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Home My WebLink About225-015Alaska 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: Colville River Field, Qannik Oil Pool, CRU CD4-540 Conoco Phillips Alaska, Inc. Permit to Drill Number: 225-015 Surface Location: FSL 2219.49 FEL 354.88 S24 T011N R4E UM Bottomhole Location: FSL 363.62 FEL 499.74 S21 T11N 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 25 th day of June 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 12:14:46 -08'00' 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 CRU Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 20,678 TVD: 4233 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): 17.9 15. Distance to Nearest Well Open Surface: x- 377887 y- 5957353 Zone- 4 54.6 to Same Pool: 1977' to CD4-588 16. Deviated wells: Kickoff depth: 90° feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: Brine degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 80 40 40 120 120 16" 13-5/8" 88.2# L80 H563 1533272.6 40 40 2687 2424 12-1/4" 9-5/8" 47# T95 H563 2687 40 40 7647 3504 8-1/2" x 9-1/2" 7-5/8" 29.7 / 33.7#L80 x P-110 S H523 7647 7497 7258 15351 4019 6-1/2" 4-1/2" 12.6# P-110S H563 7854 15176 8060 20678 4233 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Chris Brillon Contact Email:hilda.dupont@cop.com Wells Engineering Manager Contact Phone: 907-265-6675 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips 59-52-180 CD4-540 P.O. Box 100360 Anchorage, Alaska, 99510-0360 Colville River Unit NarwhalFSL 2219.49 FEL 354.88 S24 T011N R4E UM ADL372096, ADL372097, ADL384211, ADL380077 FSL 4842.25 FEL 3163.80 S21 T11N R5E UM 931994000, 931996000, 932080000, 932036000 1/3/1900 Cement to surface with 10 yds slurry FSL 363.62 FEL 499.74 S21 T11N R5E UM 640, 1239, 2485, 2148.81 363' to ADL380081 GL / BF Elevation above MSL (ft): 1915 1492 18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) 1029 sx of 11.0 ppg DeepCRETE + 306 sx of 15.8 ppg Class G 568 sx of 15.8 ppg Class G + 204 sx of 15.8 ppg Class G 1383 sx of 15.8 ppg Class G N/A Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Casing Length Size Cement Volume MD Surface Conductor/Structural Perforation Depth MD (ft): Perforation Depth TVD (ft): Intermediate Production Liner 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.Hilda Dupont Authorized Name: Authorized Title: Authorized Signature: Commission Use Only See cover letter for other requirements. Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 4/1/2025 By Gavin Gluyas at 11:03 am, Feb 13, 2025 Diverter variance granted per 20 AAC 25.035(h)(2) X 72.7 A.Dewhurst 20MAR25 50-103-20909-00-00 4/1/2026 Qannik Oil Pool VTL 6/24/2025 Initial BOP test to 5000 psig; subsequent BOP test to 3850 psig Annular preventer test to 2500 psig Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension attached Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available. 225-015 Alaska,Inc 90.3 DSR-2/18/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 12:15:01 -08'00' 06/25/25 06/25/25 RBDMS JSB 062625 ZhϰͲϱϰϬ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. &58&' CPAI’s 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 Sincerely, cc: CD4-540 Well File / Jenna Taylor ATO 1560 Will Earhart ATO 1552 Hilda Dupont Chris Brillon ATO 1548 Drilling Engineer Kate Dodson for Hilda Dupont SiSiSiiSiiiiiiiincnnnnnnnnnnnnnnnnnnnnerely, HiHiildldldldldlldlllddldlddldlldddaaa DDDDDDDDDuDuDDDDDDDDDupopopont KaKKaKKaKKKKKaKaKaKaKaaaKaKteteteteteteteteeteteetettetteee DDDDDDDDDDDDDDDD fofooofofofofofofofofofofofooofofofr rrrrrrrrrrrrrrr Hildooontnt February 13, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-540 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well from the CD4 drilling pad. The intended spud date for this well is April 1, 2025. The intended rig used to drill the well is Doyon 26. CD4-540 will be a fractured stimulated producer in the Narwhal sand. The 16" surface hole will TD above the C-30 sand and then 13-5/8" casing will be set and cemented to surface. The intermediate hole will be drilled in two sections to mitigate issues with formation instability over the long interval. The 12-1/4" intermediate #1 section will be drilled to below the C-10 sand and landed at an inclination of 87°. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 250’ TVD (which is greater than 500’MD) above the shoe. The second intermediate will be drilled with a 8-1/2" x 9-1/2" under-reamed steerable drilling assembly, ultimately landing 15’ TVD above the Narwhal sand at an inclination of ~82°. A 7-5/8" liner string will be set and cemented from TD to secure the shoe and cover 250’TVD (which is greater than 500’MD)above top of uppermost hydrocarbon bearing zone (K-3 Top), providing sufficient isolation and reducing the chance of losses during the cementing job due to weak formations. Offset wells CD4-595, CD4-594, CD4-597, CD4-588, CD4-586, CD4-539 and CD4-587 have been approved by AOGCC on same cement design. It is also included in the ERIO 6 application. The production interval will be comprised of a 6-1/2" horizontal hole that will be geo-steered in the Narwhal sand. The well will be completed as a stimulated producer with 4-1/2" production liner with swell packers and AU sleeves and tied back to surface with a 4-1/2” tubing upper completion string. The well will be tied into existing CD4 facilities. After well completion the well will by hydraulically fractured. CPAI request a variance to the diverter requirement under 20 AAC25.035 (h)(2). At CD4, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. A variance is also requested for a BOPE test interval of 21 days for this project. Doyon 26 is a strong participant in the CPAI BOPE between well maintenance program reflected by low failure rates in BOP tests since its entry in the CPAI fleet. The variance allows effective drilling and completion of problematic intermediate shale sections and efficient management of losses in the production sections when they are encountered. 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 completion diagram 4. Drilling fluids program summary 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: Hilda Dupont at 907-265-6675 hilda.dupont@cop.com or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com) request a variance to the diverter requirement Recommend approving variance. -A.Dewhurst 20MAR25 CD4-540 AOGCC 10-401 APD 1 | 10 CD4-540 Well Plan Application for Permit to Drill Table of Contents 1. Well Name ............................................................................................................................................. 2 2. Location Summary ................................................................................................................................. 2 3. Proposed Drilling Program ..................................................................................................................... 3 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 ............................................................................................................................ 7 9. Abnormally Pressured Formation Information ........................................................................................ 8 10. Seismic Analysis ..................................................................................................................................... 8 11. Seabed Condition Analysis ..................................................................................................................... 8 12. Evidence of Bonding ............................................................................................................................... 8 13. Discussion of Mud and Cuttings Disposal and Annular Disposal .............................................................. 8 14. Drilling Hazards Summary ...................................................................................................................... 8 15. Proposed Completion Schematic .......................................................................................................... 10 CD4-540 AOGCC 10-401 APD 2 | 10 1. Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as CD4-540. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface FSL 2219.49 FEL 354.88 S24 T011N R4E UM NAD27 Northing: 5957352.82 Easting: 377887.10 RKB Elevation 54.6’ AMSL Pad Elevation 17.9’ AMSL Top of Productive Horizon (Heel) FSL 4842.25 FEL 3163.80 S21 T11N R5E UM NAD27 Northing: 5959779.43 Easting: 390629.72 Measured Depth, RKB: 15459‘ MD True Vertical Depth, RKB: 4035 ‘ TVD True Vertical Depth, SS: 3962 ‘ TVDss Total Depth (Toe) FSL 363.62 FEL 499.74 S21 T11N R5E UM NAD27 Northing: 393239.42 Easting: 5955263.21 Measured Depth, RKB: 20678‘ MD True Vertical Depth, RKB: 4233‘ TVD True Vertical Depth, SS: 4161‘ TVDss Well Plat CD4-540 AOGCC 10-401 APD 3 | 10 3. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) 1. Install landing ring on conductor on existing 20” conductor. Conductor set at 135’ RKB. 2. Move in / rig up Doyon 26 on conductor. 3. Pick up 5” DP and prepare surface drilling fluid. 4. Spud and directionally drill 16" hole to casing point at 2687' MD/ 2424' TVD as per directional plan. Run MWD / LWD logging tools (LMWD Program: GR/DIR) in drill string as required for directional monitoring and formation data gathering. 5. Run and cement new 13-5/8" 88.2# L80 H563 casing to surface. Adequate excess cement will be pumped to ensure cement returns the surface. 6. Install wellhead and test to 1000 psi. Nipple up BOPE with the following equipment/configuration: 7. 18-3/4” Annular / Upper 4-1/2” x 7-5/8” VBR / Blind/Shear Ram / Lower 3-1/2” x 6-5/8” VBR 8. Test BOPE to 250psi low / 5,000psi high. Test annular to 250psi low / 3,500psi high. 9. This test pressure meets the requirements for the 21-day pressure testing cycle which requires an initial pressure test to full working pressure of the BOPE. All subsequent tests will be performed to 250 psi low / 3,850 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi. 10. Test casing to 3300 psi for 30min. 11. PU 12-1/4" bit and rotary steerable drilling assembly. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 12. Drill out cement and 20' new hole. Perform FIT to 11.5 ppg EMW minimum. 13. Displace well to FWP. 14. Directionally drill 12-1/4" hole to casing point 7647' MD/ 3504' TVD. Run MWD/LWD logging tools (LMWD Program: GR/RES/DIR) in drill string as required for directional monitoring and formation data gathering. 15. Circulate wellbore clean and pull out of the hole to surface. 16. Rig up and run new 9-5/8" 47# T95 H563 casing. 17. Rig up and pump cement as per program. Displace cement with mud, check floats upon bumping plug. Top of cement to be 250’ TVD above the intermediate 1 casing shoe. 18. Test casing to 3850 psi for 30min. 19. Pick up 8-1/2" x 9-1/2" under reamer and rotary steerable assembly. RIH, clean out cement to top of float equipment. CD4-540 AOGCC 10-401 APD 4 | 10 20. Drill out cement and 20' of new hole. Perform FIT to 11 ppg EMW minimum. 21. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 9.0 ppg FWP. 22. Directionally drill 8-1/2" x 9-1/2" Intermediate 2 hole to casing point at 15351' MD/ 4019' TVD, landing ~15’ TVD above top of Narwhal Central Sand. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/DIR) in drill string as required for directional monitoring and formation data gathering. 23. Circulate well clean, flow check and strip out of hole to surface. 24. Rig up and run new 7-5/8" 29.7 / 33.7# L80 x P-110 S H523 liner with hanger and liner top packer on DP. 25. Rig up and pump cement as per program. Displace cement with mud, check floats upon bumping plug. Top of cement to be 250’ TVD above top of uppermost possible hydrocarbon bearing zone K3 to provide sufficient isolation and reduce losses during the cementing job due to weak formations. Offset wells on CD4-595, CD4-594, CD4-597, CD4-588, CD4-586, CD4- 539 and CD4-587 have been approved by AOGCC on same cement design. 26. Test casing to 3850 psi for 30min. 27. Pick up 6-1/2" Bit and rotary steerable drilling assembly and RIH and clean out cement to top of float equipment. 28. Drill out cement and 20' of new hole. Perform FIT to a minimum of 10.3 EMW. Displace to 8.2 ppg VersaClean (OBM) drilling fluid. 29. Directionally drill 6-1/2" hole to TD at 20678’ MD/ 4233’ TVD using MPD as per directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/SON/DIR) in drill string as required for directional monitoring and formation data gathering. 30. Circulate well clean, flow check and backream out of hole to intermediate II shoe. 31. Displace to KW fluid and observe well for flow. Trip out of hole on elevators and lay down BHA. 32. PU and run 4-1/2" production liner with swell packers and AU sleeves lower completion, and line to TD. 33. PU and run 4-1/2” 12.6# L80 HYD563 tubing upper completion, circulate around with kill weight brine. 34. Land tubing. 35. Nipple down BOPE, nipple up tree and test against BPV. 36. Freeze protect 4-1/2” x 9-5/8” annulus with diesel. 37. Set BPV, secure well and move rig off. uppermost possible hydrocarbon bearing zone K3 CD4-540 AOGCC 10-401 APD 5 | 10 4. BOP and Diverter Information Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP and diverter schematics on file for Doyon 26 CPAI requests a variance to the diverter requirement under 20 AAC 25.035 (h)(2). At CD4, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. There are 6 previously drilled wells (CD4-289, CD4-290, CD4-594, CD4-499, CD4-291, CD4-292 and CD4-586, CD4-587) within 500’ and 4 previously drilled wells (CD4-320, CD4-536, CD4-539, CD4-302) within 1000’ of the proposed surface shoe location. None of these wells encountered any significant indication of shallow gas or gas hydrates. 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 ܯܲܵܲ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ ܯܲܵܲ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ) × ܸܶܦ 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 SURF 16" 20" 120 120 13 8.4 52 2687 2424 8.6 1,084 69 69 842 INT1 12-1/4" 13-5/8" 2687 2424 13 8.6 1,084 7647 3504 9.1 1,658 1,308 1,396 1,308 INT2 8-1/2" x 9-1/2" 9-5/8" 7647 3504 13 9.1 1,658 15351 4019 8.6 1,797 1,395 2,018 1,395 PROD 6-1/2" 7-5/8" 15351 4019 13 8.6 1,797 20678 4233 8.7 1,915 1,492 2,315 1,492 *Maximum potential pore pressure in the Susitna Sand if present (B) data on potential gas zones; CD4-540 AOGCC 10-401 APD 6 | 10 The well bore is not expected to penetrate any hydrates nor 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 Section 14 - Drilling Hazards Summary 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 20 42 94 H40 Welded Cemented to surface with 10 yds slurry 13-5/8" 16" 88.2# L80 H563 Cement to Surface 9-5/8" 12-1/4" 47# T95 H563 250’ TVD above the INT1 casing shoe 7-5/8" 8-1/2" x 9-1/2" 29.7 / 33.7# L80 x P-110 S H523 250’ above highest significant hydrocarbon bearing zone – K3 top 4-1/2" 6-1/2" 12.6# P-110S H563 Uncemented open hole liner with ICD’s and swell packers 13-5/8" Surface Casing run to 2687' MD/ 2424' TVD Cement Plan: Cement from 2687’ MD to 2187’ (500’ of tail) with DeepCRETE + Adds @ 15.8 ppg, and from 2187' to surface with 11.0 ppg DeepCRETE. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1268’ MD), zero excess in 20” conductor. Lead 352 bbls => 1029 sx of 11.0 ppg DeepCRETE + Add's @ 1.92 ft³/sk Tail 63 bbls => 306 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk 9-5/8" Intermediate Casing run to 7647' MD/ 3504' TVD Cement Plan: Primary cement job consists of 500 ft 15.8 ppg tail slurry and top of 15.8 ppg lead slurry is designed to be at 7147’ MD, which is 250' TVD above the prognosed shallowest hydrocarbon bearing zone INT1. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2 nd stage cement job will be performed to isolate this zone. Assume 30% excess annular volume. Lead 192 bbls => 568 sx of 15.8 ppg Class G + Add's @ 1.9 ft³/sk Tail 42 bbls => 204 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk 7-5/8" Intermediate Liner run to 15351' MD/ 4019' TVD Cement Plan: 4495' CD4-540 AOGCC 10-401 APD 7 | 10 Top of slurry is designed to be at 8830’ MD, which is 250' TVD above the prognosed shallowest hydrocarbon bearing zone K3. Assume 30% + 20 Additional bbls excess annular volume. Tail 286 bbls => 1383 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Intermediate #2 Production Hole Size in 16" 12-1/4" 8-1/2" x 9-1/2" 6-1/2" Casing Size in 13-5/8" 9-5/8" 7-5/8" 4-1/2" Density ppg 10.5 ppg 10.8 ppg 9.0 ppg 8.2 ppg PV cP ALAP ALAP ALAP ALAP YP lb./100 ft2 35-80 25-40 20 - 26 9-13 Funnel Viscosity s/qt 200 40 - 50 70 - 90 60 - 80 Initial Gels lb./100 ft2 NA 10-18 8-15 6-15 10 Minute Gels lb./100 ft2 NA <25 <20 8-20 API Fluid Loss cc/30 min <10 <10 <10 NA HPHT Fluid Loss cc/30 min NA NA <5 <10 pH 10.8-11.0 9.5 – 10.0 9.5 – 10.0 NA Surface Hole: The Surface interval will be drilled with a freshwater DrillPlex. Keep flow line viscosity at r200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight ч10.0ppg through the base of Permafrost and increase to 10.5 ppg prior to TD. Control LGS using solids control system and dilutions where necessary. Intermediate #1: The Intermediate 1 interval will be drilled with a FWP. Ensure good hole cleaning by maximizing fluid annular velocity and rotary speed. Maintain mud weight at 10.8 ppg for shallow instability. Good filter cake quality, hole cleaning and maintenance of low gravity drill solids (by diluting as required) will all be important in maintaining good hole conditions. Intermediate #2: The Intermediate 2 interval will be drilled with a FWP. Ensure good hole cleaning by maximizing fluid annular velocity and rotary speed. Maintain mud weight at 9.0 ppg for instability. Good filter cake quality, hole cleaning and maintenance of low gravity drill solids (by diluting as required) will all be important in maintaining good hole conditions. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The Production interval will be drilled with VersaClean (OBM). Ensure good hole cleaning by maximizing fluid annular velocity. Good filter cake quality, hole cleaning, and maintenance of low gravity drill solids CD4-540 AOGCC 10-401 APD 8 | 10 (by diluting as required) will all be important in maintaining good hole conditions. Mitigate wellbore instability with MPD targeting ~10 ppg EMW on connections. Please refer to the pit diagram on file for Doyon 26. All drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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) Drill cuttings and drilling mud from the well will be disposed of by hauling to CD1 Waste Injection Facility where they will be disposed by injecting to approved Class I or Class II Disposal wells. 14. Drilling Hazards Summary 16" Hole | 13-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low-density cement slurries, port collar, control pipe running speeds 12-1/4" Hole | 9-5/8" 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 CD4-540 AOGCC 10-401 APD 9 | 10 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 Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8-1/2" x 9-1/2" Hole | 7-5/8" Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner 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, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/2" Hole | 4-1/2" Liner - Horizontal 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 CD4-540 AOGCC 10-401 APD 10 | 10 15. Proposed Completion Schematic Tubing / Liner Completion: 1) 4-½” SLB TRMAXX-CMT SSSV X Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG 4-5 (2x) 3) HES Opsis Downhole Gauge 4) SLB CMU Sliding Sleeve 5) HES TNT Production Packer 6) 4-½” DB Landing Nipple (3.75" ID) 7) 5500psi Burst Disc 8) VersaFlex Hanger w/ Tie Back sleeve 9) 3500psi Float Sub 10) Swell Packer and Sleeve Completion 4-½” 12.6# P110S HYD563 Liner w/ swell packers and AU sleeve MW: 8.8 Visc Brine 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-1/2” Production Hole TD at 20,678' MD / 4,233' TVD Tubing 4-1/2" 12.6# L-80 Hyd563 CD4-540wp05 Proposed GL 1/24/2025 Production Packer VersaFlex Liner Hanger Packer Downhole Gauge 16" Surface Hole Surface Casing 13-5/8", 88.2#, L-80 HYD563 Set at 2,687' MD / 2,424' TVD 8-½” X 9-½" Intermediate 2 Hole Intermediate 2 Liner 7-5/8" 29.7# x 33.7# (heavy heel) L-80 / P-110S HYD523 Liner top at +/- 7,503' MD / 3,496' TVD Shoe set @ 15,351' MD / 4,019' TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8" 47# L-80 HYD563 Set @ 7,647' MD / 3,504' TVD K-3 Top 13,445' MD / 3,818' TVD 4-String Producer Schematic Plan Int2 TOC 8830' MD / 3,568' TVD (250' TVD above K-3 Top) Narwhal Central Sand Top 15,459' MD / 4,034’ TVD 15,201' MD / 3,998' TVD Plan Int1 TOC 4,495' MD / 3,254' TVD (250' TVD above shoe) S S S V 55 500 500 700 700 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 15000 15000 20684 CD4-540 wp05 Plan Summary 0 4 Dogleg Severity0 3500 7000 10500 14000 17500 21000 Measured Depth 13-3/8" 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] 1024 1117 1208 CD4-12 1024 1117 1208 1027 1120 1210 Nanuq 5 1336 1430 1521 CD4-209 1120 1205 CD4-210 1122 1207 1122 1207 1122 1207 922 1017 1107 CD4-213 922 1017 1107 922 1017 1107 922 1017 1107 922 1017 1107 55 100200300400 499 599 698 796 894 CD4-539 115215315 4145126117098079051003 CD4-537 wp03 99199299400500601702 804 905 1006 CD4-542 wp11.1 0 2500 True Vertical Depth0 1500 3000 4500 6000 7500 9000 Vertical Section at 150.00° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Casing 4-1/2" Production Liner 15 30 45 Centre to Centre Separation0 425 850 1275 1700 2125 2550 2975 Measured Depth Equivalent Magnetic Distance DDI 7.342 SURVEY PROGRAM Date: 2019-09-27T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.80 1600.00 CD4-540 wp05 (CD4-540) r.5 SDI_URSA1 1600.00 2680.00 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 2680.00 7650.00 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 7650.00 15350.00 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 15350.00 20677.90 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS Ground / 17.90 CASING DETAILS TVD MD Name2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing4232.70 20677.89 4-1/2" Production Liner Mag Model & Date: BGGM2024 10-May-25 Magnetic North is 13.42° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.50° 57122.71nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 54.80 0.00 0.00 54.80 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00000 3 500.00 2.00 63.00 499.96 1.58 3.11 1.00 63.00 0.18 Start Build 1.50000 4 700.00 5.00 63.00 699.56 7.13 13.99 1.50 0.00 0.82 Start Build 2.00000 5 1284.57 16.69 63.00 1272.70 56.98 111.83 2.00 0.00 6.57 Start 104.39882 hold at 1284.57406 MD 6 1388.97 16.69 63.00 1372.70 70.59 138.54 0.00 0.00 8.14 Start Build 2.75000 7 2745.38 53.99 63.00 2459.70 420.54 825.36 2.75 0.00 48.48 Start 20.00000 hold at 2745.37571 MD 8 2765.38 53.99 63.00 2471.46 427.89 839.78 0.00 0.00 49.33 Start DLS 2.75000 TFO 84.07734 9 3043.33 55.14 72.28 2632.84 513.77 1048.89 2.75 84.08 79.51 Start 410.54739 hold at 3043.33343 MD 10 3453.88 55.14 72.28 2867.49 616.31 1369.78 0.00 0.00 151.15 Start DLS 2.75000 TFO 7.70213 11 4181.50 75.00 75.00 3172.70 800.00 2000.00 2.75 7.70 307.18 Start 500.00000 hold at 4181.49978 MD 12 4681.50 75.00 75.00 3302.11 925.00 2466.51 0.00 0.00 432.18 Start DLS 3.00000 TFO 0.20706 13 5077.81 86.89 75.04 3364.37 1025.97 2843.91 3.00 0.21 533.44 Start 8453.85906 hold at 5077.81461 MD 1413531.67 86.89 75.04 3823.11 3204.69 10999.30 0.00 0.00 2724.31 Start DLS 3.50000 TFO 97.37476 1515467.39 82.00 143.00 4035.70 2618.76 12714.45 3.50 97.37 4089.31 CD4-NE5B (LL) T0.5 082524 Start DLS 3.50000 TFO 107.19445 1615669.76 79.97 149.87 4067.45 2452.35 12824.91 3.50 107.19 4288.66 Start 580.77655 hold at 15669.75613 MD 1716250.53 79.97 149.87 4168.63 1957.72 13111.98 0.00 0.00 4860.55 Start DLS 3.00000 TFO -6.45134 1816419.34 85.00 149.30 4190.70 1813.45 13196.68 3.00 -6.45 5027.85 CD4-NE5B (LL) T01 082524 Start DLS 3.00000 TFO -3.49134 1916549.39 88.89 149.06 4197.62 1701.94 13263.20 3.00 -3.49 5157.68 Start 2299.26721 hold at 16549.39377 MD 2018848.66 88.89 149.06 4241.99 -269.84 14445.04 0.00 0.00 7456.21 Start DLS 1.50000 TFO -0.13156 21 18922.37 90.00 149.06 4242.70 -333.06 14482.93 1.50 -0.13 7529.90 CD4-NE5B (LL) T02 082524 Start DLS 1.50000 TFO -1.01403 2218944.26 90.33 149.05 4242.64 -351.84 14494.19 1.50 -1.01 7551.80 Start 1733.63460 hold at 18944.26499 MD 23 20677.90 90.33 149.05 4232.70 -1838.67 15385.66 0.00 0.00 9285.17 CD4-NE5B (LL) T03 082524 TD at 20677.89959 FORMATION TOP DETAILS TVDPath Formation 1257.10 Base Perm 2212.61 C40 2444.50 C30 2771.17 C20 3005.68 C10 3486.64 Fault #1 3727.55 Tom's Sand 3819.06 K3 3892.30 K3_FS1 3951.90 K3_FS2 3975.38 K3_FS3 4021.30 K3_FS4 4032.89 Top Narwhal (central) 4114.81 Left of Lefty 4237.71 Lefty (enter from bottom) 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 54.8+17.9 @ 72.70usft (D26) -1500 0 1500 3000 4500True Vertical Depth0 1500 3000 4500 6000 7500 9000 10500 Vertical Section at 150.00° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Casing 4-1/2" Production Liner 1000 2000 3 0 0 0 4000500060007000800090001000011000120001300014000150001600017000180001900020000206780° 3 0° 5 5 ° 6 0 °75°87°80°89°90°90°CD4-540 wp05Base Perm C40 C30 C20 C10 Fault #1 Tom's SandK3 K3_FS1 K3_FS2 K3_FS3 K3_FS4 Top Narwhal (central) Left of Lefty Lefty (enter from bottom) CD4-540 wp05 12:47, January 22 2025Section View -4000 -2000 0 2000 4000 6000 South(-)/North(+)0 2000 4000 6000 8000 10000 12000 14000 West(-)/East(+) CD4-NE5B (LL) T03 082524 CD4-NE5B (LL) T02 082524 CD4-NE5B (LL) T01 082524 CD4-NE5B (LL) T0.5 082524 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Casing 4-1/2" Production Liner5001000150020002500300035004000 4 2 3 3 C D 4 -5 4 0 w p 0 5 CD4-540 wp05 While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 12:50, January 22 20253ODQ9LHZ 0.00 0.75 1.50 2.25 3.00 3.75 4.50 5.25 6.00 6.75 7.50 Separation Factor-1250 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 16250 17500 18750 20000 21250 Measured Depth (2500 usft/in) CD4-588/CD4-588 Plan: CD4-537 (NE5B C)/CD4-537 wp03 Plan: CD4-542 (NE4A STOP Drilling Take Immediate Action Caution Monitor Closely Normal Operations Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4-540 Wellbore: CD4-540 Design: CD4-540 wp05 0 35 Centre to Centre Separation0 500 1000 1500 2000 2500 Partial Measured DepthCD4-12CD4-12PB1Nanuq 5CD4-209CD4-210CD4-210ACD4-210APB1CD4-210BCD4-213CD4-213ACD4-213BCD4-213BPB1CD4-213BPB2CD4-539CD4-537 wp03CD4-542 wp11.1Equivalent Magnetic Distance CD4-540 wp05 Ladder View 0 150 300 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured DepthNanuk 1CD4-03CD4-05CD4-07CD4-12CD4-12PB1Nanuq 5CD4-16CD4-17CD4-208CD4-208ACD4-208AL1CD4-208APB1CD4-208PB1CD4-209CD4-210CD4-210ACD4-210APB1CD4-210BCD4-211CD4-211L1CD4-211L1-01CD4-213CD4-213ACD4-213BCD4-213BPB1CD4-213BPB2CD4-214CD4-214L1CD4-215CD4-215L1CD4-23CD4-23PB1CD4-23PB2CD4-24CD4-24PB1CD4-24PB2CD4-25CD4-25L1CD4-25PB1CD4-26CD4-27CD4-27PB1CD4-27PB2CD4-27PB3CD4-289CD4-291CD4-291PB1CD4-292CD4-302CD4-304CD4-304PB1CD4-306CD4-318CD4-318ACD4-318PB1CD4-319CD4-320CD4-320PB1CD4-321CD4-322CD4-499CD4-536CD4-539CD4-96CD4-96ACD4-96APB1Nanuq 3CD4-432 wp05CD4-529 wp01CD4-531 wp07CD4-533 wp03CD4-535 wp02CD4-537 wp03CD4-542 wp11.1CD4-536Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 54.80 1600.00 CD4-540 wp05 (CD4-540) r.5 SDI_URSA1 1600.00 2680.00 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 2680.00 7650.00 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 7650.0015350.00 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 15350.00 20677.90 CD4-540 wp05 (CD4-540) MWD+IFR2+SAG+MS 13:22, January 22 2025 CASING DETAILS TVD MD Name 2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing 4232.70 20677.89 4-1/2" Production Liner 55 500 500 700 700 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 15000 15000 20684 CD4-540 wp05 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] 3220 Nanuk 1 1252 1335 1415 CD4-03 1048 1146 1241 1329 1412 1490 CD4-05 117217317 420 522 625 727 829 928 1024 1117 1208 1295 1381 CD4-12 117217317 420 522 625 727 829 928 1024 1117 1208 1295 1381 CD4-12PB1 120220320 423 525 628 730 832 931 1027 1120 1210 1297 1383 Nanuq 5 116216316417517617716813906 CD4-16 117217317417 517 616 714 810 902 CD4-17 944 1046 1143 1235 1322 1408 1489 CD4-208 944 1046 1143 1235 1322 1408 1489 CD4-208A 944 1046 1143 1235 1322 1408 1489 CD4-208AL1 944 1046 1143 1235 1322 1408 1489 CD4-208APB1 944 1046 1143 1235 1322 1408 1489 CD4-208PB1 731 836 939 1042 1143 1242 1336 1430 1521 1608 1691 CD4-209 626 730 833 934 1030 1120 1205 1283 1358 CD4-210 628 732 835 936 1032 1122 1207 1285 1360 CD4-210A 628 732 835 936 1032 1122 1207 1285 1360 CD4-210APB1 628 732 835 936 1032 1122 1207 1285 1360 CD4-210B 116216317419522625729833936 10371134CD4-211 116216317419522625729833936 10371134CD4-211L1 116216317419522625729833936 10371134CD4-211L1-01 116216316 418 520 622 723 824 922 1017 1107 1191 1270 CD4-213 116216316 418 520 622 723 824 922 1017 1107 1191 1270 CD4-213A 116216316 418 520 622 723 824 922 1017 1107 1191 1270 CD4-213B 116216316 418 520 622 723 824 922 1017 1107 1191 1270 CD4-213BPB1 116216316 418 520 622 723 824 922 1017 1107 1191 1270 CD4-213BPB2 116216316 417518 619 719 818 913 1004 1087 CD4-214 116216316 417518 619 719 818 913 1004 1087 CD4-214L1 116216316417518618 717 813 907 995 CD4-215 116216316417518618 717 813 907 995 CD4-215L1 117 217317415513 610 706 800 CD4-23 117 217317415513 610 706 800 CD4-23PB1 117 217317415513 610 706 800 CD4-23PB2 1936 2022 2102 2178 CD4-292 118218318418517616 713809 CD4-318 117217317417516615 712808 CD4-318A 118218318418517616 713809 CD4-318PB1 117217317 417 515 612 707 800 886 CD4-319 116216316 415 514 612 709CD4-320 116216316 415 514 612 709CD4-320PB1 117217317415514611 706CD4-321 117217317 415513610CD4-322 2050 2146 2239 2329 2417 2502 2585 CD4-499 55 100200300399498 595 693 789 885 980 1075 1169 1262 CD4-536 55 100200300400499 599 698 796 894 992 1088 1184 1280 CD4-539 1475 1552 1619 1676 CD4-96 1475 1552 1619 1676 CD4-96A 1475 1552 1619 1676 CD4-96APB1 73115215314412CD4-432 wp05115215314412509606 700 796 889CD4-533 wp03 115215314413511608 705 800 896 989 1082 CD4-535 wp02 115215315 414512611709807905100311001198129613961493 1589 1686 1783 1880 1977 2074 2171 2268 2365 2462 2560 2657275528502943303731363235 3334 3432 3528 3626 3724 3823 3923 4024 4127 4228 4326 176471774617846179461804618146182461834618446185461864618746188471894919050191491924919349194491954919649197491984919949200492014920249203492044920510CD4-537 wp03 99199299400500601702804 905 1006 1106 1207 1307 1406 1507 CD4-542 wp11.1 55 100200300399498 595 693 789 885 980 1075 1169 1262 CD4-536 SURVEY PROGRAM Date: 2019-09-27T00:00:00 Validated: Yes Version: From To Tool 54.80 1600.00 r.5 SDI_URSA1 1600.00 2680.00 MWD+IFR2+SAG+MS 2680.00 7650.00 MWD+IFR2+SAG+MS 7650.00 15350.00 MWD+IFR2+SAG+MS 15350.00 20677.90 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing 4232.70 20677.89 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 54.80 0.00 0.00 54.80 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00000 3 500.00 2.00 63.00 499.96 1.58 3.11 1.00 63.00 0.18 Start Build 1.50000 4 700.00 5.00 63.00 699.56 7.13 13.99 1.50 0.00 0.82 Start Build 2.00000 5 1284.57 16.69 63.00 1272.70 56.98 111.83 2.00 0.00 6.57 Start 104.39882 hold at 1284.57406 MD 6 1388.97 16.69 63.00 1372.70 70.59 138.54 0.00 0.00 8.14 Start Build 2.75000 7 2745.38 53.99 63.00 2459.70 420.54 825.36 2.75 0.00 48.48 Start 20.00000 hold at 2745.37571 MD 8 2765.38 53.99 63.00 2471.46 427.89 839.78 0.00 0.00 49.33 Start DLS 2.75000 TFO 84.07734 9 3043.33 55.14 72.28 2632.84 513.77 1048.89 2.75 84.08 79.51 Start 410.54739 hold at 3043.33343 MD 10 3453.88 55.14 72.28 2867.49 616.31 1369.78 0.00 0.00 151.15 Start DLS 2.75000 TFO 7.70213 11 4181.50 75.00 75.00 3172.70 800.00 2000.00 2.75 7.70 307.18 Start 500.00000 hold at 4181.49978 MD 12 4681.50 75.00 75.00 3302.11 925.00 2466.51 0.00 0.00 432.18 Start DLS 3.00000 TFO 0.20706 13 5077.81 86.89 75.04 3364.37 1025.97 2843.91 3.00 0.21 533.44 Start 8453.85906 hold at 5077.81461 MD 1413531.67 86.89 75.04 3823.11 3204.69 10999.30 0.00 0.00 2724.31 Start DLS 3.50000 TFO 97.37476 1515467.39 82.00 143.00 4035.70 2618.76 12714.45 3.50 97.37 4089.31 CD4-NE5B (LL) T0.5 082524 Start DLS 3.50000 TFO 107.19445 1615669.76 79.97 149.87 4067.45 2452.35 12824.91 3.50 107.19 4288.66 Start 580.77655 hold at 15669.75613 MD 1716250.53 79.97 149.87 4168.63 1957.72 13111.98 0.00 0.00 4860.55 Start DLS 3.00000 TFO -6.45134 1816419.34 85.00 149.30 4190.70 1813.45 13196.68 3.00 -6.45 5027.85 CD4-NE5B (LL) T01 082524 Start DLS 3.00000 TFO -3.49134 1916549.39 88.89 149.06 4197.62 1701.94 13263.20 3.00 -3.49 5157.68 Start 2299.26721 hold at 16549.39377 MD 2018848.66 88.89 149.06 4241.99 -269.84 14445.04 0.00 0.00 7456.21 Start DLS 1.50000 TFO -0.13156 2118922.37 90.00 149.06 4242.70 -333.06 14482.93 1.50 -0.13 7529.90 CD4-NE5B (LL) T02 082524 Start DLS 1.50000 TFO -1.01403 2218944.26 90.33 149.05 4242.64 -351.84 14494.19 1.50 -1.01 7551.80 Start 1733.63460 hold at 18944.26499 MD 23 20677.90 90.33 149.05 4232.70 -1838.67 15385.66 0.00 0.00 9285.17 CD4-NE5B (LL) T03 082524 TD at 20677.89959 CD4-540 wp05 AC Flipbook SURVEY PROGRAM Depth From Depth To Tool 54.80 1600.00 r.5 SDI_URSA1 1600.00 2680.00 MWD+IFR2+SAG+MS 2680.00 7650.00 MWD+IFR2+SAG+MS 7650.00 15350.00 MWD+IFR2+SAG+MS 15350.00 20677.90 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing 4232.70 20677.89 4-1/2" Production Liner 10 10 20 20 30 30 40 40 50 50 60 60 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in] 1024 1117 1208 CD4-12 1024 1117 1208 1027 1120 1210 Nanuq 5 1336 1430 1521 CD4-209 1120 1205 CD4-210 1122 1207 1122 1207 1122 1207 922 1017 1107 CD4-213 922 1017 1107 922 1017 1107 922 1017 1107 922 1017 1107 55 100200300 400 499 599 698 796 894 CD4-539 1619 CD4-96 16191619 115215314 414512611709807 905 1003 CD4-537 wp03 99199299400500 601 702 804 905 1006 CD4-542 wp11.1 55 500 500 700 700 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 15000 15000 20684 From Colour To MD 54.80 To 2700.00 MD Azi TFace 54.80 0.00 0.00 300.00 0.00 0.00 500.00 63.00 63.00 700.00 63.00 0.00 1284.57 63.00 0.00 1388.97 63.00 0.00 2745.38 63.00 0.00 2765.38 63.00 0.00 3043.33 72.28 84.08 3453.88 72.28 0.00 4181.50 75.00 7.70 4681.50 75.00 0.00 5077.81 75.04 0.21 13531.67 75.04 0.00 15467.39 143.00 97.37 15669.76 149.87 107.19 16250.53 149.87 0.00 16419.34 149.30 -6.45 16549.39 149.06 -3.49 18848.66 149.06 0.00 18922.37 149.06 -0.13 18944.26 149.05 -1.01 20677.90 149.05 0.00 CD4-540 wp05 AC Flipbook SURVEY PROGRAM Depth From Depth To Tool 54.80 1600.00 r.5 SDI_URSA1 1600.00 2680.00 MWD+IFR2+SAG+MS 2680.00 7650.00 MWD+IFR2+SAG+MS 7650.00 15350.00 MWD+IFR2+SAG+MS 15350.00 20677.90 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing 4232.70 20677.89 4-1/2" Production Liner 25 25 50 50 75 75 100 100 125 125 150 150 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [50 usft/in] 3220Nanuk 1 265727552850294330373136 3235 3334 3432 3528 3626 3724 3823 3923 4024 4127 4228 4326 CD4-537 wp03 55 500 500 700 700 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 15000 15000 20684 From Colour To MD 2600.00 To 7700.00 MD Azi TFace 54.80 0.00 0.00 300.00 0.00 0.00 500.00 63.00 63.00 700.00 63.00 0.00 1284.57 63.00 0.00 1388.97 63.00 0.00 2745.38 63.00 0.00 2765.38 63.00 0.00 3043.33 72.28 84.08 3453.88 72.28 0.00 4181.50 75.00 7.70 4681.50 75.00 0.00 5077.81 75.04 0.21 13531.67 75.04 0.00 15467.39 143.00 97.37 15669.76 149.87 107.19 16250.53 149.87 0.00 16419.34 149.30 -6.45 16549.39 149.06 -3.49 18848.66 149.06 0.00 18922.37 149.06 -0.13 18944.26 149.05 -1.01 20677.90 149.05 0.00 CD4-540 wp05 AC Flipbook SURVEY PROGRAM Depth From Depth To Tool 54.80 1600.00 r.5 SDI_URSA1 1600.00 2680.00 MWD+IFR2+SAG+MS 2680.00 7650.00 MWD+IFR2+SAG+MS 7650.00 15350.00 MWD+IFR2+SAG+MS 15350.00 20677.90 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing 4232.70 20677.89 4-1/2" Production Liner 75 75 150 150 225 225 300 300 375 375 450 450 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [150 usft/in] 7646 774578447943804381428241 CD4-537 wp03 55 500 500 700 700 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 15000 15000 20684 From Colour To MD 7600.00 To 15400.00 MD Azi TFace 54.80 0.00 0.00 300.00 0.00 0.00 500.00 63.00 63.00 700.00 63.00 0.00 1284.57 63.00 0.00 1388.97 63.00 0.00 2745.38 63.00 0.00 2765.38 63.00 0.00 3043.33 72.28 84.08 3453.88 72.28 0.00 4181.50 75.00 7.70 4681.50 75.00 0.00 5077.81 75.04 0.21 13531.67 75.04 0.00 15467.39 143.00 97.37 15669.76 149.87 107.19 16250.53 149.87 0.00 16419.34 149.30 -6.45 16549.39 149.06 -3.49 18848.66 149.06 0.00 18922.37 149.06 -0.13 18944.26 149.05 -1.01 20677.90 149.05 0.00 CD4-540 wp05 AC Flipbook SURVEY PROGRAM Depth From Depth To Tool 54.80 1600.00 r.5 SDI_URSA1 1600.00 2680.00 MWD+IFR2+SAG+MS 2680.00 7650.00 MWD+IFR2+SAG+MS 7650.00 15350.00 MWD+IFR2+SAG+MS 15350.00 20677.90 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2424.63 2686.85 13-3/8" Surface Casing 3504.13 7653.32 9-5/8" Intermediate Casing 4020.14 15355.54 7" Intermediate Casing 4232.70 20677.89 4-1/2" Production Liner 75 75 150 150 225 225 300 300 375 375 450 450 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [150 usft/in] 15670 15742 15815 15893 15974 16059 16147 1623816338 16444 16551 16650167491684916948170481714817247173471744717547176471774617846179461804618146182461834618446185461864618746188471894919050191491924919349194491954919649197491984919949200492014920249203492044920510 CD4-537 wp03 55 500 500 700 700 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 15000 15000 20684 From Colour To MD 15300.00 To 20678.00 MD Azi TFace 54.80 0.00 0.00 300.00 0.00 0.00 500.00 63.00 63.00 700.00 63.00 0.00 1284.57 63.00 0.00 1388.97 63.00 0.00 2745.38 63.00 0.00 2765.38 63.00 0.00 3043.33 72.28 84.08 3453.88 72.28 0.00 4181.50 75.00 7.70 4681.50 75.00 0.00 5077.81 75.04 0.21 13531.67 75.04 0.00 15467.39 143.00 97.37 15669.76 149.87 107.19 16250.53 149.87 0.00 16419.34 149.30 -6.45 16549.39 149.06 -3.49 18848.66 149.06 0.00 18922.37 149.06 -0.13 18944.26 149.05 -1.01 20677.90 149.05 0.00 CD4-540 wp05 Spider Plot 13:44, January 22 2025 54.80 To 20677.90 Northing (4500 usft/in)Easting (4500 usft/in)3540455055606570 7 5Nanuk 13540CD4-53635 40 45 5 0 55 60 65 70 75 CD4-03354045505560657075CD4-05354045505560657075CD4-073 54 04 550 5 56 065 70 CD4-123 54 04 550 5 56 065 70 CD4-12PB13 5 4 0 4 5 5 0 5 5 6 0 6 5 7 0Nanuq 53540455055606570CD4-1635404550556065707 5CD4-173 540455 0556 0CD4-20835 40 45 5 0 5 5 6 0 6 5 70 7 5CD4-208A35 40 45 5 0 5 5 6 0 6 5 70 75CD4-208AL135 40 45 50 55 60 65 7 0CD4-208APB13 540455 0556 0CD4-208PB1354045505560 CD4-20935404 55 05560CD4-21035 40 45 50 55 60 65 70 75 CD4-210A35 40 45 50 55 60 65 70 75 CD4-210APB135 40 45 50 55 60 65 70 75CD4-210B3540455 05560 CD4-2113540455 05560CD4-211L13540455 05560CD4-211L1-0135404550 5560CD4-2133 5 4 0 4 55 05 56 0 6 57 0CD4-213A3540455055606570CD4-213B3540455055606570CD4-213BPB13540455055606570CD4-213BPB2354 04 55 05560 CD4-214354 04 55 05560CD4-214L135404 5 5 055 6 0 CD4-21535404 5 5 055 6 0CD4-215L1354 0 4 5 5055606 5 70 7 5CD4-23354 0 4 5 5 0 5 5 6 0 6 5 70CD4-23PB1354 0 4 5 5055606 5 70CD4-23PB235 40 45 50 55 60 65 7075CD4-2435 40 45 50 55 60 65 7075CD4-24PB135 40 45 50 55 60 65 7075CD4-24PB235 40 45 50 55 60 6 5 707 5CD4-2535 40 45 50 55 60 6 5 707 5CD4-25L135 40 45 50 55 60 6 570CD4-25PB1354045505560657075CD4-2635 40 45 50 55 60 65 70 75CD4-2735 40 45 50 55 60 65 70 75CD4-27PB135 40 45 50 55 60 65 70 75CD4-27PB235 40 45 50 55 60 65 70 75CD4-27PB3354045505560CD4-28935404550556 0 CD4-29035404550556 0 CD4-29135404550556 0 CD4-291PB13 5404550556 0 CD4-292354045505560CD4-298354045505560CD4-298PB13540455055606 5CD4-301354045505 5 60 65CD4-301A354045505 5 60 65CD4-301B3540455055606570CD4-3023540455055606570CD4-3043540455055606570CD4-304PB13540455055606570CD4-3063 5 4 0 4 5 5 0 5 5 6 0 6570CD4-3183 5 4 0 4 5 5 0 5 5 6 0 6570CD4-318A3 5 4 0 4 5 5 0 5 5 6 06570CD4-318PB135 40 45 50 55 606570CD4-31935404550556065 7 0 CD4-32035404550556 06 5 7 0CD4-320PB1354045505560657075CD4-321354045505560657075CD4-3223540 CD4-4993540CD4-5363540CD4-5393540CD4-5863540CD4-586L1 wp013540CD4-587354 0 CD4-5883540CD4-594354045CD4-594PH135404 5CD4-5953 5 404 5CD4-595PH13540CD4-59735404550556 065 70 7 5 CD4-9335404550556 065 70 75 CD4-93A3 5 4 0 4 5 5 0 5 5 6 0 6 5 70CD4-963 5 4 0 4 5 5 0 5 5 6 0 6 5 70 7 5 CD4-96A3 5 4 0 4 5 5 0 5 5 6 0 6 5 70 7 5 CD4-96APB1354045505560657075Nanuq 33540CD4-432 wp053 5 4 0 CD4-529 wp013540CD4-531 wp073540CD4-533 wp033540CD4-535 wp023540CD4-537 wp03354 0 CD4-542 wp11.135404550556065707 5 80Nanuk 23540CD4-540 wp05 CD4-540 wp05 Spider Plot 13:50, January 22 2025 54.80 To 20677.90 Northing (1500 usft/in)Easting (1500 usft/in)25283033353840434548505355586063656870 7 3 7 5Nanuk 12528303335CD4-53625 28 30 33CD4-03CD4-05CD4-072 5 2 8 30 33 3 5 3 8 4 0 4 3 4 5 4 8CD4-122 5 2 8 30 33 3 5 3 8 4 0 4 3 4 5 4 8CD4-12PB12 5 2 8 3 0 3 3 3 5 3 8Nanuq 5CD4-16CD4-172 52830333538404345485 0535558 6 0 6 3CD4-20825 2830 33 35 38 40 43 45CD4-208A25 2830 33 35 38 40 43 45CD4-208AL125 2830 33 35 38 40 43 45CD4-208APB12 52830333538404345485 0535558 6 0 6 3CD4-208PB12528303335384043454850535558 6 0 6 3 CD4-20925283033 353 8CD4-2102528 30 33 35CD4-210A2528 30 33 35CD4-210APB12528 30 33 35CD4-210B2528CD4-2112528CD4-211L12528CD4-211L1-0125 28 30CD4-213252830333 53 84 04 34 5 4 85 0CD4-213A2 5CD4-213B25 2 8CD4-213BPB125 28CD4-213BPB2CD4-214CD4-214L1CD4-215CD4-215L1CD4-23CD4-23PB1CD4-23PB225CD4-2425CD4-24PB125CD4-24PB2CD4-25CD4-25L1CD4-25PB1CD4-26CD4-27CD4-27PB1CD4-27PB2CD4-27PB32528303335384043454850535558606 3 CD4-28925283033353840434548505355586 0 CD4-29025283033353840434548505355586 0 CD4-29125283033353840434548505355586 0 CD4-291PB12 52830333538404345485053555 8 6 0 6 3 CD4-29225283033353840434548505355586063CD4-2982528303335384043454850535558606 3 CD4-298PB12528303335384043454850535558636 5 68CD4-30125283033353840434548505355 58 60 63 65 68CD4-301A2528303335384043454850535 5 58 60 63 65 68CD4-301B25283033353840434548505355586063656870CD4-30225CD4-30425CD4-304PB125CD4-306CD4-318CD4-318ACD4-318PB125CD4-31925 28 303335384043 45485053555 86 063 6 5 6 8 7 0 CD4-32025 28 303335384043 45 4850 5 355 5860636 5 6 8 7 0CD4-320PB1CD4-321CD4-3222528303335384 0CD4-4992528303335CD4-53625283033353840CD4-53925283033353840CD4-58625283033353840CD4-586L1 wp0125283033353840CD4-5872528303335384 0 CD4-58825283033CD4-59425283033CD4-594PH12528CD4-5952528CD4-595PH1252830CD4-59725CD4-9325CD4-93A2 5CD4-962 5CD4-96A2 5CD4-96APB1Nanuq 32 5283 033353840CD4-432 wp0525 28 3 0CD4-529 wp012 528CD4-531 wp0725283033CD4-533 wp032528303335CD4-535 wp0225283033353840CD4-537 wp032528303335384 0 CD4-542 wp11.1Nanuk 225283033353840CD4-540 wp05 CD4-540 wp05 Spider Plot 13:54, January 22 2025 54.80 To 20677.90 Northing (400 usft/in)Easting (400 usft/in) 1 517 192123252729313335373941434547495153555 7 5961636567697 1 7 3 7 5Nanuk 11517192123252729CD4-5361 5 1 7 19 21CD4-03151719CD4-05151719CD4-071 5 1 7 1 9 2 1 2 3CD4-121 5 1 7 1 9 2 1 2 3CD4-12PB11 5 1 7 1 9 2 1 2 3Nanuq 5CD4-16CD4-171 5 1 7 1 9 2 1 23 2 5 2 7 2 9 3 161CD4-2081 5 1 7 1 9 2 1 23 25 27 29 31CD4-208A1 5 1 7 1 9 2 1 23 25 27 29 31CD4-208AL11 5 1 7 1 9 2 1 23 25 27 29 31CD4-208APB11 5 1 7 1 9 2 1 23 2 5 2 7 2 9 3 161CD4-208PB11517192123 25 27293133 35 37 39 41 43 45 47 49 51 53CD4-2091 5 17 1 9 2 1 23CD4-2101 5 17 1 9 2 1 23CD4-210A1 5 17 1 9 2 1 23CD4-210APB11 5 17 1 9 2 1 23CD4-210B151719CD4-211151719CD4-211L1151719CD4-211L1-0115 17 19 21CD4-21315 17 19 21CD4-213A15 17 19 21CD4-213B15 17 19 21CD4-213BPB115 17 19 21CD4-213BPB21 5CD4-2141 5CD4-214L115CD4-21515CD4-215L115 1 7CD4-2315 1 7CD4-23PB115 1 7CD4-23PB215CD4-2415CD4-24PB115CD4-24PB2CD4-25CD4-25L1CD4-25PB1CD4-26CD4-27CD4-27PB1CD4-27PB2CD4-27PB3151719212325272931333537394143454749CD4-28915171921232527293133353739414345474951535557596 1 CD4-2901517192123252729313335373941434547495153555759CD4-2911517192123252729313335373941434547495153555759CD4-291PB11 51 71 92 1232 52 72 93 1333537394143454749 5 1 5 3 5 5 5 7 5 9CD4-29215171921232527293133CD4-29815171921232527293133CD4-298PB1151719212325272931CD4-301151719212325272931CD4-301A151719212325272931CD4-301B151719212325272931333537394143CD4-30215171921CD4-30415171921CD4-304PB1151719CD4-306CD4-318CD4-318ACD4-318PB115CD4-31915 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 6 5 6 7 6 9 CD4-32015 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 6 5 6 7 6 9 CD4-320PB1CD4-321CD4-322151719 21232527293133353739CD4-4991517192123252729CD4-53615171921232527CD4-5391517192123252729CD4-5861517192123252729CD4-586L1 wp0115171921232527CD4-58715171921232527CD4-58815171921232527CD4-59415171921232527CD4-594PH11517192123CD4-5951517192123CD4-595PH115171921232527CD4-59715171921CD4-9315171921CD4-93A15 17 19 21 23CD4-9615 17 19 21 23CD4-96A15 17 19 21 23CD4-96APB1Nanuq 339CD4-432 wp0515 17CD4-529 wp011 5 17 192123CD4-531 wp0715171921232527CD4-533 wp031 5 171921232527CD4-535 wp021 5 1 7 1 9 2 1 2 3 25272931CD4-537 wp0315171921232527CD4-542 wp11.115171921232527293133CD4-540 wp05 CD4-540 wp05 Spider Plot 13:56, January 22 2025 54.80 To 20677.90 Northing (80 usft/in)Easting (80 usft/in)101214CD4-53624 6 8 10 12 14CD4-03246810121416CD4-052468101214CD4-07246 8 1 0 1 2 1 4CD4-12246 8 1 0 1 2 1 4CD4-12PB1246 8 1 0 1 2 1 4Nanuq 52468CD4-1624 6CD4-17246 8 1 0 1 2 1 4 1 6CD4-208246 8 1 0 1 2 1 4 1 6CD4-208A246 8 1 0 1 2 1 4 1 6CD4-208AL1246 8 1 0 1 2 1 4 1 6CD4-208APB1246 8 1 0 1 2 1 4 1 6CD4-208PB12468 1012 14 16 18 20 22 24 26 28CD4-209246 8 10 1 2 1 4CD4-210246 8 10 1 2 1 4CD4-210A246 8 10 1 2 1 4CD4-210APB1246 8 10 1 2 1 4CD4-210B246 8 1 01214CD4-211246 8 1 01214CD4-211L1246 8 1 01214CD4-211L1-0124 6 8 10 12 14CD4-21324 6 8 10 12 14CD4-213A24 6 8 10 12 14CD4-213B24 6 8 10 12 14CD4-213BPB124 6 8 10 12 14CD4-213BPB22 46 8 10CD4-2142 46 8 10CD4-214L12468CD4-2152468CD4-215L12468 1 0 12 141618CD4-289246 8 1 0 121416CD4-2902 4681 0 1214161820CD4-2912 4681 0 1214161820CD4-291PB124 6 8101 2 1 4 1 6 1 8 2 0 2 2 2 4 2 6 2 8 3 0 3 2CD4-2922 46810121416CD4-2982 46810121416CD4-298PB1246810121416CD4-301246810121416CD4-301A246810121416CD4-301B246810121416CD4-302246 8 1 0 1 21416CD4-304246 8 1 0 1 21416CD4-304PB1246 8 1 01214CD4-30624CD4-31824CD4-318A24CD4-318PB1246 8 10 12 14 1 6 1820222426CD4-499101214CD4-5362468101214CD4-5390 246 81012CD4-586246 81012CD4-586L1 wp0124681012CD4-587246 8101214CD4-5882468101214CD4-5942468101214CD4-594PH1246810121416CD4-595246810121416CD4-595PH1246810121416CD4-597246 8 1 0 1 214CD4-93246 8 1 0 1 214CD4-93A2 4681 0 12 14 16 18CD4-962 4681 0 12 14 16 18CD4-96A2 4681 0 12 14 16 18CD4-96APB11214CD4-535 wp026 8 1 0 1 2 1 4 1 6 1 8 2 0 2 2 CD4-537 wp0324 681012141618CD4-542 wp11.1246 810121416182022CD4-540 wp05 CD4-540 wp05 CD4-298 CD4-298PB1 CD4-301 CD4-301A CD4-302 CD4-586CD4-586L1 wp01CD4-587 CD4-588 CD4-59 CD4-537 wp03 CD4-542 wp11.1 3-D ViewCD4-540 wp05 14:14, January 22 2025 CD4-540 wp05 CD4-298 CD4-298PB1 CD4-301 CD4-301A CD4-301B CD4-302 CD4-588CD4-594PH1 CD4-537 wp03 CD4-542 wp11.1 3-D ViewCD4-540 wp05 14:13, January 22 2025 CD4-540 wp05 Nanuq 5 CD4-289 CD4-290 CD4-291 CD4-291PB1 CD4-292 CD4-298 CD4-298PB1 CD4-301 CD4-301A CD4-301B CD4-302 CD4-320 CD4-588 CD4-594PH1 CD4-537 wp03 CD4-542 wp11.1 3-D ViewCD4-540 wp05 14:13, January 22 2025 -3000 -1500 0 1500 3000 4500 South(-)/North(+) (1500 usft/in)10500 12000 13500 15000 16500 18000 19500 21000 West(-)/East(+) (1500 usft/in) C D 4 -2 9 8 C D 4 -2 9 8 P B 1 C D 4 -3 0 1 C D 4 -3 0 1 ACD4-3 0 1 B 4050C D 4 -5 3 9 4050410041504200C D 4 -586405041004150C D 4 -5 8 6 L 1 w p 0 14050 41 00C D 4 -5 8 7 4 0 5 0 4 1 0 0 4 1 5 0 4 20 0 C D 4 -5 8 8 40504 1 0 0 C D 4 -5 3 7 w p 0 3 4 0 5 0 4 1 0 0 4 1 5 0 C D 4 -5 4 2 w p 1 1 .14050 4 1 0 0 4 1 5 0 4 2 0 0 C D 4 -5 4 0 w p 0 5 CD4-540 wp05 Quarter Mile View 14:12, January 22 2025 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVD Shape CD4-NE5B (LL) T0.5 082524 4035.70 Circle (Radius: 100.00) CD4-NE5B (LL) T01 082524 4190.70 Circle (Radius: 100.00) CD4-NE5B (LL) T02 082524 4242.70 Circle (Radius: 100.00) CD4-NE5B (LL) T03 082524 4232.70 Circle (Radius: 100.00) CD4-NE5B (LL) T01 QM 4190.70 Circle (Radius: 1320.00) CD4-NE5B (LL) T02 QM 4242.70 Circle (Radius: 1320.00) CD4-NE5B (LL) T03 QM 4232.70 Circle (Radius: 1320.00) -600 -300 0 300 600 900 South(-)/North(+) (300 usft/in)0 300 600 900 1200 1500 1800 2100 West(-)/East(+) (300 usft/in)2425N a n u k 1 2425C D 4 -5 3 6 C D 4 -0 3 C D 4 -0 5 C D 4 -0 7 C D 4 -1 2CD4-1 2 P B 1 N a n u q 5 C D 4-16C D 4 -1 7 2 425 C D 4 -2 0 8 2 425 C D 4 -2 0 8 A 2 425 CD4-208AL12 425 C D 4 -2 0 8 A P B 1 2 425 C D 4 -2 0 8 P B 1 2425 CD4 -2 0 9 C D 4 -2 1 0 C D 4 -2 1 0 A C D 4 -2 1 0 A P B 1 CD 4-210B C D 4 -2 1 1CD4-211L1CD4-211L1-01C D 4 -2 1 3 CD4-213ACD4-213BCD4-213BPB1CD4-213BPB2C D 4 -2 1 4 C D 4 -2 1 4 L 1 C D 4 -2 1 5 C D 4 -2 1 5 L 1 C D 4 -2 3 C D 4 -2 3 P B1 C D 4 -2 3 P B 2 C D 4 -2 4 C D 4 -2 4 P B 1 CD4-24PB2C D 4 -2 5 C D 4 -2 5 L 1 C D 4 -25P B 1C D 4 -2 6 C D 4 -2 7 CD4-27PB1 CD4-27PB2 C D4 -2 7 P B 3 2425C D 4 -2 8 9 2425C D4 -2 9 02425 C D 4 -2 9 124252425 C D 4 -2 9 2 2425C D 4 -2 9 8 24252425C D 4 -3 0 1242524252425CD4-302C D 4 -3 0 4CD4-304P B 1CD4-306C D 4 -3 1 8CD4-3 18 ACD4-3 1 8 P B 1 C D4-3 1 9 2425 C D 4 -3 2 0 2425 C D 4 -3 2 0 P B 1 CD4-321CD4-3222425C D 4 -4 9 92425CD4-5 3 62425 C D 4 -5 3 92425 C D 4 -5 86 2425C D 4 -5 8 72425CD4-5 88 2425C D 4 -5 9 42425 C D 4 -5 9 52425 C D 4 -5 9 7 C D 4-93C D 4 -9 3 A CD4-96CD4-9 6A C D 4 -9 6 A P B 1Nanuq 3C D 4 -4 3 2 w p 0 5 C D 4-529 w p 01C D 4 -5 3 1 w p0 7 2425C D 4 -5 3 3 w p 0 32425 C D 4 -5 3 5 w p 0 2 2 4 2 5 C D 4 -5 3 7 w p 0 3 2425C D 4 -5 4 2 w p 1 1 .1 13-3/8" Surface Casing2425 C D 4 -5 4 0 w p 0 5 CD4-540 wp05 Surface Casing 500' radius 15:22, January 22 2025 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVD Shape CD4-NE5B (LL) T0.5 082524 4035.70 Circle (Radius: 100.00) CD4-NE5B (LL) T01 082524 4190.70 Circle (Radius: 100.00) CD4-NE5B (LL) T02 082524 4242.70 Circle (Radius: 100.00) CD4-NE5B (LL) T03 082524 4232.70 Circle (Radius: 100.00) CD4-540 Srf Csg 2424.63 Circle (Radius: 500.00) CD4-NE5B (LL) T01 QM 4190.70 Circle (Radius: 1320.00) CD4-NE5B (LL) T02 QM 4242.70 Circle (Radius: 1320.00) CD4-NE5B (LL) T03 QM 4232.70 Circle (Radius: 1320.00) -600 -300 0 300 600 900 South(-)/North(+) (300 usft/in)0 300 600 900 1200 1500 1800 2100 West(-)/East(+) (300 usft/in)2425N a n u k 12425 C D 4 -2 8 9 2425C D4 -2 9 02425 C D 4 -2 9 1 24 2 5 C D 4 -2 9 22425 C D 4 -4 9 92425 C D 4 -5 9 4 13-3/8" Surface Casing2425 C D 4 -5 4 0 w p 0 5 CD4-540 wp05 Surface Casing 500' radius 15:26, January 22 2025 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVD Shape CD4-NE5B (LL) T0.5 082524 4035.70 Circle (Radius: 100.00) CD4-NE5B (LL) T01 082524 4190.70 Circle (Radius: 100.00) CD4-NE5B (LL) T02 082524 4242.70 Circle (Radius: 100.00) CD4-NE5B (LL) T03 082524 4232.70 Circle (Radius: 100.00) CD4-540 Srf Csg 2424.63 Circle (Radius: 500.00) CD4-NE5B (LL) T01 QM 4190.70 Circle (Radius: 1320.00) CD4-NE5B (LL) T02 QM 4242.70 Circle (Radius: 1320.00) CD4-NE5B (LL) T03 QM 4232.70 Circle (Radius: 1320.00) CD4-540wp05 Surface Location CD4-540wp05 Surface Location CD4-540wp05 Surface Casing CD4-540wp05 Surface Casing CD4-540wp05 Intermediate Casing 1 CD4-540wp05 Intermediate Casing 1 CD4-540wp05 Intermediate Casing 2 CD4-540wp05 Intermediate Casing 2 CD4-540wp05 Top Narwhal CD4-540wp05 Top Narwhal CD4-540wp05 Lefty CD4-540wp05 Lefty CD4-540wp05 TD CD4-540wp05 TD &' W,KE͗ϵϬϳͲϲϳϬͲϰϳϯϵ W,KE͗ϵϬϳͲϲϳϬͲϰϳϯϵ W,KE͗ϵϬϳͲϲϳϬͲϰϳϯϵ )67+72($7$/$$ . 6 80,$4'HVLJQ 0XQLFLSDO 6HUYLFHV//&$(&/ Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 225-015 QANNIK OIL CRU CD4-540 COLVILLE RIVER WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:COLVILLE RIV UNIT CD4-540Initial Class/TypeDEV / PENDGeoArea890Unit50360On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250150Field & Pool:COLVILLE RIVER, QANNIK OIL - 120180NA1 Permit fee attachedYes ADL372096, ADL372097, ADL384211, and ADL3800772 Lease number appropriateYes3 Unique well name and numberYes COLVILLE RIVER, QANNIK OIL - 120180 - governed by CO 6054 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 80'18 Conductor string providedYes Surface casing set at 2687' MD19 Surface casing protects all known USDWsYes 107% excess20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgNo swell packers/frac sleeves22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes variance per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulationsYes Max reservoir pressure is 1915 psig(8.7 ppg EMW); will drill w/ 8.2 ppg EMW with MPD to ~10 ppg28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 1492 psig; will test BOPs to 5000 psig initially and subsequently to 3850 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNo34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S not anticipated35 Permit can be issued w/o hydrogen sulfide measuresYes Narwhal sand anticipated to be 8.7 ppg EMW. MPD to be employed in production hole.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate3/20/2025ApprVTLDate6/5/2025ApprADDDate3/20/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 6/25/2025