Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
224-117
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-04-05_22644_KRU_1H-106_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22644 KRU 1H-106 50-029-23800-00 Caliper Survey w/ Log Data 05-Apr-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-117 T40319 4/16/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.16 08:00:08 -08'00' Originated: Delivered to:27-Mar-25Alaska Oil & Gas Conservation Commiss27Mar25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDMT7-15 50-103-20885-00-00 224-037 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Feb-251H-106 50-029-23800-00-00 224-117 Kuparuk River WL TTiX-PPROF FINAL FIELD 22-Feb-251C-157 50-029-23754-00-00 223-038 Kuparuk River WL TTiX-FSI FINAL FIELD 27-Feb-25CD3-127 50-103-20634-00-00 211-005 Colville River WL Patch&Packer FINAL FIELD 8-Mar-251C-151 50-029-23497-00-00 213-123 Kuparuk River WL TTiX-FSI FINAL FIELD 12-Mar-253S-624 50-103-20868-00-00 223-104 Kuparuk River WL TTiX-FSI FINAL FIELD 22-Mar-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40238T40239T40240T40241T40242T402431H-10650-029-23800-00-00224-117Kuparuk RiverWLTTiX-PPROFFINAL FIELD22-Feb-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.03.28 08:11:16 -08'00' T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Jan 09, 2025 AOGCC Attention: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 1H-106/ KRU 1H-106L1 Kuparuk River API #: 50-029-23800-00-00/50-029-23800-60-00 Permit No: 224-117/224-118 Rig: Doyon 25 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Hampton, Jerissa Jerissa.Hampton@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com 224-117: T39942 224-118: T39943 KRU 1H-106 0-029-23800-00-00 /224-117 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.09 08:10:34 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U WSAK 1H-106 JBR 01/10/2025 MISC. INSPECTIONS: GAS DETECTORS: DIVERTER SYSTEM:MUD SYSTEM: P/F P/F P/F Alarm Visual Alarm Visual Time/Pressure Size Number of Failures:0 Remarks: TEST DATA Rig Rep:Roy Fritts/Joson FetterlOperator:ConocoPhillips Alaska, Inc.Operator Rep:Rob Reinhardt/Lloyd Shirle Contractor/Rig No.:Doyon 25 PTD#:2241170 DATE:11/2/2024 Well Class:DEV Inspection No:divAGE241104112006 Inspector Adam Earl Inspector Insp Source Related Insp No: Test Time:1 ACCUMULATOR SYSTEM: Location Gen.:P Housekeeping:P Warning Sign P 24 hr Notice:P Well Sign:P Drlg. Rig.P Misc:NA Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:0 NA Designed to Avoid Freeze-up?P Remote Operated Diverter?P No Threaded Connections?P Vent line Below Diverter?P Diverter Size:21.25 P Hole Size:16 P Vent Line(s) Size:16 P Vent Line(s) Length:166 P Closest Ignition Source:78 P Outlet from Rig Substructure:146 P Vent Line(s) Anchored:P Turns Targeted / Long Radius:NA Divert Valve(s) Full Opening:P Valve(s) Auto & Simultaneous: Annular Closed Time:22 P Knife Valve Open Time:17 P Diverter Misc:0 NA Systems Pressure:P2800 Pressure After Closure:P2250 200 psi Recharge Time:P20 Full Recharge Time:P69 Nitrogen Bottles (Number of):P6 Avg. Pressure:P1975 Accumulator Misc:NA0 P PTrip Tank: P PMud Pits: P PFlow Monitor: 0 NAMud System Misc: 9 9 9 9 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-106 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-117 Surface Location: 70 FNL, 762 FEL, S33 T12N R10E, UM Bottomhole Location: 4127 FSL, 495 FEL, S14 T12N R10E, 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 29th day of October 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.29 07:20:37 -06'00' 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 and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 21,776 TVD: 4129 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): 93.61 15. Distance to Nearest Well Open Surface: x- 549580 y- 5980633 Zone- 4 54 to Same Pool: 1242' to 1H-120 16. Deviated wells: Kickoff depth: 700 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93.31 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 80 40 40 120 120 16" 13-3/8" 68# L80 H563 1928 40 40 1928 1864 12-1/4" 9-5/8" 40# L80 H563 10463 40 40 10463 3922 6-3/4" 4-1/2" 12.6# 13CR-80 JFE BEAR 6309 9750 3744 21776 4129 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): N/A 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: Brad.Gorham@conocophillips.com Wells Engineering Manager Contact Phone: 907-265-6487 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field West Sak Oil Pool October 15th, 2024 4784' to ADL025636 1466 sx of 14.0 ppg Ext. Class G + 346 sx of 15.3 ppg Class G 1082 sx of 11.0 ppg LiteCRETE + 328 sx of 15.8 ppg Class G Cement to surface with 10 yds slurry 1562 N/A:Open Hole Standalone Screens 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: Brad Gorham Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Perforation Depth TVD (ft): N/A N/A N/A N/A N/A 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) 1975 P.O. Box 100360 Anchorage, Alaska, 99510-0360 70 FNL, 762 FEL, S33 T12N R10E, UM ADL025637, ADL025638, ADL025639 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska, Inc.59-52-180 KRU 1H-106 5095 FSL, 4690 FEL, S26 T12N R10E, UM 931812000, 931695000, 931696000 4127 FSL, 495 FEL, S14 T12N R10E, UM 2560, 2560, 2560 GL / BF Elevation above 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) By Grace Christianson at 3:34 pm, Aug 23, 2024 A.Dewhurst 10OCT24 224-117 Diverter variance not approved; diverter required. DSR-8/26/24 50-029-23800-00-00 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Surface casing LOT and annular LOT to the AOGCC as soon as available BOPE testing on a 21-day interval is approved with the attached conditions RAM configuration allowing three preventers for MPSP < 3000 psig is approved as outlined in 20 AAC 25.035.c.1.A for Int and production holes VTL 10/28/2024 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.29 07:20:49 -06'00'10/29/24 10/29/24 RBDMS JSB 103024 KRU 1H-10 and 1H-10L1 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, AK 99510-0360 Telephone 907-276-1215 August 21, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill 1H-106 Dear Sir or Madam, ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore West Sak B Sand – Dual Lateral Producer from the 1H drilling pad. The intended spud date for this well is October 15th, 2024. It is intended that Doyon 25 be used to drill the well. 1H-106 will drill a 16" surface hole on diverter. 13-3/8'' casing will be run and cemented to surface. The remaining intervals will utilize Doyon 25’s 13-5/8” x 5000 psi BOP stack with required ram. The 12-1/4'' intermediate hole section will be landed in the top of the West Sak B sand. 9-5/8'' intermediate casing will be run and cemented in place with a 500’ or 250’ TVD column of cement above the highest hydrocarbon bearing zone per AOGCC regulation. The lower 6-3/4'' West Sak B production lateral will be initiated and then directionally drilled to complete the 1H-106. The lateral will be geo-steered and completed with 4-1/2'' Open Hole Standalone Screens. A separate Permit to Drill application will be submitted for the 1H-106L1 wellbore. The upper 1H-106L1 6-3/4'' West Sak D production lateral will be geo-steered and completed with 4-1/2'' Open Hole Standalone Screens. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. Three consecutive surface intervals have recently been drilled at 1H, (1H-112, 1H-120, 1H-107), and have not encountered any shallow gas or had any issues related to hydrates. A variance is also requested for a BOPE test interval of 21 days for this project. Doyon 25 supported the CPAI BOPE between well maintenance program with a replacement of its NOV BOP stack with a Cameron stack due to lack of NOV support. The variance allows effective drilling and completion of this multi-lateral well with reservoir instability and a complex middle completion to isolate the lateral junction. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a) 2. Proposed drilling program 3. Proposed drilling fluids program summary 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.005 (c) (4) (a-c) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Brad Gorham at 907-265-6487 (Brad.Gorham@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com). Regards, Brad Gorham Staff Drilling Engineer cc: 1H-106 Well File / Jenna Taylor ATO 1732 David Lee ATO 1552 Chris Brillon ATO 1548 Data presented in attached emails do not justify diverter variance. -A.Dewhurst 25SEP24 variance is also requested for a BOPE test interval variance of the diverter 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 1 | 14 1H-106 Well Plan Application for Permit to Drill Table of Contents 1. Well Name ............................................................................................................................................. 2 2. Location Summary ................................................................................................................................. 2 3. Proposed Drilling Program ..................................................................................................................... 5 4. Diverter and BOP Information ................................................................................................................ 6 5. MASP Calculations ................................................................................................................................. 7 6. Procedure for Conducting Formation Integrity Tests ............................................................................... 9 7. Casing and Cementing Program .............................................................................................................. 9 8. Drilling Fluid Program .......................................................................................................................... 11 9. Abnormally Pressured Formation Information ...................................................................................... 11 10. Seismic Analysis ................................................................................................................................... 12 11. Seabed Condition Analysis ................................................................................................................... 12 12. Evidence of Bonding ............................................................................................................................. 12 13. Discussion of Mud and Cuttings Disposal .............................................................................................. 12 14. Drilling Hazards Summary .................................................................................................................... 12 15. Proposed Completion Schematic .......................................................................................................... 14 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 2 | 14 1. Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H-106 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface 70 FNL, 762 FEL, S33 T12N R10E, UM NAD27 Northing: 5980632.86 Easting: 549579.90 RKB Elevation 39.61’ AMSL Pad Elevation 54’ AMSL Top of Productive Horizon (Heel) 5095 FSL, 4690 FEL, S26 T12N R10E, UM NAD27 Northing: 5985845.09 Easting: 556165.95 Measured Depth, RKB: 10463‘ MD True Vertical Depth, RKB: 3922‘ TVD True Vertical Depth, SS: 3828‘ TVDss Total Depth (Toe) 4127 FSL, 495 FEL, S14 T12N R10E, UM NAD27 Northing: 5995468.27 Easting: 560275.34 Measured Depth, RKB: 21776‘ MD True Vertical Depth, RKB: 4129‘ TVD True Vertical Depth, SS: 4035‘ TVDss Please see attached well stick diagram for the current planned development of the pad. 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 3 | 14 Pad Layout 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 4 | 14 Well Plat 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 5 | 14 3. Proposed Drilling Program 1. MIRU Doyon 25 onto well over pre-installed 20” insulated conductor. Install diverter and function test. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan, with Spud Mud. (LWD Program: GR/RES/GWD). 4. Run and cement new 13-3/8'' surface casing to surface. Results of the cement operation will be submitted as soon as possible. 5. Install BOPE with the following equipment/configuration: 13-5/8” annular preventer, 9-5/8'' FBR’s, blind ram and 2-7/8” x 5” VBR’s. x See section 4 for ram configuration justification. 6. Test BOPE to 250 psi low / 5000 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4'' drilling BHA to drill intermediate #1. 8. Chart casing pressure test to 3500 psi for 30 minutes, if not already done on plug bump. 9. Drill out shoe track and 20’ of new hole. 10. Displace well to FWP. 11. Perform LOT to maximum EMW of 14 ppg. Minimum LOT required to drill ahead is 10.8 ppg EMW. 12. Drill 12-1/4'' hole to the casing point. (LWD Program: GR/RES). 13. Circulate wellbore clean and POOH. 14. Run 9-5/8'' intermediate casing to TD. 15. Pump single stage cement job to isolate the casing shoe. Planned top 250' TVD above the shallowest hydrocarbon bearing zone within the Ugnu C. Test casing on plug bump to 3500 psi for 30 minutes. 16. Change upper 9-5/8'' solid body rams to 2-7/8” x 5” VBR’s. Test BOPE to 250 psi/3500 psi. (24-48 hr. regulatory notice). 17. Pick up 8.5” Cleanout BHA to perform cleanout of the shoe track. RIH. 18. Chart casing pressure test to 3500 psi for 30 minutes and record results, if not already done on plug bump. 19. Drill out shoe track and 20’ of new hole. Displace well to FloPro WBM 20. Perform FIT to max 13 ppg EMW. Minimum required to drill ahead is 9.6 ppg EMW. 21. Pick up and run in hole with 6-3/4'' drilling BHA to drill production hole (LWD Program: GR/RES/Azimuthal RES/DEN/NEU). SimOps, perform 9-5/8'' annulus freeze protect. 22. Drill 6-3/4'' horizontal hole to TD of 1H-106 directional profile (LWD Program: GR/RES/Azimuthal RES/DEN/NEU) 23. Circulate wellbore clean and POOH. 24. Run 4-1/2'' OHSAS and swell packer completion, set liner hanger and packer. Chart casing pressure test 3,500 psi. POOH LD DP. 25. POOH with liner running tools and lay down same. shallowest hydrocarbon bearing zone within the Ugnu C 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 6 | 14 26. Run and set Baker whipstock system, for the 1H-106L1 lateral in the West Sak D sand. 27. Mill 8-1/2'' window until top mill across face and clean up same. 28. POOH with milling BHA. Transfer to 1H-106L1 PTD 4. Diverter and BOP Information Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP and diverter schematics on file for Doyon 25. Doyon 25 will use a BOPE stack equipped with an annular preventer, fixed, 9-5/8'' solid body rams, blind/shear rams and variable bore rams while drilling and running casing in the intermediate section of 1H-106. 1H-106 has a MASP of 1562 psi in the production hole section using the methodology presented in section 5 MASP calculations. 20 AAC 25.035.e.1.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sized to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Intermediate Drilling/ Casing x Annular Preventer (iii) x 9-5/8'' Fixed Rams x Blind/Shear Rams (ii) x VBR’s (i) Production: x Annular Preventer (iii) x Solid Body Rams x Blind/Shear Rams (ii) x VBR’s (i) PTD 224-118 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 7 | 14 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 80 80 12.5 8.6 36 1928 1864 8.6 833 44 44 647 INT 12.25 13.375 1928 1864 12.5 8.6 833 10463 3922 9.2 1,876 1,025 1,025 1,484 PROD 6.75 4.5 10463 3922 12.5 9.2 1,876 21776 4129 9.2 1,975 1,562 2,157 1,562 VBR 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 8 | 14 (B) data on potential gas zones; The 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 1H-106 AOGCC 10-401 APD 8/20/2024 1H-106 AOGCC 10-401 APD 9 | 14 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 13-3/8'' 16" 68# L80 H563 Cement to Surface 9-5/8'' 12-1/4'' 40# L80 H563 250' TVD above T/ Ugnu C 4-1/2'' 6-3/4'' 12.6# 13CR-80 JFE BEAR N/A – Open Hole Stand Alone Screens 13-3/8'' Surface Casing run to 1928' MD/ 1864' TVD Cement Plan: Cement from 1928’ MD to 1428’ (500’ of tail) with Class G + Adds @ 15.8 ppg, and from 1428' to surface with 11.0 ppg LiteCRETE. Assume 250% excess annular volume in the lead and 50% in the tail, zero excess in 20” conductor. Lead 368 bbls => 1082 sx of 11.0 ppg LiteCRETE + Add's @ 1.91 ft³/sk Tail 68 bbls => 328 sx of 15.8 ppg Class G + Add's @ 1.165 ft³/sk 9-5/8'' Intermediate Liner run to 10463' MD/ 3922' TVD Cement Plan: Cement from 10463’ MD to 9463’ MD (1000’ of tail) with Class G + Adds @ 15.3 ppg, and from 9463’ MD to ~3678’ MD with 14.0 ppg extended class G Ext. Class G. Top of slurry is designed to be at 3678' MD/ 2845' TVD, which is 250' TVD above T/ Ugnu C. Assume 25% excess annular volume in the lead and 25% in the tail. Lead 403 bbls => 1466 sx of 14.0 ppg Ext. Class G + Add's @ 1.545 ft³/sk Tail 76 bbls => 346 sx of 15.3 ppg Class G + Add's @ 1.23 ft³/sk which is 250' TVD above T/ Ugnu C. 1H-106 AOGCC 10-401 APD 8/20/2024 1H-107 AOGCC 10-401 APD 10 | 14 Weight Yieldft3bblsft3bblsft3bblsft3bbls ppgft3/ SackLead: Conductor 0' - 80' 80 0.182 0% 82 14.52 0 0.00 0 0 82 14.52 43 11.0 ppg LiteCRETE 1.910Lead: Thru Perm 80' - 1428' 1348 0.075 250% 567 100.97 1417 252.44 0 0 1984 353.41 1039 11.0 ppg LiteCRETE 1.910648 115.49 1417 252.44 0 02066 367.93 1082 11.0 ppg LiteCRETE 1.91Weight Yieldft3bblsft3bblsft3bblsft3bbls ppgft3/ SackTail: 500' 1428' - 1928' 500 0.075 50% 210 37.45 105 18.73 0 0 315 56.18 271 15.8 ppg Class G 1.165Tail: Shoe Track 1848' - 1928' 80 0.150 0% 67 11.98 0 0.00 0 0 67 11.98 58 15.8 ppg Class G 1.165278 49.43 105 18.73 0 0383 68.16 328 15.8 ppg Class G 1.165Weight Yieldft3bblsft3bblsft3bblsft3bbls ppgft3/ SackLead Lead: 250' TVD above T/ Ugnu C 3678' - 9463' 5785 0.056 25% 1812 322.70 453 80.67 0 0 2265 403.37 1466 14.0 ppg Ext. Class G 1.5451812 322.70 453 80.67 0 02265 403.37 1466 14.0 ppg Ext. Class G 1.545Weight Yieldft3bblsft3bblsft3bblsft3bbls ppgft3/ SackTop Tail (1000' Tail Coverage) to Shoe 9463' - 10463' 1000 0.056 25% 313 55.78 78 13.95 0 0 391 69.73 318 15.3 ppg Class G 1.230Shoe Track 10383' - 10463' 80 0.076 0% 34 6.07 0 0.00 0 0 34 6.07 28 15.3 ppg Class G 1.230347 61.85 78 13.95 0 0426 75.79 346 15.3 ppg Class G 1.23Total VolumeSurfaceIntermediateTailTotal Lead Volume = 14.52 + 353.41 bbls = 367.93 bbls => 1,082 sx of 11.0 ppg LiteCRETE @ 1.91 ft³/skFootageFootageLeadPlacementTotal Tail Volume = 56.18 + 11.98 bbls = 68.16 bbls => 328 sx of 15.8 ppg Class G @ 1.165 ft³/skSacks BlendPlacement bbl/ft% ExcessVolumeXS VolumeAdditional bblsTotal VolumeSacks Blendbbl/ft% ExcessVolumeXS VolumeAdditional bblsTotal Lead Volume = 403.37 bbls => 1,466 sx of 14.0 ppg Ext. Class G @ 1.545 ft³/skPlacement Footage bbl/ft% ExcessVolumeXS VolumeAdditional bblsTotal VolumeSacks BlendPlacement Footage bbl/ft% ExcessVolumeTailTotal Tail Volume = 69.73 + 6.07 bbls = 75.79 bbls => 346 sx of 15.3 ppg Class G @ 1.23 ft³/skXS VolumeAdditional bblsTotal VolumeSacks Blend 1H-106 AOGCC 10-401 APD 8/20/2024 1H-107 10-401 APD 11 | 14 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in 16" 12-1/4'' 6-3/4'' Casing Size in 13-3/8'' 9-5/8'' 4-1/2'' Mud System Spud Mud FWP FloPro NT Base Fluid WBM WBM WBM Density ppg 8.8 - 9.5 ppg 9.2 ppg 9.2 ppg PV cP ALAP ALAP ALAP YP lb./100 ft2 30 - 80 20 - 30 15 - 30 Funnel Viscosity s/qt 100 - 300 N/A N/A Initial Gels lb./100 ft2 30 - 50 8 - 15 10 10 Minute Gels lb./100 ft2 30 - 50 < 30 15 API Fluid Loss cc/30 min N.C. < 10 4 HPHT Fluid Loss cc/30 min N/A N/A 10 pH 9.0 - 10.0 9.0 - 10.0 9.0 – 9.5 Surface Hole: A freshwater Spud Mud will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 8.8 - 9.5 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.2 ppg and be prepared to add loss circulation materials as needed if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as needed) will all be important in maintaining wellbore stability. Production Hole: The horizontal production interval will be drilled with water-based mud drill-in fluid weighted to 9.2 ppg. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations. 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. 1H-106 AOGCC 10-401 APD 8/20/2024 1H-107 10-401 APD 12 | 14 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 Requirements of 20 AAC 25.005 (c)(14) Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14. Drilling Hazards Summary 16" Hole | 13-3/8'' Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Reduced pump rates, Reduced drilling fluid temperatures, Additions of ScreenKleen Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti-Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accuracy. 12-1/4'' Hole | 9-5/8'' Casing Interval Event Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 1H-106 AOGCC 10-401 APD 8/20/2024 1H-107 10-401 APD 13 | 14 6-3/4'' Hole | 4-1/2'' Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreaming. Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti-Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. Utilize periscope to maintain geological certainty to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Consider logging casing thickness to calibrate casing wear model. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and drag. Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. To be posted in Rig Floor Doghouse Prior to Spud Well Proximity Risks: 1H is a multi-well pad, containing an original plan of 38 wells. The 1H NEWS Phase 2 program will consist of 4 dual lateral wells targeting West Sak B & D sands. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Fault Crossings – Lost circulation: Standard LCM material and potentially wellbore strengthening pills are expected to be effective in dealing with lost circulation if required. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 1H-106 AOGCC 10-401 APD 8/20/2024 1H-107 10-401 APD 14 | 14 15. Proposed Completion Schematic 40 500 500 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 8000 8000 9000 9000 10000 10000 11000 11000 12000 12000 15000 15000 20000 20000 22000 1H-106 wp17 Plan Summary 1H-106 wp17 1H-118 1H-401 1H-117 1H-109 1H-112L1 1H-116 1H-108 1H-108B1H-108A 1H-113 1H-112 1H-112PH1 1H-105 1H-05 1H-502 wp07 1H-120L1 1H-120 1H-114 1H-101L4 1H-102L1 1H-102 1H-102L4 1H-102L3 1H-102L2 1H-107 (O31) wp16.1 1H-107L1 wp07 1H-101L1 1H-101L3 1H-101 1H-101L2 1H-103 1H-115 1H-104L1 1H-1041H-104L2 1H-104PB1 1H-111 1H-110 1H-103L3 1H-103L1 1H-103L4 1H-103L2 1H-112PH1 1H-106L1 wp05 0 Dogleg Severity 0 3500 7000 10500 14000 17500 21000 Measured Depth 13-3/8" Surface Casing 9-5/8" Intermediate Casing4-1/2" Production Casing 50 50 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usf 1H-401 1H-117 1H-109 1H-108 1H-108B 1H-108A 1H-114 1H-101L4 1H-102L1 1H-102 1H-102L4 1H-102L3 1H-102L2 1H-107 (O31) wp16.1 1H-107L1 wp07 1H-101L11H-101L31H-1011H-101L2 1H-103 1H-115 1H-104L1 1H-104 1H-104L2 1H-104PB1 1H-111 1H-103L3 1H-103L1 1H-103L4 1H-103L2 0 6000 True Vertical Depth 0 3000 6000 9000 12000 15000 18000 21000 Vertical Section at 36.16° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 4-1/2" Production Casing 0 48 Centre to Centre Separation 0 3000 6000 9000 12000 15000 18000 21000 Measured Depth Equivalent Magnetic Distance DDI 7.491 SURVEY PROGRAM Date: 2024-07-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.61 1927.87 1H-106 wp17 (Plan: 1H-106) r.5 SDI_URSA1 1927.87 10463.00 1H-106 wp17 (Plan: 1H-106) MWD+IFR2+SAG+MS 10463.00 21776.42 1H-106 wp17 (Plan: 1H-106)MWD+IFR2+SAG+MS Surface Location North / 5980384.67 East / 1689611.52 Ground / 54.00 CASING DETAILS TVD MD Name 1863.61 1927.88 13-3/8" Surface Casing 3922.00 10463.00 9-5/8" Intermediate Casing 4128.61 21776.41 4-1/2" Production Casing Mag Model & Date:BGGM202415-Sep-24 Magnetic North is 13.95° East of True North Mag Dip & Field Strength:80.63°57193.37nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 39.61 0.00 0.00 39.61 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 52.00 699.91 3.22 4.13 1.50 52.00 5.04 Start DLS 2.00 TFO 0.00 4 900.00 7.00 52.00 899.11 13.95 17.86 2.00 0.00 21.80 Start DLS 2.50 TFO 0.00 5 1565.82 23.65 52.00 1539.00 121.89 156.02 2.50 0.00 190.48 Start 109.16 hold at 1565.82 MD 6 1674.98 23.65 52.00 1639.00 148.85 190.52 0.00 0.00 232.60 Start DLS 3.00 TFO 0.00 7 1877.87 29.73 52.00 1820.19 204.93 262.30 3.00 0.00 320.22 Start 50.00 hold at 1877.87 MD 8 1927.87 29.73 52.00 1863.61 220.19 281.84 0.00 0.00 344.08 Start 50.00 hold at 1927.87 MD 9 1977.87 29.73 52.00 1907.03 235.46 301.38 0.00 0.00 367.94 Start DLS 3.00 TFO 1.87 10 3740.54 82.60 53.50 2854.04 1085.66 1429.62 3.00 1.87 1720.10 Start 5265.00 hold at 3740.54 MD 11 9005.54 82.60 53.50 3532.15 4191.32 5626.68 0.00 0.00 6704.08 Start DLS 3.00 TFO -148.94 12 9620.51 66.98 43.28 3693.38 4582.10 6069.65 3.00 -148.94 7280.97 Start 207.54 hold at 9620.51 MD 13 9828.05 66.98 43.28 3774.53 4721.16 6200.61 0.00 0.00 7470.51 Start DLS 3.00 TFO -0.83 14 10488.68 86.80 43.00 3923.61 5188.35 6638.34 3.00 -0.83 8106.00 Start 50.00 hold at 10488.68 MD 15 10538.68 86.80 43.00 3926.40 5224.87 6672.38 0.00 0.00 8155.56 Start DLS 3.00 TFO 4.97 16 10658.78 90.39 43.31 3929.35 5312.43 6754.49 3.00 4.97 8274.71 Start 696.93 hold at 10658.78 MD 17 11355.71 90.39 43.31 3924.61 5819.53 7232.55 0.00 0.00 8966.21 Start DLS 2.00 TFO 49.79 18 11395.91 90.91 43.93 3924.15 5848.63 7260.29 2.00 49.79 9006.07 Start 286.66 hold at 11395.91 MD 19 11682.57 90.91 43.93 3919.61 6055.07 7459.13 0.00 0.00 9290.07 Start DLS 2.00 TFO 179.17 20 11786.97 88.82 43.96 3919.86 6130.23 7531.57 2.00 179.17 9393.50 Start 522.47 hold at 11786.97 MD 21 12309.44 88.82 43.96 3930.61 6506.26 7894.14 0.00 0.00 9911.03 Start DLS 1.00 TFO -177.79 22 12476.59 87.15 43.89 3936.49 6626.58 8010.02 1.00 -177.79 10076.54 Start 529.03 hold at 12476.59 MD 23 13005.61 87.15 43.89 3962.78 7007.35 8376.34 0.00 0.00 10600.12 Start DLS 2.00 TFO -8.67 24 13023.29 87.50 43.84 3963.61 7020.08 8388.58 2.00 -8.67 10617.62 Start DLS 2.50 TFO 52.91 25 13139.97 89.26 46.17 3966.91 7102.53 8471.04 2.50 52.91 10732.85 Start 209.43 hold at 13139.97 MD 26 13349.40 89.26 46.17 3969.61 7247.57 8622.10 0.00 0.00 10939.08 Start DLS 2.00 TFO 131.53 27 13458.18 87.82 47.79 3972.38 7321.76 8701.59 2.00 131.53 11045.88 Start 1319.81 hold at 13458.18 MD 28 14777.99 87.82 47.79 4022.61 8207.75 9678.53 0.00 0.00 12337.66 Start DLS 2.00 TFO 76.00 29 14923.92 88.53 50.63 4027.26 8303.02 9788.95 2.00 76.00 12479.73 Start 519.46 hold at 14923.92 MD 30 15443.38 88.53 50.63 4040.61 8632.44 10190.38 0.00 0.00 12982.57 Start DLS 3.50 TFO -102.19 31 15876.23 85.41 35.78 4063.61 8946.54 10485.48 3.50 -102.19 13410.28 Start DLS 3.50 TFO -74.40 32 16316.23 89.66 20.96 4082.61 9332.21 10693.63 3.50 -74.40 13844.49 Start DLS 3.50 TFO -45.80 33 16515.67 94.52 15.95 4075.32 9521.15 10756.69 3.50 -45.80 14034.23 Start DLS 3.50 TFO -139.35 34 16693.51 89.80 11.90 4068.61 9693.56 10799.42 3.50 -139.35 14198.64 Start DLS 3.25 TFO -109.92 35 17329.65 82.90 352.36 4109.46 10324.49 10823.29 3.25 -109.92 14722.09 Start DLS 3.50 TFO 32.13 36 17669.72 93.00 358.66 4121.61 10662.70 10796.78 3.50 32.13 14979.50 Start DLS 1.50 TFO 133.46 37 17850.51 91.13 0.63 4115.09 10843.34 10795.66 1.50 133.46 15124.68 Start 146.75 hold at 17850.51 MD 38 17997.26 91.13 0.63 4112.19 10990.05 10797.27 0.00 0.00 15244.07 Start DLS 2.00 TFO 178.44 39 18128.96 88.50 0.70 4112.61 11121.74 10798.80 2.00 178.44 15351.28 Start DLS 3.00 TFO -160.22 40 18313.61 83.29 358.81 4125.83 11305.83 10798.03 3.00 -160.22 15499.46 Start DLS 2.50 TFO 12.16 41 18625.23 90.90 0.45 4141.61 11616.81 10796.05 2.50 12.16 15749.35 Start DLS 2.00 TFO -29.06 42 18660.84 91.52 0.10 4140.86 11652.41 10796.22 2.00 -29.06 15778.19 Start 197.50 hold at 18660.84 MD 43 18858.33 91.52 0.10 4135.61 11849.84 10796.58 0.00 0.00 15937.79 Start DLS 2.00 TFO -12.49 44 18949.92 93.31 359.71 4131.75 11941.34 10796.43 2.00 -12.49 16011.57 Start 192.86 hold at 18949.92 MD 45 19142.79 93.31 359.71 4120.61 12133.88 10795.45 0.00 0.00 16166.44 Start DLS 2.00 TFO 172.98 46 19305.64 90.08 0.11 4115.80 12296.64 10795.18 2.00 172.98 16297.69 Start 132.72 hold at 19305.64 MD 47 19438.37 90.08 0.11 4115.61 12429.37 10795.42 0.00 0.00 16404.98 Start DLS 2.00 TFO -126.56 48 19444.92 90.00 0.00 4115.61 12435.91 10795.43 2.00 -126.56 16410.27 Start DLS 2.00 TFO -178.95 49 19527.12 88.36 359.97 4116.79 12518.10 10795.41 2.00 -178.95 16476.61 Start 405.86 hold at 19527.12 MD 50 19932.97 88.36 359.97 4128.43 12923.79 10795.19 0.00 0.00 16804.01 Start DLS 2.00 TFO 1.05 51 20015.17 90.00 0.00 4129.61 13005.98 10795.17 2.00 1.05 16870.35 Start DLS 2.00 TFO -13.29 52 20031.94 90.33 359.92 4129.56 13022.75 10795.16 2.00 -13.29 16883.88 Start 869.36 hold at 20031.94 MD 53 20901.30 90.33 359.92 4124.61 13892.10 10793.99 0.00 0.00 17585.04 Start DLS 2.00 TFO 174.13 54 20931.39 89.73 359.98 4124.60 13922.18 10793.97 2.00 174.13 17609.32 Start 845.03 hold at 20931.39 MD 55 21776.42 89.73 359.98 4128.61 14767.20 10793.74 0.00 0.00 18291.39 TD at 21776.42 FORMATION TOP DETAILS TVDPath Formation 1498.61 T-5 1638.61 Base Permafrost 1898.61 T-3 2112.61 K-15 3095.61 Ugnu C 3360.61 Ugnu B 3489.61 Ugnu A 3735.61 Nb 3861.61 WSAK D 3896.61 WSAK C 3917.61 WSAK B Plan: 54+39.61 @ 93.61usft (Doyon 25) Project: Kuparuk River Unit_1Site: Kuparuk 1H PadWell: Plan: 1H-106 (O33)Wellbore: Plan: 1H-106Design: 1H-106 wp17060001200018000South(-)/North(+) (3000 usft/in)0 6000 12000 18000 24000West(-)/East(+) (3000 usft/in)1H-106 T006 Rev041H-106 T002 Rev041H-106 T003 Rev041H-106 T010 Anchor Point Rev041H-106 T007 Rev041H-106 T008 Rev041H-106 Extra T001 Rev051H-106 T001 Rev041H-106 T011 Anchor Point Rev041H-106 T004 Rev041H-106 T015 Rev041H-106 Lateral TD 1320 ft1H-106 T014 Rev041H-106 T009 Rev041H-106 T005 Rev051H-106 T017 Rev041H-106 Landing Heel1H-106 T016 Rev041H-106 T013 Rev051H-106 Heel Target 1320ft1H-106 T012 Rev051H-1181H-4011H-1171H-1091 H -1 1 6 1H-1081H-108B1 H -1 0 8 A 1 H -11 3 1H-1051 H -0 51H-502wp071H-1141H-101L41H-102L11H-1021H-102L41H-102L31H-102L21H-107(O31)wp16.11H-107L1wp071H-101L11H-101L31H-1011H-101L21H-1031H-1151H-104L11H-1041H-104L21H-104PB11 H -1 1 1 1H-1101H-103L31H-103L11H-103L41H-103L21H-112PH11H-112L11H-1121H-120L11H-1201H-106L1 wp0513-3/8" Surface Casing9-5/8" Intermediate Casing4-1/2" Production Casing1H-106 T018 Rev04 500100015002000250030003500400041291H-106 wp17Plan View with offset wells Project: Kuparuk River Unit_1Site: Kuparuk 1H PadWell: Plan: 1H-106 (O33)Wellbore: Plan: 1H-106Design: 1H-106 wp17060001200018000South(-)/North(+) (3000 usft/in)0 6000 12000 18000 24000West(-)/East(+) (3000 usft/in)1H-106 T006 Rev041H-106 T002 Rev041H-106 T003 Rev041H-106 T010 Anchor Point Rev041H-106 T007 Rev041H-106 T008 Rev041H-106 Extra T001 Rev051H-106 T001 Rev041H-106 T011 Anchor Point Rev041H-106 T004 Rev041H-106 T015 Rev041H-106 Lateral TD 1320 ft1H-106 T014 Rev041H-106 T009 Rev041H-106 T005 Rev051H-106 T017 Rev041H-106 Landing Heel1H-106 T016 Rev041H-106 T013 Rev051H-106 Heel Target 1320ft1H-106 T012 Rev0513-3/8" Surface Casing9-5/8" Intermediate Casing4-1/2" Production Casing1H-106 T018 Rev04 500100015002000250030003500400041291H-106 wp17Plan View 030006000True Vertical Depth (1500 usft/in)0 4000 8000 12000 16000Vertical Section at 36.16° (2000 usft/in)13-3/8" Surface Casing9-5/8" Intermediate Casing4-1/2" Production Casing 100020003000400050006000700080009000100001100012000130001400015000160001700018000 1 9 0 0 020000210001H-106 wp17Start Build 1.50Start DLS 2.00 TFO 0.00Start DLS 2.50 TFO 0.00Start 109.16 hold at 1565.82 MDStart DLS 3.00 TFO 0.00Start 50.00 hold at 1877.87 MDStart 50.00 hold at 1927.87 MDStart DLS 3.00 TFO 1.87Start 5265.00 hold at 3740.54 MDStart DLS 3.00 TFO -148.94Start 207.54 hold at 9620.51 MDStart DLS 3.00 TFO -0.83Start DLS 3.00 TFO 4.97Start DLS 2.00 TFO 49.79Start DLS 2.00 TFO 179.17Start DLS 1.00 TFO -177.79Start DLS 2.00 TFO -8.67Start DLS 2.50 TFO 52.91Start DLS 2.00 TFO 131.53Start DLS 2.00 TFO 76.00Start DLS 3.50 TFO -102.19Start DLS 3.50 TFO -74.40Start DLS 3.50 TFO -45.80Start DLS 3.50 TFO -139.35Start DLS 3.25 TFO -109.92Start DLS 3.50 TFO 32.13Start DLS 1.50 TFO 133.46Start DLS 2.00 TFO 178.44Start DLS 3.00 TFO -160.22Start DLS 2.50 TFO 12.16Start DLS 2.00 TFO -29.06Start DLS 2.00 TFO -12.49Start DLS 2.00 TFO 172.98Start DLS 2.00 TFO -126.56Start DLS 2.00 TFO -178.95Start DLS 2.00 TFO 1.05Start DLS 2.00 TFO -13.29Start DLS 2.00 TFO 174.13TD at 21776.42Section View Project: Kuparuk River Unit_1Site: Kuparuk 1H PadWell: Plan: 1H-106 (O33)Wellbore: Plan: 1H-106Design: 1H-106 wp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ewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Wednesday, 25 September, 2024 11:16 To:Gorham, Brad Cc:Hobbs, Greg S; Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 1H-106 PTD (224-117): Questions Brad, The data presented on the oīset mudgas are not suĸcient to jus Ɵfy a diverter variance. If there are speciĮc HSE risks with the rig up operaƟon, that may be a topic to discuss with Victoria. Andy From: Gorham, Brad <Brad.Gorham@conocophillips.com> Sent: Monday, 23 September, 2024 15:27 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 1H-106 PTD (224-117): Questions Andy, The minimum distance to KRU/PBU is ~500 feet while the minimum distance to KRU/MPU is ~1,152 feet. Additionally, I have attached slides showing the mudgas data from the previous 1H wells that were drilled in 2017- 18. Although some of these other wells had higher shows of gas, none of these events ever resulted in an LEL alarm being triggered or any pit gain. The data shows that there is clearly a hydrate interval that is encountered and that the gas quickly dissipates after drilling through it. Lastly, I would like to reiterate that the primary driver in requesting the diverter variance is to eliminate the HSE risk associated with the diverter rig up operation. Let me know if you have any questions or concerns or would like any additional information. Thanks, Brad From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, September 16, 2024 5:16 PM To: Gorham, Brad <Brad.Gorham@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 1H-106 PTD (224-117): 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. 2 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. Brad, I’m reviewing the KRU 1H-106 PTD applicaƟon and have two quesƟons: x What is the minimum distance this well gets to both the KRU/PBU and KRU/MPU unit boundaries? x To help evaluate the diverter variance request, would you please provide a list of other 1H or near-oīset wells with mudlogs across the surface secƟon? Andy PS: Thank you for the clear wellbore schemaƟc and the way that you organized the drilling program across the two related 106/106L1 permits. Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 ConocoPhillips 1 ConocoPhillips 2 Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in 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. WEST SAK OIL 224-117 KUPARUK RIVER KRU 1H-106 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV U WSAK 1H-106Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241170KUPARUK RIVER, WEST SAK OIL - 490150NA1Permit fee attachedYesADL025637, ADL025638 , and ADL0256392Lease number appropriateYes3Unique well name and numberYesKUPARUK RIVER, WEST SAK OIL - 490150 - governed by CO 406C4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor18Conductor string providedYesSC set at 1928' MD19Surface casing protects all known USDWsYes202% excess planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoopen hole standalone screens; no cement22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYes27If diverter required, does it meet regulationsYesMax reservoir pressure is 1975 psig(9.2 ppg EMW); will drill w/ 8.8-9.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1562 psig; will test BOPE to 5000 initially & 3500 subsequently; 21 day BOPE testing frequency30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoWell 1H-104 measured 160 ppm H2S in July of 2023. H2S measures required.35Permit can be issued w/o hydrogen sulfide measuresYesTarget reservoir anticipated to be at 9.2 ppg EMW.36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate9/25/2024ApprVTLDate10/28/2024ApprADDDate9/16/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/29/2024
