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222-056
DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-21016-01-00Well Name/No.KUPARUK RIV UNIT 1G-13A Completion Status 1-OILCompletion Date 6/30/2022 Permit to Drill 2220560 Operator ConocoPhillips Alaska, Inc. MD 10307 TVD 6312 Current Status 1-OIL 7/19/2023 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:GR/Res NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 7/22/2022-10 7635 Electronic Data Set, Filename: 1G-13A_10-Jul- 22_3.5inTubing_Surface- 7621.7_CenteredData.las 36820ED Digital Data DF 7/22/2022 Electronic File: 1G-13A 2022-07-10 READ.pdf36820EDDigital Data DF 7/22/2022 Electronic File: 2022-07-10_22037_KRU_1G- 13A_CaliperSurvey_LogData_Transmittal.docx 36820ED Digital Data DF 7/22/2022 Electronic File: 630B0940.jpg36820EDDigital Data DF 7/22/2022 Electronic File: KRU_1G-13A_10-Jul- 22_CaliperSurveyLog.pdf 36820ED Digital Data DF 7/22/2022 Electronic File: KRU_1G-13A_10-Jul- 22_CaliperSurveyLog.tif 36820ED Digital Data DF 7/22/2022 Electronic File: 1G-13A 2022-10-07 3.5'' Tubing ModalID.csv 36820ED Digital Data DF 7/22/2022 Electronic File: 1G-13A 2022-10-07 3.5'' Tubing.IDX 36820ED Digital Data DF 7/22/2022 Electronic File: 1G-13A 2022-10-07 3.5'' Tubing.RGB 36820ED Digital Data DF 7/22/2022 Electronic File: 1G-13A 2022-10-07 3.5'' Tubing.SRV 36820ED Digital Data DF 7/22/2022 Electronic File: 1G-13A 2022-10-07 3.5'' Tubing.UNW 36820ED Digital Data DF 7/22/2022 Electronic File: PDSViewer.ico36820EDDigital Data DF 7/22/2022 Electronic File: Sample Data.IDX36820EDDigital Data DF 7/22/2022 Electronic File: Sample Data.rgb36820EDDigital Data DF 7/22/2022 Electronic File: Sample Data.UNW36820EDDigital Data Wednesday, July 19, 2023AOGCC Page 1 of 6 DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-21016-01-00Well Name/No.KUPARUK RIV UNIT 1G-13A Completion Status 1-OILCompletion Date 6/30/2022 Permit to Drill 2220560 Operator ConocoPhillips Alaska, Inc. MD 10307 TVD 6312 Current Status 1-OIL 7/19/2023 UIC No DF 7/22/2022 Electronic File: PDS 3-D Caliper Data Viewer Help.doc 36820ED Digital Data DF 7/22/2022 Electronic File: PDS 3-D Caliper Data Viewer Help.pdf 36820ED Digital Data DF 8/4/20227234 10307 Electronic Data Set, Filename: 1G-13A GAMMA RES.las 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_222- 056_BKR_Distribution AOGCC.docx 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A 2MD Final Log.cgm36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A 5MD Final Log.cgm36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A 5TVDSS Final Log.cgm36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 09.cgm36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 10.cgm36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 11.cgm36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A GAMMA RES.ASC36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 01.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 02.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 03.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 04.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 05.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 06.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 07.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 08.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 09.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 10.ASC 36846ED Digital Data Wednesday, July 19, 2023AOGCC Page 2 of 6 1G-13A GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-21016-01-00Well Name/No.KUPARUK RIV UNIT 1G-13A Completion Status 1-OILCompletion Date 6/30/2022 Permit to Drill 2220560 Operator ConocoPhillips Alaska, Inc. MD 10307 TVD 6312 Current Status 1-OIL 7/19/2023 UIC No DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 11.ASC 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A 2MD Final.pdf36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A 5MD Final.PDF36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A 5TVDSS Final.PDF36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 09.PDF36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 10.PDF36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 11.PDF36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A NAD27 Definitive Surveys.pdf 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A NAD27 Definitive Surveys.txt 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A NAD83 Definitive Surveys.pdf 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A NAD83 Definitive Surveys.txt 36846ED Digital Data DF 8/4/2022 Electronic File: 1G-13A 2MD Final.tif36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A 5MD Final.tif36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A 5TVDSS Final.tif36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 09.tif36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 10.tif36846EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Log_Run 11.tif36846EDDigital Data DF 8/4/20227234 8172 Electronic Data Set, Filename: 1G-13APB1 GAMMA RES.las 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_222- 056_BKR_Distribution AOGCC.docx 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 2MD Final Log.cgm36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 5MD Final Log.cgm36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 5TVDSS Final Log.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 01.cgm 36847ED Digital Data Wednesday, July 19, 2023AOGCC Page 3 of 6 1G-13APB1 GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-21016-01-00Well Name/No.KUPARUK RIV UNIT 1G-13A Completion Status 1-OILCompletion Date 6/30/2022 Permit to Drill 2220560 Operator ConocoPhillips Alaska, Inc. MD 10307 TVD 6312 Current Status 1-OIL 7/19/2023 UIC No DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 02.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 03.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 04.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 05.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 06.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 07.cgm 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 GAMMA RES.ASC36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 01.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 02.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 03.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 04.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 05.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 06.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 07.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13A_PWD Digital Data_Run 08.ASC 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 2MD Final Log.PDF36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 5MD Final Log.PDF36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 5TVDSS Final Log.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 01.PDF 36847ED Digital Data Wednesday, July 19, 2023AOGCC Page 4 of 6 DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-21016-01-00Well Name/No.KUPARUK RIV UNIT 1G-13A Completion Status 1-OILCompletion Date 6/30/2022 Permit to Drill 2220560 Operator ConocoPhillips Alaska, Inc. MD 10307 TVD 6312 Current Status 1-OIL 7/19/2023 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 02.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 03.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 04.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 05.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 06.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 07.PDF 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 NAD27 Definitive Surveys.pdf 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 NAD27.txt36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 NAD83 Definitive Surveys.pdf 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 NAD83 Definitive Surveys.txt 36847ED Digital Data DF 8/4/2022 Electronic File: 1G-13APB1 2MD Final Log.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 5MD Final Log.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1 5TVDSS Final Log.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 01.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 02.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 03.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 04.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 05.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 06.tif36847EDDigital Data DF 8/4/2022 Electronic File: 1G-13APB1_PWD Log_Run 07.tif36847EDDigital Data Wednesday, July 19, 2023AOGCC Page 5 of 6 DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-21016-01-00Well Name/No.KUPARUK RIV UNIT 1G-13A Completion Status 1-OILCompletion Date 6/30/2022 Permit to Drill 2220560 Operator ConocoPhillips Alaska, Inc. MD 10307 TVD 6312 Current Status 1-OIL 7/19/2023 UIC No INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:6/30/2022 Release Date:6/8/2022 Wednesday, July 19, 2023AOGCC Page 6 of 6 M. Guhl 7/19/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1G-13A JBR 01/03/2023 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:2 3 1/2 & 5 1/2 test joints used. Tested annular with 3 1/2. HCR Choke was a FP, greased and retested (pass). HCR Kill was a FP changed out valve and retested (pass) stayed onsite to witness. Tested all bladder bottles (all pass) Test Results TEST DATA Rig Rep:Tony MoralesOperator:ConocoPhillips Alaska, Inc.Operator Rep:Mark Adams Rig Owner/Rig No.:Nabors 7ES PTD#:2220560 DATE:11/13/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSTS221114153703 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 11.5 MASP: 2994 Sundry No: 322-595 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 2 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 13 5/8 P #1 Rams 1 2 7/8 x 5 P #2 Rams 1 blinds P #3 Rams 1 3 1/2 x 5 1/2 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 1/8 FP Kill Line Valves 2 3 1/8 & 2 P Check Valve 0 NA BOP Misc 2 2 1/16 P System Pressure P3000 Pressure After Closure P1350 200 PSI Attained P20 Full Pressure Attained P111 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P29 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 FP 3 1/2 & 5 1/2 test joints used. Tested annular with 3 1/2. HCR Choke was a FP, greased and retested (pass). HCR Kill was a 3 1/2 & 5 1/2 test joints used. Tested annular with 3 1/2. HCR Choke was a FP, greased and retested (pass). HCR Kill was a FP changed out valve and retested (pass) stayed onsite to witness. Tested all bladder bottles (all pass) 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Set LT Packer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10307'feet None feet true vertical 6312' feet 7940', 7956'feet Effective Depth measured feet true vertical feet feet 8055' Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 7757' MD 6331' TVD Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL 47 B2 Packer Packer: Otis RRH Packer Packer: NS Liner Top Packer Packer: Otis WD Packer Packer: Swell Packer-PESI SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Intervention Engineer 7541-7596', 7626-7640' 6137-6187', 6215-6227' measuredPacker Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 412 Gas-Mcf MD 1383 Size 105' 413 1365238 0 1100 199 measured TVD 7" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-056-0 50-029-21016-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025640 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1G-13A Plugs Junk measured Length Tie-Back String Slotted Liner 7248' 2441' Casing 6396' 5898' 2-3/8" 8087' 7279' 10090' 6301' 2406' 105'Conductor Surface Production 16" 10-3/4" 68' 2444' 2197' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 7314', 7388', 7634', 7727', 7819' true vertical 5930', 5997', 6222', 6306', 6368' 5930' TVD 5997' TVD 6222' TVD 6306' TVD 6368' TVD N/A 7314' MD 7388' MD 7634' MD 7727' MD 7819' MD N/A feet10307' 6312' L-80/J-55 6331' TVD By Samantha Carlisle at 10:59 am, Jan 31, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2023.01.31 10:14:05-09'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 1/4/2023 REPAIR WELL RUN 2.77" GAUGE RING, BRUSH, MAG BAR, & 2.68" MAGNET DOWN TO NS LTP @ 7634' RKB (TOOLS RELATIVELY CLEAN); RAN 2.5" BAILER W/ 2.62" BOTTOM DOWN TO LTP @ 7634' (RECOVER THICK FLUID); PULLED 2.72" NS LTP @ 7634' RKB (MISSING ALL ELEMENTS & WIRE VISIBLE IN TOP OF PACKER). IN PROGRESS. 1/5/2023 REPAIR WELL MAKE SEVERAL RUNS W/ DUAL BRUSH ASSEMBLY W/ WIRE GRAB & RECOVER 2 MISSING ELEMENTS, 1' OF WIRE, AND 4.5" L x .58" THICK PIECE OF CEMENT (SEE ATTACHMENTS) MEASURED BHP (3517 psi) @ 7649' RKB & BRUSH n' FLUSH TBG ALONG WITH INSIDE OF LINER. SET 2.72" NS LTP 10' SPACER NO-GO STINGER & 1.78" RX PLUG (OAL 19.55' / SN: NSP21) @ 7633' RKB, MIT TBG 2500 PSI (PASS), PULLED 1.78" R PLUG @ 7651' RKB. JOB COMPLETE. 1G-13 Liner Top Packer Summary of Operations Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Fished Wire & Tools lost in hole & Replaced NS LTP 1G-13A 1/5/2023 zembaej General Notes: Last 3 entries Com Date Last Mod By 16" conductor, 10-3/4" SC, 7" old PC, 5-1/2" new PC tieback installed during 2022 RWO (XO to 3-1/2" tbg at 7101'), 3-1/2" tbg, 2-3/8" 2022 CTD slotted liner 11/20/2022 spilch Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 37.5 105.0 105.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 37.5 2,443.9 2,197.1 45.50 K-55 BTC PRODUCTION 7 6.28 31.8 8,087.1 6,395.9 26.00 J-55 BTC Tie-Back String 5 1/2 4.89 30.7 7,279.2 5,897.6 17.00 L-80 Hyd 513 Slotted Liner 2 3/8 1.99 7,649.1 10,090.0 6,300.9 4.60 L-80 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 29.2 Set Depth 7,118.0 Set Depth 5,752.4 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.00 Hanger 7.100 Tubing Hanger, Cameron C-bowl w/ 3.5 EUE 8rd Box x Box Camero n C-Bowl 2.950 528.7 528.7 0.80 Nipple - X 4.500 3.5" x 2.813" X-Nipple HES X Nipple 2.813 3,339.3 2,896.0 40.50 Mandrel GAS LIFT 4.710 GLM, 3.5" x 1", KBG-2-9, Vam top Box x Pin SLB KBG-2-9 2.818 6,655.5 5,354.3 33.29 Mandrel GAS LIFT 4.710 GLM, 3.5" x 1", KBG-2-9, Vam top Box x Pin SLB KBG-2-9 2.818 6,992.5 5,641.6 29.56 Mandrel GAS LIFT 4.710 GLM, 3.5" x 1", KBG-2-9, Vam top Box x Pin SLB KBG-2-9 2.818 7,049.8 5,691.7 28.16 Nipple - X 4.500 3.5" x 2.813" X-Nipple HES X Nipple 2.813 7,098.5 5,735.0 26.87 Locator 4.490 GBH-22 Locator Baker Baker GBH-2 Locator 2.980 7,099.8 5,736.1 26.84 Seal Assembly 3.980 Baker 80-40 Seal Assembly (4.57' From Fully Located) Baker 80-40 Seal Assembl y 3.000 Top (ftKB) 7,276.0 Set Depth 7,369.3 Set Depth 5,979.5 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,296.3 5,913.1 24.88 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,299.8 5,916.3 24.85 LOCATOR 4.500 BAKER LOCATOR SUB 2.997 7,300.5 5,916.9 24.85 PBR 5.875 BAKER 80-40 PBR **SHEARED** 2.997 7,313.5 5,928.7 24.72 PACKER 6.000 BAKER FHL 47 B2 PACKER 2.930 7,353.9 5,965.5 24.33 NIPPLE 4.375 OTIS NO GO X NIPPLE 2.810 7,355.3 5,966.7 24.31 OVERSHOT 5.750 OTIS SBR OVERSHOT w/ 2.813" X PROFILE 4.750 Top (ftKB) 7,362.0 Set Depth 7,757.2 Set Depth 6,330.8 String Ma 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,362.0 5,972.9 24.25 SBR 4.750 OTIS SBR SLICK STICK 2.992 7,388.2 5,996.8 23.99 PACKER 5.980 OTIS RRH PACKER , 60000# SHEAR 2.970 7,531.4 6,128.0 23.50 BLAST RINGS 3.500 2.992 7,562.2 6,156.3 23.62 BLAST RINGS 3.500 BLAST JOINTS w/ 1" CARBIDE RINGS 2.992 7,718.6 6,299.1 27.94 LOCATOR 4.000 OTIS ST SLOT LOCATOR 3.000 7,719.8 6,300.2 28.35 SEAL ASSY 4.500 OTIS SEAL ASSEMBLY 3.000 7,725.9 6,305.5 30.41 MULE SHOE 3.500 OTIS MULE SHOE GUIDE 2.992 7,726.8 6,306.3 30.71 PACKER 6.156 OTIS WD PACKER 4.000 7,730.4 6,309.4 31.93 MILL 3.500 MILL OUT EXTENSION 2.992 7,746.7 6,322.7 37.77 NIPPLE 4.750 CAMCO D NIPPLE NO GO 2.750 7,756.4 6,330.2 41.25 WLEG 4.570 OTIS WIRELINE RE-ENTRY GUIDE 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 31.3 31.3 0.00 EMERGENCY SLIPS 11" x 5.5" Emergency Slips. 11/18/2022 5.500 7,142.6 5,774.4 26.32 MANDREL - DMY MMG, 1.5", DMY, [***exception MANDREL in casing string ****] MMG DMY 11/18/2022 1.500 7,275.0 5,893.8 25.05 CUT CHEMICAL TUBING CUT AT 7275' RKB 10/22/2022 2.992 7,634.0 6,221.9 23.86 PACKER Northern Solutions Liner Top Packer, Spacer pipe, & Stinger w/ 1.78" RX Nipple (18.4' OAL) Northern Solutions Mono- Pack LTP NSP2 1 1/5/2023 1.781 7,705.0 6,286.8 24.01 WHIPSTOCK NS Monobore WS Northern Solutions Monobor e 6/23/2022 0.000 1G-13A, 1/30/2023 3:35:22 PM Vertical schematic (actual) Slotted Liner; 7,649.1-10,090.0 PRODUCTION; 31.8-8,087.1 FISH; 7,956.0 FISH; 7,940.0 RPERF; 7,800.0-7,846.0 APERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 PACKER; 7,313.5 Tie-Back String; 30.7-7,279.2 CUT; 7,275.0 MANDREL - DMY; 7,142.6 Nipple - X; 7,049.8 Mandrel GAS LIFT; 6,992.5 Mandrel GAS LIFT; 6,655.5 Mandrel GAS LIFT; 3,339.3 SURFACE; 37.5-2,443.9 Nipple - X; 528.7 CONDUCTOR; 37.5-105.0 EMERGENCY SLIPS; 31.2 Hanger; 29.2 KUP PROD KB-Grd (ft) 41.00 RR Date 10/11/198 3 Other Elev 1G-13A ... TD Act Btm (ftKB) 10,307.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292101601 Wellbore Status PROD Max Angle & MD Incl (°) 100.30 MD (ftKB) 9,850.46 WELLNAME WELLBORE1G-13 Annotation Last WO: End Date 11/20/2022 H2S (ppm) 165 Date 7/31/2015 Comment Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,339.3 2,896.0 40.50 1 GAS LIFT GLV BTM 1 1,369.0 11/22/2022 SLB KBG-2-9 0.125 6,655.5 5,354.3 33.29 2 GAS LIFT GLV BTM 1 1,345.0 11/22/2022 SLB KBG-2-9 0.125 6,992.5 5,641.6 29.56 3 GAS LIFT OV BTM 1 0.0 11/22/2022 SLB KBG-2-9 0.125 7,425.1 6,030.5 23.75 6 PROD OPEN OPEN 1 0.0 5/8/2022 3:30 0.000 7,493.3 6,093.1 23.40 7 PROD OPEN 1 0.0 10/15/2000 0.000 7,679.9 6,263.9 23.97 8 PROD DPHF CV Broke 1 0.0 10/15/2000 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,935.9 1,791.0 37.16 XO Threads 5.500 5.5" 15.5# L-80 Hyd 563 Box x 5.5" 17# L-80 Hyd 513 Pin 4.892 7,142.0 5,773.9 26.33 Mandrel GAS LIFT 5.870 SLB 3.5" x 1.5" MMG, SN# 23761- 07 SLB MMG 2.920 7,198.2 5,824.3 25.65 Packer 6.280 3.5" x 7" SLB BluePack Packer, SN# C21P-1909 SLB BluePack 2.894 7,251.1 5,872.1 25.23 Nipple - X 4.500 3..5 x 2.813" X nipple SN# 0004739293-6 HES X Nipple 2.813 7,272.3 5,891.4 25.07 Overshot 6.020 3.5" x 7" Poor Boy Overshot w/ 6.15' of swallow. (1.25'' from fully located) Baker Poorboy Overshot 3.590 7,820.0 6,368.1 65.56 Swell Packer 2.700 Swell Packer -PESI HLB 1.686 9,009.1 6,385.8 90.57 Deployment Sleeve 2.375 OH Permanent QCLL, L-80, NSAK 350-238 NS AK 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,541.0 7,596.0 6,136.8 6,187.2 C-4, C-3, 1G-13 12/1/1983 12.0 IPERF GO 5" TCP 7,626.0 7,640.0 6,214.6 6,227.4 C-1, 1G-13 12/1/1983 12.0 IPERF GO 5" TCP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,400.0 7,727.0 6,007.5 6,306.4 Squeeze Behind Casing Squeeze 15.8 PPG CLASS G CEMENT. 5/25/2022 7,400.0 7,747.0 6,007.5 6,322.9 Plug Kick-Off Plug 15.8 PPG CLASS G CEMENT, MILLED OUT DOWN TO CA-2 PLUG @ 7747' 5/25/2022 1G-13A, 1/30/2023 3:35:23 PM Vertical schematic (actual) Slotted Liner; 7,649.1-10,090.0 PRODUCTION; 31.8-8,087.1 FISH; 7,956.0 FISH; 7,940.0 RPERF; 7,800.0-7,846.0 APERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 PACKER; 7,313.5 Tie-Back String; 30.7-7,279.2 CUT; 7,275.0 MANDREL - DMY; 7,142.6 Nipple - X; 7,049.8 Mandrel GAS LIFT; 6,992.5 Mandrel GAS LIFT; 6,655.5 Mandrel GAS LIFT; 3,339.3 SURFACE; 37.5-2,443.9 Nipple - X; 528.7 CONDUCTOR; 37.5-105.0 EMERGENCY SLIPS; 31.2 Hanger; 29.2 KUP PROD 1G-13A ... WELLNAME WELLBORE1G-13 Annotation Last WO: End Date 11/20/2022 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10307'feet 7650', feet true vertical 6312'feet 7601', 7940', 7956' feet Effective Depth measured 10307'feet 7198', 7313', 7388', 7634', 7727', 7819' feet true vertical 6312'feet 5824', 5929', 5997', 6222', 6306', 6368' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/J-55 7757' MD 6331' TVD Packers and SSSV (type, measured and true vertical depth) 7198' MD 7313' MD 7388' MD 7634' MD 7727' MD 7819' MD N/A 5824' TVD 5929' TVD 5997' TVD 6222' TVD 6306' TVD 6368' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2444' 2197' Burst Collapse Production Liner 8055' 2441' Casing 6637' 2-3/8" 8087' 10090' 6301' 2406' 105'Conductor Surface Intermediate 16" 10-3/4" 67' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-056 50-029-21016-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025640 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1G-13A Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 105' ~ ~~ Well Remains Shut-In ~~ ~ 322-595 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer Packer: Baker FHL 47 B2 Packer Packer: Otis RRH Packer Packer: NS Liner Top Packer Packer: Otis WD Packer Packer: Swell Packer SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Senior RWO/CTD Engineer 7541-7596', 7626-7640' feet 6137-6187', 6215-6227' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 4:12 pm, Dec 20, 2022 Page 1/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/11/2022 03:00 11/11/2022 06:30 3.50 MIRU, MOVE MOB P Pull pits away from sub. Load shop and office. 11/11/2022 06:30 11/11/2022 12:00 5.50 MIRU, MOVE MOB P Move pits, Taylor camp and shop to 1G pad. spot truck shop and Taylor camp. Build rig mat layout around wellhead for Sub base spread pit liner and stage wellhead equipment behind 1G-13. Stage DSA's for BOP stack. Lower derrick on sub-base. clean up 2A-26 location. Notified AOGCC intent to test BOP at 12:00 PM on 12/12/22. Notice sent at 11:50AM 11/11/22. 11/11/2022 12:00 11/11/2022 18:00 6.00 MIRU, MOVE MOB P Transport sub T/ 1G. 11/11/2022 18:00 11/11/2022 19:00 1.00 MIRU, MOVE MOB P Place dunnage around cellar. Hang tree in cellar. 11/11/2022 19:00 11/11/2022 21:00 2.00 MIRU, MOVE MOB P Spot sub over well. Place mats and herculite under front of rig. 11/11/2022 21:00 11/11/2022 22:15 1.25 MIRU, MOVE MOB P Spot pits to sub. Place mats and herculite under pits. 11/11/2022 22:15 11/12/2022 00:00 1.75 MIRU, MOVE DMOB P Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. 11/12/2022 00:00 11/12/2022 03:00 3.00 MIRU, MOVE MOB P Raise derrick. Bridal down. Take on fresh water and 9.6 PPG NaCl in pits. R/U tiger tank line. 11/12/2022 03:00 11/12/2022 04:30 1.50 MIRU, MOVE MOB P Rig up circ manifold in cellar. Get measurements for riser height from tubing spool height. Complete rig acceptance checklist. Rig accepted @ 04:30 Hrs. 11/12/2022 04:30 11/12/2022 05:30 1.00 MIRU, WELCTL PRTS P PT circ manifold & tiger tank lines T/ 3500 PSI. Bleed gas off Tbg and IA. 11/12/2022 05:30 11/12/2022 07:30 2.00 MIRU, WELCTL KLWL P Circulate 9.6# NaCl SxS @ 4 BPM ICP= 500 PSI FCP=635 PSI 11/12/2022 07:30 11/12/2022 08:00 0.50 MIRU, WELCTL OWFF P Bleed trapped pressure off TBG and IA monitor well for 30 minutes well static. 11/12/2022 08:00 11/12/2022 08:15 0.25 MIRU, WELCTL MPSP P Set HP BPV. 11/12/2022 08:15 11/12/2022 10:00 1.75 MIRU, WELCTL PRTS P Attempt to test BPV to 1000 PSI from below. Flow seen at monitor on TBG side. Bled pressure off IA. Pulled HP BPV and inspected for damage. No apparent damage seen, replaced poppet and body seal set HP BPV. Pressure test under BPV to 1000 PSI . 11/12/2022 10:00 11/12/2022 12:00 2.00 MIRU, WHDBOP NUND P Bleed off void. ND Tree and adapter. Install tree test dart. Inspect hanger neck threads - Good. Function LDS. 11/12/2022 12:00 11/12/2022 14:00 2.00 MIRU, WHDBOP NUND P N/U DSA and BOP. 11/12/2022 14:00 11/12/2022 18:30 4.50 MIRU, WHDBOP NUND P Change rams. Swap 3 1/2" x 5 1/2" VBR's F/ UPR T/ LPR. Swap 2 7/8" x 5 " VBR's F/ LPR T/ UPR. 11/12/2022 18:30 11/12/2022 21:00 2.50 MIRU, WHDBOP RURD P R/U testing equipment. M/U FOSV on top of 3 1/2" & 5 1/2" TJ. Run doughnut test joints in BOP and identify placement for functioning BOP and testing. Fill stack w/ fresh water. Attempt shell test. Identified Hyd IBOP faled. Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 Page 2/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2022 21:00 11/12/2022 21:30 0.50 MIRU, WHDBOP SVRG P Steam IBOP, greased actuator. Failed low pressure test. Passing shell on Lower Kelly Valve. 11/12/2022 21:30 11/13/2022 00:00 2.50 MIRU, WHDBOP PRTS T B/D testing equipment. Change out Hyd IBOP. 11/13/2022 00:00 11/13/2022 02:00 2.00 MIRU, WHDBOP PRTS T Change out Hyd IBOP. Change out lower kelly valve due to condition of threads. Fill BOPE w/ fresh water. Shell test BOPE - Good test. 11/13/2022 02:00 11/13/2022 04:00 2.00 MIRU, WHDBOP WAIT P Notify AOGCC rep Guy Cook of successful shell test. Wait on AOGCC rep to perform BOPE test. 11/13/2022 04:00 11/13/2022 14:00 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, w/ 3 1/2" test joints. Test LVBR's w/ 3 1/2" and 5 1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV, and IBOP, Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =20 sec, full recovery attained =111 sec. UVBR's= 6 sec, LVBR's= 6 sec. Annular= 29 sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Test witnessed by AOGCC rep Guy Cook. 11/13/2022 14:00 11/13/2022 15:30 1.50 MIRU, WHDBOP BOPE T Replace HCR Kill. Finished testing BOPE 11/13/2022 15:30 11/13/2022 16:00 0.50 MIRU, WHDBOP RURD P RD testing equipment set up floor to pull tubing. 11/13/2022 16:00 11/13/2022 16:15 0.25 MIRU, WHDBOP MPSP P Pulled BPV Filled BOP stack. 11/13/2022 16:15 11/13/2022 16:30 0.25 COMPZN, RPCOMP RURD P PU Landing joint, MU to hanger BOLDS 11/13/2022 16:30 11/13/2022 16:45 0.25 COMPZN, RPCOMP PULL P Pull Hanger to floor Weight broke back at 100K off seat, PUW=88K 7,275.0 7,245.0 11/13/2022 16:45 11/13/2022 17:15 0.50 COMPZN, RPCOMP SVRG P Service rig. Service tubing tongs. 7,245.0 7,245.0 11/13/2022 17:15 11/13/2022 18:15 1.00 COMPZN, RPCOMP CIRC P Circulate SxS @ 5 BPM, 475 PSI 7,245.0 7,245.0 11/13/2022 18:15 11/13/2022 18:30 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow. 7,245.0 7,245.0 11/13/2022 18:30 11/13/2022 21:30 3.00 COMPZN, RPCOMP PULL P L/D hanger and landing joint. L/D completion F/ 7245' T/ 5351', PUW=88K. 7,245.0 5,351.0 11/13/2022 21:30 11/13/2022 22:15 0.75 COMPZN, RPCOMP BHAH P M/U BHA #1 TST-3 Storm Packer and 2 joints of DP T/ tubing string. RIH T/ 82' COE. PUW=70K, SOW=60K. 5,351.0 5,433.0 11/13/2022 22:15 11/13/2022 22:30 0.25 COMPZN, RPCOMP PACK P Rotate T/ left 1 turn S/O set storm packer @ 82' COE. Rotate T/ right release from packer. 5,433.0 82.0 11/13/2022 22:30 11/13/2022 22:45 0.25 COMPZN, RPCOMP BHAH P L/D 2 joints of DP and setting tool. 82.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 Page 3/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/13/2022 22:45 11/13/2022 23:15 0.50 COMPZN, RPCOMP PRTS P PT storm packer T/ 1000 PSI for 10 Min - Good test. 0.0 0.0 11/13/2022 23:15 11/14/2022 00:00 0.75 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Suck stack out. Pull flow nipple 0.0 0.0 11/14/2022 00:00 11/14/2022 02:00 2.00 COMPZN, RPCOMP NUND P N/D BOP, DSA, & 7 1/16" x 11" 3K tubing spool. 0.0 0.0 11/14/2022 02:00 11/14/2022 03:45 1.75 COMPZN, RPCOMP NUND P N/U 11" 3K x 11" 3K casing spool. M/U 2nd IA valve on casing spool. 0.0 0.0 11/14/2022 03:45 11/14/2022 04:15 0.50 COMPZN, RPCOMP PRTS P PT 7" casing packoff T/ 3000 PSI for 15 Min - Good test. 0.0 0.0 11/14/2022 04:15 11/14/2022 07:30 3.25 COMPZN, RPCOMP NUND P Install 11" test plug. RILDS. N/U DSA, adapter spool & BOP. Finished tightening flanges on X-O's and BOPS. Installed riser and filled stack with 9.6# 0.0 0.0 11/14/2022 07:30 11/14/2022 08:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 11/14/2022 08:00 11/14/2022 08:30 0.50 COMPZN, RPCOMP PRTS P Tested BOP stack to 250/3000 PSI for 5 minutes each 0.0 0.0 11/14/2022 08:30 11/14/2022 09:15 0.75 COMPZN, RPCOMP RURD P Blow down surface equipment. 0.0 0.0 11/14/2022 09:15 11/14/2022 09:45 0.50 COMPZN, RPCOMP PULD P Pick up Storm packer equalizing tool and 2 joints of DP. RIH to 68' 0.0 68.0 11/14/2022 09:45 11/14/2022 10:15 0.50 COMPZN, RPCOMP MPSP P Release equalizing valve in storm packer, 0 PSI on DP closed in annular picked up 2 feet. Released storm packer, verified 0 PSI. 68.0 66.0 11/14/2022 10:15 11/14/2022 10:45 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes while setting up to LD tubing. 66.0 66.0 11/14/2022 10:45 11/14/2022 11:15 0.50 COMPZN, RPCOMP PULD P Break out of top drive LD 2 joints of DP and storm packer. 66.0 5,351.0 11/14/2022 11:15 11/14/2022 17:00 5.75 COMPZN, RPCOMP PULL P LD Tubing F/5351' PUW= 69K T/800' 5,351.0 800.0 11/14/2022 17:00 11/14/2022 17:30 0.50 COMPZN, RPCOMP SVRG P Service rig - Change out tubing tongs. 800.0 800.0 11/14/2022 17:30 11/14/2022 19:00 1.50 COMPZN, RPCOMP PULL P Continue pulling out of hole with 3.5" tubing F/800' T/surface Measured cut joint at 3.5" OD good chemical cut. 14.27' of joint recovered above cut. 800.0 0.0 11/14/2022 19:00 11/14/2022 20:15 1.25 COMPZN, RPCOMP RURD P Rig up to pick up DP change elevators. rig down power tongs. clear floor. Mobilize BHA #2 tools to RF and pipe shed. 0.0 0.0 11/14/2022 20:15 11/14/2022 20:30 0.25 COMPZN, RPCOMP SFTY P PJSM on picking up BHA 0.0 0.0 11/14/2022 20:30 11/14/2022 22:15 1.75 COMPZN, RPCOMP BHAH P M/U BHA #2 milling assembly w/ 6.125 packer mill, sting mill, magnets and boot baskets T/ 270', SOW=38K. 0.0 270.0 11/14/2022 22:15 11/15/2022 00:00 1.75 COMPZN, RPCOMP PULD P PUDP F/ 270' T/ 2037', PUW=68K, SOW=57K. 270.0 2,037.0 11/15/2022 00:00 11/15/2022 02:15 2.25 COMPZN, RPCOMP PULD P PUDP F/ 2037' T/ 4654', PUW=108K, SOW=78K. 2,037.0 4,654.0 11/15/2022 02:15 11/15/2022 02:45 0.50 COMPZN, RPCOMP WASH P Wash in hole F/ 4654' T/ 4736'. Set down 10K. Pick up confirm tag. 4,654.0 4,736.0 11/15/2022 02:45 11/15/2022 11:30 8.75 COMPZN, RPCOMP MILL P Mill F/ 4736' T/ 4750', 50-80 RPM, 4.5K Free torque. ROT=90K. Tq on bottom 5-8K. WOB 3-15K. Pumped 20 Bbls hi- vis pill @ 4740' while continuing to mill. 4,736.0 4,750.0 11/15/2022 11:30 11/15/2022 12:00 0.50 COMPZN, RPCOMP SVRG P Service Rig. Grease IR, TD and draw works. 4,750.0 4,750.0 Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 Page 4/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/15/2022 12:00 11/15/2022 13:30 1.50 COMPZN, RPCOMP CIRC P Circ 25 Bbls hi-vis pill around at 4750'. Slow RPM to 15-30 RPM, increase pump rate to 4 BPM. Reciprocate while rotating as sweep is pumped around. 4,750.0 4,750.0 11/15/2022 13:30 11/15/2022 16:30 3.00 COMPZN, RPCOMP TRIP P POOH from 4718.9' to surface 4,750.0 270.0 11/15/2022 16:30 11/15/2022 18:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #2 milling assembly w/ 6.125 packer mill, sting mill, magnets and boot baskets F/ 270', SOW=42K. Clean magnets and baskets. 270.0 0.0 11/15/2022 18:00 11/15/2022 18:30 0.50 COMPZN, RPCOMP SFTY P PJSM 0.0 0.0 11/15/2022 18:30 11/15/2022 19:00 0.50 COMPZN, RPCOMP SVRG P Service Rig. Grease IR, TD and draw works. 0.0 0.0 11/15/2022 19:00 11/15/2022 20:00 1.00 COMPZN, RPCOMP BHAH P P/U BHA #3 spear fishing assembly w/ 5.008" grapple T/ 259.74', SOW=35K. 0.0 259.7 11/15/2022 20:00 11/15/2022 22:45 2.75 COMPZN, RPCOMP PULD P PUDP singles F/ 260' T/ 3097', RIH on stands to 4750'. PUW 110=K, SOW=80K. 259.7 4,750.0 11/15/2022 22:45 11/15/2022 23:00 0.25 COMPZN, RPCOMP FISH P Tag top of fish at 4750'. Set down on top of fish, stack 20k on fish. Work top of fish. Kick on pumps at 2 BPM and lower spear into fish. Wash down 1.5' into fish. Set 25k down. PU 50k over pull fire jars. Set down, PU 55k over pull (165k total). Jars fire, feel lower packer release. PUW 120k-130k (10k-20k over string weight). 4,750.0 4,734.0 11/15/2022 23:00 11/16/2022 00:00 1.00 COMPZN, RPCOMP CIRC P Circ STS # 3 BPM, 320 PSI. 4,734.0 4,734.0 11/16/2022 00:00 11/16/2022 01:15 1.25 COMPZN, RPCOMP TRIP P POOH racking back DP f/ 4734' to 3820'. Notice overpulls every ~40'. Become detained at 3820' 4,734.0 3,820.0 11/16/2022 01:15 11/16/2022 03:45 2.50 COMPZN, RPCOMP JAR P Jar fish working up from 230k to 300k (120k overpull to 190k overpull). Fish freed and moved up hole 50' where it became detained again. Noticed 10k increased drag as fish moved uphole. 3,820.0 3,770.0 11/16/2022 03:45 11/16/2022 04:30 0.75 COMPZN, RPCOMP CIRC P Circulating 50bbl 3% 776 lube pill # 3 BPM, 320 PSI. While jarring @ 100K over. Straight pull T/ 290K. Pipe began to move. 3,770.0 3,770.0 11/16/2022 04:30 11/16/2022 08:00 3.50 COMPZN, RPCOMP TRIP P Pumping 5 1/2" casing patch out of hole T/ 3470'. @ 3 BPM, 320 PSI. PUW=100K. Weight swings T/ 125K Increase pump rate 4 BPM, 3,770.0 259.0 11/16/2022 08:00 11/16/2022 09:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #3 Spear F/ 259' T/ surface, PUW=52K - Fish on, Remove spear from 5 1/2" liner. 259.0 0.0 11/16/2022 09:30 11/16/2022 10:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease pipe skate. 0.0 0.0 11/16/2022 10:00 11/16/2022 11:00 1.00 COMPZN, RPCOMP RURD P R/U GBR casing equipment. 0.0 0.0 11/16/2022 11:00 11/16/2022 12:30 1.50 COMPZN, RPCOMP PULL P L/D 5 1/2", 15.5#, Hyd 511 casing patch. 1 partial joint, 13 full joints and lower packer joint. 0.0 0.0 11/16/2022 12:30 11/16/2022 13:00 0.50 COMPZN, RPCOMP RURD P R/D GBR casing equipment. 0.0 0.0 11/16/2022 13:00 11/16/2022 13:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease IR and handling equipment. 0.0 0.0 11/16/2022 13:30 11/16/2022 14:30 1.00 COMPZN, RPCOMP RURD P Mobilize BHA #4 T/ RF and pipe shed. 0.0 0.0 11/16/2022 14:30 11/16/2022 14:45 0.25 COMPZN, RPCOMP SFTY P PJSM on P/U BHA 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 Page 5/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/16/2022 14:45 11/16/2022 16:30 1.75 COMPZN, RPCOMP BHAH P M/U BHA #4 Clean out assembly T/ 309', SOW=38K. 0.0 309.0 11/16/2022 16:30 11/16/2022 19:15 2.75 COMPZN, RPCOMP TRIP P RIH 309' T/ 4720'. SOW=85k 309.0 4,720.0 11/16/2022 19:15 11/16/2022 23:00 3.75 COMPZN, RPCOMP REAM P Wash and ream from 4720'-5300'. 30 RPM, 3bpm. Worked tight spot F/ 4820- 4855'. RIH to 6450'. Wash and ream F/ 6450' to top of fish at 7268'. Swallow 6' of fish, wash and ream with 5 passes over top of fish. SOW=108K, ROT= 116K, RPM=60, TQ=2.8K-3.2K 4,720.0 7,274.0 11/16/2022 23:00 11/17/2022 00:00 1.00 COMPZN, RPCOMP CIRC P PU above fish. Slow to 10RPM and circulate 40 bbl vis pill. When pill at bit, swallow fish and pump sweep around. Once pill left BHA, recip pipe until full pill past BHA. Once pill past BHA, PU above fish, cut rotation, increase pumps to 4 bpm and circ pill to surface. 7,274.0 7,266.0 11/17/2022 00:00 11/17/2022 00:45 0.75 COMPZN, RPCOMP CIRC P Circulate viscous pill to surface. 4BPM/675PSI 7,266.0 7,266.0 11/17/2022 00:45 11/17/2022 03:15 2.50 COMPZN, RPCOMP PULD P LDDP T/ 4374'. PUW= 140k 7,266.0 4,375.0 11/17/2022 03:15 11/17/2022 04:45 1.50 COMPZN, RPCOMP SLPC P Slip and Cut drill line 4,375.0 4,375.0 11/17/2022 04:45 11/17/2022 08:00 3.25 COMPZN, RPCOMP PULD P LDDP F/ 4374' T/ 309'. PUW=98K. 4,375.0 309.0 11/17/2022 08:00 11/17/2022 10:15 2.25 COMPZN, RPCOMP BHAH P L/D BHA #4 F/ 309' T/ surface. 309.0 0.0 11/17/2022 10:15 11/17/2022 10:45 0.50 COMPZN, RPCOMP RURD P Pull 11" wear bushing. 0.0 0.0 11/17/2022 10:45 11/17/2022 11:30 0.75 COMPZN, RPCOMP CLEN P Remove Baker fishing package from RF and pipe shed. 0.0 0.0 11/17/2022 11:30 11/17/2022 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Repair leak in on TD. 0.0 0.0 11/17/2022 12:00 11/17/2022 12:45 0.75 COMPZN, RPCOMP PRTS P PT 4 1/2" EUE FOSV Verify joint count and jewelry running order. 0.0 0.0 11/17/2022 12:45 11/17/2022 14:15 1.50 COMPZN, RPCOMP RURD P R/U GBR Casing equipment. 0.0 0.0 11/17/2022 14:15 11/17/2022 14:45 0.50 COMPZN, RPCOMP SFTY P PJSM w/ SLB, Baker, GBR and rig crew on running 5 1/2" tie back liner. 0.0 0.0 11/17/2022 14:45 11/17/2022 15:30 0.75 COMPZN, RPCOMP PUTB T Wait on correct heads for casing tongs. 0.0 0.0 11/17/2022 15:30 11/17/2022 23:45 8.25 COMPZN, RPCOMP PUTB P RIH w/ 3 1/2" x 5 1/2" tie back liner T/ 5344', PUW=135k, SOW=64K. 3 1/2" EUE torqued T/ 2250 Ft/lbs Run-n -seal dope used. 5 1/2" Hyd 513 torque turned T/ 6100 Ft/lbs. Jet lube seal guard dope used. 5 1/2" Hyd 563 torque turned T/ 6000 Ft/lbs. Jet lube seal guard dope used. 0.0 5,344.0 11/17/2022 23:45 11/18/2022 00:00 0.25 COMPZN, RPCOMP PULD P M/U 17# Hyd513 to 15.5# Hyd563 crossover. M/U Hyd563 crossover on TIW valve. 5,344.0 5,346.0 Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 Page 6/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2022 00:00 11/18/2022 02:30 2.50 COMPZN, RPCOMP PULD P RIH w/ 3 1/2" x 5 1/2" tie back liner T/ 7279', PUW=146K, SOW=65K. 5 1/2" Hyd 563 torque turned T/ 6000 Ft/lbs. Jet lube seal guard dope used. Kelly up and wash down joint 169. Wash down. Observe pressure increase. S/O 10k confirm shear screw release at 7276'. Fully locate to 7281.15 ORKB'. P/U 2 from fully located T/ 7279.15' ORKB. 5,346.0 7,279.2 11/18/2022 02:30 11/18/2022 04:15 1.75 COMPZN, RPCOMP HOSO P P/U Space out 5.5 so there is a 2.5 stick up on RF. M/U Cement hose T/ top of last full joint. RIH T/ 7269' 7,279.2 7,269.0 11/18/2022 04:15 11/18/2022 05:00 0.75 COMPZN, RPCOMP CIRC P Reverse Circ 100 Bbls 9.6# CI NaCl followed by 10 Bbls 9.6 NaCl to flush lines. 7,269.0 7,269.0 11/18/2022 05:00 11/18/2022 06:15 1.25 COMPZN, RPCOMP WWSP P Set 11" x 5 1/2" emergency slips from RF. S/O slips took string weight w/ bottom of overshot @ 7279.75' ORKB. RILDS energize pack off. 7,269.0 7,279.8 11/18/2022 06:15 11/18/2022 06:45 0.50 COMPZN, RPCOMP PRTS P PT pack off on emergency slips against annular T/ 3000 PSI for 30 Min. 7,279.8 7,279.8 11/18/2022 06:45 11/18/2022 07:15 0.50 COMPZN, RPCOMP SVRG P Service Rig 7,279.8 7,279.8 11/18/2022 07:15 11/18/2022 08:30 1.25 COMPZN, RPCOMP RURD P R/U slick line T/ liner w/ 4 1/2' FOSV. 7,279.8 7,279.8 11/18/2022 08:30 11/18/2022 09:45 1.25 COMPZN, RPCOMP SLKL P RIH w/ slick line XX plug. Set plug in X nipple @ 7251'. Sheared off plug. POOH. 7,279.8 7,279.8 11/18/2022 09:45 11/18/2022 10:00 0.25 COMPZN, RPCOMP RURD P Stand back slick line. 7,279.8 7,279.8 11/18/2022 10:00 11/18/2022 10:15 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 7,279.8 7,279.8 11/18/2022 10:15 11/18/2022 11:00 0.75 COMPZN, RPCOMP PACK P Pressure up T/ 3750 PSI set SLB packer. Hold pressure for 30 Min. 7,279.8 7,279.8 11/18/2022 11:00 11/18/2022 11:45 0.75 COMPZN, RPCOMP PRTS P PT 5 1/2" liner T/ 3000 PSI for 30 Min. 7,279.8 7,279.8 11/18/2022 11:45 11/18/2022 12:15 0.50 COMPZN, RPCOMP RURD P R/D testing equipment. Suck out stack and joint of 5 1/2' liner. 0.0 0.0 11/18/2022 12:15 11/18/2022 13:45 1.50 COMPZN, RPCOMP NUND P N/D split BOP stack and lift T/ expose 5 1/2" liner. 0.0 0.0 11/18/2022 13:45 11/18/2022 14:45 1.00 COMPZN, RPCOMP CUTP P R/U WHACHS saw. Make final cut on 5 1/2" liner. Pull cut joint out of BOP and L/D 0.0 0.0 11/18/2022 14:45 11/18/2022 16:00 1.25 COMPZN, RPCOMP NUND P N/D DSA and drilling spool. Rack BOP back on pedestal. 0.0 0.0 11/18/2022 16:00 11/18/2022 18:00 2.00 COMPZN, RPCOMP NUND P N/U 11"3K x 7 1/16" 5K Cameron C- bowl tubing spool. Install 2nd IA valve. 0.0 0.0 11/18/2022 18:00 11/18/2022 18:30 0.50 COMPZN, RPCOMP PRTS P PT. 11' x 5.5" packoff and lower break on tubing head T/ 3000 PSI for 15 Min. 0.0 0.0 11/18/2022 18:30 11/18/2022 21:00 2.50 COMPZN, RPCOMP NUND P NU BOP. Run test joint. Close upper pipe rams. 0.0 0.0 11/18/2022 21:00 11/18/2022 21:30 0.50 COMPZN, RPCOMP PRTS P Run test joint. Close upper pipe rams. RU and test break to 250psi/5min, 3500psi/5min. Good test. Bleed off pressure. 0.0 0.0 11/18/2022 21:30 11/18/2022 22:30 1.00 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 11/18/2022 22:30 11/18/2022 23:00 0.50 COMPZN, RPCOMP MPSP P Pull test plug. 0.0 0.0 11/18/2022 23:00 11/18/2022 23:30 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 Page 7/7 1G-13 Report Printed: 12/8/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2022 23:30 11/19/2022 00:00 0.50 COMPZN, RPCOMP SFTY P PJSM for running completion 0.0 0.0 11/19/2022 00:00 11/19/2022 11:30 11.50 COMPZN, RPCOMP RCST P Running 3.5", 9.3#, L-80, EUE-M completion. Install 3.5" SCC on joints below GLMs. 3 1/2" EUE-M torqued T/ 2250 Ft/lbs. Run-n-seal dope applied. Wash joint 225 in hole @ 1.5 BPM, 260 PSI. Pressure increase identified. Located no-go @ 7122.6' ORKB w/ 5K down weight. 0.0 7,122.6 11/19/2022 11:30 11/19/2022 12:45 1.25 COMPZN, RPCOMP HOSO P Lay down joints #225, #224, #223. M/U 10.2', 8.23', 6.30', 2.07' space out pups. M/U joint #223. M/U hanger and landing joint. 7,122.6 7,088.0 11/19/2022 12:45 11/19/2022 13:15 0.50 COMPZN, RPCOMP RURD P R/U circ equipment. 7,088.0 7,088.0 11/19/2022 13:15 11/19/2022 14:15 1.00 COMPZN, RPCOMP CRIH P Circulate 85 Bbls 9.6 PPG CI NaCl followed by 52 Bbls 9.6 PPG NaCl @ 2.5 BPM, 630 PSI. 7,088.0 7,088.0 11/19/2022 14:15 11/19/2022 15:15 1.00 COMPZN, RPCOMP RCST P RIH land hanger. Bottom of seals @ 7118.03' ORKB, 4.57' from fully located. RILDS. 7,088.0 7,118.0 11/19/2022 15:15 11/19/2022 16:15 1.00 COMPZN, RPCOMP PRTS P PT tubing T/ 3000 PSI for 30 Min. Bleed tubing T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump tubing pressure shear out SOV. 7,118.0 7,118.0 11/19/2022 16:15 11/19/2022 16:30 0.25 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Pull landing joint. 7,118.0 11/19/2022 16:30 11/19/2022 17:00 0.50 COMPZN, RPCOMP PRTS P Install HP BPV. Pressure test down IA through SOV to 1000psi for 10 minutes. Good Test 11/19/2022 17:00 11/19/2022 17:30 0.50 COMPZN, WHDBOP SVRG P Service rig 11/19/2022 17:30 11/20/2022 00:00 6.50 COMPZN, WHDBOP SVRG P Between well maintenance 11/20/2022 00:00 11/20/2022 07:00 7.00 COMPZN, WHDBOP SVRG P Between well maintenance. UVBR's & blinds packer elements were changed out proactively due to wear identified when inspected. 11/20/2022 07:00 11/20/2022 08:45 1.75 COMPZN, WHDBOP NUND P N/D BOP & DSA. Break choke hose off for HCR change, out of critical path. 11/20/2022 08:45 11/20/2022 10:00 1.25 COMPZN, WHDBOP NUND P Install tree test dart. N/U adapter spool and tree. PT hanger void to 5000psi for 15min. 11/20/2022 10:00 11/20/2022 10:15 0.25 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min 11/20/2022 10:15 11/20/2022 10:45 0.50 COMPZN, WHDBOP RURD P R/U circ manifold & testing equipment. 11/20/2022 10:45 11/20/2022 11:30 0.75 COMPZN, WHDBOP PRTS P PT Tree T/ 5000 PSI for 15 Min. 11/20/2022 11:30 11/20/2022 12:00 0.50 COMPZN, WHDBOP SVRG P Service rig 11/20/2022 12:00 11/20/2022 12:30 0.50 COMPZN, WHDBOP MPSP P Pull tree test dart & BPV. 11/20/2022 12:30 11/20/2022 13:00 0.50 COMPZN, WHDBOP SVRG P Service rig 11/20/2022 13:00 11/20/2022 14:30 1.50 COMPZN, WHDBOP FRZP P LRS pump 43 Bbls freeze protect @ 2 BPM, ICP-1100, FCP=1600. U-tube well. Pressures equalized @ 600 PSI. 11/20/2022 14:30 11/20/2022 16:00 1.50 DEMOB, MOVE DMOB P Secure tree and cellar. Record final pressures. T=550, IA=525, OA=0, OOA=75 Rig: NABORS 7ES RIG RELEASE DATE 11/20/2022 DTTMSTART JOBTYP SUMMARYOPS 10/14/2022 REPAIR WELL SET 2.80" CATCHER W/ STINGER IN RBP @ 7332' RKB; UNABLE TO PULL OV @ 7245' RKB (DISCUSS WITH RWO ENGR) & ELECTED TO PULL GLV @ 6697' RKB; DRIFT W/ 10' X 2.625" STEM DOWN TO 7332' RKB (NO ANOMALIES). READY FOR CIRC OUT. 10/14/2022 MAINTAIN WELL PUMPED 255 BBLS OF SW DOWN TBG UP THE IA TO DISPLACE WELL TO SW. PUMED 84 BBLS DIESEL DOWN TBG AND U-TUBE INTO IA FOR A FREEZE PROTECT. DRAW DOWN TBG X IA DOWN TO 0 PSI AND MONITOR FOR 15 MIN W/ NO CHANGE. (JOB COMPLETE) 10/22/2022 REPAIR WELL RUN 1: RIH W/ STRING SHOT. UNABLE TO GET THROUGH GLM #1 AT 3104'. POOH. CHECK TOOLS. BEND IN BOTTOM NOSE RUN 2: STRING SHOT TUBING OVER INTERVAL 7266' RKB TO 7276' RKB RUN 3: CHEM CUT TUBING AT 7275' RKB, CCL TO CUTTER = 11.3', CCL STOP DEPTH = 7263.7' RKB. TOOLS HUNG UP AT 3180' JARED FREE. TOOLS HUNG UP AGAIN AT 3115'. BROKE WEAKPOINT TO GET FREE. ***~31' EL TOOLSTRING LEFT IN HOLE*** 10/23/2022 REPAIR WELL RECOVERED E-LINE TOOLSTRING @ 7295' RKB. JOB COMPLETE. 10/29/2022 REPAIR WELL CIRC OUT PUMPED 258 BBLS 9.2 PPG NaCl BRINE TOTUBING TAKING RETURNS FROM IA TO 1G-15 PRODUCTION LINE BLEED PRESSURE OFF JUMPER HOSE MONITOR PRESSURES FOR 30 MINUTES INITIAL T/I/O = 0/0/700 30 MINUTE T/I/O = 25/0/700 PUMPED 84 BBLS DSL U-TUBED FOR FREEZE PROTECT 11/11/2022 RECOMPLETION Pull pits away from sub. Load shop and office. Transport pits, office and shop to 1G. Set shop and office. Stage pits on pad. Bridal up. Lay derrick over. Pull sub off of 2A-26. Clean up around well. Transport sub to 1G. Spot sub over well. Spot pits to sub. Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. 11/12/2022 RECOMPLETION Raise derrick. Bridal down. Get measurements for riser height from tubing spool height. Take on fresh water and 9.6 PPG NaCl in pits. Rig up circ manifold in cellar. Complete acceptance checklist. Pressure test circ manifold & tiger tank to 3500 PSI. Bleed free gas off TBG/IA. Kill well with 9.6 PPG NaCl. Shut in well monitor for pressure. 30 Min no flow test. Install HP BPV. PT from below to 1000 PSI for 10 Min. Nipple down tree. Install HP dart. Nipple up BOP. Change rams 3 1/2" x 5 1/2" in LPR. Rig up test equipment. Shell test BOPE. Hyd IBOP failed. Changing out Hyd IBOP. 11/13/2022 RECOMPLETION Continue changing out Hyd IBOP and lower kelly valve. Shell test BOP. Wait on AOGCC rep Guy Cook to witness BOPE test. Testing BOPE as per sundry. Replace HCR Kill. Complete BOPE test. Pull dart and BPV. Make up landing joint. BOLDS. Pull hanger to rig floor and lay down. Circulate well. Lay down completion T/ 5351' Make upBHA #1 storm packer and set at 82' COE. Pressure test storm packer to 1000 PSI for 10 Min. 11/14/2022 RECOMPLETION Nipple down BOP. Nipple down tubing spool. Install 11" 3K casing head. Test 7" packoff to 3000 PSI for 15 min. Install test plug. Nipple up BOP. Test stack break as per AOGCC. Pull test plug. Install wear bushing. Engage storm packer. Close annular, pick up and release storm packer. OWFF. Lay down packer. Lay down remaining completion. Make up BHA #2 Packer milling assembly. Pick up drill pipe T/ 2037'. 11/15/2022 RECOMPLETION Continue pick up drill pipe T/ 4654'. Wash down T/ 4736', set down 10K. Obtain parameters. Mill CPH liner top packer F/ 4736' T/ 4750'. Circ sweep. POOH and LD BHA #2. PU BHA #3 fishing assembly. RIH and tag top of fish @ 4750'. Set down and wash to 4751.5'. PU and jar fish free with 55k over pull. Circ Surf to surf. 11/16/2022 RECOMPLETION Pulling casing patch out of hole racking back DP. Fish hung up at 3,770' Jar fish. Pump lube pill. Pump 5 1/2" patch out of hole. Lay down BHA #3. RU GBR and lay down 575' of 5.5" Hyd511 casing patch. MU BHA #4 clean out assembly. Perform cleanout run. POOH LD DP. 11/17/2022 RECOMPLETION Lay down drill pipe T/ 4247'. Cut and slip drill line. Continue laying down drill pipe. Lay down BHA #4. Pull wear bushing. Test 4 1/2" EUE FOSV. Rig up GBR. Run 3.5" by 5.5" tieback. 11/18/2022 RECOMPLETION Finish running 3.5" by 5.5" tieback. Wash last joint down identify pressure spike, shear set screws, fully locate tie back string. Space out. Circulate CI NaCl around back side. Drop emergency slips, land casing. RILDS. Pressure test pack off against annular to 3000 PSI for 30 Min. Rig up slick line. Set plug in X nipple. Rig down slick line. Set SLB packer. Test liner T/ 3000 PSI for 30 Min. Nipple down BOP. Cut 5 1/2" with WACHS saw. Nipple up new tubing spool. Pressure test pack off to 3000 PSI for 15 Min. Set test plug. Nipple up BOP. Test BOP breaks to 250/3500 PSI. 11/18/2022 REPAIR WELL (7-ES RIG JOB) SET 2.81'' XX PLUG W/ FILL EXT @ 7252' RKB. JOB COMPLETE. 11/19/2022 RECOMPLETION Run 3.5" completion. Space out. PU and circ CI brine. Land tubing hanger. PT tbg and IA. Install and test BPV. Perform between well maintenance. 1G-13 RWO Summary of Operations 11/20/2022 RECOMPLETION Complete between well maintenance. Nipple down BOP. Nipple up adaptor spool and tree. Pressure tree. Pump freeze protect. RDMO 11/21/2022 REPAIR WELL FREEZE PROTECT OA POST RIG, 30 BBLS DSL DWN OA 11/22/2022 REPAIR WELL PULLED SOV @ 6992' RKB & SET OV. PULLED DMY'S @ 6655' RKB, 3339' RKB & SET GLV'S. OBTAIN GOOD TBG TEST & IA DDT. EQUALIZED & PULLED 2.81'' XX PLUG @ 7251' RKB. ATTEMPT TO PULL CATCHER & ENCOUNTER FILL @ 7278' RKB. W/ 2.5'' PUMP BAILER RECOVERED MUD AND DEBRIS @ 7278' RKB. IN PROGRESS. 11/23/2022 REPAIR WELL W/ MULTIPLE 2.5'' PUMP BAILERS, BAILED FILL & DEBRIS FROM 7275' RKB ~ 7294' RKB. IN PROGRESS. 11/24/2022 REPAIR WELL BAILED FILL FROM 7291' RKB ~ 7315' RKB. IN PROGRESS. 11/25/2022 REPAIR WELL BAILED FILL FROM 7291' RKB ~ 7327' RKB. PULLED 3.5'' CATCHER @ 7327' RKB. EQUALIZED RBP & ATTEMPT TO PULL @ 7332' RKB. IN PROGRESS. 11/26/2022 REPAIR WELL BAIL FILL ON TOP OF RBP & PULLED 3.5'' RBP @ 7332' RKB. EQUALIZED & PULLED 2.81'' XX PLUG @ 7354' RKB. ATTEMPT TO PULL RX PLUG @ 7634' RKB & ENCOUNTER FILL. IN PROGRESS. 11/27/2022 REPAIR WELL ATTEMPT TO BAIL W/ 1.75'' BAILER IN LINER TOP PACKER @ 7634' RKB & BECOME DETAINED FOR 3 HOURS. . W/ 2.5'' PUMP BAILER, BAILED FILL TO TOP OF LINER TOP PACKER @ 7634' RKB. BAILED W/ 1.5'' PUMP TO 7644' RKB. IN PROGRESS. 11/28/2022 REPAIR WELL BAIL FILL ON R-PLUG IN LTP @ 7650' RKB. ATTEMPT TO EQUALIZED R-PLUG W/ 1.78'' GS (DOGLESS) BUT UNABLE TO GET PAST 7646' RKB (STICKY). RAN 1.75'' PUMP BAILER & BECAME DETAINED @ 7646' RKB, JARRED FOR 30 MINS TO GET FREE & PARTED WIRE @ SURFACE AROUND TOP SHEEVE. ESTIMATE 7464' OF WIRE LEFT IN HOLE & 45' TOOLSTRING (RS,5',KJ,5',KJ,5',OJ,KJ,LSS,10' x 1.75'' PUMP BAILER). RIG DOWN TO GET WELL HOUSE SET TO AIDE IN FISHING OPERATIONS. 12/5/2022 REPAIR WELL DEPLOYED 2.25" BLIND ON 5' OF 1.875 STEM TO BOX WIRE OFF FISH. GRABBED TOP OF WIRE @ 95' SLM. PULLED 1400# ON WIRE (WIRE IS STILL CONNECTED TO FISH). WIRE STRETCHED UP TO 15' SLM PLACING TOOL STRING ACROSS ALL TREE VALVES.SHEARED OFF GR @ 71' SLM LEAVING GRAB ASSEMBLY. DECIDED TO RDMO TO DUSCUSS OPTIONS/RISKS. Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post Rig plug pulls, Gas lift & fish. 1G-13A 11/28/2022 fergusp General Notes: Last 3 entries Com Date Last Mod By 16" conductor, 10-3/4" SC, 7" old PC, 5-1/2" new PC tieback installed during 2022 RWO (XO to 3-1/2" tbg at 7101'), 3-1/2" tbg, 2-3/8" 2022 CTD slotted liner 11/20/2022 spilch Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 37.5 105.0 105.0 65.00 H-40 WELDED SURFACE 45.5#/55.5# 10 3/4 9.95 37.5 2,443.9 2,197.1 45.50 K-55 BTC PRODUCTION 7 6.28 31.8 8,087.1 6,395.9 26.00 J-55 BTC Tie-Back String 5 1/2 4.89 30.7 7,279.2 5,897.6 17.00 L-80 Hyd 513 Slotted Liner 2 3/8 1.99 7,649.1 10,090.0 6,300.9 4.60 L-80 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 29.2 Set Depth 7,118.0 Set Depth 5,752.4 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.00 Hanger 7.100 Tubing Hanger, Cameron C-bowl w/ 3.5 EUE 8rd Box x Box Camero n C-Bowl 2.950 528.7 528.7 0.80 Nipple - X 4.500 3.5" x 2.813" X-Nipple HES X Nipple 2.813 3,339.3 2,896.0 40.50 Mandrel GAS LIFT 4.710 GLM, 3.5" x 1", KBG-2-9, Vam top Box x Pin SLB KBG-2-9 2.818 6,655.5 5,354.3 33.29 Mandrel GAS LIFT 4.710 GLM, 3.5" x 1", KBG-2-9, Vam top Box x Pin SLB KBG-2-9 2.818 6,992.5 5,641.6 29.56 Mandrel GAS LIFT 4.710 GLM, 3.5" x 1", KBG-2-9, Vam top Box x Pin SLB KBG-2-9 2.818 7,049.8 5,691.7 28.16 Nipple - X 4.500 3.5" x 2.813" X-Nipple HES X Nipple 2.813 7,098.5 5,735.0 26.87 Locator 4.490 GBH-22 Locator Baker Baker GBH-2 Locator 2.980 7,099.8 5,736.1 26.84 Seal Assembly 3.980 Baker 80-40 Seal Assembly (4.57' From Fully Located) Baker 80-40 Seal Assembl y 3.000 Top (ftKB) 7,276.0 Set Depth 7,369.3 Set Depth 5,979.5 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,296.3 5,913.1 24.88 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,299.8 5,916.3 24.85 LOCATOR 4.500 BAKER LOCATOR SUB 2.997 7,300.5 5,916.9 24.85 PBR 5.875 BAKER 80-40 PBR **SHEARED** 2.997 7,313.5 5,928.7 24.72 PACKER 6.000 BAKER FHL 47 B2 PACKER 2.930 7,353.9 5,965.5 24.33 NIPPLE 4.375 OTIS NO GO X NIPPLE 2.810 7,355.3 5,966.7 24.31 OVERSHOT 5.750 OTIS SBR OVERSHOT w/ 2.813" X PROFILE 4.750 Top (ftKB) 7,362.0 Set Depth 7,757.2 Set Depth 6,330.8 String Ma 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,362.0 5,972.9 24.25 SBR 4.750 OTIS SBR SLICK STICK 2.992 7,388.2 5,996.8 23.99 PACKER 5.980 OTIS RRH PACKER , 60000# SHEAR 2.970 7,531.4 6,128.0 23.50 BLAST RINGS 3.500 2.992 7,562.2 6,156.3 23.62 BLAST RINGS 3.500 BLAST JOINTS w/ 1" CARBIDE RINGS 2.992 7,718.6 6,299.1 27.94 LOCATOR 4.000 OTIS ST SLOT LOCATOR 3.000 7,719.8 6,300.2 28.35 SEAL ASSY 4.500 OTIS SEAL ASSEMBLY 3.000 7,725.9 6,305.5 30.41 MULE SHOE 3.500 OTIS MULE SHOE GUIDE 2.992 7,726.8 6,306.3 30.71 PACKER 6.156 OTIS WD PACKER 4.000 7,730.4 6,309.4 31.93 MILL 3.500 MILL OUT EXTENSION 2.992 7,746.7 6,322.7 37.77 NIPPLE 4.750 CAMCO D NIPPLE NO GO 2.750 7,756.4 6,330.2 41.25 WLEG 4.570 OTIS WIRELINE RE-ENTRY GUIDE 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 31.3 31.3 0.00 EMERGENCY SLIPS 11" x 5.5" Emergency Slips. 11/18/2022 5.500 62.0 62.0 0.00 OTHER Baited wire grab assembly 2.25" bait sub, 3' x 1.5" stem, 2.50" wire finder, 11" x 1.25 ext, 35" BLB, 2.25" 3 leg wire line grab (OAL 9.68') Listed in SLM on depths. 12/5/2022 0.000 7,142.6 5,774.4 26.32 MANDREL - DMY MMG, 1.5", DMY, [***exception MANDREL in casing string ****] MMG DMY 11/18/2022 1.500 7,275.0 5,893.8 25.05 CUT CHEMICAL TUBING CUT AT 7275' RKB 10/22/2022 2.992 1G-13A, 12/8/2022 2:22:35 PM Vertical schematic (actual) Slotted Liner; 7,649.1-10,090.0 PRODUCTION; 31.8-8,087.1 FISH; 7,956.0 FISH; 7,940.0 PACKER; 7,819.0 APERF; 7,800.0-7,846.0 RPERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 TUBING PLUG; 7,650.0 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 FISH; 7,601.0 OTHER; 7,595.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 PACKER; 7,313.5 Tie-Back String; 30.7-7,279.2 CUT; 7,275.0 MANDREL - DMY; 7,142.6 Nipple - X; 7,049.8 Mandrel GAS LIFT; 6,992.5 Mandrel GAS LIFT; 6,655.5 Mandrel GAS LIFT; 3,339.3 SURFACE 45.5#/55.5#; 37.5- 2,443.9 Nipple - X; 528.7 CONDUCTOR; 37.5-105.0 OTHER; 62.0 EMERGENCY SLIPS; 31.2 Hanger; 29.2 KUP PROD KB-Grd (ft) 41.00 RR Date 10/11/198 3 Other Elev 1G-13A ... TD Act Btm (ftKB) 10,307.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292101601 Wellbore Status PROD Max Angle & MD Incl (°) 100.30 MD (ftKB) 9,850.46 WELLNAME WELLBORE1G-13 Annotation End DateH2S (ppm) 165 Date 7/31/2015 Comment Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,595.0 6,186.3 23.75 OTHER Deployed blind box 1.875" rope socket, 5' x 1.875" WB, XO, & 2.25" blind box. (OAL 80") 12/5/2022 0.000 7,601.0 6,191.8 23.77 FISH Slickline tool string & wire. Tools stuck in LTP, BTM @ 7646' RKB. Top of tool string ~7601. With ~ 7464' of .125" wire. 11/28/2022 0.000 7,634.0 6,221.9 23.86 PACKER Northern Solutions Liner Top Packer, Spacer pipe, & Stinger w/ 1.78" RX Nipple (18.4' OAL) NSP2 1 7/3/2022 1.780 7,650.0 6,236.6 23.90 TUBING PLUG 1.78" RX Plug w/ Seal Guide 7/3/2022 0.000 7,705.0 6,286.8 24.01 WHIPSTOCK NS Monobore WS Northern Solutions Monobor e 6/23/2022 0.000 7,819.0 6,367.7 65.16 PACKER 6/30/2022 1.867 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,339.3 2,896.0 40.50 1 GAS LIFT GLV BTM 1 1,369.0 11/22/2022 SLB KBG-2-9 0.125 6,655.5 5,354.3 33.29 2 GAS LIFT GLV BTM 1 1,345.0 11/22/2022 SLB KBG-2-9 0.125 6,992.5 5,641.6 29.56 3 GAS LIFT OV BTM 1 0.0 11/22/2022 SLB KBG-2-9 0.125 7,425.1 6,030.5 23.75 6 PROD OPEN OPEN 1 0.0 5/8/2022 3:30 0.000 7,493.3 6,093.1 23.40 7 PROD OPEN 1 0.0 10/15/2000 0.000 7,679.9 6,263.9 23.97 8 PROD DPHF CV Broke 1 0.0 10/15/2000 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,935.9 1,791.0 37.16 XO Threads 5.500 5.5" 15.5# L-80 Hyd 563 Box x 5.5" 17# L-80 Hyd 513 Pin 4.892 7,142.0 5,773.9 26.33 Mandrel GAS LIFT 5.870 SLB 3.5" x 1.5" MMG, SN# 23761- 07 SLB MMG 2.920 7,198.2 5,824.3 25.65 Packer 6.280 3.5" x 7" SLB BluePack Packer, SN# C21P-1909 SLB BluePack 2.894 7,251.1 5,872.1 25.23 Nipple - X 4.500 3..5 x 2.813" X nipple SN# 0004739293-6 HES X Nipple 2.813 7,272.3 5,891.4 25.07 Overshot 6.020 3.5" x 7" Poor Boy Overshot w/ 6.15' of swallow. (1.25'' from fully located) Baker Poorboy Overshot 3.590 7,820.0 6,368.1 65.56 Swell Packer 2.700 Swell Packer -PESI HLB 1.686 9,009.1 6,385.8 90.57 Deployment Sleeve 2.375 OH Permanent QCLL, L-80, NSAK 350-238 NS AK 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,541.0 7,596.0 6,136.8 6,187.2 C-4, C-3, 1G-13 12/1/1983 12.0 IPERF GO 5" TCP 7,626.0 7,640.0 6,214.6 6,227.4 C-1, 1G-13 12/1/1983 12.0 IPERF GO 5" TCP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,400.0 7,727.0 6,007.5 6,306.4 Squeeze Behind Casing Squeeze 15.8 PPG CLASS G CEMENT. 5/25/2022 7,400.0 7,747.0 6,007.5 6,322.9 Plug Kick-Off Plug 15.8 PPG CLASS G CEMENT, MILLED OUT DOWN TO CA-2 PLUG @ 7747' 5/25/2022 1G-13A, 12/8/2022 2:22:36 PM Vertical schematic (actual) Slotted Liner; 7,649.1-10,090.0 PRODUCTION; 31.8-8,087.1 FISH; 7,956.0 FISH; 7,940.0 PACKER; 7,819.0 APERF; 7,800.0-7,846.0 RPERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 TUBING PLUG; 7,650.0 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 FISH; 7,601.0 OTHER; 7,595.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 PACKER; 7,313.5 Tie-Back String; 30.7-7,279.2 CUT; 7,275.0 MANDREL - DMY; 7,142.6 Nipple - X; 7,049.8 Mandrel GAS LIFT; 6,992.5 Mandrel GAS LIFT; 6,655.5 Mandrel GAS LIFT; 3,339.3 SURFACE 45.5#/55.5#; 37.5- 2,443.9 Nipple - X; 528.7 CONDUCTOR; 37.5-105.0 OTHER; 62.0 EMERGENCY SLIPS; 31.2 Hanger; 29.2 KUP PROD 1G-13A ... 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'B 3 < 'B 3 1 ;3 51 C% & 7 1 %7 23 6 22 4 1 6C 62 4 6 4 2 > 64 / /#(! 1 2 1 > 12 % 2% 1 - 62 12 7 2 1 1 !;"( 2% % !;"" 4 % 1 1 1 7 17 6 4 4 % 7 7 2% 2 2 6 62 1 5<3 2 1 1 4 = 2 !;"( A // 62 1 4 2% 3 % 3 62 Adam Klem Digitally signed by Adam Klem Date: 2022.08.03 06:33:41 -08'00' Casing Strings Top (ftKB) 37.5 Set Depth … 105.0 OD (in) 16 Casing Description CONDUCTOR Set Depth (ft… 105.0 Wt/Len (lb/ft) 65.00 Grade H-40 Top Connection WELDED ID (in) 15.06 Top (ftKB) 37.5 Set Depth … 2,197.1 OD (in) 10 3/4 Casing Description SURFACE 45.5#/55.5# Set Depth (ft… 2,443.9 Wt/Len (lb/ft) 45.50 Grade K-55 Top Connection BTC ID (in) 9.95 Top (ftKB) 31.8 Set Depth … 6,395.9 OD (in) 7 Casing Description PRODUCTION Set Depth (ft… 8,087.1 Wt/Len (lb/ft) 26.00 Grade J-55 Top Connection BTC ID (in) 6.28 Top (ftKB) 7,649.1 Set Depth … 6,300.9 OD (in) 2 3/8 Casing Description Slotted Liner Set Depth (ft… 10,090.0 Wt/Len (lb/ft) 4.60 Grade L-80 Top Connection STL ID (in) 1.99 Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Make Model Nominal ID (in) 7,649.1 6,235.7 23.89 SBR (Seal Bore Receptacle) Deployment Sleeve w/6' Sealbore Receptical (PBR) Baker 2.250 7,820.0 6,368.1 65.56 Swell Packer Swell Packer -PESI HLB 1.686 9,009.1 6,385.8 90.57 Deployment Sleeve OH Permanent QCLL, L-80, NSAK 350- 238 NS AK 1.920 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.3 Set Depth … 5,979.5 String Ma… 3 1/2 Tubing Description TUBING Set Depth (ftKB) 7,369.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.3 31.3 0.00 HANGER 8.000 MCEVOY TUBING HANGER 3.500 480.4 480.4 0.18 NIPPLE 4.750 CAMCO DS LANDING NIPPLE 2.875 3,103.9 2,715.9 39.81 GAS LIFT 5.390 CAMCO KBUG 2.920 4,652.7 3,863.5 43.84 GAS LIFT 5.390 CAMCO KBUG 2.920 5,832.8 4,726.0 42.28 GAS LIFT 4.725 CAMCO KBG2-9- 1R 2.920 6,697.4 5,389.4 32.95 GAS LIFT 4.725 CAMCO KBG2-9- 1R 2.920 7,245.2 5,866.8 25.28 GAS LIFT 4.725 CAMCO KBG2-9- 1R 2.920 7,296.3 5,913.1 24.88 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,299.8 5,916.3 24.85 LOCATOR 4.500 BAKER LOCATOR SUB 2.997 7,300.5 5,916.9 24.85 PBR 5.875 BAKER 80-40 PBR **SHEARED** 2.997 7,313.5 5,928.7 24.72 PACKER 6.000 BAKER FHL 47 B2 PACKER 2.930 7,353.9 5,965.5 24.33 NIPPLE 4.375 OTIS NO GO X NIPPLE 2.810 7,355.3 5,966.7 24.31 OVERSHOT 5.750 OTIS SBR OVERSHOT w/ 2.813" X PROFILE 4.750 Top (ftKB) 7,362.0 Set Depth … 6,330.8 String Ma… 3 1/2 Tubing Description TUBING Original Set Depth (ftKB) 7,757.2 Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,362.0 5,972.9 24.25 SBR 4.750 OTIS SBR SLICK STICK 2.992 7,388.2 5,996.8 23.99 PACKER 5.980 OTIS RRH PACKER , 60000# SHEAR 2.970 7,531.4 6,128.0 23.50 BLAST RINGS 3.500 2.992 7,562.2 6,156.3 23.62 BLAST RINGS 3.500 BLAST JOINTS w/ 1" CARBIDE RINGS 2.992 7,718.6 6,299.1 27.94 LOCATOR 4.000 OTIS ST SLOT LOCATOR 3.000 7,719.8 6,300.2 28.35 SEAL ASSY 4.500 OTIS SEAL ASSEMBLY 3.000 7,725.9 6,305.5 30.41 MULE SHOE 3.500 OTIS MULE SHOE GUIDE 2.992 7,726.8 6,306.3 30.71 PACKER 6.156 OTIS WD PACKER 4.000 7,730.4 6,309.4 31.93 MILL 3.500 MILL OUT EXTENSION 2.992 7,746.7 6,322.7 37.77 NIPPLE 4.750 CAMCO D NIPPLE NO GO 2.750 7,756.4 6,330.2 41.25 WLEG 4.570 OTIS WIRELINE RE-ENTRY GUIDE 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Make Model SN ID (in) 4,732.0 3,920.6 44.09 CSG PATCH PRODUCTION CASING PATCH SET DURING WORKOVER (OAL= 567') 3.750 4,755.0 3,937.1 44.15 LEAK - P- CASING Production casing leak at 4755' repaired with SealTite 6.280 5,940.0 4,805.1 42.69 LEAK - TUBING TUBING LEAK (IDENTIFIED ON LDL RUN 7/9/22) 2.992 7,354.0 5,965.5 24.33 TUBING PLUG 2.813" XX PLUG (48" OAL & HAS 8-3/16 EQ PORTS) 0.000 7,634.0 6,221.9 23.86 PACKER Northern Solutions Liner Top Packer, Spacer pipe, & Stinger w/ 1.78" RX Nipple (18.4' OAL) NSP21 1.780 7,650.0 6,236.6 23.90 TUBING PLUG 1.78" RX Plug w/ Seal Guide 0.000 7,705.0 6,286.8 24.01 WHIPSTOCK NS Monobore WS Northern Solutions Monobore 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,103.9 2,715.9 39.81 1 GAS LIFT GLV BTM 1 1,368.0 5/9/2022 6:00 0.188 4,652.7 3,863.5 43.84 2 GAS LIFT GLV BTM 1 1,348.0 5/9/2022 11:00 0.188 5,832.8 4,726.0 42.28 3 GAS LIFT GLV BTM 1 1,330.0 5/9/2022 12:30 0.188 6,697.4 5,389.4 32.95 4 GAS LIFT GLV BTM 1 1,315.0 7/20/2022 8:30 0.188 7,245.2 5,866.8 25.28 5 GAS LIFT OV BTM 1 0.0 5/9/2021 12:30 0.188 1G-13A, 8/1/2022 8:57:32 AM Vertical schematic (actual) Slotted Liner; 7,649.1-10,090.0 PRODUCTION; 31.8-8,087.1 FISH; 7,956.0 FISH; 7,940.0 PACKER; 7,819.0 RPERF; 7,800.0-7,846.0 APERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 TUBING PLUG; 7,650.0 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze – Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 TUBING PLUG; 7,354.0 PACKER; 7,313.5 GAS LIFT; 7,245.2 GAS LIFT; 6,697.4 LEAK - TUBING; 5,940.0 GAS LIFT; 5,832.8 CSG PATCH; 4,732.0 LEAK - P-CASING; 4,755.0 GAS LIFT; 4,652.7 GAS LIFT; 3,103.9 SURFACE 45.5#/55.5#; 37.5- 2,443.9 NIPPLE; 480.4 CONDUCTOR; 37.5-105.0 KUP PROD KB-Grd (ft) 41.00 RR Date 10/11/198 3 Other Elev… 1G-13A ... TD Act Btm (ftKB) 10,307.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292101601 Wellbore Status PROD Max Angle & MD Incl (°) 100.30 MD (ftKB) 9,850.46 WELLNAME WELLBORE1G-13 Annotation End DateH2S (ppm) 165 Date 7/31/2015 Comment Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,425.1 6,030.5 23.75 6 PROD OPEN OPEN 1 0.0 5/8/2022 3:30 0.000 7,493.3 6,093.1 23.40 7 PROD OPEN 1 0.0 10/15/2000 0.000 7,679.9 6,263.9 23.97 8 PROD DPHF CV Broke 1 0.0 10/15/2000 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,541.0 7,596.0 6,136.8 6,187.2 C-4, C-3, 1G-13 12/1/1983 12.0 IPERF GO 5" TCP 7,626.0 7,640.0 6,214.6 6,227.4 C-1, 1G-13 12/1/1983 12.0 IPERF GO 5" TCP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,400.0 7,727.0 6,007.5 6,306.4 Squeeze – Behind Casing Squeeze 15.8 PPG CLASS G CEMENT. 5/25/2022 7,400.0 7,747.0 6,007.5 6,322.9 Plug – Kick-Off Plug 15.8 PPG CLASS G CEMENT, MILLED OUT DOWN TO CA-2 PLUG @ 7747' 5/25/2022 1G-13A, 8/1/2022 8:57:32 AM Vertical schematic (actual) Slotted Liner; 7,649.1-10,090.0 PRODUCTION; 31.8-8,087.1 FISH; 7,956.0 FISH; 7,940.0 PACKER; 7,819.0 RPERF; 7,800.0-7,846.0 APERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 TUBING PLUG; 7,650.0 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze – Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 TUBING PLUG; 7,354.0 PACKER; 7,313.5 GAS LIFT; 7,245.2 GAS LIFT; 6,697.4 LEAK - TUBING; 5,940.0 GAS LIFT; 5,832.8 CSG PATCH; 4,732.0 LEAK - P-CASING; 4,755.0 GAS LIFT; 4,652.7 GAS LIFT; 3,103.9 SURFACE 45.5#/55.5#; 37.5- 2,443.9 NIPPLE; 480.4 CONDUCTOR; 37.5-105.0 KUP PROD 1G-13A ... WELLNAME WELLBORE1G-13 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,927.0 3/26/2022 1G-13 spilch Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set GLV, Pulled Catcher, & Set XX Plug 7/21/2022 1G-13 zembaej Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Make Model SN ID (in) 7,710.0 6,291.4 24.00 TUBING PUNCH PRE-CTD TUBING PUNCHG, 4 SPF -> 21 HOLES 2.992 7,747.0 6,325.2 23.93 TUBING PLUG 2.75" CA-2 PLUG 0.000 7,819.0 6,391.1 23.80 PACKER 1.867 7,940.0 6,501.8 23.58 FISH KickOver Tool Tray & 1" CV Lost Downhole on 9/17/89 7,956.0 6,516.5 23.55 FISH SHUT-IN TOOL ELECTRONIC SHUT-IN TOOL PARTED, LEAVING LOWER PORTION @7956' w/SHOCK ABSORBER & DUAL GAUGES BELOW 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,800.0 7,846.0 6,373.7 6,415.8 A-4, A-3, 1G-13 8/7/1984 4.0 APERF DA Csg Gun; 90 deg phasing 7,800.0 7,846.0 6,373.7 6,415.8 A-4, A-3, 1G-13 10/13/1992 4.0 RPERF Atlas 2 5/8 Jumbo Jet; 180 deg phasing Notes: General & Safety End Date Annotation 7/4/2022 NOTE: Slickline Identified Tbg Leak Between 5937'-5967' 7/8/2019 Note: SealTite repaired PC leak at 4755' 9/17/2010 NOTE: 1G-13, 8/1/2022 8:57:30 AM Vertical schematic (actual) PRODUCTION; 31.8-8,087.1 Slotted Liner; 7,649.1-10,090.0 FISH; 7,956.0 FISH; 7,940.0 PACKER; 7,819.0 RPERF; 7,800.0-7,846.0 APERF; 7,800.0-7,846.0 TUBING PLUG; 7,747.0 PACKER; 7,726.8 TUBING PUNCH; 7,710.0 WHIPSTOCK; 7,705.0 PRODUCTION; 7,679.9 TUBING PLUG; 7,650.0 PACKER; 7,634.0 IPERF; 7,626.0-7,640.0 IPERF; 7,541.0-7,596.0 PRODUCTION; 7,493.3 PRODUCTION; 7,425.1 Squeeze – Behind Casing Squeeze; 7,400.0 ftKB PACKER; 7,388.2 TUBING PLUG; 7,354.0 PACKER; 7,313.5 GAS LIFT; 7,245.2 GAS LIFT; 6,697.4 LEAK - TUBING; 5,940.0 GAS LIFT; 5,832.8 CSG PATCH; 4,732.0 LEAK - P-CASING; 4,755.0 GAS LIFT; 4,652.7 GAS LIFT; 3,103.9 SURFACE 45.5#/55.5#; 37.5- 2,443.9 NIPPLE; 480.4 CONDUCTOR; 37.5-105.0 KUP PROD KB-Grd (ft) 41.00 RR Date 10/11/198 3 Other Elev… 1G-13 ... TD Act Btm (ftKB) 8,110.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292101600 Wellbore Status PROD Max Angle & MD Incl (°) 44.32 MD (ftKB) 4,500.00 WELLNAME WELLBORE1G-13 Annotation Last WO: End Date 7/31/2005 H2S (ppm) 165 Date 7/31/2015 Comment SSSV: NIPPLE ! " # $ % & ' ( ( )* + , - , . ! ! / - $ 0 1 ' 0 2 3 2 " ) 4 . 5 - 4 " # 6 7 6 8 9 3 : 5 / . # - 7 " / 7 6 8 9 : ; 5 / . # - 7 " / < < = 0 . ! ! / - $ 0 1 ' 9 > " ? 9 ; 9 > " @ ! 6 > " A . ! ! / $ 0 1 ' ,9 ; B " - - *" . 5 . / 7 ! / - . # " 7 * - . , 9 ; / . 6 > - . 6 > - C. - A ! " # . / $ 0 1 ' *- . ; ; ! 6 > " - *- . ! " 4 6 - . 7 " / - < < *- . , / 7 / = 7 4 / - *- . + ! 6 > " - . ! ! / - $ 0 1 ' D - ( ? / 4 5 - - E ! " # ! " . " - ) E ! " # $! / 4 5 5 ' 6 . 5 ! - 6 : E ? 9 ) 9. / / - - < : E ) < ! " # $ % ! " & ' ( # $ ) * : E 8 * ? < Page 1/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/20/2022 20:00 6/20/2022 22:30 2.50 MIRU, MOVE RURD P Rig down checklist, prep shop for transport, load out misc trucks and equipment , prep for transport of rig 0.0 0.0 6/20/2022 22:30 6/20/2022 23:30 1.00 MIRU, MOVE DMOB P Truck on location 22:30, load shop 0.0 0.0 6/20/2022 23:30 6/20/2022 23:45 0.25 MIRU, MOVE DMOB P PJSM w NES rig move crew. 0.0 0.0 6/20/2022 23:45 6/21/2022 00:00 0.25 MIRU, MOVE DMOB P Jack the service mod, attach sow, pull outer mats and start to pull off well row. 0.0 0.0 6/21/2022 00:00 6/21/2022 00:21 0.35 MIRU, MOVE DMOB P Continue to pull the service module off well row. 0.0 0.0 6/21/2022 00:21 6/21/2022 00:42 0.35 MIRU, MOVE DMOB P Jack the sub and pull the mats. 0.0 0.0 6/21/2022 00:42 6/21/2022 01:03 0.35 MIRU, MOVE DMOB P Pull sub from well row and de-sow. 0.0 0.0 6/21/2022 01:03 6/21/2022 01:45 0.70 MIRU, MOVE DMOB P Jeep uo service and sub module, line up on pad with pull and weighted sows. Final walk around. 0.0 0.0 6/21/2022 01:45 6/21/2022 05:45 4.00 MIRU, MOVE MOB P Roll off 3A-18 to 1G-13 @ 01:45 2:45 CPF 3 main pad 05:00 pull off spine on to G&R access road. 0.0 0.0 6/21/2022 05:45 6/21/2022 06:00 0.25 MIRU, MOVE RURD P On pad, crew change, 0.0 0.0 6/21/2022 06:00 6/21/2022 06:21 0.35 MIRU, MOVE RURD P Pull pits to well row, drop sow and jeep, reatach sow, and spot on edge of pad. 0.0 0.0 6/21/2022 06:21 6/21/2022 08:00 1.65 MIRU, MOVE RURD P Pull Sub on well row, de-jeep, spot sub over 1G-13, set mats, set sub. 0.0 0.0 6/21/2022 08:00 6/21/2022 08:45 0.75 MIRU, MOVE RURD P Spott innerr mats, spot service module, place remaining mats, set module. 0.0 0.0 6/21/2022 08:45 6/21/2022 09:30 0.75 MIRU, MOVE RURD P Safe out landings and stairs. 0.0 0.0 6/21/2022 09:30 6/21/2022 14:00 4.50 MIRU, MOVE RURD P Work RU Checklist Rig up PUTZ, start to inventory pits with seawater and used powerpro milling fluid. Hook up steam, Nipple up stack *** Rig accept 14:00 0.0 0.0 6/21/2022 14:00 6/21/2022 18:30 4.50 MIRU, WHDBOP RURD P Continue to work RU check list, harvest RKB's, 0.0 0.0 6/21/2022 18:30 6/22/2022 00:00 5.50 MIRU, WHDBOP BOPE P BOPE test to 250 psi low / 4,000 psi high Witness waived AOGCC Adam Earl Test 1. Swab 2- Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 -Pass Test 3. BOP TV 1, Charlie 3, 7, & 11 - Pass Test 4. Manual choke D & Super choke C - Pass Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 - Pass Test 6. Charlie 1, 9, Bravo 5, and Tango 1 –Pass - install TIW test joint - Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 -Pass 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 2/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/22/2022 00:00 6/22/2022 04:00 4.00 MIRU, WHDBOP BOPE P Test 8. Annular BOP 250/2500- Test 9. Upper 2” pipe slip rams, Bravo 6, & 8-Pass Test 10. Bravo 7 – swap out 2” test joint for 2-3/8”-Pass Test 11. 2-3/8” pipe slip rams, TIW#2 – Pass- Test 12. Draw down accumulator- 1900 N2 average // Koomy 3000 start 2350 End 23 sec to 200 49 sec to full charge 3000 psi Tested all gas detectors, pits, cellar, Verified flow alarms - PVT 0.0 0.0 6/22/2022 04:00 6/22/2022 05:30 1.50 MIRU, WHDBOP CTOP P Stab injector and line up to reverse circulate coil, test inner reel valve and stripper-Pass 0.0 0.0 6/22/2022 05:30 6/22/2022 06:00 0.50 MIRU, WHDBOP CTOP P PT tiger tank line and ODS PDL - the only PDL 0.0 0.0 6/22/2022 06:00 6/22/2022 06:30 0.50 MIRU, WHDBOP CTOP P Blow down test eq and choke 0.0 0.0 6/22/2022 06:30 6/22/2022 08:00 1.50 MIRU, WHDBOP CTOP P Swap MM2, and MM6, install checks, inspect pack offs, Test for pressure below master - Zero. OPEN up, fill the hole - 1.9 bbls. 0.0 0.0 6/22/2022 08:00 6/22/2022 09:06 1.10 MIRU, WHDBOP PULD P PJSM, PU BHA #1, NS Inner wedge WS. 0.0 73.0 6/22/2022 09:06 6/22/2022 11:00 1.90 MIRU, WHDBOP TRIP P RIH W BHA #1 Start power pro down the coil WOB bobbles at 7,367' to 2.5 k lbs, 7,379' to 1.5 k lbs & 7,420' to 1.7 k lbs Set down hard at 7,440' 5 to 6 k WOB three times 73.0 7,444.0 6/22/2022 11:00 6/22/2022 14:48 3.80 MIRU, WHDBOP TRIP T PU wt 37 k lbs, WOB to -2.37 k lbs. POOH Pulled up into -2.7 k WOB three times @ 7372' Geo says -18' correction Pulled through the 4th time - continue out of hole 7,444.0 74.0 6/22/2022 14:48 6/22/2022 15:24 0.60 SLOT, WELLPR PULD T LD BHA #1 over a dead well. 73.0 0.0 6/22/2022 15:24 6/22/2022 16:00 0.60 SLOT, WELLPR PULD T PU BHA #2 - Clean out assembly over a dead well. 0.0 64.0 6/22/2022 16:00 6/22/2022 17:30 1.50 SLOT, WELLPR TRIP T RIH with clean out assembly 64.0 7,300.0 6/22/2022 17:30 6/22/2022 20:00 2.50 SLOT, WELLPR REAM T Ream down cleaning up spots 7376',7419',7419-7422, // Clean down to 7735' // K1 area too hot to tie in // PU 30K 90ROHS T/ 7740 reaming Repeated @ 180, 270, HS, dry drift clean pump sweeps for POOH Dry Drift Clean 7300 - 7740 7,300.0 7,740.0 6/22/2022 20:00 6/22/2022 21:30 1.50 SLOT, WELLPR TRIP T POOH for WS 7,740.0 50.0 6/22/2022 21:30 6/22/2022 22:15 0.75 SLOT, WELLPR PULD T Lay down BHA# 2 Clean out assembly 50.0 0.0 6/22/2022 22:15 6/22/2022 23:15 1.00 SLOT, WELLPR PULD T PU BHA# 3 WS Setting Assembly // Swap out gamma tool for comparison // 0.0 50.0 6/22/2022 23:15 6/23/2022 00:00 0.75 SLOT, WELLPR TRIP T Tag up and set counters // RIH min rate EDC open 50.0 1,900.0 6/23/2022 00:00 6/23/2022 01:15 1.25 SLOT, WELLPR TRIP T RIH w/ BHA# 3 WS Setting Assembly 1,900.0 7,280.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 3/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/23/2022 01:15 6/23/2022 02:15 1.00 SLOT, WELLPR DLOG P Log HRZ for -9' Correction Start Log @ 7280' Log again @ 7420' gamma wrap again max out tool RIH to 7500' CCL T/ 7730' 32K PU 7,280.0 7,730.0 6/23/2022 02:15 6/23/2022 02:51 0.60 SLOT, WELLPR WPST P PU WT 32K // Run WS to setting Depth 7705 TOWS 7716.21' Bit Depth Orient HS // Pump .5bpm PP 3300 Diff 1810 DHWOB 3.5K // set down 6.5K // PU 40K -6.8 DHWOB Tool did not shear off // set down pump 1.5 bpm Diff up to 2000 then down to 1600 // Flow in 1.5 Flow out 1.1 // PU 32K WS Released 7,730.0 7,716.2 6/23/2022 02:51 6/23/2022 04:15 1.40 SLOT, WELLPR TRIP P Open EDC POOH for window mill assembly # 1 7,716.2 50.0 6/23/2022 04:15 6/23/2022 05:30 1.25 SLOT, WELLPR PULD P PJSM / Flow check well for Lay down bha on dead well, reconfigure tool. 50.0 0.0 6/23/2022 05:30 6/23/2022 06:12 0.70 SLOT, WELLPR PULD P PU BHA # 4 WS milling assembly 1st run - BHI 0.6° AKO with wear band turned in, diamond string reamer ( rerun) and fresh diamond speed mill. 2.80" no go on DSM. 0.0 74.7 6/23/2022 06:12 6/23/2022 07:30 1.30 SLOT, WELLPR TRIP P RIH W BHA #4 milling assembly #1. 74.7 7,280.0 6/23/2022 07:30 6/23/2022 07:45 0.25 SLOT, WELLPR DLOG P Tie into the HRZ for a -10' correction, close EDC PU Wt 44 k lbs 7,280.0 7,328.0 6/23/2022 07:45 6/23/2022 08:09 0.40 SLOT, WELLPR TRIP P Continue on in hole, dry tag TOB at 7706', set 4.2 k WOB , PU 44 k lbs. Set rate cree pback in hole 7,328.0 7,705.3 6/23/2022 08:09 6/23/2022 17:09 9.00 PROD1, WHPST WPST P WH 0 psi, IA 2 psi, OA 503 psi, CT 3,483 psi, AT 1.86 bpm in and 1.86 bpm out, BHP 3417 psi, not yet targeting 11.8 ppg at window - sealed well no exit. Free spin diff 461 psi. CT Wt 18 k lbs, 7,705.7' - engage auto drill at 1 ft/hr - CT 18 k lbs, WOB 0.8 k 7,706.1 - WOB up to 1.9 k lbs, park and let mill off for a min - reengage 7,706.5' Increase WOB target to 2.0 - 2.5 k lbs - CT Wt 16 k lbs, WOB 2.5 k lbs 7,7076.9' Well started drinking a little fluid, had been 10.5 ppg EMW, increased BH to 11 ppg with choke 7,707.5' Motor work increased sharply, WOB started falling off ~3' in, cross cutting 3.5 7,708.8' @ 1 ft/hr, CT 15.6 k, 2.03 k WOB, 7,705.3 7,711.3 6/23/2022 17:09 6/23/2022 17:54 0.75 PROD1, WHPST WPST P Perform reaming passes X 3 // dry drift clean 7,711.3 7,711.3 6/23/2022 17:54 6/23/2022 19:24 1.50 PROD1, WHPST TRIP P POOH for window mill assembly# 2 7,711.3 60.0 6/23/2022 19:24 6/23/2022 19:54 0.50 PROD1, WHPST PULD P Lay down BHA# 3 Window Mill Assembly# 1 Window Mill 2.80 G 2.79 NG String Reamer 2.80 NG 60.0 0.0 6/23/2022 19:54 6/23/2022 20:39 0.75 PROD1, WHPST PULD P Pick up BHA# 4 Window mill assembly# 2 1.25° FB Motor w/ 2.80 FR window mill and 2.80 string reamer 0.0 60.0 6/23/2022 20:39 6/23/2022 22:39 2.00 PROD1, WHPST TRIP P Tag up and set counters, RIH w/ BHA# 4 window mill assembly# 2 60.0 7,711.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 PU WT 32K // Run WS to setting Depth g 7705 TOWS 7716.21' Bit Depth p Orient HS // Pump .5bpm PP 3300 Diffpp 1810 DHWOB 3.5K // set down 6.5K // PU 40K -6.8 DHWOB Tool did not shear off // set down pump 1.5 bpm Diff up topp p p 2000 then down to 1600 // Flow in 1.5 Flow out 1.1 // PU 32K WS Released Page 4/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/23/2022 22:39 6/24/2022 00:00 1.35 PROD1, WHPST WPST P Mill second Exit starting @ 7713.04 per proceedure 1.28 DHWOB 1030 diff 4000 pump pressure // Hand advance coil till step 14 per program 7,711.0 7,713.4 6/24/2022 00:00 6/24/2022 03:24 3.40 PROD1, WHPST WPST P Mill second Exit starting @ 7713.44 per proceedure 1.28 DHWOB 1030 diff 4000 pump pressure // Hand advance coil till step 14 per program 7,713.4 7,716.3 6/24/2022 03:24 6/24/2022 04:54 1.50 PROD1, WHPST WPST P Drill rat hole to 7730 7,716.3 7,730.0 6/24/2022 04:54 6/24/2022 06:39 1.75 PROD1, WHPST REAM P Perform reaming passes, at, as milled, 30 L 30 R and 180° from HS. dry drift - Clean 7,730.0 7,730.0 6/24/2022 06:39 6/24/2022 08:09 1.50 PROD1, WHPST TRIP P PU Wt 34 k lbs, PUH into tubing, open EDC. Pull -4 k CT Wt and -3 k WOB at ~7357' - X nipple. 7,730.0 67.0 6/24/2022 08:09 6/24/2022 09:15 1.10 PROD1, WHPST PULD P PUD BHA #5, string reamer 2.79" no go, fat radius mill 2.78" no go. 67.0 0.0 6/24/2022 09:15 6/24/2022 10:09 0.90 PROD1, WHPST CIRC P Jet stack 0.0 0.0 6/24/2022 10:09 6/24/2022 11:39 1.50 PROD1, WHPST PULD P PD BHA #6, build drilling assembly with 2.2° AKO motor and rebuilt HCC dynamus bit. 0.0 67.0 6/24/2022 11:39 6/24/2022 12:51 1.20 PROD1, WHPST TRIP P RIH W BHA #6 67.0 7,254.0 6/24/2022 12:51 6/24/2022 13:03 0.20 PROD1, WHPST DLOG P Tie into the HRZ for a -8' correction. 7,254.0 7,313.0 6/24/2022 13:03 6/24/2022 13:30 0.45 PROD1, WHPST PULD P Continue in hole, park and close EDC, PU Wt 32 k lbs, run through window - clean Set rate WH 373 psi, IA 5 psi, OA 254 psi, CT 3,886 psi at 1.85 bpm in and 1.81 bpm out, BHP 3850 psi, targeting 11.8 ppg EMW, Free spin 498 psi, CT RIH Wt 13.88 k lbs, 7,313.0 7,730.0 6/24/2022 13:30 6/24/2022 17:42 4.20 PROD1, DRILL DRLG P OBD ran into clay ~70' past the window. Targeted lower WOB with better ROP of ~70 ft/hr. 10-15 ft/h when stacked out. 7,730.0 7,865.0 6/24/2022 17:42 6/24/2022 19:54 2.20 PROD1, DRILL TRIP P Pump sweeps POOH for lateral assembly // Tag up and space out 1.2' for pressure un-deploy // 7,865.0 80.0 6/24/2022 19:54 6/24/2022 21:06 1.20 PROD1, DRILL PULD P PJSM // PUD BHA$# 6 Build assembly 80.0 0.0 6/24/2022 21:06 6/24/2022 22:30 1.40 PROD1, DRILL PULD P PD BAH# 7 Lateral Assembly 0.0 80.0 6/24/2022 22:30 6/25/2022 00:00 1.50 PROD1, DRILL TRIP P Tag up set counters // RIH w/ BHA# 7 .5°+ AKO w/ HCC ( New Design Bit X32510) 80.0 6,500.0 6/25/2022 00:00 6/25/2022 00:15 0.25 PROD1, DRILL TRIP P Tag up set counters // RIH w/ BHA# 7 .5°+ AKO w/ HCC ( New Design Bit X32510) 6,500.0 7,280.0 6/25/2022 00:15 6/25/2022 00:30 0.25 PROD1, DRILL DLOG P Log HRZ for depth control // -8' correction 7,280.0 7,340.0 6/25/2022 00:30 6/25/2022 00:42 0.20 PROD1, DRILL TRIP P RIH to window for wt check and close EDC // Log RA Tag @ 7712' // RIH to bottom for drilling 7,340.0 7,885.0 6/25/2022 00:42 6/25/2022 03:15 2.55 PROD1, DRILL DRLG P OBD F/ 7885' T/ 8032 1.82 3946 pp 508 diff Ann 3909 1.82 in 1.81 out MW in 8.74 MW out 8.79 ROP= 100'/hr + 7,885.0 8,032.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 OBD F/ 7885' T/ 8032 Page 5/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/25/2022 03:15 6/25/2022 06:30 3.25 PROD1, DRILL DRLG P Drilling breal to 8070' then apeared to fault out of zone. DROP down to 15-7 ft/hr. Heavy clay on the shakers, nigh Geo lost. Cut 8,050-8,55 cut 150 - 164 API gamma rock. 8,032.0 8,121.0 6/25/2022 06:30 6/25/2022 11:30 5.00 PROD1, DRILL DRLG P PU Wt 36 k lbs, WH 420 psi, IA 6 psi, OA 568 psi, CT 4,087 PSI 1.84 bpm in 1.87 bpm out BHP 3923 psi, targeting 11.8 ppg at the window. CT RIH wt 15.5 k lbs, Free spin 500 psi, WOB Geos instructed DD to turn straight down. Clay balls raining off shaker. CT PU Wt clean and consistently 36 k lbs. Geos called it,pulling for plug back. 8,121.0 8,172.0 6/25/2022 11:30 6/25/2022 13:54 2.40 PROD1, DRILL TRIP T PU Wt 33 lbs, PUH cleaning up for open hole anchored billet Settign area clean, window clean. park and open EDC Continue out of hole pumping 2.3 bpm POOH. 8,172.0 64.0 6/25/2022 13:54 6/25/2022 15:30 1.60 PROD1, DRILL PULD T PUD BHA # 7. 64.0 0.0 6/25/2022 15:30 6/25/2022 17:06 1.60 PROD1, DRILL PULD T PD BHA #8. BOT Open Hole Anchored Whipstock. WS and anchors 12.07' long, Billet 9.31' open hole anchors 2.76'. 0.0 73.2 6/25/2022 17:06 6/25/2022 18:24 1.30 PROD1, DRILL TRIP T RIH W BHA #8 OHAB.// 73.2 7,276.0 6/25/2022 18:24 6/25/2022 18:36 0.20 PROD1, DRILL DLOG T Tie in HRZ for -7.5' correction 7,276.0 7,340.0 6/25/2022 18:36 6/25/2022 19:06 0.50 PROD1, DRILL TRIP T PU Wt. 35K // RIH T/ 7882.09, pu to 30K // Pump .25bbl/min PP 4500 Diff 2163 DHWOB 3.05 // Good Set // Push 4.5 DHWOB set good // 7,340.0 7,882.0 6/25/2022 19:06 6/25/2022 21:00 1.90 PROD1, DRILL TRIP T POOH for drilling assembly // Tag up space out 1.2' // 7,882.0 60.0 6/25/2022 21:00 6/25/2022 22:30 1.50 PROD1, DRILL PULD T PUD BHA# 8 OHAB setting assembly // Lay down drilling tools 60.0 0.0 6/25/2022 22:30 6/26/2022 00:00 1.50 PROD1, DRILL PULD T PD BHA# 9 Lateral Assembly 0.0 72.0 6/26/2022 00:00 6/26/2022 02:00 2.00 PROD1, DRILL TRIP T Tag up set depth // RIH w/ BHA# 9 Lateral BHA .5+° AKO Extreme Motor w/ New Style HCC Bit // Tie in HRZ -7' correction // Dry tag Billet @ 7870 72.0 7,870.0 6/26/2022 02:00 6/26/2022 04:00 2.00 PROD1, DRILL KOST T 34K pu // 1.8 bpm 3800 psi 545 diff // Mill F/7869.8' T/7870.8 @ 1'/hr // F/ 7870.8 T/7871.8 @ 2'/hr // F/ 7871.8 T/7872.8 @ 3'/hr 7,870.0 7,872.8 6/26/2022 04:00 6/26/2022 08:48 4.80 PROD1, DRILL DRLG T Drill Ahead F/7872.8' T/8073 1.84 4046pp 499diff 3926ann 1.84 in 1.83 out MW in 8.72 MW out 8.76 7,872.8 8,073.0 6/26/2022 08:48 6/26/2022 09:00 0.20 PROD1, DRILL WPRT P PU Wt 35 k, pull short wiper to below billet, hole clean. RBIH 8,073.0 8,073.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 6/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/26/2022 09:00 6/26/2022 11:00 2.00 PROD1, DRILL DRLG P Back in sand BOBD WH 331 psi, IA 2 psi, OA 647 psi, CT 4137 psi, @ 1.85 in and out. Free spin 555 psi. BHP 3936 psi, holding 11.8 ppg EMW at the window, 11.86 ppg at the bit. CT WT 12 k WOB 2.4 - ROP 200-400 ft/hr Mud swap - New mud at the bit-8,136' , Ankerite stringers, 8,147'. PU for new parameters, CT 3920 psi at 1.85 bpm in and 1.85 bpm out, BHP 3945, WH 466 psi. New free spin 518 psi, CT Wt, increase target MW from 11.9 to 12.0 ppg EMW at the window to maintain 1 for 1. 8,073.0 8,211.0 6/26/2022 11:00 6/26/2022 16:36 5.60 PROD1, DRILL DRLG P OBD, WH 547, IA 2 psi, OA 594 psi, CT 4059 psi, @ 1.83 in & 1.83 bpm out. BHP 4035 psi, targeting 12.1 ppg EMW at the window, 12.16 at the bit. CT Wt 12 k lbs, WOB 1.78 Lots of ankerite stringers. ROP 280-30 ft/hr 8500 PU Wt 32 k lbs 8677 PU Wt 36 k lbs 8,211.0 8,852.0 6/26/2022 16:36 6/26/2022 17:36 1.00 PROD1, DRILL DRLG P PU Wt 35 k lbs Pull long wiper to window for tie in and verification of BHP.// Tie in +3' correction 8,852.0 7,270.0 6/26/2022 17:36 6/26/2022 17:45 0.15 PROD1, DRILL CTOP P Pressure Survey @ window 11.8 equiv 7,270.0 7,270.0 6/26/2022 17:45 6/26/2022 18:15 0.50 PROD1, DRILL TRIP P RIH to drill Ahead 7,270.0 8,852.0 6/26/2022 18:15 6/27/2022 00:00 5.75 PROD1, DRILL DRLG P OBD, WH 547, IA 2 psi, OA 594 psi, CT 4059 psi, @ 1.83 in & 1.83 bpm out. BHP 4035 psi, targeting 12.1 ppg EMW at the window, 12.16 at the bit. CT Wt 12 k lbs, WOB 1.78 9170 Run into Ankerite low rop 8,852.0 9,194.0 6/27/2022 00:00 6/27/2022 01:00 1.00 PROD1, DRILL DRLG P OBD, WH 547, IA 2 psi, OA 594 psi, CT 4059 psi, @ 1.83 in & 1.83 bpm out. BHP 4035 psi, targeting 12.1 ppg EMW at the window, 12.16 at the bit. CT Wt 12 k lbs, WOB 1.78 9170 Run into Ankerite low rop 9,194.0 9,242.0 6/27/2022 01:00 6/27/2022 01:24 0.40 PROD1, DRILL WPRT P PU Wt. 37K Pump sweeps pull 800' wiper to 8450' 9,242.0 8,450.0 6/27/2022 01:24 6/27/2022 01:42 0.30 PROD1, DRILL TRIP P Trip back to bottom for drilling 8,450.0 9,242.0 6/27/2022 01:42 6/27/2022 06:30 4.80 PROD1, DRILL DRLG P OBD F/ 9242' T/9300 1.82 bpm 4048 pp 490 diff 4109Ann 12.47 at bit 12.1 at window Ct. Wt. 12.8 DHWOB 2.25K Ankerite 9170'-9200' 9240'-9247' 9256'-9274' Stall at 9247' PU Wt. 37K Stall at 9273.93' PU Wt. 34K 9,242.0 9,300.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 7/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/27/2022 06:30 6/27/2022 13:12 6.70 PROD1, DRILL DRLG P Broke out, drilling ahead in faster sand PU Wt 36 k lbs, WH 466, IA 4 psi, OA 944 psi - bleed IA to 540 psi. CT 4008 psi at 1.83 bpm in and out. Stage BHP down in tenths to 11.8 ppg. Maintaining 1 for 1. BHP4023 at 11.8 ppg EMW at the window. 12.16 ppg at the bit. 9,441 - PU Wt 40 k lbs - FS 524 psi @ 1.85 bpm 9492' - PU Wt 40 k lbs - 9513' - PU Wt 40 k lbs - Bypass HP screens 9,513 - PU Wt 40 k stall - sent 5x5 with 2 ppb beads 9,300.0 9,534.0 6/27/2022 13:12 6/27/2022 18:12 5.00 PROD1, DRILL DRLG P In clay, slow ROP. CT Wt 9 k lbs, WOB 1.5 k lsb, RP ~30 ft/hr WH 344 psi, IA 3 psi, OA 610 psi, CT 4211 psi, BHP 4027 psi targeting 11.8 ppg EMW 9,534.0 9,670.0 6/27/2022 18:12 6/27/2022 18:42 0.50 PROD1, DRILL WPRT P Wiper up to 8849 9,670.0 9,670.0 6/27/2022 18:42 6/28/2022 00:00 5.30 PROD1, DRILL DRLG P OBD F/ 9670 T/ 9813 1.82 bpm 4112 pp 501 diff 4010 ann ( Free Spin ) MW in 8.68 MW out 8.78 9,670.0 9,813.0 6/28/2022 00:00 6/28/2022 05:36 5.60 PROD1, DRILL DRLG P OBD F/ 9670 T/ 9813 1.82 bpm 4112 pp 501 diff 4010 ann ( Free Spin ) MW in 8.68 MW out 8.78 9,813.0 10,050.0 6/28/2022 05:36 6/28/2022 05:54 0.30 PROD1, DRILL WPRT P PU Wt 35 k lbs PUH on scheduled wiper #2 10,050.0 9,248.0 6/28/2022 05:54 6/28/2022 06:15 0.35 PROD1, DRILL WPRT P RBIH, CT Wt 12 k to 9 k while RBIH - clean hole 9,248.0 10,050.0 6/28/2022 06:15 6/28/2022 08:30 2.25 PROD1, DRILL DRLG P WH 290 psi, IA 4 psi, OA 670 psi. CT 4,373 psi @ 1.84 bpm in & out. BHP 11.8 ppg EMWat the window, 4,081 psi, 12.47 ppg EMW at the bit. Free spin 543 psi. CT Wt 8 k with 1.8 k WOB. Prepare for mud swap. 10,095 PU Wt 36 k lbs - Free spin - 528 psi Exporting old mud to Tiger tank - New mud down the coil at 10,111 10,050.0 10,112.0 6/28/2022 08:30 6/28/2022 08:54 0.40 PROD1, DRILL WPRT P PU Wt 36 k lbs, PUH wiping to 9,589' while chasing new mud to the bit. Weight transfer shot, unable to keep WOB. - RBIH 10,112.0 10,112.0 6/28/2022 08:54 6/28/2022 10:54 2.00 PROD1, DRILL DRLG P BOB with new mud. WH 307 psi, IA 6 psi, OA 660 psi, CT 4,093 psi @ 1.84 bpm in & out. Targeting 11.8 ppg EMW at the window, BHP 4071 psi, 12.4 ppg at the bit. Free spin 513 psi. PU to acquire new mud parameters - PU Wt 33 k lbs, WH 507 psi, CT 416 psi, BHP 4051 targeting 11.8 ppg 12.4 ppg at the bit, Free spin 505 psi. RIH Ct Wt 12.7 k lbs BOBD, *** New mud at the bit 10112' 10,112.0 10,141.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 8/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/28/2022 10:54 6/28/2022 12:54 2.00 PROD1, DRILL DRLG P OBD, 1.82 bpm/4,135 psi/Diff 540 psi, WHP 467, BHP 4,058, IA 6, OA 597 Crossing fault @ ~10,090', looking like we are high in section, dropping to 87° to find sand PU's around 44 k CTSW Still good Weight to Bit Attempted pumping 10 beaded pill (1 ppb) no change Raised the lube in new mud system up 1% 776 w/no change 10,141.0 10,158.0 6/28/2022 12:54 6/28/2022 14:54 2.00 PROD1, DRILL DRLG P OBD, 1.82 bpm/4,135 psi/Diff 540 psi, WHP 467, BHP 4,058, IA 6, OA 597 10,158.0 10,172.0 6/28/2022 14:54 6/28/2022 16:30 1.60 PROD1, DRILL DRLG P OBD, 1.84 bpm/4,164 psi/DIff 540 psi, WHP 410, BHP 4,043, IA 6, OA 604 Drop INC to 87° looking for sand PUW's been around 44 k CTSW No change in ROP, still getting clay in samples. 10,172.0 10,193.0 6/28/2022 16:30 6/28/2022 17:48 1.30 PROD1, DRILL DRLG P OBD, 1.86 bpm/4,291 psi/DIff 576 psi, WHP 410, BHP 4,066, IA 6, OA 625 Drop INC to 85° looking for sand PUW's been around 44 k CTSW No change in ROP, still getting clay in samples. 10,193.0 10,212.0 6/28/2022 17:48 6/28/2022 17:54 0.10 PROD1, DRILL WPRT P BHA wiper, PUW=45K then 33K dragging. Clean pick up. Still low ROP 10,212.0 10,212.0 6/28/2022 17:54 6/28/2022 19:06 1.20 PROD1, DRILL DRLG P Drill, 1.86 BPM @ 4115 PSI FS, BHP=4077. CT weight-10.2K DHWOB=1.5K. ROP ~18FPH 10,212.0 10,230.0 6/28/2022 19:06 6/28/2022 19:42 0.60 PROD1, DRILL DRLG P Encountered high gamma. +150 for 10' section 10,230.0 10,240.0 6/28/2022 19:42 6/28/2022 20:12 0.50 PROD1, DRILL DRLG P Suspect big balling, low ROP with good weight transfer. Mix screen clean pill. ROP=15 FPH, Pump 20 BBl pill 10,240.0 10,247.0 6/28/2022 20:12 6/28/2022 20:24 0.20 PROD1, DRILL WPRT P Screen clean at bit. PUH RBIH hover above bottom. PUW=35K 10,247.0 10,247.0 6/28/2022 20:24 6/28/2022 22:30 2.10 PROD1, DRILL DRLG P Drilling, 1.85 BPM @ 4080 PSI FS, BHP=4035, ROP=25FPM. Very little inprovment in ROP. Pump second pill down 10,247.0 10,300.0 6/28/2022 22:30 6/28/2022 22:30 PROD1, DRILL WPRT P Call TD, Pump 10 X 10 sweeps start swab wiper, PUW=37K 7898 Midnight 10,300.0 7,898.0 6/29/2022 00:00 6/29/2022 01:48 1.80 PROD1, DRILL WPRT P Continue with swab wiper 7,898.0 65.0 6/29/2022 01:48 6/29/2022 03:12 1.40 PROD1, DRILL WPRT P Tag up at surface, Reset cpunters, RBIH 65.0 7,280.0 6/29/2022 03:12 6/29/2022 03:24 0.20 PROD1, DRILL DLOG P Log GR tie in for -7' correction 7,280.0 7,321.0 6/29/2022 03:24 6/29/2022 03:30 0.10 PROD1, DRILL WPRT P Continue in well 7,321.0 7,651.0 6/29/2022 03:30 6/29/2022 03:54 0.40 PROD1, DRILL PRTS P Perform static pressure test, MD 7650'. Sensor depth TVD 6199'. Annular pressure 3821 PS, EMW=11.8 15 minutes later Annular pressure 3599psi, EMW=11.2 and dropping. Prepare liner running pill and completion fluid to plan prefered mud weight 11.8PPG 7,651.0 7,651.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 9/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/29/2022 03:54 6/29/2022 05:54 2.00 PROD1, DRILL WPRT P Continue in well, clean pass through window Confirm TD 10,307' 7,651.0 10,307.0 6/29/2022 05:54 6/29/2022 07:06 1.20 PROD1, DRILL TRIP P POOH, laying in beaded LRP up to the window 10,307.0 7,700.0 6/29/2022 07:06 6/29/2022 09:06 2.00 PROD1, DRILL TRIP P Continue POOH, 7,700.0 72.2 6/29/2022 09:06 6/29/2022 09:36 0.50 PROD1, DRILL OWFF P At surface, check well for flow Unstab INJH, inspect pipe (good) 72.2 72.2 6/29/2022 09:36 6/29/2022 10:06 0.50 PROD1, DRILL BHAH P LD tools BHA #9 over a dead well 72.2 0.0 6/29/2022 10:06 6/29/2022 10:36 0.50 PROD1, DRILL CTOP P Perfrom Function test of BOPE RD equipment 0.0 0.0 6/29/2022 10:36 6/29/2022 10:54 0.30 COMPZ1, CASING PUTB P Prep RF for liner ops PJSM for PU A Liner segement #1 0.0 0.0 6/29/2022 10:54 6/29/2022 12:30 1.60 COMPZ1, CASING PUTB P PU A Liner complition w/35 jts of slotted liner, non-ported BN, and QCLL 0.0 1,080.9 6/29/2022 12:30 6/29/2022 13:00 0.50 COMPZ1, CASING BHAH P PU BHI CoilTrak tools Surface test tools (good) 1,080.9 1,124.7 6/29/2022 13:00 6/29/2022 15:00 2.00 COMPZ1, CASING RUNL P Tag up, reset counter depths, RIH Pumping min rate Correct to the EOP flag minus 12.5' PUW 34 k CTSW, minus 8.0k DHWOB 1,124.7 8,350.0 6/29/2022 15:00 6/29/2022 15:12 0.20 COMPZ1, CASING DLOG P Log the HRZ plus 4.0' (minus 8.0') 8,350.0 8,386.0 6/29/2022 15:12 6/29/2022 15:42 0.50 COMPZ1, CASING TRIP P Continue IH PUW 39 k CTSW, minus 6.2 k DHWOB 8,386.0 10,090.0 6/29/2022 15:42 6/29/2022 16:00 0.30 COMPZ1, CASING RUNL P Bring pump up to 1.6 bpm/Diff 1,200 psi PUW 30 k, minus 4.0 k DHWOB 10,090.0 9,009.1 6/29/2022 16:00 6/29/2022 16:42 0.70 COMPZ1, CASING RUNL P Hesitate for second beaded LRP Send it down coil 9,009.1 9,009.1 6/29/2022 16:42 6/29/2022 18:42 2.00 COMPZ1, CASING TRIP P POOH, laying beaded LRP 9,009.1 44.2 6/29/2022 18:42 6/29/2022 19:12 0.50 COMPZ1, CASING OWFF P At surface, check well for flow 44.2 44.2 6/29/2022 19:12 6/29/2022 19:24 0.20 COMPZ1, CASING PULD P LD setting tools over a dead well 44.2 0.0 6/29/2022 19:24 6/29/2022 19:42 0.30 COMPZ1, CASING RURD P Prep RF for liner ops 0.0 0.0 6/29/2022 19:42 6/30/2022 00:36 4.90 COMPZ1, CASING PUTB P PU second & final liner segment w/ 38 jts of slotted liner, swell packer, and disovable bullnose. 0.0 1,190.0 6/30/2022 00:00 6/30/2022 01:00 1.00 COMPZ1, CASING PUTB P Continue PU Liner 1,190.0 1,358.7 6/30/2022 01:00 6/30/2022 01:48 0.80 COMPZ1, CASING BHAH P PU CoilTrak tools, BHA #11 Surface test (good) 1,358.7 1,403.0 6/30/2022 01:48 6/30/2022 03:06 1.30 COMPZ1, CASING RUNL P Tag up, reset counter depths, RIH 1,403.0 7,614.0 6/30/2022 03:06 6/30/2022 03:18 0.20 COMPZ1, CASING RUNL P Correct to the flag depth, -10.6' correction 7,614.0 7,604.0 6/30/2022 03:18 6/30/2022 03:24 0.10 COMPZ1, CASING RUNL P RIH 7,604.0 8,620.0 6/30/2022 03:24 6/30/2022 03:36 0.20 COMPZ1, CASING DLOG P Log formation for depth, +2.0' PUW 41 k, -4k DHWOB 8,620.0 8,620.0 6/30/2022 03:36 6/30/2022 03:48 0.20 COMPZ1, CASING TRIP P Continue RIH 8,620.0 9,009.0 6/30/2022 03:48 6/30/2022 04:00 0.20 COMPZ1, CASING RUNL P Latch into QCLL, PUW 44 k CTSW, - 15k DHWOB 9,009.0 9,009.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 Page 10/10 1G-13 Report Printed: 7/25/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/30/2022 04:00 6/30/2022 04:18 0.30 COMPZ1, CASING RUNL P Release liner on depth, 1.8 bpm/1,200 psi diff, PUW 32 k BOL = 10,090', TOL = 7,649' 9,009.0 7,649.0 6/30/2022 04:18 6/30/2022 04:36 0.30 DEMOB, WHDBOP TRIP P Perform static above window 11.8 ppg, 3,787 psi, sensor depth 6,099' 7,649.0 7,620.0 6/30/2022 04:36 6/30/2022 06:06 1.50 DEMOB, WHDBOP DISP P Displace well to SW 7,620.0 2,635.0 6/30/2022 06:06 6/30/2022 07:24 1.30 DEMOB, WHDBOP FRZP P Freeze protect wel from 2,500' 2,635.0 44.3 6/30/2022 07:24 6/30/2022 09:24 2.00 DEMOB, WHDBOP PULD P Tag up, spaceout, PUD BHA #11 44.3 0.0 6/30/2022 09:24 6/30/2022 10:42 1.30 DEMOB, WHDBOP CLEN P Flush stack and surface Lines pull checks for next well 0.0 0.0 6/30/2022 10:42 6/30/2022 15:00 4.30 DEMOB, WHDBOP RURD P Rig move checklists, blow down surface lines RD ops ****On Gen Power 15:00 6/20/2022**** 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 6/30/2022 ! 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rom:Conklin, Amy A To:Brooks, James S (OGC) Cc:Klem, Adam Subject:RE: [EXTERNAL]FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 Date:Wednesday, August 3, 2022 12:37:46 PM Attachments:image001.png Hi James, We looked into this and the Ground Level is correct at 97’, so the KB should be 138’ per the instructions on page 2. If possible, please correct it on the form and let me know if you have any questions or need any additional information. Thanks, Amy From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Wednesday, August 3, 2022 9:47 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: RE: [EXTERNAL]FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 Hi, Can we get the following fix: Location tab: Gr = Ground level. KB = Kelly Bushing, which is part of the drill rig. Gr number should never be larger than the KB number, so you should refer to the attached survey and correct the values to match what that shows. However, the survey doesn’t have the correct values so it’s a question for Amy as to what the KB is above MSL (mean sea level), per the instructions on page 2 item 9 thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Tuesday, August 2, 2022 1:25 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: [EXTERNAL]FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 Hello James, I am just waiting to have Adam re-sign the form after the correction. I will send it to you ASAP. Thanks, Amy From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Tuesday, August 2, 2022 11:19 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: RE: [EXTERNAL]FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 Hi, In line 32 Adam Klem did not sign the form. Can you resubmit this form with the correction and the needed sig ? thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Tuesday, August 2, 2022 10:01 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov>; Klem, Adam <Adam.Klem@conocophillips.com> Subject: RE: [EXTERNAL]FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 Good Morning James, Yes, it looks like a typo on my part, sorry. This should be correct. Please let me know if not. 1405’ FSL, 663’ FEL, T12N, R10E, UM Thanks, Amy From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Tuesday, August 2, 2022 9:21 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: [EXTERNAL]FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 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. Hi, I am having issues with the Y coordinate for the Top of Productive Interval as it is coming up yellow when I enter it into the db. Here is screenshot of issue: I had someone else double check my data entry. Could you recheck this number ? thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Monday, August 1, 2022 1:21 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 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: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Monday, August 1, 2022 1:19 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Klem, Adam <Adam.Klem@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: KRU 1G-13/ 1G-13A Plug back and Redrill 10-407 Hello, I have attached the 10-407 for KRU 1G-13/ 1G-13A. Please let me know if you need any additional information. Thanks, Amy Amy A. Conklin Well Integrity Analyst ConocoPhillips Alaska 700 G Street, ATO 1307, Anchorage, AK 99501 Office: (907) 265-1484 Cell: (907) 841-2477 Amy.A.Conklin@conocophillips.com T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Aug 04, 2022 AOGCC Attention: Kayla Junke 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. 1G-13APB1 Kuparuk River API #: 50-029-21016-70-00 Permit No: 222-056 Rig: CDR3 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: Jenny Jones Jenny.E.Jones@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com PTD:222-056 T36847 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.04 09:07:14 -08'00' T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Aug 04, 2022 AOGCC Attention: Kayla Junke 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. 1G-13A Kuparuk River API #: 50-029-21016-01-00 Permit No: 222-056 Rig: CDR3 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: Jenny Jones Jenny.E.Jones@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com PTD:222-056 T36846 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.04 09:05:33 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-07-10_22037_KRU_1G-13A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22037 KRU 1G-13A 50-029-21016-01 Caliper Survey w/ Log Data 10-Jul-22 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 PTD:222-056 T36820 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.22 09:07:03 -08'00' 5HJJ-DPHV% 2*& )URP 0DGVRQ5REHUW 5REHUW0DGVRQ#QDERUVFRP! 6HQW :HGQHVGD\-XQH 30 7R %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ &F 5HJJ-DPHV% 2*& +REEV*UHJ6 .QHDOH0LFKDHO/ &RPSDQ\0DQ1DERUV&'5 6XEMHFW &'5%237(675(3257*$ $WWDFKPHQWV *6WDWH5HSRUW[OV[ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚKWƚĞƐƚƌĞƉŽƌƚĨƌŽŵZϯ͘ dŚĂŶŬLJŽƵ͘͘͘ DĂĚĚLJDĂĚƐŽŶ ZŝŐDĂŶĂŐĞƌZϯ 1$%256$/$6.$'5,//,1*,1& 'LUHFW ,0RELO ƌŽďĞƌƚ͘ŵĂĚƐŽŶ#QDERUVFRP,ZZZQDERUVFRP ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:CDR3AC DATE: 6/22/22 Rig Rep.: Rig Phone: 907-670-6082 Operator: Op. Phone:907-670-6050 Rep.: E-Mail Well Name: PTD #22220560 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:3601 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2''P Trip Tank NA NA Annular Preventer 1 7 1/16''P Pit Level Indicators PP #1 Rams 1 Blind Shear P Flow Indicator PP #2 Rams 1 2'' Combi P Meth Gas Detector PP #3 Rams 1 2 3/8'' Combi P H2S Gas Detector PP #4 Rams 1 2'' Combi P MS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16''P Inside Reel valves 1P HCR Valves 2 2 1/16''P Kill Line Valves 5 2 1/16''P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 3 4 1/16'' / swab FP Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2350 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 12 P Full Pressure Attained (sec)47 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 @ 1900 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:10.0 Hours Repair or replacement of equipment will be made within Same days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6/20/22 04:25 Waived By Test Start Date/Time:6/21/2022 18:30 (date) (time)Witness Test Finish Date/Time:6/22/2022 4:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Pit level alarms tested, LEL and H2S alarms tested. Verified flow through Micromotion. 4 1/16'' swab valve failed. Greased and retested good. R. Madson / R. Beard Conoco Phillips Alaska P. Klein / C. Erdman KRU 1G-13A Test Pressure (psi): cdr3.companyman@conocophillips.com Form 10-424 (Revised 02/2022) 2022-0622_BOP_Nabors_CDR3AC_KRU_1G-13A 9 9 9 9 9999 9 9 9 9 -5HJJ FP 4 1/16'' swab valve failed. 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Senior RWO/CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-13A ConocoPhillips Alaska, Inc. Permit to Drill Number: 222-056 Surface Location: 191' FSL, 466' FWL, Sec. 29, T12N, R10E, UM Bottomhole Location: 1395’ FNL, 1560’ FEL, Sec. 6, T11N, R10E, UM Dear Mr. Klem: 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 well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment of this well. 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, Jeremy M. Price Chair DATED this ___ day of June, 2022. Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.08 13:09:22 -08'00' ! " # $%& %' %"( % ) * *% & $% + ,+ ( % # $ # -& .$ /0 % 0% %" .$%.+$ 0 %. 1 2 # -3 4 56 , 7 8! % 5 %$% %6 9 "% % + + ) : % ; .* .+$ 1 $+ #< % 8 % . 8! % 50% %. -96 =>0 % ,!5 6/ % . &% + /8=-8;/<;=;1; ( %8 $ 2 > # 9, $+$ % + % "5-= -/=1/6 , $+$) %"" %# + ) %" "# + %" !%"# , 7 , 7 1? -14;? 89@ !;= ! 11-/A 99=/A =1=A 2<=A 2--A < 5 $ * %*% & %6 B+% 5$+ 6 9<8=AC9</2A =/A -<9A 2219A ) + 3 + %%D E . -= #$% 0& # %" " $ $ # # ): % # * %"3+ " $ -= -/=/= F+ $% % .$ % $ % # % $ G.+$ $ .+$ % % G # C $% + CC + $#%C"# C " % % %# $ FAE. ,+ " FAE. )-$+ E. % FAE. %" % FAE. 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.XSDUXN 5LYHU 2LO ; .XSDUXN 5LYHU 8QLW .58 *$ ; WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 1G-13AInitial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2220560KUPARUK RIVER, KUPARUK RIV OIL - 490100NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesDirectional plan view included, no land plat.8If 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)NA18Conductor string providedNA19Surface casing protects all known USDWsNA20CMT vol adequate to circulate on conductor & surf csgNA21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented slotted liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitYesPTD 190-116, Sundry 322-26525If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYesMax formation pressure is 4180 psig(12.8 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 3601 psig; will test BOPs to 4000 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoWells on 1G-Pad are H2S-bearing. H2S measures required. (KRU 1G-11A reportedly measured 100 ppm on 12/135Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate5/19/2022ApprVTLDate6/7/2022ApprDLBDate5/19/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03JLC 6/7/2022
