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Home My WebLink About225-1031. 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?N/A Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Kuparuk River Field / Coyote Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4507 1343 4-1/2" CICR & CMT 4590' MD None Casing Collapse Structural Conductor Surface 2470 Intermediate 4790 / 7870 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:For lower abandonment Date: GAS WAG GSTOR SPLUG AOGCC Representative: Victoria Loepp GINJ Op Shutdown Abandoned Contact Name: Cameron Johnson Contact Email: Contact Phone:907-223-6277 Authorized Title: Drilling Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3984 4507 3984 cameron.johnson2@cop.com 11/12/2025 Packer: SSSV: None 4429 2585' Perforation Depth MD (ft): 4469 20" 10-3/4" 80' 3968 120' 2625' 7-5/8" Length Size TVD BurstMD 6890 / 10860 5210 120' 2511' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025528 / ADL025544 225-103 P.O. Box 100360, Anchorage, AK 99510 50-103-20905-01-00 ConocoPhillips Alaska Inc KRU 3T-731A 11/11/2025 Tubing Grade: Tubing MD (ft): Packer: SSSV: N/A Perforation Depth TVD (ft): Tubing Size: 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 P 2 6 5 6 t _ Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 325-695 By Grace Christianson at 12:38 pm, Nov 12, 2025 x X 10-407 DSR-11/13/25 BOP test to 4000 psig Annular preventer test to 2500 psig no X X SFD 11/13/2025VTL 11/13/2025JLC 11/13/2025 11/13/25 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 12, 2025 Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application: Plug for Redrill for KRU 3T-731A (PTD 225-103) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry to plug back the KRU 3T-731A well with the intention re-drill the well from the surface casing shoe to TD. Future drilling operations include kicking off a cement plug under the surface casing shoe, drilling a 9-7/8 intermediate hole section, running and cementing 7-5/8 casing, and drilling a 6-1/2 production section that will be completed with a cemented 4-1/2 liner. The predicted start date for the plug back operations is 11/12/2025. Doyon Rig 142 will perform the work. The sidetrack and drilling procedure will be covered in a separate Application for a Permit to Drill. 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 10-403 2. A proposed abandonment program 3. 3T-731A current schematic 4. 3T-731A Proposed Plug Back 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 Cameron Johnson at 907-223-6277 (cameron.johnson2@conocophillips.com) Sincerely, cc: 3T-731A Well File / Jenna Taylor ATO 1804 Will Earhart ATO 1552 Cameron Johnson Chris Brillon ATO 1548 Drilling Engineer Patrick Perfetta ATO 1408 KRU 3T-731A AOGCC Sundry Saved: 12-Nov-25 Change to Approved Sundry, Well KRU 3T-731A Page 1 of 5 Printed: 12-Nov-25 KRU 3T-731 PTD# 225-103 Application for Sundry Approval Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ..................................................................... 2 2. Overview................................................................................................................................... 2 3. Planned Operations.................................................................................................................. 2 4. BOPE Information..................................................................................................................... 2 5. Casing and Cementing In Place ................................................................................................ 2 6. Abandonment Cement ............................................................................................................. 3 7. Discussion of Mud and Cuttings Disposal................................................................................ 3 8. Schematics ................................................................................................................................ 5 KRU 3T-731A AOGCC Sundry Saved: 12-Nov-25 Change to Approved Sundry, Well KRU 3T-731A Page 2 of 5 Printed: 12-Nov-25 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted for is KRU 3T-731A 2. Overview The KRU 3T-731A well re-entered with the intention to re-drill the production lateral. Below is an overview of the well operations. 1. The original lateral was abandoned with coil tubing prior to the rig moving on. 2. 4-1/2 upper completion was pulled from the pre-rig cut 3. A whipstock was set, and a window was milled in the 7-5/8 Casing 1. Top of Window: 4469' MD / 3968' TVD 2. Bottom of Window: 4483' MD / 3974' TVD 4. 20 of new formation was drilled in the C35 formation 5. A LOT was performed to 12.9 ppg EMW 6. A mud motor BHA was picked up and run in hole. 7. Pack-off tendencies and instability was observed when drilling began and overpull was observed while pulling back into the window 8. A milling assembly was made up and run in hole to recover the window exit. 1. Instability continued. The decision was made to plug back and re-drill from under the surface casing shoe 3. Planned Operations 1. A 7-5/8 Cement Retainer will be run in hole and set above the window in the 7-5/8 casing 2. Cement will be squeezed into the open hole to abandon the rat-hole. 1. A small amount of cement will be left on top of the retainer 3. A 7-5/8 Cast Iron Bridge Plug will be set 300-500 below the surface casing shoe 4. The 7-5/8 Casing will be cut above this bridge plug 5. The 7-5/8 Casing will be pulled from this cut 6. A cement kick-off plug will be spotted on the cast iron bridge plug up into the surface casing shoe 7. The well will be re-drilled after kicking off this plug This will be covered under an application for a permit to drill. 1. A 9-7/8 Intermediate section will be drilled and 7-5/8 casing will be run. 2. The 6-1/2 Production section will be drilled as previously planned and completed with a cemented 4- 1/2 liner with frac sleeves. 4. BOPE Information Please reference BOPE schematics on file for Doyon 142 5. Casing and Cementing In Place Cement in Place Behind Casing The 3T-731 well was completed as a two-string well. The 10-3/4 surface casing was run and cemented with the following. 150 bbls of 11.0 ppg Lead Cement was returned to surface. OD Hole Size Depth (MD) Weight Grade Conn. 20 42 120 94 H-40 Welded 10 3/4 13 1/2 2625 45.5 L-80 Hyd563 7 5/8 9 7/8 3943 29.7 L-80 Hyd563 7 5/8 9 7/8 4785 33.7 P-110S Hyd563 4 1/2 8 3/4 13192 12.6 P-110S Hyd563-MS 2491 sx of 14.8 ppg Lead and 226 sx of 15.3 ppg Tail. TOC logged at 4010' MD / 3717' TVD Casing and Cement In Place Cement Program 10 yds 949 sx of 11.0 ppg Lead and 281 sx of 15.8 ppg Tail (cement returned to surface) VTL 11/13/25 State witnessed tag and PT required. KRU 3T-731A AOGCC Sundry Saved: 12-Nov-25 Change to Approved Sundry, Well KRU 3T-731A Page 3 of 5 Printed: 12-Nov-25 The 7-5/8 x 4-1/2 production casing string was run to TD. Lost circulation was experienced during the primary cement job. A cement log was run and the TOC was not sufficient. The 4-1/2 liner was perforated at 12725 MD and a secondary cement job was pumped as follows. A wireline cement evaluation was performed and the top of cement was found at 4010 MD / 3717 MD. The required TOC for this well was 500 MD / 250 TVD above the top of the Coyote formation at 4843 MD / 4106 TVD. The following interpretation was provided by the ConocoPhillips Cementing SME. Channeling of annular fluid from surface to 1,050 Fluid is most likely diesel pumped as freeze protection. From 1,050 to 3,240 fluid is very homogenous reading 20mV, this is most likely mud remaining in hole from previous operation due to losses during cement job. Amplitude of annular fluid drops from 20 mV to 10-11 mV from 3,240 to 3,920 most likely more mud from previous operation, again due to lack of removal because of losses during the cement job. Moderate to good bond from 3,920 to 3,980 Kick to the left on Gamma indicates the possible loss zone at 3,970 3,980. 3,980 to 4,010 Moderate bond. Good cement bond for Isolation from 4,010 to 4,830. Coil Tubing Abandonment Prior to Doyon 142 moving onto 3T-731 to redrill the production lateral, the original production lateral was abandoned with coil tubing as follows. A 4-1/2 cement retainer was set at 4590 MD 56 bbls of 15.8 ppg cement was bullheaded below retainer to abandon lateral A state witnessed tag and MIT-T was performed. 6. Abandonment Cement Abandonment Plug The rathole below the window in the 7-5/8 casing will be abandoned by placing a 7-5/8 cement retainer in the 7- 5/8 Casing at 4385' MD / 3930' TVD, above the window in the 7-5/8 casing. 30 bbls of 16.5 ppg Glass G Cement will pumped, 20 bbls will be squeezed below the retainer and the rest will be placed on top of the retainer. This will be tagged and pressure tested to 1500 psi for 30 minutes, to be witnessed by AOGCC inspector. Kick Off Plug A 7-5/8 cement retainer will be set in the 7-5/8 casing at 3000 MD. The 7-5/8 casing will be cut and pulled above this retainer. A 16.5 ppg cement kick off plug will be placed on top of the cement retainer with a planned top of the plug at 2425 MD, 200 inside the surface casing shoe. 7. Discussion of Mud and Cuttings Disposal Lead Tail 438 bbls => 949 sx of 11.0 ppg + Add's @ 2.59 ft³/sk 58 bbls => 281 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk Lead Tail 590 bbls => 2491 sx of 14.8 ppg Class G + Add's + Add's @ 1.33 ft³/sk 50 bbls => 226 sx of 15.3 ppg Class G + Add's + Add's @ 1.24 ft³/sk KRU 3T-731A AOGCC Sundry Saved: 12-Nov-25 Change to Approved Sundry, Well KRU 3T-731A Page 4 of 5 Printed: 12-Nov-25 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. KRU 3T-731A AOGCC Sundry Saved: 12-Nov-25 Change to Approved Sundry, Well KRU 3T-731A Page 5 of 5 Printed: 12-Nov-25 8. Schematics Current Schematic KRU 3T-731A AOGCC Sundry Saved: 12-Nov-25 Change to Approved Sundry, Well KRU 3T-731A Page 6 of 5 Printed: 12-Nov-25 Abandonment Schematic Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer SFD 11/13/2025 325-695 KRU 3T-731A 225-103 SFD 11/13/2025 From:Loepp, Victoria T (OGC) To:Cameron Johnson Subject:Re: KRU 3T-731A (PTD 225-103) Sundry Application - Plug for Re-Drill - APPROVAL Date:Wednesday, November 12, 2025 9:45:21 PM Cameron, Approval is granted to proceed as outlined below. Victoria Sent from my iPhone On Nov 12, 2025, at 9:22PM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: Victoria, Schlumberger loaded out 50 bbls of 16.5 ppg cement. The rig will pump all 50 bbls. Placing ~35 bbls below the cement retainer and leave ~15 bbls on top of the retainer. Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Johnson, Cameron Sent: Wednesday, November 12, 2025 8:54 PM To: 'Loepp, Victoria T (OGC)' <victoria.loepp@alaska.gov>; 'Guhl, Meredith D (OGC' <meredith.guhl@alaska.gov>; 'Dewhurst, Andrew D (OGC)' <andrew.dewhurst@alaska.gov>; 'Davies, Stephen F (OGC)' <steve.davies@alaska.gov>; 'Starns, Ted C (OGC)' <ted.starns@alaska.gov>; 'AOGCC Permitting (CED sponsored)' <aogcc.permitting@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: KRU 3T-731A (PTD 225-103) Sundry Application - Plug for Re-Drill Victoria, As discussed on the phone, the rig was unable to get to the originally planned set depth of the retainer for the lower abandonment. The plan forward for the rig is outlined below. Set cast iron cement retainer at current depth of 4135 MD. Pump the abandonment cement plug as previously planned Pump 35 bbls 16.5 ppg cement. Bullhead 20 bbls below the retainer, leaving 15 bbls on top of the retainer. The volume below the retainer to TD of the rat hole is 16.4 bbls (14.8 bbls inside 7-5/8 casing and 1.6 bbls in the open hole). Please reply to this email with approval to proceed. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Johnson, Cameron Sent: Wednesday, November 12, 2025 12:33 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Guhl, Meredith D (OGC <meredith.guhl@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: KRU 3T-731A (PTD 225-103) Sundry Application - Plug for Re-Drill Good afternoon Attached is the sundry package for plugging back the KRU 3T-731A well to be re-drilled from under the surface casing shoe. As noted in the email below, verbal approval has been given to begin the abandonment process. This work is anticipated to start on this evening around 18:00 hrs. An application for a permit to drill will be submitted for the re-drill of this well. Please let me know if you have any questions regarding the sundry application. Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, November 11, 2025 6:53 PM To: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Subject: Re: [EXTERNAL]Re: 3T-731A_PTD 225-103_Status Update and Proposed Abandonment APPROVAL Yes Sent from my iPhone On Nov 11, 2025, at 3:18 PM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: Victoria, Thank you for the quick response. Just to confirm, you have given verbal approval to perform the lower abandonment tonight (cement retainer and Plug #1) if the wellbore cannot be recovered. A 10-403 will be submitted tomorrow if we move forward with abandonment. A 10-401 will follow for the new PTD. Notification will be made to the AOGCC inspectors for the tag and pressure test if we do move forward with abandonment. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, November 11, 2025 3:13 PM To: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL]Re: 3T-731A_PTD 225-103_Status Update and Proposed Abandonment APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Cameron, A state witnessed tag and pressure test is required on the plug CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. back. Abandonment is approved if the existing well bore cannot be recovered. A change of approved sundry must be submitted before proceeding with further operations. A new 10-401 PTD will be required for the redrill. Victoria Sent from my iPhone On Nov 11, 2025, at 2:18 PM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: Victoria, To summarize our conversation: Previous Ops: 1. 4-1/2 upper completion was pulled from the pre-rig cut 2. The whipstock was set, and a window was milled in the 7-5/8 Casing 1. Top of Window: 4469' MD / 3968' TVD 2. Bottom of Window: 4483' MD / 3974' TVD 3. 20 of new formation was drilled in the C35 formation 4. A LOT was performed to 12.9 ppg EMW 5. A mud motor BHA was picked up and run in hole. 6. Pack-off tendencies were observed when drilling began and overpull was observed while pulling back into the window Current operation: 1. A milling assembly is being made up and run in hole to dress the window and clean up the rat hole. Plan forward (successful milling run) 2. If the milling assembly is successful in cleaning up the window/rat hole, a kick-off assembly will be run back in hole and the well will continue as originally planned. Plan forward (unsuccessful milling run). The rig will begin the plug back process to re-drill the well from under the surface casing shoe. 1. A 7-5/8 Cement Retainer will be set above the window in the 7-5/8 casing 2. Cement will be squeezed into the open hole to abandon the rat-hole. 1. A small amount of cement will be left on top of the retainer 3. A 7-5/8 Cast Iron Bridge Plug will be set 300-500 below the surface casing shoe 4. The 7-5/8 Casing will be cut above this bridge plug 5. The 7-5/8 Casing will be pulled from this cut 6. A cement kick-off plug will be spotted on the cast iron bridge plug up into the surface casing shoe 7. The well will be re-drilled after kicking off this plug 1. A 9-7/8 Intermediate section will be drilled and 7-5/8 casing will be run. 2. The 6-1/2 Production section will be drilled as previously planned and completed with a cemented 4-1/2 liner with frac sleeves. Please find two schematics attached to this email. The first being the current status of the well, the second being the proposed abandonment. As discussed, the decision to move forward with the abandonment will likely be late tonight. Does the AOGCC give approval to proceed with the abandonment, if attempts at recovering the existing wellbore are not successful? Please do not hesitate to reach out if you have any questions. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK 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, Coyote Oil Pool, KRU 3T-731A Conoco Phillips Alaska, Inc. Permit to Drill Number: 225-103 Surface Location: 1634' FSL, 5151' FEL, S1, T12N, R7E, UM Bottomhole Location: 3393' FSL, 3293' FEL, S13, T12N, 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, Jessie L. Chmielowski Commissioner DATED this 29 th day of October 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: 13,192 TVD: 4181 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property:14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 51 15. Distance to Nearest Well Open Surface: x- 467338 y- 6003362 Zone- 4 12 to Same Pool: 284' to 3T-731 16. Deviated wells: Kickoff depth: 300 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# H40 Welded 80 40 40 120 120 13-1/2" 10-3/4" 45.5# L80 H563 2585 40 40 2625 2511 9-7/8" 7-5/8" 29.7# L80 H563 3903 40 40 3943 3887 9-7/8" 7-5/8" 33.7# P110-S H563 557 3943 3887 4500 3982 6-1/2" 4-1/2" 12.6# P110-S H563 8692 4350 3913 13192 4181 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 3717' TVD (logged) 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: Chris Brillon Contact Email:cameron.johnson2@cop.com Wells Engineering Manager Contact Phone: 907-223-6277 Date: Permit to Drill API Number: Permit Approval Number: Date: Conditions of approval : 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 Kuparuk River Field Coyote Oil Pool 11/23/2025 1907' to ADL025528 Cemented to surface with ~10 yds slurry 949 sx of 11.0 ppg Class G + Add's + 281 sx of 15.8 ppg Class G + Add's. Returns at surface 1343 Perforation Depth TVD (ft): 10 yards 4500 3982 Cement Volume MD 1761 If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 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: Cameron Johnson Commission Use Only See cover letter for other requirements. Production Perforation Depth MD (ft): Intermediate 4,500.00 7-5/8" 29.7# and 33.7# Liner Surface 2,586.00 10-3/4" Lead: 438 bbls of 11.0 ppg ArcticCem Tail: 58 bbls of 15.8 ppg Class G Surface Conductor/Structural 80.00 20" 13269 4178 ~4505' MD - 6139' MD Casing Length Size Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) P.O. Box 100360 Anchorage, Alaska, 99510-0360 1634 FSL, 5151 FEL, S1 T12N R7E, UM ADL025528 / ADL025544 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc 59-52-180 KRU 3S-731A 1017 FSL, 4679 FEL, S1 T12N R7E, UM LONS 01-013 3393 FSL, 3293 FEL, S13 T12N R7E, UM 2560 / 2560 GL / BF Elevation above MSL (ft): 2491 sx of 14.8 ppg Class G + Add's + 226 sx of 15.3 ppg Class G + Add's. Logged at 4010' MD 1061 sx of 15.3 ppg Class G + Add's Lead: 590 bbls of 14.8 ppg Class G Tail: 50 bbls of 15.3 ppg Class G 4010' MD (logged) N ype of W l 1b S Class: os N N s N D h Ye h o well is p G S S 20 A SS S Ns No S G E S N s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 225-103 By Grace Christianson at 2:00 pm, Oct 01, 2025 3T-731A 50-103-20905-01-00 TS 10/9/25 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 A.Dewhurst 24OCT25 4,500' 3887 X DSR-10/15/25 3887 VTL 10/29/2025 11/6/25 VTL 10/29/25 10/29/25 10/29/25 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 September 30, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 3T-731A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill to re-enter the 3T-731 well and re-drill the production lateral. The intended spud date for this well is 11/23/2025. Doyon 142 will perform the work. A 6-5/8 window will be milled at ~4500 in the existing 7-5/8 casing string on the 3T-731 well. Once the window is exited a 6-1/2 production lateral will be drilled in the Coyote formation to a total depth of ~13192 MD. The production lateral will be completed with a cemented 4-1/2 Liner containing frac sleeves. The upper completion will include a production packer with GLMs and a downhole gauge 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. This variance allows for effective drilling and completion of problematic zones and longer intervals in the well construction process. 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. Proposed drilling program 3. Proposed drilling fluids program summary 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.005 (c) (4) (a-c) 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 Cameron Johnson at 907-223-6277 (Cameron.johnson2@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: 3T-731A Well File / Jenna Taylor ATO 1804 Will Earhart ATO 1552 Cameron Johnson Chris Brillon ATO 1548 Drilling Engineer Patric Perfetta ATO-1408 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 1 | 12 3T-731A Well Plan Application for Permit to Drill Table of Contents 1. Well Name ............................................................................................................................................ 2 2. Location Summary ................................................................................................................................ 2 3. Proposed Drilling Program ................................................................................................................... 4 4. BOP and Diverter Information.............................................................................................................. 4 5. MASP Calculations ................................................................................................................................ 6 6. Procedure for Conducting Formation Integrity Tests .......................................................................... 7 7. Casing and Cementing Program ........................................................................................................... 7 8. Drilling Fluid Program ........................................................................................................................... 8 9. Abnormally Pressured Formation Information .................................................................................... 9 10. Seismic Analysis .................................................................................................................................... 9 11. Seabed Condition Analysis ................................................................................................................... 9 12. Evidence of Bonding ............................................................................................................................. 9 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ......................................................... 9 14. Drilling Hazards Summary .................................................................................................................. 10 15. Proposed Completion Schematic ....................................................................................................... 12 16. Attachments ....................................................................................................................................... 12 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 2 | 12 1. Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 3T-731A 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface 1634 FSL, 5151 FEL, S1 T12N R7E, UM NAD27 Northing: 6003362 Easting: 467338 RKB Elevation 51.1AMSL Pad Elevation 12AMSL Top of Productive Horizon (Heel) 1017 FSL, 4679 FEL, S1 T12N R7E, UM NAD27 Northing: 6002743 Easting: 467808 Measured Depth, RKB: 4850 Total Vertical Depth, RKB: 4100 Total Vertical Depth, SS: 4131 Total Depth (Toe) 3394 FSL, 3293 FEL, S13 T13N R7E, UM NAD27 Northing: 5994555 Easting: 469163 Measured Depth, RKB: 13192 Total Vertical Depth, RKB: 4181 Total Vertical Depth, SS: 4130 Pad Layout 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 3 | 12 Well Plat 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 4 | 12 3. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) 1. Continue operations from 3T-731 Sundry 2. Mill 6-5/8 window in 7-5/8 casing at 4500 MD 3. Dress window and pull out of the hole with the milling assembly 4. Pick up and run in hole with 6 1/2 drilling BHA. 5. Pass through window and drill 20 feet of new formation. Perform FIT. Minimum acceptable leak- off value is 11.0 ppg EMW. 6. Drill 6 1/2 hole to section TD of ~13192 MD (LWD Program: GR/RES/Den/Neu). 7. Circulate the hole clean and POOH. 8. Run 4 1/2 liner with toe valve, frac sleeves and liner hanger to TD. 9. Perform 4-1/2 liner cement job 10. Run 4 1/2 upper completion with glass plug, production packer, downhole gauge, and gas lift mandrels. Space out and land tubing hanger. 11. Pressure test hanger seals to 5000 psi. 12. Pressure up against the glass plug to set production packer, test tubing to 4200 psi, chart test. 13. Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test. 14. Install HP-BPV and test to 1500 psi. 15. Nipple down BOP. 16. Install tubing head adapter assembly. N/U tree and test to 10000 psi/10 minutes. 17. Freeze protect down tubing and annulus. 18. Secure well. Rig down and move out. Please note This well will be fracd 4. BOP and Diverter Information Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP schematics on file for Doyon 142. Doyon 142 will use a BOPE stack equipped with an annular preventer, variable bore rams, blind/shear rams, and variable bore rams while drilling and running liner for the production hole section of 3T-731A. 3T-731A has a MASP of 1,343 psi in the intermediate hole section using the methodology in section 5 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: 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 5 | 12 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 Production Drilling/Casing: Annular Preventer (iii) VBRs (i) Blind/Shear Rams (ii) VBRs (i) 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 6 | 12 5. MASP Calculations Requirements of 20 AAC 25.005(c)(4) (A) maximum downhole pressure and maximum potential surface pressure; Maximum Potential Surface Pressure (MPSP) is determined as the lesser of: Method 1: surface pressure at breakdown of the formation casing seat with a gas gradient to the surface Method 2: formation pore pressure at the next casing point less a gas gradient to the surface 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 The following presents data used for calculation of Maximum Potential Surface Pressure (MPSP) while drilling: 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 PROD 6-1/2" 7-5/8" 4500 3982 14 8.1 1,677 13192 4181 8.1 1,761 1,343 2,500 1,343 (B) data on potential gas zones; The planned wellbore 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 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 7 | 12 6. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) Drill out window and perform LOT test or FIT in accordance with the LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 7. 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 4 1/2 6 1/2 12.60 P110-S Hyd563 1061 sx of 15.3 ppg Class G + Add's 4 1/2 Production Liner run to 13192 MD / 4181 TVD Top of slurry is designed to be at the liner top at ~ 4350 MD, Assume 30% excess annular volume. Tail 247 bbls => 1061 sx of 15.3 ppg Class G + Add's + Add's @ 1.31 ft³/sk OD Hole Size Depth (MD) Weight Grade Conn. 20 42 120 94 H-40 Welded 10 3/4 13 1/2 2625 45.5 L-80 Hyd563 7 5/8 9 7/8 3943 29.7 L-80 Hyd563 7 5/8 9 7/8 4785 33.7 P-110S Hyd563 4 1/2 8 3/4 13192 12.6 P-110S Hyd563-MS Casing and Cement In Place Cement Program 10 yds 949 sx of 11.0 ppg Lead and 281 sx of 15.8 ppg Tail (cement returned to surface) 2491 sx of 14.8 ppg Lead and 226 sx of 15.3 ppg Tail. TOC logged at 4010' MD / 3717' TVD 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 8 | 12 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Production Hole Size in. 6 1/2 Casing Size in. 4 1/2 Density PPG 9.0 10.5 PV cP <20 YP lb./100 ft2 10-20 Funnel Viscosity s/qt. 35-50 Initial Gels lb./100 ft2 5- 10 10 Minute Gels lb./100 ft2 7 - 15 API Fluid Loss cc/30 min. < 6.0 HPHT Fluid Loss cc/30 min. < 10.0 OWR 75:25 80:20 E-Stability 400 1000 Production Hole: The horizontal production interval will be drilled with a non-aqueous drilling fluid weighted to 9.0 10.5 ppg. MPD will be available for adding backpressure during connections if necessary. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 9 | 12 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. 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. 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 10 | 12 14. Drilling Hazards Summary Drilling Area Risks: 6 1/2 Hole / 4 1/2 Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Medium Reduce pump rates, real time ECD monitoring, maintain mud rheology, add lost circulation material as needed Hole swabbing on trips Medium 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 Medium Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Running Liner to Bottom Medium 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 To be posted in Rig Floor Doghouse Prior to Spud 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 11 | 12 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. 3T-731A AOGCC 10-401 APD 9/30/2025 3T-731A AOGCC 10-401 APD 12 | 12 15. Proposed Completion Schematic 16. Attachments 4443 4500 4500 4800 4800 5200 5200 5500 5500 6000 6000 8000 8000 9000 9000 11000 11000 12000 12000 13192 3T-731A wp02 Plan Summary 0 4 0 2000 4000 6000 8000 10000 12000 Measured Depth 20" Conductor Casing 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] 45004600 4699 4797 4894 3T-731 3000 4000 0 1500 3000 4500 6000 7500 9000 10500 Vertical Section at 168.03° 7-5/8" Intermediate Casing 4-1/2" Production Liner 0 15 30 4500 4650 4800 4950 5100 5250 5400 5550 Measured Depth DDI 6.872 SURVEY PROGRAM Date: 2025-08-26T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 118.75 167.27 3T-713 Srvy 1 - SLB MWD Inc only r.5 MWD 258.69 2558.05 3T-731 Srvy 2 - SLB Surveys - IPM IFR MWD+IFR2+SAG+MS 2651.74 4443.49 3T-731 Srvy 3 - SLB Surveys - IPM IFRMWD+IFR2+SAG+MS 4443.49 4900.00 3T-731A wp02 (3T-731A) r.5 SDI_URSA1 4900.00 13191.78 3T-731A wp02 (3T-731A) MWD+IFR2+SAG+MS Ground / 12.00 CASING DETAILS TVD MD Name 3981.54 4500.00 7-5/8" Intermediate Casing 4181.00 13191.77 4-1/2" Production Liner Mag Model & Date: BGGM2025 15-Dec-25 Magnetic North is 13.44° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.59° 57144.22nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 4443.49 63.52 165.24 3957.05 -253.11 350.73 0.00 0.00 320.32 Start DLS 2.90 TFO 14.10 2 4500.00 65.11 165.68 3981.54 -302.40 363.51 2.90 14.10 371.20 Start DLS 16.00 TFO -30.00 3 4513.00 66.92 164.55 3986.82 -313.88 366.56 16.00 -30.00 383.06 Start 20.00 hold at 4513.00 MD 4 4533.00 66.92 164.55 3994.67 -331.61 371.46 0.00 0.00 401.42 Start DLS 3.50 TFO -50.00 5 4733.00 71.51 158.90 4065.67 -508.98 430.19 3.50 -50.00 587.11 Start DLS 3.50 TFO -12.14 6 5258.62 89.53 155.09 4151.93 -983.97 632.33 3.50 -12.14 1093.69 Start 335.68 hold at 5258.62 MD 7 5594.31 89.53 155.09 4154.71 -1288.43 773.69 0.00 0.00 1420.84 Start DLS 3.50 TFO 89.47 8 6077.35 89.70 172.00 4158.00 -1750.00 910.00 3.50 89.47 1900.64 Start DLS 3.50 TFO 68.11 9 6086.15 89.81 172.29 4158.04 -1758.72 911.20 3.50 68.11 1909.42 Start 7105.63 hold at 6086.15 MD 1013191.78 89.81 172.29 4181.00 -8800.00 1865.00 0.00 0.00 8995.46 TD at 13191.78 FORMATION TOP DETAILS No formation data is available 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 3T-731 actual @ 51.00usft (D142) True Vertical Depth6000700080009000100001100012000130001319290°3T-731A wp02 South(-)/North(+) Separation Factor 0 35 4500 4800 5100 5400 5700 6000 Partial Measured Depth 3T-731A wp02 Ladder View 0 150 300 4500 6000 7500 9000 10500 12000 Measured Depth Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 118.75 167.27 3T-713 Srvy 1 - SLB MWD Inc only r.5 MWD 258.69 2558.05 3T-731 Srvy 2 - SLB Surveys - IPM IFR MWD+IFR2+SAG+MS 2651.74 4443.49 3T-731 Srvy 3 - SLB Surveys - IPM IFR MWD+IFR2+SAG+MS 4443.49 4900.00 3T-731A wp02 (3T-731A)r.5 SDI_URSA1 4900.00 13191.78 3T-731A wp02 (3T-731A) MWD+IFR2+SAG+MS 15:20, September 10 2025 CASING DETAILS TVD MD Name 3981.54 4500.00 7-5/8" Intermediate Casing 4177.96 13191.78 4-1/2" Production Liner 4443 4500 4500 4800 4800 5200 5200 5500 5500 6000 6000 8000 8000 9000 9000 11000 11000 12000 12000 13192 3T-731A wp02 TC View 50 50 100 100 150 150 200 200 250 250 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 130891312613164 3S-719 445045004550 4600464946994748479748464894494349915040508851365184523252805328537754265474552355715623 568057365794585259115970603060896689673967896839688969396989703970897139718972397289733973887438748875387588763876887738 77887838 78887938 798880388088813881888238 8288833883888438848885388588863886888738 87888838 88888938898890389088913891889238928893389388943894889538 95889638968897389788983898889938998710037 10087 10137101871023710287103371038710437104871053710587106371068710737107871083710887 10937 109871103711087 111371118711237 1128711337 1138711437114871153711587116371168711737117871183711887119371198712037120871213712187122371228712337123871243712487125371258712637126871273712787128371288712937 12987130371308713137 13187 3T-731 SURVEY PROGRAM Date: 2025-08-26T00:00:00 Validated: Yes Version: From To Tool 118.75 167.27 r.5 MWD 258.69 2558.05 MWD+IFR2+SAG+MS 2651.74 4443.49 MWD+IFR2+SAG+MS 4443.49 4900.00 r.5 SDI_URSA1 4900.00 13191.78 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 3981.54 4500.00 7-5/8" Intermediate Casing 4177.96 13191.78 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 4443.49 63.52 165.24 3957.05 -253.11 350.73 0.00 0.00 320.32 Start DLS 2.90 TFO 14.10 2 4500.00 65.11 165.68 3981.54 -302.40 363.51 2.90 14.10 371.20 Start DLS 16.00 TFO -30.00 3 4513.00 66.92 164.55 3986.82 -313.88 366.56 16.00 -30.00 383.06 Start 20.00 hold at 4513.00 MD 4 4533.00 66.92 164.55 3994.67 -331.61 371.46 0.00 0.00 401.42 Start DLS 3.50 TFO -50.00 5 4733.00 71.51 158.90 4065.67 -508.98 430.19 3.50 -50.00 587.11 Start DLS 3.50 TFO -12.14 6 5258.62 89.53 155.09 4151.93 -983.97 632.33 3.50 -12.14 1093.69 Start 335.68 hold at 5258.62 MD 7 5594.31 89.53 155.09 4154.71 -1288.43 773.69 0.00 0.00 1420.84 Start DLS 3.50 TFO 89.47 8 6077.35 89.70 172.00 4158.00 -1750.00 910.00 3.50 89.47 1900.64 Start DLS 3.50 TFO 68.11 9 6086.15 89.81 172.29 4158.04 -1758.72 911.20 3.50 68.11 1909.42 Start 7105.63 hold at 6086.15 MD 1013191.78 89.81 172.29 4181.00 -8800.00 1865.00 0.00 0.00 8995.46 TD at 13191.78 Northing (2000 usft/in)41 South(-)/North(+) (2000 usft/in)39 4041 4242 South(-)/North(+) (2500 usft/in) 3T-731A wp02 Surface Location 3T-731A wp02 Surface Location # Schlumberger-Confidential 3T-731A wp02 Surface Casing 3T-731A wp02 Surface Casing # Schlumberger-Confidential 3T-731A wp02 Top Whipstock KOP 3T-731A wp02 Top Whipstock KOP # Schlumberger-Confidential 3T-731A wp02 TD 3T-731A wp02 TD # Schlumberger-Confidential 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. COYOTE OILKUPARUK RIVER KRU 3T-731A 225-103 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Loepp, Victoria T (OGC) To:Johnson, Cameron Subject:RE: KRU 3T-731 Sundry Application - Plug for Re-Drill_Update Date:Tuesday, October 28, 2025 1:00:00 PM Working on it now. Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Sent: Tuesday, October 28, 2025 10:20 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 3T-731 Sundry Application - Plug for Re-Drill_Update Victoria, Doyon 142 is currently drilling the 3T-614 production lateral. The rig is scheduled to release on November 5th. Operations on 3T-731A are expected to begin on November 6th. We received the approved sundry to abandon the lateral with coil tubing and to perform the tubing cut. Have any questions come up in the review of the PTD? Regards, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Johnson, Cameron Sent: Tuesday, October 14, 2025 6:39 AM To: AOGCC Permitting (CED sponsored <aogcc.permitting@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Loepp, Victoria T (DOA <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC <steve.davies@alaska.gov>; Guhl, Meredith D (OGC <meredith.guhl@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 3T-731 Sundry Application - Plug for Re-Drill_Update Good morning, To better secure the well and establish barriers prior to the rig moving over the well, ConocoPhillips is proposing to use coil-tubing to plug back the lateral, rather than an on-rig cement squeeze as previously submitted. Please find the proposed plan attached to this email. This pre-rig coil tubing work will need to be performed in the next two weeks to allow for all pre-rig work to be completed before the rig moves over the 3T-731 well. I understand that this is a rushed request, please reach out with any questions or concerns with the proposed plan. As a schedule update, Doyon 142 wrapped up the 3T-622 well over the weekend and is cemented surface casing on 3S-714. It is estimated the rig will begin work on the 3T-731 well on November 8th. Additional updates will be communicated as they become available. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Johnson, Cameron Sent: Wednesday, October 1, 2025 7:31 AM To: AOGCC Permitting (CED sponsored <aogcc.permitting@alaska.gov> Cc: Loepp, Victoria T (DOA <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC <steve.davies@alaska.gov>; Guhl, Meredith D (OGC <meredith.guhl@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3T-731 Sundry Application - Plug for Re-Drill Good morning, Attached is the sundry package for plugging back the KRU 3T-731 well to be re-drilled. This work is anticipated to start on November 23rd, 2025. Schedule updates will be communicated as the rig continues to drill and complete other wells. An application for a permit to drill will be submitted following this email. Please let me know if you have any questions regarding the sundry application. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska O: 907.223.6277 | M: 907.720.3162 | ANO-938, 700 G Street, Anchorage, AK 1 Starns, Ted C (OGC) From:Starns, Ted C (OGC) Sent:Thursday, October 9, 2025 2:22 PM To:'Johnson, Cameron' Cc:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 3S-731A (PTD 225-103) questions Thank you Cameron, Theres no need to re-submit the 10-401. I can edit it and move on from there. Thank you for the clarication, I just needed to check that all was in order. Have a nice afternoon. Ted From: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Sent: Thursday, October 9, 2025 1:51 PM To: Starns, Ted C (OGC) <ted.starns@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-731A (PTD 225-103) questions Hey Ted, You are correct, this will be drilled from the 3T pad and the proposed name of the wellbore is KRU 3T-731A The sundry submi ed is for KRU 3T-731 The PTD applica on is for KRU 3T-731A Please let me know if the 10-401 needs to be corrected and re-submi ed. I apologize for any confusion that this may have caused. Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ATO-1540, 700 G Street, Anchorage, AK From: Starns, Ted C (OGC) <ted.starns@alaska.gov> Sent: Thursday, October 9, 2025 11:32 AM To: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; You don't often get email from cameron.johnson2@conocophillips.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 3S-731A (PTD 225-103) questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Cameron, Im initiating the process to review the permit for the KRU 3S-731A well and noticed that based on the location and the plat it appears this well is planned to be drilled o of the 3T pad, also appearing as the 3T-731A in the application materials. Just to conrm, this well should be named 3T-731A and not 3S-731A as written on the 10-401, correct? Thank you Ted Ted Starns Petroleum Geologist AOGCC 907-793-1225 (o ce) WELL PERMIT CHECKLISTCompany ConocoPhillips Alaska, Inc.Well Name: KUPARUK RIVER UNIT 3T-731AInitial Class/TypeDEV / PENDGeoArea890 Unit 11160On/Off ShoreOnProgram DEVWell bore segAnnular DisposalPTD#:2251030Field & Pool:KUPARUK RIVER, COYOTE OIL - 490120NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes KUPARUK RIVER, COYOTE OIL - 490120 - governed by CO 8194 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)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA18 Conductor string providedNA19 Surface casing protects all known USDWsNA20 CMT vol adequate to circulate on conductor & surf csgNA21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes Max reservoir pressure is 1761 psug(EMW 8.1 ppg); will drill w/ 9.0-10.5 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 1343 psig; will test BOPs to 5000 psig initially and subsequently to 4000 paig30 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 H2S not anticipated35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 8.1 ppg EMW36 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]ApprADDDate10/24/2025ApprVTLDate10/28/2025ApprADDDate10/24/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/29/2025