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Home My WebLink About225-1381. 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Colville River / Undefined Waste Disposal 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14120 3947 none None Casing Collapse Structural Conductor Surface 3180 Intermediate 1 3090 Intermediate 2 5410 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: Abby Warren Contact Email: Contact Phone:907-240-9293 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 6974 abby.warren@conocophillips.com 10960-10974 Perf Pups: 11792-14067 807 4.5" 6894-6898 Perf Pups: 6981-6976' 1/20/2026 14090'2827 4-1/2" x 3-1/2" 6974 Packer: Baker Premier Packer SSSV: TRMAXX-5E SSV (flipper locked out/hydraulic sleeve open) 8233' 2630' Perforation Depth MD (ft): 10756' 20" 11-3/4" 80' 6828' 114' 2670' 69837" 9-5/8" 11413' Length Size L80 TVD Burst 11056 7240 MD 5750 5830 114' 2327.5' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025558, ADL0025559 225-138 P.O. Box 100360, Anchorage, AK 99510 50-103-20659-01-00 ConocoPhillips Alaska Inc CRU CD1-47NA Tubing Grade: Tubing MD (ft): Packer:10722' MD/6813' TVD SSSV:2118' MD / 1997' TVD 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 approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: AOGCC USE ONLY Contact Name: Abby Warren Contact Email: Contact Phone:907-240-9293 e: Drilling Engineer abby.warren@conocophillips.com certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and re with Date: 15. Well Status after proposed work: OIL WINJ W DSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval: Date: esentative: Date for Operations: 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSV Type: Packers and SSSV MD (ft) and TVD (ft): SSSV: TRMAXX-5E SSV (flipper locked out/hydraulic sleeve open) Packer:10722' MD/6813' TVD SSSV:2118' MD / 1997' TVD 11056L804-1/2" x 3-1/2"6894-6898 Perf Pups: 6981-6976'2-14067 pth MD (ft):Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 697414090'4.5"2827 54107240698311413'7"807te2 309057506828'10756'9-5/8"8233'te 1 318058302327.5'2670'11-3/4"2630'e 114'114'20"80'or al CollapseBurstTVDMDSizeLength Junk (MD): None Plugs (MD): none MPSP (psi): 3947 Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft): 6974 D (ft): PRESENT WELL CONDITION SUMMARY 10. Field/Pool(s): Colville River / Undefined Waste Disposal signation (Lease Number): ADL0025559 8. Well Name and Number: CRU CD1-47 g: tion or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No NA 5. Permit to Drill Number: 6. API Number: 225-138 50-103-20659-01-00 4.Current Well Class: Exploratory Development Stratigraphic Service 360, Anchorage, AK 99510 ame: s Alaska Inc quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp W ell Alter Cas Other: _r Casing __________________ __ Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 326-030 By Grace Christianson at 2:09 pm, Jan 14, 2026 TS 1/15/26 A DSR-1/16/26 X X 10-407 Class I disposal operations to be in accordance with EPA issued permit. CBL logs and interpretation to be submitted to the AOGCC asap before proceeding for 9-5/8" and 7". BOP test to 5000 psi initially and subsequently BOP test pressure to 4200 psi; Annular preventer test to 2500 psi. A variance for packer depth under 20 AAC 25.412(b) is granted to allow packer to be placed up to ~300' above the Int2 shoe depth and in the confining zone. BOPE testing on a 21-day interval is approved with the attached conditions VTL 1/22/2026JLC 1/22/2026 01/22/26 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 January 14th, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application: Change approved program for CD1-47A (PTD 225-138) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a change to the approved program for CD1-47A. The request is to go to a 21 day BOPE test interval while under the approved permit to drill 225-138. Doyon 142 strongly supports the CPAI BOPE between well maintenance program and over the last year has had 26 full BOP tests with 20 passing tests for a 77% first time pass rate. There were 28 component failures over 754 components tested in these 26 tests equating to a 96% overall BOPE equipment effectiveness during BOPE testing in 2025. 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 If you have any questions or require further information, please contact Abby Warren at 907-240-9293 (abby.warren@conocophillips.com) Sincerely, cc: CD1-47 Well File / Jenna Taylor ATO 1804 Will Earhart ATO 1552 Abby Warren Justin Cremer ATO 1548 Drilling Engineer Sarah Frey ATO 1778 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: Coville River Unit, Undefined Waste Disposal Pool, CRU CD1-47A Conoco Phillips Alaska, Inc. Permit to Drill Number: 225-138 Surface Location: 4728 FSL, 3029 FEL, S5 T11N, R5E, UM Bottomhole Location: 4993 FSL, 5040 FEL, S32, T12N, R5E, 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 7th day of January 2026. 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 11,933 TVD: 10019 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): 58.5 15. Distance to Nearest Well Open Surface: x- 385674 y- 5975579 Zone- 4 19.5 to Same Pool: 1042' to CD1-01 16. Deviated wells: Kickoff depth: 2728 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 57 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 10-5/8 x 11- 3/4 9-5/8" 47# T95 H523 500 2523 2248 3023 2523 10-5/8 x 11- 3/4 9-5/8" 47# L80 H523 4949 3023 2523 7972 6639 8-1/2" x 9-7/8" 7" 29# P110-S H563 2251 7822 6510 10223 8561 6" 4-1/2" 12.6# P110-S H563 1710 10073 8433 11933 10019 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 114 2327.5 6828 7001 6974 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: Justin Cremer Contact Email:abby.warren@cop.com Wells Engineering Manager Contact Phone: 907-240-9293 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 Colville River Undefined Waste Disposal 1/20/2025 4992' to ADL025559 170 sx of 15.3 ppg Class G + Adds 331 sx of 13.0 ppg extended class G + 136 sx of 15.3 ppg Class G + Adds 819 sx of 11.0 ppg Crete Lead + 141 sx of 15.3 ppg Class G + Add's 3947 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: Abby Warren Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Perforation Depth TVD (ft): 11,413.00 Liner 2,827 4.5 14090 Intermediate 2 807 7 Intermediate 1 8,233 9.625 114 Surface 2,670 11.75 715 sx of 10.7ppg lead + 302.6 sx of 15.8 Class G 2673 Conductor/Structural 114 16 10756 14090 6974 Casing Length Size Cement Volume MD 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) 4949 P.O. Box 100360 Anchorage, Alaska, 99510-0360 4728 FSL, 3029 FEL, S5 T11N, R5E, UM ADL025559 / ADL025558 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc 59-52-180 CD1-47A 4488 FSL, 4841 FEL, S32, T12N, R5E, UM 49933 FSL, 5040 FEL, S32, T12N, R5E, UM 2469 / 2459 GL / BF Elevation above MSL (ft): ons 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 If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: See cover letter for other requirements. Permit Approval Date: API Number:to Drill er: Commission Use Only Contact Name: Justin Cremer Contact Email:abby.warren@cop.com Wells Engineering Manager Contact Phone:907-240-9293 Date: ereby certify that the foregoing is true and the procedure approved herein will not be ed from without prior written approval. zed Name: zed Title: zed Signature: Abby Warren tachments: Property Plat BOP Sketch Drhhilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketchh Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements lic Fracture planned?Yes No Perforation Depth TVD (ft):ation Depth MD (ft): 6974140904.52,827Liner 700111,413.007807ntermediate 2 68289.6258,233ntermediate 1 10756 2327.52,670Surface 11.75 715 sx of 10.7ppg lead + 302.6 sx of 15.8 Class G 2673 114114nductor/Structural 114 16 TVDCasingLengthSizeCement Volume MD Junk (measured): 14090 6974 al Depth MD (ft): Total Depth TVD (ft): Plugs (measured):Effect. Depth MD (ft):Effect. Depth TVD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)Y 170 sx of 15.3 ppg Class G + Adds10019119338433100731710H563P110-S12.6#4-1/2"6" 331 sx of 13.0 ppg extended class G + 136 sx of 15.3 ppg Class G + Adds856110223651078222251H563P110-S29#7"x 9-7/8" 819 sx of 11.0 ppg Crete Lead + 141 sx of 15.3 ppg Class G + Add's66397972252330234949H523L8047#9-5/8"8 x 11- /4 2523302322482523500H523T9547#9-5/8"8 x 11- /4 TVDMDTVDMDLengthCouplingGradeWeightCasingole (including stage data) sing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: Surface:3947 viated wells: Kickoff depth: 2728 feet Maximum Hole Angle: 57 degrees 15. Distance to Nearest Well Open to Same Pool: 1042' to CD1-01 10. KB Elevation above MSL (ft):58.5 19.5 cation of Well (State Base Plane Coordinates - NAD 27): e: x- 385674 y- 5975579 Zone- 4 14. Distance to Nearest Property: 4992' to ADL025559 7. Property Designation: 8. DNR Approval Number: 9. Acres in Property: cation of Well (Governmental Section): e: Productive Horizon: Depth: 13. Approximate Spud Date: 1/20/2025 12. Field/Pool(s): Colville River Undefined Waste Disposal 6. Proposed Depth: MD: 11,933 TVD: 10019 ress: 11. Well Name and Number:rator Name:5. Bond: Blanket Single Well Bond No. 1c.Specify if well is proposed for: Coalbed Gas Gas Hydrates Geothermal Shale Gas 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp Stratigraphic Test Development - Oil Service - Winj Single Zone Exploratory - Oil Development - Gas Service - Supply Multiple Zone pe of Work: Lateral Reentry 4949 ox 100360 Anchorage, Alaska, 99510-0360 4728 FSL, 3029 FEL, S5 T11N, R5E, UM ADL025559 / ADL025558 oPhillips Alaska Inc 59-52-180 CD1-47A 4488 FSL, 4841 FEL, S32, T12N, R5E,UM 49933 FSL, 5040 FEL,S32, T12N, R5E, UM 2469 / 2459 GL / BF El ti b MSL (ft) Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 225-138 By Grace Christianson at 11:12 am, Dec 19, 2025 4,993 FSL SFD Class I disposal operations to be in accordance with EPA issued permit. ~4,300' in CD1-01A SFD CBL logs and interpretation to be submitted to the AOGCC asap before proceeding for 9-5/8" and 7".. BOP test pressure to 4200 psi; Annular preventer test to 2500 psi. X VTL 1/7/2026 50-103-20659-01-00 Class I - EPA CDW 12/22/2025 DSR-12/19/25SFD 1/6/2026 A variance for packer depth under 20 AAC 25.412(b) is granted to allow packer to be placed up to ~300' above the Int2 shoe depth and in the confining zone. CDW 12/22/2025 SFD 01/07/26 01/07/26 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 18th, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Re-Enter and Re-Drill CD1-47 / CD1-47A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a permit to re-enter and sidetrack the CD1-47 producer well from the CD1 drilling pad. This well, originally drilled in November 2012, has been shut-in for reservoir pressure management since December 2021. The intended rig acceptance for this well is January 20th, 2026 using Doyon Rig 142, estimated spud for the sidetrack is February 9th, 2025. In a Sundry request currently being submitted, prior to Doyon 142 rig move onto CD1-47, pre-rig work will include spotting P&A cement plug, testing tubing and IA integrity, and cutting 4-1/2 tubing. When Doyon 142 rig moves onto CD1-47 well, the proposed plan is to de-complete the well and set a CIBP, perforate and cement the Halo formations, set a second CIBP, test, then mill the 9-5/8 x 11-3/4 LTP, cut and pull the 9-5/8 liner below the surface casing shoe, then set a 16 ppg kickoff plug below and into the surface casing shoe. With this permit to drill, the Doyon 142 will re-drill with a four-string design. A 10-5/8 x 11-3/4 intermediate 1 section to +/- 7972 MD, case the hole with 9-5/8 liner and cement. A 9-5/8 tieback will then be run. For intermediate 2 an 8-1/2 x 9-7/8 hole will be drilled to TD and a 7 liner run and cemented. A 7 tieback will be run to surface. Then, the rig will drill a 6 production section to TD at 11,933 MD, and case the hole with 4-1/2 15.2# liner and cement. CD1-47A be completed as an unstimulated Waste Disposal service well, along with 4-1/2 tubing with production packer tied back to surface. The liner will be perforated post well. The upper completion of 4-1/2 tubing will be run and set in place using an injection packer in the 7 intermediate tieback. A variance for the packer depth for injection wells under AOGCC 20 AAC 25.412 (b) will also be requested so that it may be located greater than 200 feet measured depth from above the top of the perforations, but shall not be located above the confining zone, and shall have outer casing cement volume sufficient to place cement a minimum of 300 feet measured depth above the planned packer depth. The confining zone for the injection interval is the Kingak formation which is ~1600 ft thick. 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 Abby Warren at 907-240-9293 (abby.warren@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: CD1-47A Well File / Jenna Taylor ATO 1560 Will Earhart ATO 1552 Abby Warren Justin Cremer ATO 1548 Drilling Engineer Andy Mack Kuukpik Corp , g p CD1-47A be completed as an unstimulated Waste Disposal, , service well, along with 4-1/2 tubing with production packer tied back to surface. A variance pp p g p g j p for the packer depth for injection wells under AOGCC 20 AAC 25.412 (b) will also be requested so that it may be located greater thanrp p j () q y g 200 feet measured depth from above the top of the perforations, but shall not be located above the confining zone, and shall have aap p p ,g , outer casing cement volume sufficient to place cement a minimum of 300 feet measured depth above the planned packer depth. CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 1 | 12 CD1-47A 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...................................................................................................................5 5. MASP Calculations ....................................................................................................................................5 6.Procedure for Conducting Formation Integrity Tests.................................................................................6 7. Casing and Cementing Program.................................................................................................................6 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 CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A 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 CD1-47A 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface 4728' FSL, 3029' FEL, S5 T11N R5E, UM NAD27 Northings: 5975580 Eastings: 385675 RKB Elevation 58.5 AMSL Pad Elevation 15.5 AMSL Top of Productive Horizon (Heel) 4488' FSL, 4841' FEL , S32 T12N R5E, UM NAD27 Northings: 5980647 Eastings: 383924 Measured Depth, RKB: 10,894 MD True Vertical Depth, RKB: 9,133 TVD True Vertical Depth, SS: 9,075 TVDss Total Depth (Toe) 4993' FSL, 5040' FEL, S32 T12N R5E, UM NAD27 Northings: 5981155 Eastings: 383731 Measured Depth, RKB: 11,933 True Vertical Depth, RKB: 10,019 True Vertical Depth, SS: 9,960 Pad Layout CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 3 | 12 Well Plat No other wells intersect the planned disposal interval within a 1/2-mile radius. SFD CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 4 | 12 3. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) 1. RIH to 16 ppg cement kick off plug. Sidetrack below existing surface casing shoe with 10-5/8 drilling BHA. (LWD Program: GR, RES, DEN, NEU, Sonic) 2. Drill 20 of new hole. Perform FIT/LOT. Minimum LOT required to drill ahead is 10.4 ppg EMW. 3. Drill 10-5/8 x 11-3/4hole to section TD utilizing an underreamer. Circulate clean and POOH. 4. Change upper VBRs to 9-5/8" solid body rams. Test BOPE to 250/4,000 psi. (24-48 hr. regulatory notice). 5. Run 9-5/8 liner and cement to the top of the liner (a minimum of 250 TVD or 500 MD above any hydrocarbon bearing zones). Pressure test casing if possible on plug bump to 4000 psi. 6. Run 9-5/8 tieback to surface. Pressure test backside to 2500 psi to confirm seals 7. RU wireline to run CBL. Log 9-5/8 cement quality 8. Change upper 9-5/8" solid body rams to 4-1/2 x 7 VBRs. Test BOPE to 250/4,000 psi. (24-48 hr. regulatory notice). 9. RIH with 8-1/2 BHA (LWD Program: GR, RES, DEN, NEU). Drill 20 of new hole, perform FIT/LOT. Minimum LOT required to drill ahead is 11.3 ppg EMW 10. Drill 8-1/2 x 9-7/8 hole to section utilizing an underreamer TD (LWD Program: GR/RES/Den/Neu/Sonic). Circulate clean and POOH 11. Run 7 liner and cement to top of liner. If possible pressure test to 4600 psi. Set liner top packer. 12. Run 7 tieback to surface. Pressure test back side to 4000 psi 13. RU wireline to run CBL. Log 7 cement quality 14. Pick up and RIH with 6 drilling assembly. 15. Drill out shoe track and 20 feet of new formation. Perform FIT. Minimum acceptable initial leak-off for drilling ahead is 10.5 ppg EMW. 16. Drill 6" hole to section TD (LWD Program: GR/RES/Den/Neu/Sonic). 17. Circulate the hole clean and POOH. 18. Run 4-1/2 liner to TD, pressure test to 4600 psi on plug bump if possible and set liner hanger. 19. Cement 4-1/2 liner from TD to liner top. Set liner top packer. POOH LD DP. 20. RU to run upper completion. 21. Run 4-1/2 upper completion with production packer, downhole gauge, and gas lift mandrels. Space out and land tubing hanger. 22. Pressure test hanger seals to 5,000 psi. 23. Pressure test tubing to 4,600 psi, chart test. 24. Bleed tubing pressure to 2200 psi and test IA to 4,600 psi, chart test. Shear out SOV 25. Install HP-BPV and test to 1500 psi. 26. Nipple down BOP. 27. Install tubing head adapter assembly. N/U tree and test. 28. Freeze protect down tubing and annulus. 29. Secure well. Rig down and move out. Per attached email dated 1/6/2026, CPAI Logs and interpretation to AOGCC asap before drilling ahead.4200 Logs and interpretation to AOGCC asap before drilling ahead. 4200 CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 5 | 12 4. BOP and Diverter Information Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP and diverter schematics on file for Doyon 142 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 INT1 10-5/8 x 11-3/4 11.75" 2673 2323 15 8.5 1,027 7972 6639 9 3,107 1,580 1,580 2,443 INT2 8-1/2 x 9-7/8" 9-5/8" 7972 6639 11.5 9 3,107 10287 8616 10.7 4,794 3,306 3,306 3,932 PROD 6" 7" 10287 8616 12.5 10.7 4,794 11932 10019 9.5 4,949 3,947 4,739 3,947 (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 CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 6 | 12 6.Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) Drill out casing shoe 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 OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 16 34 94 H40 Welded Existing: Drilled 11-3/4" 14" 60# L80 BTC-M Existing: Cement to Surface 9-5/8 10-5/8 x 11-3/4 47# 47# T-95 L-80 H523 H523 Cemented liner to inside the 11-3/4 surface casing 9-5/8 47# L-80 H523 Uncemented Tieback to surface 7" 8-1/2 x 9- 7/8" 29# P110S H563 Cemented liner to inside the 9-5/8 liner 7 29# P110S H563 Uncemented tieback to surface 4-1/2" 6" 15.2# P110-S H563 Cemented liner to inside the 7 liner 4-1/2 15.2# P-110SS H563 Uncemented tubing to surface The upper completion of 4-1/2 tubing will be run and set in place using an injection packer in the 7 intermediate tieback. A variance for the packer depth for injection wells under AOGCC 20 AAC 25.412 (b) will also be requested so that it may be located greater than 200 feet measured depth from above the top of the perforations, but shall not be located above the confining zone, and shall have outer casing cement volume sufficient to place cement a minimum of 300 feet measured depth above the planned packer depth. The confining zone for the injection interval is the Kingak formation which is ~1600 ft thick. Recommend approval of variance requested. Packer placement and cement should provide equivalent isolation of disposal fluid to authorized disposal zone. CPAI responsible to ensure compliance with EPA issued Class I disposal permit. CDW 12/22/2025. A variance for the packer depth for injection wells under AOGCC 20 AAC 25.412 (b) will also be requested so that it may be located greater than 200 feet measured depth from above the top of the perforations, but shall not be located above the confining zone, and shall have outer casing cement volume sufficient to place cement a minimum of 300 feet measured depth above the planned packer depth. The confining zone for the injection interval is the Kingak formation which is ~1600 ft thick. CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 7 | 12 9-5/8" Intermediate 1 liner run to 7972' MD/ 6639' TVD Cement Plan: Cement from 7972 MD to 7472 (500 of tail) with Class G + Adds @ 15.3 ppg, and from 7472' to liner top with 11.0 ppg CRETE. Assuming 30% excess. *Minimum depth required is TOC at 3263 MD (500 above the top hydrocarbon bearing zone). Lead 279 bbls => 819 sx of 11.0 ppg DeepCRETE + Add's @ 1.91 ft³/sk Tail 31.4 bbls => 141 sx of 15.3 ppg Class G + Add's @ 1.25 ft³/sk 7" Intermediate 2 liner run to 10287' MD/ 8616' TVD Cement Plan: Cement from 10287 MD to 9787 (500 of tail) with Class G + Adds @ 15.3 ppg, and from 9787' to liner top with 13 ppg extended G. Assuming 30% excess. Lead 112 bbls => 331 sx of 13.0 ppg DeepCRETE + Add's @ 1.90 ft³/sk Tail 30.3 bbls => 136 sx of 15.3 ppg Class G + Add's @ 1.25 ft³/sk 4-1/2" Production Liner run to 11932' MD/ 10019' TVD Cement Plan: Primary cement job consists of a 15.3 ppg slurry designed to be from TD at 11932' MD to top of liner with 30% excess. Tail 38 bbls => 170 sx of 15.3 ppg Class G + Add's + Add's @ 1.25 ft³/sk CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 8 | 12 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Intermediate 1 Intermediate 2 Production Hole Size in 10-5/8" x 11-3/4 8-1/2 x 9-7/8" 6" Casing Size in 9-5/8" 7 4-1/2" Density ppg 9.8-11.3 ppg 10.5-11.5 ppg 9.0-10.5 ppg LSYP lb./100 ft2 8-11 8-11 5-8 YP lb./100 ft2 20-30 20-30 20-30 Initial Gels lb./100 ft2 10-15 10-15 6-10 10 Minute Gels lb./100 ft2 <20 <20 <20 API Fluid Loss cc/30 min <10 to Qannik <6.0 from Qannik to HRZ <6.0 <6.0 HPHT Fluid Loss cc/30 min <10 from HRZ to TD <10 <10 pH 9.5-10 9.5 10.0 9.5-10.0 Oil/Water Ratio N/A N/A N/A Intermediate 1: WBM system will be used. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.8-11.3 ppg and be prepared to add loss circulations materials as needed. Weight up as necessary for the shales Intermediate 2: WBM system will be used. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 10.5-11.5 ppg and be prepared to add loss circulations materials as needed. Weight up as necessary for the shales Production Hole: The production interval will be drilled with WBM system 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. CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A 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) Incidental fluids developed from drilling operations on well CD1-47A will be injected into the Class 1 disposal well on CD1. CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 10 | 12 14. Drilling Hazards Summary 10-5/8" x 11-3/4 Hole | 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Hole Swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Well Collision Low Travelling cylinder diagrams Abnormal Pressure Low Increased mud weight. Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, control pipe running speeds Sloughing shale / tight hole Medium MPD for shale stability, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner 8-1/2 x 9-7/8" Hole | 7" Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Medium MPD for shale stability, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner 6" Hole | 4-1/2" Liner - Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material 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 Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers To be posted in Rig Floor Doghouse Prior to Spud CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 11 | 12 Well Proximity Risks: CD1 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: Offset injection has the potential to increase reservoir pressure in the Alpine C over predicted. 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 sections. Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Swabbed Kicks Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD1-47A AOGCC 10-401 APD 12/18/2025 CD1-47A AOGCC 10-401 APD 12 | 12 15.Proposed Completion Schematic Class I CDW 12/22/2025 3,765' ? See proposed directional survey. SFD CD1-47A wp04.3 Plan Summary 0 3 3000 4500 6000 7500 9000 10500 12000 Measured Depth 11-3/4" Surface Casing 9-5/8" Intermediate Casing 7" 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] 2802290230023102 3201 3300 3398 3495 CD1-47 2802290230023102 3201 3300 3398 3495 0 7500 0 1750 3500 5250 7000 8750 10500 12250 Vertical Section at 339.90° 11-3/4" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Casing 4-1/2" Production Liner 0 18 35 Centre to Centre Separation2800 2975 3150 3325 3500 3675 3850 4025 Measured Depth Equivalent Magnetic Distance DDI 6.015 SURVEY PROGRAM Date: 2022-05-24T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 116.22 822.22 CD1-47PB1 Gyro (CD1-47PB1) GYD-GC-SS 858.22 2728.29 CD1-47PB1 (CD1-47PB1) MWD+IFR2+SAG+MS 2728.29 2775.00 CD1-47A wp04.3 (CD1-47A) MWD+IFR2+SAG+MS 2775.00 3350.00 CD1-47A wp04.3 (CD1-47A) MWD-INC_ONLY (INC>10°) 3350.00 7970.00 CD1-47A wp04.3 (CD1-47A) r.5 MWD+IFR2+SAG+MS 7970.00 10280.00 CD1-47A wp04.3 (CD1-47A) r.5 MWD+IFR2+SAG+MS 10280.00 11932.66 CD1-47A wp04.3 (CD1-47A) r.5 MWD+IFR2+SAG+MS Ground / 19.50 CASING DETAILS TVD MD Name 6639.54 7972.00 9-5/8" Intermediate Casing 8616.12 10287.00 7" Intermediate Casing 10018.73 11932.66 4-1/2" Production Liner Mag Model & Date: BGGM2025 10-Feb-26 Magnetic North is 13.13° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.52° 57057.96nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 2728.29 57.38 331.12 2356.94 801.60 -485.86 0.00 0.00 919.76 Start DLS 0.83 TFO -169.38 2 2775.00 57.00 331.04 2382.25 835.96 -504.85 0.83 -169.38 958.55 Start DLS 1.50 TFO 165.00 3 2975.00 54.11 331.99 2495.37 980.90 -583.52 1.50 165.00 1121.70 Start DLS 2.00 TFO 161.31 4 4263.62 30.50 347.93 3444.33 1774.96 -902.40 2.00 161.31 1976.98 Start 3905.41 hold at 4263.62 MD 5 8169.04 30.50 347.93 6809.31 3713.35 -1316.92 0.00 0.00 3939.75 Start DLS 1.50 TFO -80.93 6 8340.28 31.00 343.00 6956.50 3798.03 -1338.90 1.50 -80.93 4026.83 CD1-47A Flt Tgt Start DLS 1.50 TFO -79.53 7 8505.89 31.54 338.33 7098.08 3879.08 -1367.37 1.50 -79.53 4112.73 Start 3326.77 hold at 8505.89 MD 811832.66 31.54 338.33 9933.50 5496.11 -2010.02 0.00 0.00 5852.12 WD-05 T1 N Op 1 - 022425 Start 100.00 hold at 11832.66 MD 911932.66 31.54 338.33 10018.73 5544.71 -2029.34 0.00 0.00 5904.41 TD at 11932.66 FORMATION TOP DETAILS TVDPath Formation 2412.50 C30 2763.50 C20 3035.50 C10 (Halo) 4032.50 K2 6600.50 Top HRZ 6856.50 LCU 6943.50 Alpine C 7001.50 UJU 7344.50 Nechelik (LTB) 8650.50 Sag River 8688.50 Shublik 9133.50 Ivishak 9834.50 Kavik 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 39+19.5 @ 58.50usft (D142) 0200040006000800010000True Vertical Depth-2000 0 2000 4000 6000 8000 10000 12000Vertical Section at 339.90°11-3/4" Surface Casing7" Intermediate Casing4-1/2" Production LinerC D 1 -4 7 9-5/8" Intermediate Casing16" Conductor Casing9-5/8" Intermediate Casing7" Intermediate Casing4-1/2" Production Liner200030000°C30C20C10 (Halo)K2Top HRZLCUAlpine CUJUNechelik (LTB)Sag RiverShublikIvishakKavikCD1-47A wp04.39:13, October 15 2025Section View 02000400060008000South(-)/North(+)-8000 -6000 -4000 -2000 0 2000 4000West(-)/East(+)CD1-47A Flt TgtWD-05 T1 N Op 1 - 0224253000350040004500550060006500300035004000450055006000650011-3/4" Surface Casing9-5/8" Intermediate Casing7" Intermediate Casing4-1/2" Production Liner25003000750080008500900095001000010019CD1-47A wp04.3CD1-47A wp04.3While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.9:14, October 15 2025 Per attached email dated 1/6/2026, CPAI 0.000.501.001.502.002.503.003.504.004.505.005.50Separation Factor2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175 6500 6825 7150 7475 7800 8125 8450 8775Measured Depth (650 usft/in)CD1-01CD1-21CD1-30 CD1-35CD1-47STOP DrillingTake Immediate ActionCaution Monitor CloselyNormal OperationsProject: Western North SlopeSite: CD1 Alpine PadWell: CD1-47Wellbore: Plan: CD1-47ADesign: CD1-47A wp04. 0 30 60 Centre to Centre Separation2750 3000 3250 3500 3750 4000 Partial Measured Depth Equivalent Magnetic Distance CD1-47A wp04.3 Ladder View 0 150 300 Centre to Centre Separation2700 3600 4500 5400 6300 7200 8100 9000 Measured Depth Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 116.22 822.22 CD1-47PB1 Gyro (CD1-47PB1) GYD-GC-SS 858.22 2728.29 CD1-47PB1 (CD1-47PB1) MWD+IFR2+SAG+MS 2728.29 2775.00 CD1-47A wp04.3 (CD1-47A) MWD+IFR2+SAG+MS 2775.00 3350.00 CD1-47A wp04.3 (CD1-47A) MWD-INC_ONLY (INC>10°) 3350.00 7970.00 CD1-47A wp04.3 (CD1-47A) r.5 MWD+IFR2+SAG+MS 7970.0010280.00 CD1-47A wp04.3 (CD1-47A) r.5 MWD+IFR2+SAG+MS 10280.0011932.66 CD1-47A wp04.3 (CD1-47A) r.5 MWD+IFR2+SAG+MS 9:40, October 15 2025 CASING DETAILS TVD MD Name 5316.75 7972.00 9-5/8" Intermediate Casing 6605.85 10287.00 7" Intermediate Casing 6983.82 11932.66 4-1/2" Production Liner CD1-47A wp04.3 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] 2762 2807 2852 2897 2942 2988 3033 3079 3125 3171 CD1-21 2762 2807 2852 2897 2942 2988 3033 3079 3125 3171 2762 2807 2852 2897 2942 2988 3033 3079 3125 3171 27522802285229022952300230523102315232013251330033493398 3446 3495 3543 3590 3638 3684 3731 3777 3822 3867 3911 CD1-47 27522802285229022952300230523102315232013251330033493398 3446 3495 3543 3590 3638 3684 3731 3777 3822 3867 3911 SURVEY PROGRAM Date: 2022-05-24T00:00:00 Validated: Yes Version: From To Tool 116.22 822.22 GYD-GC-SS 858.22 2728.29 MWD+IFR2+SAG+MS 2728.29 2775.00 MWD+IFR2+SAG+MS 2775.00 3350.00 MWD-INC_ONLY (INC>10°) 3350.00 7970.00 r.5 MWD+IFR2+SAG+MS 7970.00 10280.00 r.5 MWD+IFR2+SAG+MS 10280.00 11932.66 r.5 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 5316.75 7972.00 9-5/8" Intermediate Casing 6605.85 10287.00 7" Intermediate Casing 6983.82 11932.66 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 2728.29 57.38 331.12 2356.94 801.60 -485.86 0.00 0.00 919.76 Start DLS 0.83 TFO -169.38 2 2775.00 57.00 331.04 2382.25 835.96 -504.85 0.83 -169.38 958.55 Start DLS 1.50 TFO 165.00 3 2975.00 54.11 331.99 2495.37 980.90 -583.52 1.50 165.00 1121.70 Start DLS 2.00 TFO 161.31 4 4263.62 30.50 347.93 3444.33 1774.96 -902.40 2.00 161.31 1976.98 Start 3905.41 hold at 4263.62 MD 5 8169.04 30.50 347.93 6809.31 3713.35 -1316.92 0.00 0.00 3939.75 Start DLS 1.50 TFO -80.93 6 8340.28 31.00 343.00 6956.50 3798.03 -1338.90 1.50 -80.93 4026.83 CD1-47A Flt Tgt Start DLS 1.50 TFO -79.53 7 8505.89 31.54 338.33 7098.08 3879.08 -1367.37 1.50 -79.53 4112.73 Start 3326.77 hold at 8505.89 MD 811832.66 31.54 338.33 9933.50 5496.11 -2010.02 0.00 0.00 5852.12 WD-05 T1 N Op 1 - 022425 Start 100.00 hold at 11832.66 MD 911932.66 31.54 338.33 10018.73 5544.71 -2029.34 0.00 0.00 5904.41 TD at 11932.66 Northing (1500 usft/in)355759355759 373747 -150001500300045006000South(-)/North(+) (1500 usft/in)-7500 -6000 -4500 -3000 -1500 0 1500 3000 4500West(-)/East(+) (1500 usft/in)CD1-22CD1-22BCD1-22BPB1CD1-229CD1-23CD1-26PB1CD1-27CD1-28CD1-30CD1-30PB1CD1-32PB1C D 1 -3 3 A C D 1 -3 6 P B 1 CD1-37CD1-38PB1CD1-39CD1-39PB1CD1-41C D 1 -4 1 P B 1 CD1-42CD1-43CD1-44C D 1 -4 4 P B 1CD1-46CD1-47CD1-47PB1CD1-48CD1-48ACD1-49WD-039934CD1-47A wp04.3CD1-47A wp04.3Quarter Mile View9:46, October 15 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD ShapeCD1-47A Flt Tgt 6956.50 Circle (Radius: 100.00)WD-05 T1 N Op 1 - 022425 9933.50 Circle (Radius: 100.00)WD-05 T1 QM 9933.50 Circle (Radius: 1320.00) CD1-47A wp04.3 Surface Location CD1-47A wp04.3 Surface Location # Schlumberger-Confidential CD1-47A wp04.3 Surface Casing CD1-47A wp04.3 Surface Casing # Schlumberger-Confidential CD1-47A wp04.3 KOP Top Whipstock CD1-47A wp04.3 KOP Top Whipstock # Schlumberger-Confidential CD1-47A wp04.3 Intermediate 1 Csg CD1-47A wp04.3 Intermediate 1 Csg # Schlumberger-Confidential CD1-47A wp04.3 Intermediate 2 Csg CD1-47A wp04.3 Intermediate 2 Csg # Schlumberger-Confidential CD1-47A wp04.3 Top Ivishak CD1-47A wp04.3 Top Ivishak # Schlumberger-Confidential CD1-47A wp04.3 TD CD1-47A wp04.3 TD # Schlumberger-Confidential 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:Warren, Abby To:Loepp, Victoria T (OGC); Drake, Steve G Cc:Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Date:Thursday, December 18, 2025 10:59:09 AM Attachments:CD1-47 Pre Rig Abandonment.pdf Victoria Yes, we will be running a USIT (step #11) to evaluate the cement behind pipe on the 9-5/8 liner. The original top of cement was estimated by cement calcs, as no log was run. Top of Halo is 3913 MD/ 3034 TVD and the bottom is 4000 MD / 3081 TVD. It is poorly developed in this area and is most likely a cemented stringer. The likelihood of cutting and pulling from 400 is decent, if we cannot pull from 400 the contingency would be to move up hole and recut. This is how most of our sidetracks below surface casings are performed and Conoco has a high success rate at it with multiple cuts. Current cement calc with pulling the casing 400 below SC and pumping the cement to 200 inside casing would be ~64 bbls of 16.0 ppg cement. In terms of the Gator perforator, we plan to run ~150 of 7 guns with 15spf. Flow area should be more than sufficient to get a proper squeeze to achieve isolation of the Halo. Pipe should be free in that area, as such Conoco does not believe there is any added benefit to perf and wash. I have attached the prerig abandonment Schematic. One thing to note on the sundry, is that section 7 for Discussion of Mud and Cuttings Disposal should read - Incidental fluids developed from drilling operations on well CD1-47A will be injected into the Class 1 disposal well on CD1. Please let me know if you have any questions. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 17, 2025 12:01 PM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill 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. Abby, Is a CBL planned to verify the TOC above the Qannik? How was the TOC estimated? Please provide log if logged. Please provide top/bottom of Halo. Please provide information on Halo development in this well. Have you considered Gator perforations across the Halo and potential perf and wash before cementing? How likely is it that the 9-5/8 casing can be cut and pulled from ~400 below the SC shoe? I dont see any cement calculations or height of cement on the SC shoe cement plug. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 _____________________________________________ From: Loepp, Victoria T (OGC) Sent: Wednesday, December 17, 2025 11:24 AM To: Abby.Warren@conocophillips.com; Drake, Steve G <steve.g.drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Abby & Steve, Please include in both sundries the well bore schematic post reservoir abandonment and pre-rig. You can email that to me. I would like the schematic modified from the 325-763 sundry. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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:Warren, Abby To:Davies, Stephen F (OGC) Cc:Earhart, Will C; Loepp, Victoria T (OGC); Dewhurst, Andrew D (OGC); Starns, Ted C (OGC) Subject:RE: [EXTERNAL]RE: CRU CD1-47A (PTD 225-138) - Additional Questions Date:Tuesday, January 6, 2026 2:05:18 PM Hi Steve, Below are the answers to your questions. Please let me know if you have any further questions. Thanks Abby From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, January 5, 2026 2:27 PM To: Earhart, Will C <William.C.Earhart@conocophillips.com>; Warren, Abby <Abby.Warren@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL]RE: CRU CD1-47A (PTD 225-138) - Additional 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. Abby, Will: In addition to my questions, below, the directional surveying requirements of 20 AAC 25.050(a) were not clearly addressed in this application, and CPAI did not check the "20 AAC 25.050 requirements" box on the Permit to Drill application form. I notice small "Survey Program" tables are included on pages 13, 29, and 30. These tables list tool types for various hole sections, but no clear statements of survey station intervals are provided. What are CPAI's plans? Please ensure that the well will be surveyed in accordance with the requirements of 20 AAC 25.050. We will survey every stand in accordance with 20 AAC 25.050. Sorry for missing the tic mark in that box. Thanks and Be Well, Steve Davies AOGCC From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, January 5, 2026 10:35 AM To: Earhart, Will C <william.c.earhart@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: FW: CRU CD1-47A (PTD 225-138) - Questions Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, January 5, 2026 10:34 AM To: Warren, Abby <abby.warren@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: CRU CD1-47A (PTD 225-138) - Questions Hello Abby, I have a few questions concerning expected pressure in the "production" section of the CD1- 47A disposal injection well and the planned mud program. The MASP calculations on page 5 indicate the anticipated pore pressure in this section is 9.5 ppg, but the drilling fluid program on page 8 indicates the planned mud density will range from 9.0 to 10.5 ppg. What are the forecast pore pressures for the Sag River and the Ivishak? How were these forecast pressures determined? Will 9.0 ppg mud be sufficient to drill the beginning of this section? The Ivishak and Sag River pore pressures are estimated based on offset log data (sonic and resistivity) using Eatons equation. It is calibrated with regional data as well as offset MDTs and other drilling information. Regionally, the pore pressure for the Ivishak and Sag River is ~9.5 ppg but may range from 9.2 9.6 ppg. In past experience we have encountered lower pore pressure in both the Ivishak and the Sag River. The range in the mud program is for the scenario that if we were to encounter losses and need to lower mud weight, there is leeway in the permit to do so. The intention is to always have a static over balance to the reservoir. We will be using a 9.5 ppg to initially drill this section and be utilizing MPD. Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov From:Warren, Abby To:Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC); Wallace, Chris D (OGC); Davies, Stephen F (OGC); Earhart, Will C Subject:FW: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Date:Monday, December 29, 2025 12:04:41 PM Attachments:image001.png image002.png Hi Victoria Please see answers in red to your questions with previous emails as well, let me know if you need further clarification on anything. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 26, 2025 11:49 AM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Sorry about the multiple emails with questions/comments. As I review the sundry and PTD, I run across additional information. What type of CBL will you be running to evaluate the Int 1 and Int 2 cementing? We will be running an ultrasonic log. Base plan is the SLB IBC/USIT, pending unit availability but will pivot to another ultrasonic if we need to. Please provide kick tolerance calculations for the surface casing at kick off point and the Int 1. See Below Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Friday, December 26, 2025 11:09 AM To: 'Warren, Abby' <Abby.Warren@conocophillips.com>; 'Drake, Steve G' <Steve.G.Drake@conocophillips.com>; 'Earhart, Will C' <william.c.earhart@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions The CD1-47A PTD requests a variance for the packer depth of greater that 200 above the top of the perforations. Please provide an approximate depth or range of depths for the packer placement. The approximate setting depth is 9,983-10,033 MD, this is based on the current INT2 shoe depth of 10,223 MD and a liner lap for the production liner of 150-200 placing the packer in the confining zone. The well will first be perforated in the Ivishak and the injection plan would be to then move up in formation over the life of the well with the Sag being the last to be perfd. Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Friday, December 26, 2025 10:45 AM To: 'Warren, Abby' <Abby.Warren@conocophillips.com>; 'Drake, Steve G' <Steve.G.Drake@conocophillips.com>; Earhart, Will C <william.c.earhart@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Another comment: The MPSP for the rig work prior to drilling the sidetrack is 3587 psi and during the drilling the sidetrack the MPSP is 3947 psi. The BOP test pressure of 4000 psi is not adequate. A BOP test pressure of 4200 psi for all the rig work is proposed. This is after the initial BOP test pressure of 5000 psi. Please comment. Thank you for catching that. I support 4200psi, that is most prudent Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Friday, December 26, 2025 9:50 AM To: 'Warren, Abby' <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions 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. Abby, Since the cement top behind the 9-5/8 liner was determined by calculation, it is uncertain that the Qannik has cement coverage until the cement log is run. Please provide information on the Qannik formation in this well and contingency plans for cementing if the TOC is below the Qannik. The Qannik reservoir is present and does look like it has reservoir quality. However, in this area the pay is primarily found in the gas cap (GOC is -4002 TVDSS) for the Qannik reservoir. Logs show that we are still in quality pay but far from the existing development, and closer to the reservoir edge. In the event we find the Qannik is not adequately isolated, we will employ the same remedial cementing concept as planned for the Halo. We have sourced enough 7 perforating guns to support this contingency Until the cement log is run, it is uncertain what is behind pipe at the Halo. If a balance plug is unsuccessful, are there contingency plans? CPAI is sourcing adequate perforating guns to repeat the perf-squeeze of the Halo and/or Qannik if necessary. We are also sourcing equipment to support section milling of the 9-5/8 casing if operationally required. What flow area per foot of perfs does the Gator provide versus the 7 guns at 15 SPF? The intended 7 TCP perf guns will produce 23.67 in2 TFA. The Gator tool would provide ~11.8 in2 of TFA per spec sheet Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Warren, Abby <Abby.Warren@conocophillips.com> Sent: Thursday, December 18, 2025 10:59 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Victoria Yes, we will be running a USIT (step #11) to evaluate the cement behind pipe on the 9-5/8 liner. The original top of cement was estimated by cement calcs, as no log was run. Top of Halo is 3913 MD/ 3034 TVD and the bottom is 4000 MD / 3081 TVD. It is poorly developed in this area and is most likely a cemented stringer. The likelihood of cutting and pulling from 400 is decent, if we cannot pull from 400 the contingency would be to move up hole and recut. This is how most of our sidetracks below surface casings are performed and Conoco has a high success rate at it with multiple cuts. Current cement calc with pulling the casing 400 below SC and pumping the cement to 200 inside casing would be ~64 bbls of 16.0 ppg cement. In terms of the Gator perforator, we plan to run ~150 of 7 guns with 15spf. Flow area should be more than sufficient to get a proper squeeze to achieve isolation of the Halo. Pipe should be free in that area, as such Conoco does not believe there is any added benefit to perf and wash. I have attached the prerig abandonment Schematic. One thing to note on the sundry, is that section 7 for Discussion of Mud and Cuttings Disposal should read - Incidental fluids developed from drilling operations on well CD1-47A will be injected into the Class 1 disposal well on CD1. Please let me know if you have any questions. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 17, 2025 12:01 PM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill 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. Abby, Is a CBL planned to verify the TOC above the Qannik? How was the TOC estimated? Please provide log if logged. Please provide top/bottom of Halo. Please provide information on Halo development in this well. Have you considered Gator perforations across the Halo and potential perf and wash before cementing? How likely is it that the 9-5/8 casing can be cut and pulled from ~400 below the SC shoe? I dont see any cement calculations or height of cement on the SC shoe cement plug. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 _____________________________________________ From: Loepp, Victoria T (OGC) Sent: Wednesday, December 17, 2025 11:24 AM To: Abby.Warren@conocophillips.com; Drake, Steve G <steve.g.drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Abby & Steve, Please include in both sundries the well bore schematic post reservoir abandonment and pre-rig. You can email that to me. I would like the schematic modified from the 325-763 sundry. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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. CRU CD1-47A UNDEFINED WDSPCOLVILLE RIVER 225-138 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name: COLVILLE RIV UNIT CD1-47AInitial Class/TypeSER / 1-OILGeoArea890Unit50360On/Off ShoreOnProgram SERWell bore segAnnular DisposalPTD#:2251380Field & Pool:COLVILLE RIVER, UNDEFINED WDSP - 120036NA1 Permit fee attachedYes Surface Location lies within ADL0025559; Top Prod Int & TD lie within ADL0025558.2 Lease number appropriateYes3 Unique well name and numberNo COLVILLE RIVER, UNDEFINED WDSP - 120036 - governed by Statewide Regs4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes Nearest well open to disposal interval is CD1-01A, 4,300' to south-southeast.6 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 waitYes Class II injection for disposal purposes authorized by Rule 2 of AIO 18E.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes None penetrate planned disposal interval within 1/2-mile radius. Nearest is CD1-01A, 4300' away.15 All wells within 1/4 mile area of review identified (For service well only)No16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)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 csgNo21 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 pitYes PTD 212-083, Sundries 325-744 & 325-76325 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 4949 psig(9.5 ppg EMW); will drill w/ 9.0-11.5 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 3947 psig; will test BOPs initially to 5000 psig and subsequently to 4200 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 shutdownYes33 Is presence of H2S gas probableYes34 Mechanical condition of wells within AOR verified (For service well only)No Measures required: will penetrate previously used disposal interval.35 Permit can be issued w/o hydrogen sulfide measuresYes Alpine C may be abnormally pressured. Mitigation discussed on p. 10, 11.36 Data presented on potential overpressure zonesNA Previous injection in undefined disposal pool about 4300' - 4600' distant may have overpressured disposal37 Seismic analysis of shallow gas zonesNA interval. Supplies available onsite to increase mud weight. MPD will be available.38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate1/5/2026ApprVTLDate1/5/2026ApprSFDDate1/6/2026AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 1/7/2026