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224-101
T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Nov 11, 2024 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-83 / MT7-83PH1 Greater Mooses Tooth API #: 50-103-20891-01/50-103-20891-00 Permit No: 224-101/ 224-102 Rig: Doyon 26 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-83/ MT7-83PH1 are located in a federal oil and gas unit. Only with respect to the MT7-83/ MT7-83PH1 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: Please return transmittal letter to: Benjamin Jacobi Benjamin.M.Jacobi@conocophillips.com Luis Arismendi Luis.arismendi@bakerhughes.com MT7-83 (PTD# 224-102): T39771 MT7-83PH1(PTD# 224-101):T39772 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.14 08:13:01 -09'00' MT7 83 (PTD# 224 102): T39771 MT7-83PH1(PTD# 224-101):T39772 g Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.14 Da MT7-83PH1 /50-103-20891-00 224-101 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 32 Township: 10N Range: 2E Meridian: Umiat Drilling Rig: Doyon 26 Rig Elevation: 54.4 ft Total Depth: 12328 ft MD Lease No.: AA098885 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 13-5/8, 13-3/8" O.D. Shoe@ 3805 Feet Csg Cut@ Feet Intermediate: 9-5/8, 9-7/8" O.D. Shoe@ 10855 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole Other 11450 ft 10443 ft Drillpipe tag Initial 15 min 30 min 45 min Result Tubing IA 1993 1914 1909 OA 38 39 39 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): The cement plug was founded on the previous cement plug. They tagged twice. The first tag was at 10442 ft MD with 10,000 pounds down on the plug. The second tag was at 10443 ft MD with 12,000 pounds down on the plug with no movement. MIT - BBLs in 5.1 and BBLs out 5 BBLs. October 3, 2024 Guy Cook Well Bore Plug & Abandonment GMTU MT7-83PH1 ConocoPhillips Alaska Inc. PTD 2241010; Sundry 324-532 None Test Data: P Casing Removal: rev. 3-24-2022 2024-1003_Plug_Verification_GMTU_MT7-83PH1_gc 9 9 9 9 9 9 999 9 9 9 9 9 9 9 999 9 9 9 The cement plug was founded on the previous cement plug tagged twice James B. Regg Digitally signed by James B. Regg Date: 2024.11.15 15:06:53 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?NA Yes No 9. Property Designation (Lease Number): 10. Field: Greater Mooses Tooth Rendezvous 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12328 8349 12328 8349 Casing Collapse Structural Conductor Surface 5380 Intermediate 8260 Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Matt Nagel Contact Email:matt.b.nagel@conocophillips.com Contact Phone: 907-263-4747 Authorized Title: Drilling Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9/23/2024 Perforation Depth MD (ft): 10855 20 13.375 / 13.625 80 9.625 / 9.87510815 3765 MD 8860 6420 120 3079 7512 120 3805 Length Size Proposed Pools: TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA098885, AA081800 224-101 P.O. Box 100360 Anchorage, Alaska 99510-0360 50-103-20891-00-00 ConocoPhillips Alaska, Inc GMTU MT7-83PH1 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-532 By Grace Christianson at 10:21 am, Sep 17, 2024 X X X NO Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig Annular preventer test to 2500 psig BOPE testing on a 21-day interval is approved with the attached conditions Surface casing LOT and annular LOT to the AOGCC as soon as available Diverter waiver approved per 20 AAC 25.035(h) Abandon file w/ PTD 10-407 X X NO SFD 9/18/2024VTL 9/26/2024 DSR-9/26/25*&: X x 10-407 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.26 16:02:44 -08'00'09/26/24 RBDMS JSB 100124 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 16th, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry for MT7-83PH1 Plug and Abandon Dear Sir or Madam: ConocoPhillips Alaska, Inc hereby applies for Application for Sundry Approval to Plug and Abandon MT7-83PH1 (PTD #: 224-101) an onshore Alpine C-Sand injector. The 16” surface hole was TD’d above the K3 sand and then 13-3/8” x 13-5/8” casing was be set and cemented to surface. The 12-1/4” intermiedate 1 section was drilled to to top of the HRZ formation. A 9-5/8” x 9-7/8” casing string will be run and cemented in place with 500’ or 250’ TVD aobve the highest hydrocarbon bearing zone. An 8-1/2” pilot hole will be drilled with TD in the Kingak formation. The interval will then be plugged back to the intermeidate 1 casing shoe and the hole section will be abandoned. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. A proposed drilling program 3. Current Wellbore Schematic 4. Proposed Abandonment Wellbore Schematic Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact: Matt Nagel, (907) 263-4747 & Matt.B.Nagel@conocophillips.com, Sincerely, cc: MT7-83 Well File / Jenna Taylor ATO 1560 David Lee ATO 1726 Chris Brillon ATO 1548 Matt Nagel Andy Mack Kuukpik Drilling Engineer MT7-83PH1 AOGCC Application for Sundry Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ...................................................... 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) .................................... 2 Requirements of 20 AAC 25.050(b) ........................................................................................................ 2 3. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) ................. 3 4. Attachments ............................................................................................................. 3 Attachment 1 Curent Wellbore Schematic .............................................................................................. 3 Attachment 2 Proposed Abandonment Wellbore Schematic .................................................................. 3 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as GMTU MT7-83PH1 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1178' FSL, 2246' FWL, S32 T10N R2E, UM NAD27 Northings: 5915990 Eastings: 290329 RKB Elevation 54.6’ AMSL Pad Elevation 100.7’ AMSL Top of Productive Horizon (Heel) 1392' FNL, 687' FEL, S33 T10N R2E, UM NAD27 Northings:5918492 Eastings: 298019 Measured Depth, RKB:11,991’ Total Vertical Depth, RKB:8,161’ Total Vertical Depth, SS:8,005’ Total Depth (Toe) 1149' FSL, 548' FEL, S33 T10N R2E, UM NAD27 Northings: 5918731 Eastings: 298164 Measured Depth, RKB:12,328’ Total Vertical Depth, RKB:8,349’ Total Vertical Depth, SS:8,193’ Requirements of 20 AAC 25.050(b) The Applicant is the only affected owner. 3. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Completion Schematic. 1. PU 3-1/2” cement string and XO to 5-7/8” DP and TIH to pilot hole TD. 2. Pump first 800’ balanced cement plug and POOH above plug. 3. Pump second 850’ balanced plug placing cement inside 9-7/8” casing. 4. TOOH and lay down 3-1/2” tubing string. 5. Pick up and run in hole with 8-1/2” x 9-7/8” drilling BHA to drill intermediate 2. (LWD Program: GR/RES) 6. Tag cement plug. 7. Cleanout cement to sidetrack depth. 8. Begin sidetrack operations. 4. Attachments Attachment 1 Curent Wellbore Schematic Attachment 2 Proposed Abandonment Wellbore Schematic PT and tag must be State Witnessed. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-83PH1 JBR 11/25/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Slow getting started dealing with many leaks after moving over to a new well. No issues during testing. We tested with a 5 7/8 " TJ. 5 min low and 10 min high for BLM. All H2s and LEL were calibrated this morning. Test Results TEST DATA Rig Rep:Newman/VanderpoolOperator:ConocoPhillips Alaska, Inc.Operator Rep:Rick Bjorhus Rig Owner/Rig No.:Doyon 26 PTD#:2241010 DATE:9/14/2024 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopSTS241004083241 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.0 MASP: 2917 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 18 3/4 "P #1 Rams 1 3 1/2" x 6 5/8 P #2 Rams 1 Blind/Shear P #3 Rams 1 3 1/2" x 6 5/8 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/16"& 3 1/P Kill Line Valves 2 3" & 3 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1700 200 PSI Attained P14 Full Pressure Attained P81 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P10@3650 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P14 #1 Rams P14 #2 Rams P15 #3 Rams P14 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9999 9 9 9 7HVW&KDUWVDWWDFKHG %23(7HVW'R\RQ *078073+ 37' $2*&&,QVS5SWERS676 %23(7HVW'R\RQ *078073+ 37' $2*&&,QVS5SWERS676 %23(7HVW'R\RQ *078073+ 37' $2*&&,QVS5SWERS676 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: Greater Mooses Tooth Field, Rendezvous Oil Pool, GMTU MT7-83PH1 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-101 Surface Location: 1178' FSL, 2246' FWL, S32 T10N R2E, UM Bottomhole Location: 1149' FSL, 548' FEL, S33 T10N R2E, 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 AOGCCreserves 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 AOGCCspecifically 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 AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie /Chmielowski Commissioner DATED this day of August 2024. 28 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.28 13:49:30 -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 and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 12,328 TVD: 8,349 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 8/22/2024 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2994' to AA081781 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 155.3 15. Distance to Nearest Well Open Surface: x- 290329 y- 5915990 Zone- 4 100.7 to Same Pool: 4240' to MT7-91 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 62 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42 20 94 H-40 Welded 80 40 40 120 120 16 13-3/8" / 13-5/8"68 / 88.2 L-80 Hyd563 3727 40 40 3767 3059 12-1/4"9-5/8" / 9- 7/8"47 / 62.8 L-80 Hyd563 10756 40 40 10796 7486 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Matt Nagel Chris Brillon Contact Email:matt.b.nagel@cop.com Wells Engineering Manager Contact Phone:907-263-4747 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng GMTU MT7-83PH1 Greater Mooses Tooth Rendezvous Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 Specifications 3745 Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 372sx 13 ppg & 524sx 15.8 ppg 2917 2640' FNL, 324' FEL, S33 T10N R2E, UM 1149' FSL, 548' FEL, S33 T10N R2E, UM 369446000, 932535000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips Alaska Inc. 1178' FSL, 2246' FWL, S32 T10N R2E, UM AA098885, AA081800 1262,68, 2515 18. Casing Program: Top - Setting Depth - Bottom 1131sx 11 ppg & 336sx 15.8 ppg Conductor/Structural LengthCasing Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Commission Use Only See cover letter for other requirements. 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): Effect. Depth MD (ft): Effect. Depth TVD (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 2:39 pm, Jul 23, 2024 224-101 SFD 8/12/2024 50-103-20891-00-00 VTL 8/27/2024 Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig Annular preventer test to 2500 psig BOPE testing on a 21-day interval is approved with the attached conditions Surface casing LOT and annular LOT to the AOGCC as soon as available Diverter waiver approved per 20 AAC 25.035(h) X DSR-7/29/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.28 13:49:42 -08'00'08/28/24 08/28/24 RBDMS JSB 082924 *07073+ 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 July 22, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-83PH1 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand injector well from the MT7 drilling pad. The intended spud date for this well is 8/22/2024. It is intended that Doyon 26 be used to drill the well. MT7-83PH1 will utilize a 16” surface hole and will TD above the K3 sand and then 13-3/8" casing will be set and cemented to surface. The 12-1/4" intermediate 1 section will be drilled to the top of HRZ formation. A 9-5/8" casing string will be run and cemented in place with a 500’ MD or 250’ TVD column of cement above the highest hydrocarbon bearing zone per AOGCC regulation. If an additional hydrocarbon zone is present, a 2nd stage cement job will be performed to cover 50’ TVD above and below the interval. A 8-1/2” pilot hole will be drilled and TD in the Kingak formation. The interval will then be abandoned and MT7-83 will sidetrack below the intermediate 1 shoe. It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Matt Nagel at 907-263-4747 (Matt.B.Nagel@conocophillips.com) or Greg Hobbs at 907-263-4794 (greg.s.hobbs@conocophillips.com). Sincerely, cc: MT7-83 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1552 Matt Nagel Chris Brillon ATO 1548 Drilling Engineer Andy Mack Kuukpik Corp Recommend approving requested variance from diverter waiver requirement. No evidence of shallow gas or hydrates in existing seismic or well data. SFD MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 1 of 12 Printed: 22-Jul-24 MT7-83PH1 Well Plan Application for Permit to Drill Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................ 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ..................................................................... 2 3. Proposed Drilling Program .................................................................................................................. 5 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) ............................................. 6 5. MASP Calculations ............................................................................................................................... 6 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ....... 7 7. Casing and Cementing Program ......................................................................................................... 7 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) ................................................................ 8 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ....................... 9 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ...................................................................... 9 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ..................................................... 9 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................... 9 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ................................................... 9 (Requirements of 20 AAC 25.005 (c)(14)) ........................................................................................................... 9 14. Drilling Hazards Summary ................................................................................................................... 9 15. Proposed Completion Schematic ...................................................................................................... 12 MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 2 of 12 Printed: 22-Jul-24 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-83PH1 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1178' FSL, 2246' FWL, S32 T10N R2E, UM NAD27 Northings: 5915990 Eastings: 290329 RKB Elevation 54.6’ AMSL Pad Elevation 100.7’ AMSL Top of Productive Horizon (Heel) 1392' FNL, 687' FEL, S33 T10N R2E, UM NAD27 Northings:5918492 Eastings: 298019 Measured Depth, RKB:11,991’ Total Vertical Depth, RKB:8,161’ Total Vertical Depth, SS:8,005’ Total Depth (Toe) 1149' FSL, 548' FEL, S33 T10N R2E, UM NAD27 Northings: 5918731 Eastings: 298164 Measured Depth, RKB:12,328’ Total Vertical Depth, RKB:8,349’ Total Vertical Depth, SS:8,193’ Please see attached well stick diagram for the current planned development of the pad. MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 3 of 12 Printed: 22-Jul-24 Pad Layout Well Stick Diagram MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 4 of 12 Printed: 22-Jul-24 MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 5 of 12 Printed: 22-Jul-24 3. Proposed Drilling Program 1. MIRU rig Doyon 26 onto well over pre-installed 20” insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan. (LWD Program: GR/RES). 4. Run and cement new 13-3/8” / 13-5/8” 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, 3-1/2” x 6-5/8’ VBR and 3-1/2” x 6-5/8” VBR. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4” drilling BHA to drill intermediate #1. (LWD Program: GR/RES). 8. Chart casing pressure test to 3,500 psi for 30 minutes. 9. Drill out shoe track and 20’ of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. 1. Send results to AOGCC as soon as available. 11. Displace well to 11.0 ppg Fresh water polymer WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and trip out of hole. 14. Change upper 3-1/2” x 6-5/8” VBR’s to 9-7/8” fixed casing rams and test same to 250/3,500 psi (24-48 hr regulatory notice) 15. Run 9-5/8” x 9-7/8” intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe or 500’ MD above uppermost hydro-carbon bearing zone. A 2nd stage cement job will be performed to isolate reservoir quality sand if exists at shallower depth. Submit results of the cement operation to AOGCC as soon as possible. 1. There is potential for the presence of the Tusk sand, which may be hydrocarbon bearing and require a second stage cement job to place cement 50’ TVD above and below the interval. The required equipment and cement plans are prepared if this becomes necessary. 17. Change upper 9-7/8” fixed casing ram to 3-1/2” x 6-5/8” VBRs. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 18. Pick up and run in hole with 8-1/2” drilling BHA to drill pilot hole. (LWD Program: GR/RES/DEN/NEU). Simops – perform annulus freeze protect. 19. Chart casing pressure test to 3,500 psi for 30 minutes. 20. Drill out shoe track and 20’ of new hole. 21. Perform FIT to max 14.0 ppg EMW. 22. Drill 8-1/2" pilot hole to section TD with OBM. 23. Circulate wellbore clean and trip OOH. 24. Prepare for P&A operations – separate sundry will be submitted. Transfer to MT7-83 PTD MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 6 of 12 Printed: 22-Jul-24 4.Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP and diverter schematics on file for Doyon 26. 5.MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD (ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 / 13.625 3,797 / 3,059 14.5 1381 2001 9.625 / 9.875 10,796 / 7,486 16.5 3387 2917 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1.Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 115 = 54 psi OR ASP = FPP – (0.1 x D) = 1381 – (0.1 x 3051) = 1076 psi Drilling below 13.375” / 13.625” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3059’ = 2001 psi OR ASP = FPP – (0.1 x D) = 3387 – (0.1 x 7486) = 2638 psi 2.Drilling below first 9.625” / 9.875” intermediate casing MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 7 of 12 Printed: 22-Jul-24 ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 7486 = 5674 psi OR ASP = FPP – (0.1 x D) = 3745– (0.1 x 8276’) = 2917 psi (B) data on potential gas zones; The well bore is not expected to penetrate any 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 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) Drill out casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 / 13.625 16 68 L-80 Hyd563 Cement to Surface 9.625 / 9.875 12.25 47 L-80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 13.375” x 13.625” Surface Casing run to 3,767’ MD /3,059’ TVD Cement Plan: Cement from 3,767’ MD to 3,267' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,267' to surface with 11.0 ppg DeepCrete. Assume 120% excess annular volume in permafrost and 50% excess below the permafrost (1001’ MD), zero excess in 20” conductor. Lead slurry from 3,134’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 2,172 ft3 => 1,131 sx of 11.0 ppg Deepcrete + Add's @ 1.92 ft3 /sk Tail slurry from 3,767’ MD to 3,267’ MD with 15.8 ppg Deepcrete + Add's Total Volume = 355 ft3 => 306 sx of 15.8 ppg Class G + Adds @ 1.16 ft3/sk MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 8 of 12 Printed: 22-Jul-24 9.625” x 9.875” Intermediate Casing run to 10,796’ MD / 7,486’ TVD Cement Plan: Primary cement job consists of 1500 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 7,400’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Albian Sub 93. If a shallower hydrocarbon zone of producible volumes is encountered while drilling, a 2nd stage cement job will be performed to isolate this zone. Assume 30% excess annular volume. Lead slurry from 9,296’ MD to 7,400’ MD with 13.0 ppg Class G + Add’s Total Volume = 706 ft3 => 372 sx of 13.0 ppg Class G + Add's @ 1.9 ft3 /sk Tail slurry from 10,796’ MD to 9,296’ MD with 15.8 ppg Class G + Add's Total Volume = 608 ft3 => 524 sx of 15.8 ppg Class G + Adds @ 1.16 ft3/sk 8.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Pilot Hole Hole Size in. 16 12.25 8.5 Casing Size in. 13.375 x 13.625 9.625 x 9.875 NA Density PPG 9.0 – 10.0 10.5 – 12.0 10.0 – 13.0 PV cP 13 10 40 YP lb./1 00 ft2 35-50 20 - 28 20 - 35 Funnel Viscosity s/qt. 200 40 - 50 70 - 90 Initial Gels lb./1 00 ft2 50 10 14 10 Minute Gels lb./1 00 ft2 60 15 42 API Fluid Loss cc/30 min. N.C. – 15.0 10 N/A HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 5.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 Surface Hole: A fresh water drilling fluid (KSI) 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 O10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 9 of 12 Printed: 22-Jul-24 Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-12.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Pilot Hole: The pilot hole section will be drilled with OBM weighted to 11.5 ppg. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight will be 11.5 targeting 13.0 EMW using MPD. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. 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 form the well will be disposed of by hauling to Alpine injection facility where they will be disposed by injecting to approved Class I or Class II Disposal wells. 14.Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375 x 13.625” 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, MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 10 of 12 Printed: 22-Jul-24 reduce fluid viscosity, control ROP Abnormal Pressure in Surface Formations 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 12.25” Hole / 9.625 x 9.875” Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8.5” Hole 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 MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 11 of 12 Printed: 22-Jul-24 Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT7-83PH1 Saved: 22-Jul-24 MT7-83PH1 Page 12 of 12 Printed: 22-Jul-24 15. Proposed Completion Schematic 54 500 500 800 800 1000 1000 1500 1500 2000 2000 2500 2500 3500 3500 5000 5000 10000 10000 11000 11000 12000 12000 12328 MT7-83PH1 wp03 Plan Summary MT7-83PH1 MT7-01 MT7-01PB1 MT7-03 MT7-03A RWO Redrill MT7-14MT7-14A MT7-15 MT7-91 MT7-92MT7-93 MT7-95 MT7-96 MT7-97 MT7-98 MT7-84 MT7-88 SouthMT7-89 South 0 4 Dogleg Severity0 2000 4000 6000 8000 10000 12000 Measured Depth 13-3/8" Surface Casing 9-5/8" INT1 Casing 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] MT7-84_E04_WP02_EXT MT7-88 wp01 South 0 5000 True Vertical Depth0 15003000450060007500 Vertical Section at 69.13° 13-3/8" Surface Casing 9-5/8" INT1 Casing 0 50 100 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured Depth Equivalent Magnetic Distance DDI 6.371 SURVEY PROGRAM Date: 2024-03-14T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.11 1000.00 MT7-83PH1 wp03 (MT7-83PH1)r.5 SDI_URSA1 1000.00 3767.00 MT7-83PH1 wp03 (MT7-83PH1) MWD+IFR2+SAG+MS 3767.00 10796.05 MT7-83PH1 wp03 (MT7-83PH1) MWD+IFR2+SAG+MS 10769.05 12327.97 MT7-83PH1 wp03 (MT7-83PH1) MWD+IFR2+SAG+MS Surface Location North / 5915734.35 East / 1430365.00Ground / 100.80 CASING DETAILS TVD MD Name 3058.94 3767.00 13-3/8" Surface Casing 7485.91 10796.05 9-5/8" INT1 Casing Mag Model & Date: BGGM2024 01-Sep-24 Magnetic North is 13.44° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.32° 57055.58nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 54.11 0.00 0.00 54.11 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 1.50 3 500.00 3.00 67.00 499.91 2.05 4.82 1.50 67.00 5.23 Start Build 2.00 4 800.00 9.00 67.00 798.13 14.29 33.67 2.00 0.00 36.55 Start DLS 2.50 TFO -1.17 5 2416.06 49.40 66.00 2179.79 326.26 740.01 2.50 -1.17 807.69 Start 6925.00 hold at 2416.06 MD 6 9341.06 49.40 66.00 6686.40 2464.86 5543.39 0.00 0.00 6057.80 Start DLS 3.00 TFO 79.09 7 10431.00 61.96 102.94 7314.33 2527.15 6413.96 3.00 79.09 6893.44 Start 365.05 hold at 10431.00 MD 8 10796.05 61.96 102.94 7485.91 2455.00 6728.00 0.00 0.00 7161.17 Start 50.00 hold at 10796.05 MD 9 10846.05 61.96 102.94 7509.41 2445.12 6771.01 0.00 0.00 7197.84 Start DLS 4.72 TFO -115.52 10 12279.48 57.98 22.98 8323.20 2919.41 7740.23 4.72 -115.52 8272.44 Start 48.49 hold at 12279.48 MD 11 12327.97 57.98 22.98 8348.91 2957.26 7756.28 0.00 0.00 8300.92 TD at 12327.97 FORMATION TOP DETAILS TVDPath Formation 994.91 Permafrost 1102.91 C40 1441.91 C30 1679.91 C20 2028.91 C10 3034.91 K3 3658.91 Albian_97 3889.91 Albian_96 4092.91 Albian_95 4997.91 Albian_94 5527.91 Albian_93 5747.91 Top_Stareater 6356.91 Albian_92 6362.91 Albian_91 7455.91 HRZ 7549.94 LCU 8161.77 Top Alpine D 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 KB (100.8 PL+54.11 DF) @ 154.91usft 0300060009000True Vertical Depth (1500 usft/in)-3000 0 3000 6000 9000Vertical Section at 69.13° (1500 usft/in)13-3/8" Surface Casing9-5/8" INT1 Casing100020003000400050006000700080009000100001100012000MT7-83/MT7-83PH1 wp03Start Build 1.50Start Build 2.00Start DLS 2.50 TFO -1.17Start 6925.00 hold at 2416.06 MDStart DLS 3.00 TFO 79.09Start 365.05 hold at 10431.00 MDStart 50.00 hold at 10796.05 MDStart DLS 4.72 TFO -115.52Start 48.49 hold at 12279.48 MDTD at 12327.97Section View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-83Wellbore: MT7-83PH1Design: MT7-83PH1 wp03 Plan View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-83Wellbore: MT7-83PH1Design: MT7-83PH1 wp03-700007000South(-)/North(+) (3500 usft/in)-14000 -7000 0 7000 14000West(-)/East(+) (3500 usft/in)MT7-83PH1 TDMT7-01MT7-01PB1MT7-02MT7-03MT7-03A RWO RedrillMT7-04MT7-05MT7-06MT7-06AMT7-06PB1MT7-07MT7-08MT7-08PB1MT7-09MT7-11MT7-14MT7-14AMT7-15MT7-91MT7-92MT7-93MT7-94MT7-95MT7-96MT7-97MT7-98MT7-99MT7-10_wp04MT7-12_wp02_EXT_PetrelMT7-84_E04_WP02_EXTMT7-88 wp01 SouthMT7-89 wp05 South13-3/8" Surface Casing9-5/8" INT1 Casing5 0 0100 0150020002500300035004000450050005500600065007000750080008349MT7-83PH1 wp03 !" 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evised 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. 224-101 GREATER MOOSES TOOTH GMTU MT7-83PH1 RENDEZVOUS OIL CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Dupont, Hilda To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC); Nagel, Matt B Subject:RE: [EXTERNAL]RE: GMTU- MT7-83PH1 (PTD 224-101) - Request and Questions Date:Monday, August 12, 2024 11:13:03 AM Good morning Steve, Our geologist confirms that we haven't observed any evidence of shallow gas or gas hydrates in the surface section with either the seismic or development data or while drilling any of the MT7 wells. Thank you, Hilda Dupont | Drilling Engineer | ConocoPhillips O: 907.265.6675 | C: 661.577.7338 | 700 G Street, ATO-1554, Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, August 9, 2024 12:44 PM To: Dupont, Hilda <Hilda.Dupont@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Nagel, Matt B <Matt.B.Nagel@conocophillips.com> Subject: [EXTERNAL]RE: GMTU- MT7-83PH1 (PTD 224-101) - Request and Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hilda, Per Matt Nagel’s out-of-office reply, I’m forwarding my request and questions to you. Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov From: Davies, Stephen F (OGC) Sent: Friday, August 9, 2024 12:41 PM To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: GMTU- MT7-83PH1 (PTD 224-101) - Request and Questions Matt, I’m reviewing CPAI’s Permit to Drill application for the MT7-83 pilot hole. I’ve reviewed the Operations Summaries for MT7-92, MT7-93, MT7-96, and MT7-98 wells along with the mud log from MT7-04, and I see no reports of shallow gas or gas hydrates down to surface casing point while drilling with approximately the same ECDs as that proposed for MT7-83. However, my concern with CPAI’s requested variance from the diverter requirement is that the planned surface casing point (to the northeast of the MT7 Drill Site) is about 2700’ away from the surface casing point in the nearest drilled well (MT7-92, PTD 223-114). Please confirm that CPAI has not observed any signs of significant shallow gas or gas hydrates while drilling to surface casing point in any of the wells from MT7. Has CPAI’s project geologist/geophysicist seen any indications of shallow gas or gas hydrates on the seismic data within this area? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-83PH1Initial Class/TypeDEV / PENDGeoArea890Unit10750On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241010GRTR MOOSES TOOTH, RENDEZV OIL - 2822NA1Permit fee attachedYesSurface Location lies within AA0098885; Top Prod Int & TD lie within AA0081800.2Lease number appropriateYes3Unique well name and numberYesGRTR MOOSES TOOTH, RENDEZV OIL - 282200 - governed by CO 7934Well 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' conductor provided18Conductor string providedYesSC set at 3767' MD19Surface casing protects all known USDWsYes60% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNo22CMT 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 approvedYes26Adequate wellbore separation proposedYesDiverter waiver granted per 20 AAC 25.035(h)27If diverter required, does it meet regulationsYesMax reservoir pressure is 3745 psig(8.7 ppg EMW); will drill w/ 10-13 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2917 psig; will test BOPs to 5000 psig initially and 4000 psig subsequently30BOPE 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)YesH2S not expected; rig has sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure range is 0.433 to 0.452 psi/ft (8.3 to 8.7 ppg EMW). Operator's planned mud program36Data presented on potential overpressure zonesNAappears sufficient to control anticipated pressures and maintain wellbore stability.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate8/9/2024ApprVTLDate8/27/2024ApprSFDDate8/12/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateRecommend approving requested variance from diverter waiver requirement: Operator reports "Our geologist confirms that we haven't observed any evidence of shallow gas or gas hydrates in the surface section with either the seismic or development data or while drilling any of the MT7 wells." (See attached email dated 8/12/2024.) Corroborated by examining records from nearby wells MT7-96, MT7-98, MT7-93, MT7-92, and MT7-04. SFD*&:JLC 8/28/2024
