedYes SC set at 2600' MD19 Surface casing protects all known USDWsYes 162% excess cement planned20 CMT vol adequate to circulate on conductor & surf csgNo21 CMT vol adequate to tie-in long string to surf csgYes Cemented production liner with frac sleeves22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes Diverter variance granted per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulationsYes Max reservoir pressure is 2233 psig(8.6 ppg EMW); will drill w/ 9.0-10.0 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 1764 psig; will test BOPs to 5000 psig and subsequently to 4000 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes None expected.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure is 0.447 psi/ft (8.6 ppg EMW). Operator's planned mud program36 Data presented on potential overpressure zonesNA appears sufficient to control anticipated pressures and maintain wellbore stability.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate10/31/2025ApprVTLDate12/17/2025ApprSFDDate10/31/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 12/17/2025