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DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22116-60-00Well Name/No. KUPARUK RIV UNIT 1A-25L1Completion Status1-OILCompletion Date10/30/2021Permit to Drill2210700Operator ConocoPhillips Alaska, Inc.MD11033TVD5987Current Status1-OIL1/24/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR, RES, CaliperNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF11/22/2021 Electronic File: 1A-25L1 2MD Final Log.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 5MD Final Log.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 5TVDSS Final Log.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 01 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 02 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 03 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 04 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 05 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 06 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 07 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 08 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 09 PWD.cgm35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 GAMMA RES.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 01.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 02.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 03.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 04.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 05.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 06.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 07.ASC35957EDDigital DataMonday, January 24, 2022AOGCCPage 1 of 3+LAS file DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22116-60-00Well Name/No. KUPARUK RIV UNIT 1A-25L1Completion Status1-OILCompletion Date10/30/2021Permit to Drill2210700Operator ConocoPhillips Alaska, Inc.MD11033TVD5987Current Status1-OIL1/24/2022UICNoDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 08.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1_ PWD Run 09.ASC35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 2MD Final.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 5MD Final.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 5TVDSS Final.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 01 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 02 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 03 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 04 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 05 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 06 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 07 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 08 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 09 PWD.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 NAD27 Definitive Survey.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 NAD27 Definitive Survey.txt35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 NAD83 Definitive Survey.pdf35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 NAD83 Definitive Survey.txt35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 2MD Final Log.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 5MD Final Log.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 5TVDSS Final Log.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 01 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 02 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 03 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 04 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 05 PWD.tif35957EDDigital DataMonday, January 24, 2022AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22116-60-00Well Name/No. KUPARUK RIV UNIT 1A-25L1Completion Status1-OILCompletion Date10/30/2021Permit to Drill2210700Operator ConocoPhillips Alaska, Inc.MD11033TVD5987Current Status1-OIL1/24/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:10/30/2021Release Date:9/9/2021DF11/22/2021 Electronic File: 1A-25L1 Run 06 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 07 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 08 PWD.tif35957EDDigital DataDF11/22/2021 Electronic File: 1A-25L1 Run 09 PWD.tif35957EDDigital Data0 0 2210700 KUPARUK RIV UNIT 1A-25L1 LOG HEADERS35957LogLog Header ScansMonday, January 24, 2022AOGCCPage 3 of 3M. Guhl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y Samantha Carlisle at 3:29 pm, Nov 22, 2021 RBDMS HEW 11/24/2021 Completion Date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igitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.11.22 12:53:32-09'00' Foxit PDF Editor Version: 11.0.0 Jeff Connelly 1A-25 CTD Final Schematic 3-1/2" Camco DS nipple @ 488' MD (2.875" min ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ 2982', 4572', 5760', 6597', 7186'Baker PBR @ 7249' MDBaker FHL Packer @ 7272' MDDS Nipple @ 7325' MD (2.812" ID)Baker Locator Sub @ 7343' MDMule Shoe @ 7344'MD_________________Baker PBR @ 7347' MDBaker HB Packer @ 7361' MD_________________3-1/2 Otis XN nipple @ 7459' MD (2.75" min ID, No-Go)9-5/8" 36# J-55 shoe @ 4641' MD7" 26# J-55 shoe @ 8093' MD16" 65# H-40 shoe @ 80' MDA-sand perfs 7776' - 7842' MDC-sand perfs 7576' - 7643' MDModified by JSC 11/1/20211A-25L1TD: 11,033' MDSwell packer (Element @ 7697')TOC: 7759' RKBSlotted liner from TD to 9921' MDLTP (7419')TOL (7429')KOP @ 7594' MD Casing Strings Casing Description Liner OD (in) ID (in) Top (ftKB) 7,429.4 Set Depth (ftKB) 11,033.0 Set Depth (TVD) … 5,987.5 Wt/Len (l…Grade Top Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,429.4 5,965.8 35.59 Deployment Sleeve w/6' Sealbore Receptical (PBR) Deployment Sleeve w/6' Sealbore Receptical (PBR) 0.000 7,683.5 6,144.5 76.88 Packer - Swell XO 511 Pin X STL Box 9,920.4 6,067.5 99.21 NSAK 350-238, OH QCLL-L80, Dissolvable Bullnose Down 1A-25L1, 11/19/2021 7:59:45 AM Vertical schematic (actual) Liner; 7,429.4-11,033.0 PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 LINER TOP; 7,429.0 Cement Plug; 7,759.0 ftKB APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 WHIPSTOCK; 7,596.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 NIPPLE; 7,458.6 PACKOFF; 7,419.0 PACKER; 7,360.9 NIPPLE; 7,325.1 PACKER; 7,272.3 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD KB-Grd (ft) 35.01 Rig Release Date 1/1/1991 1A-25L1 ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211660 Wellbore Status PROD Max Angle & MD Incl (°) 103.79 MD (ftKB) 9,860.47 WELLNAME WELLBORE1A-25 Annotation End DateH2S (ppm) 75 Date 8/10/2016 Comment Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Top Of Cement) 7,759.0 8/28/2021 1A-25 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set LTP 11/3/2021 1A-25 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,641.1 Set Depth (TVD) … 3,838.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,093.3 Set Depth (TVD) … 6,459.3 Wt/Len (l… 26.00 Grade J-55 Top Thread ABMOD BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 1,278.1 Set Depth (TVD) … 1,269.0 Wt/Len (l… 26.00 Grade TC-ll Top Thread TC-ll Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.0 Set Depth (ft… 7,352.1 Set Depth (TVD) (… 5,902.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 31.0 31.0 0.04 Hanger 3.000 7.167 McENVOY GEN IV TUBING HANGER 488.0 488.0 0.08 NIPPLE 2.875 4.520 CAMCO DS' CAMCO 'DS' NIPPLE 2,982.1 2,601.2 43.65 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/DV 4,571.6 3,786.1 40.76 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/DV 5,760.5 4,680.8 42.23 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/DV 6,596.9 5,300.1 41.71 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM 7,185.6 5,764.6 34.30 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/ DV 7,241.8 5,811.1 34.19 SEAL ASSY 2.990 3.980 BAKER 80-40 BAKER 80-40 SEAL ASSEMBLY 7,248.8 5,816.9 34.16 PBR 2.990 5.010 BAKER 80-40 BAKER PBR 7,272.3 5,836.3 34.08 PACKER 2.910 5.960 BAKER 47B2 - FHL BAKER FHL PACKER 7,325.1 5,880.1 34.24 NIPPLE 2.812 4.500 'DS' NIPPLE 7,342.8 5,894.7 34.42 LOCATOR 2.990 4.530 BAKER GBH-22 BAKER GBH-22 LOCATOR SUB 7,344.0 5,895.7 34.43 MULE SHOE 2.990 3.780 BAKER 80-40 8 ' MULE SHOE, Spacer Tube w/1 FT Space out Tubing Description TUBING 4"x3.5" Post 2013 WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,347.2 Set Depth (ft… 7,471.0 Set Depth (TVD) (… 5,999.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 7,347.2 5,898.3 34.47 PBR 3.000 5.125 BAKER PBR, 10' STROKE 7,360.9 5,909.6 34.60 PACKER 2.870 6.063 BAKER 'HB' RETRIEVABLE PACKER 7,458.6 5,989.4 36.18 NIPPLE 2.800 4.520 OTIS XN NIPPLE. Milled out to 2.80" on 7/26/21 7,470.3 5,998.8 36.42 SOS 2.992 3.500 BAKER SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,419.0 5,957.3 35.38 PACKOFF NSAK Compression PTSA Liner Top packer w/ 1.781" R Nipple. 2.73" OD X 1.78" ID X 9.50' OAL) 11/3/2021 1.780 7,429.0 5,965.4 35.59 LINER TOP CTD 2.375" Liner top, deployment sleeve w/ 6' seal bore. 10/28/2021 1.992 7,596.0 6,098.2 39.15 WHIPSTOCK 2.625" Northern Solutions High Expansion Wedge (8.78' OAL) 10/12/2021 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,982.1 2,601.2 43.65 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,229.0 8/1/2021 2 4,571.6 3,786.1 40.76 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 8/1/2021 3 5,760.5 4,680.8 42.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 4 6,596.9 5,300.1 41.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 5 7,185.6 5,764.6 34.30 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/19/2014 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,576.0 7,584.0 6,082.6 6,088.9 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,584.0 7,596.0 6,088.9 6,098.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 1A-25, 11/19/2021 8:01:31 AM Vertical schematic (actual) Liner; 7,429.4-11,033.0 LINER TOP; 7,429.0 PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 Cement Plug; 7,759.0 ftKB APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 WHIPSTOCK; 7,596.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 NIPPLE; 7,458.6 PACKOFF; 7,419.0 PACKER; 7,360.9 NIPPLE; 7,325.1 PACKER; 7,272.3 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD KB-Grd (ft) 35.01 Rig Release Date 1/1/1991 1A-25 ... TD Act Btm (ftKB) 8,120.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211600 Wellbore Status PROD Max Angle & MD Incl (°) 47.19 MD (ftKB) 2,500.00 WELLNAME WELLBORE1A-25 Annotation Last WO: End Date 11/22/2014 H2S (ppm) 75 Date 8/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,596.0 7,618.0 6,098.2 6,115.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,622.0 7,643.0 6,118.3 6,134.4 UNIT B, 1A-25 1/5/1992 4.0 APERF 180 deg Phase; HLS 2.5" 7,776.0 7,783.0 6,234.4 6,239.6 A-5, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT 7,797.0 7,842.0 6,249.9 6,282.7 A-4, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,759.0 7,798.0 6,221.8 6,250.6 Cement Plug 8/24/2021 Notes: General & Safety End Date Annotation 8/4/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1A-25, 11/19/2021 8:01:33 AM Vertical schematic (actual) Liner; 7,429.4-11,033.0 LINER TOP; 7,429.0 PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 Cement Plug; 7,759.0 ftKB APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 WHIPSTOCK; 7,596.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 NIPPLE; 7,458.6 PACKOFF; 7,419.0 PACKER; 7,360.9 NIPPLE; 7,325.1 PACKER; 7,272.3 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD 1A-25 ... WELLNAME WELLBORE1A-25 Page 1/11 1A-25 Report Printed: 11/17/2021 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) 10/17/2021 00:00 10/17/2021 04:00 4.00 MIRU, MOVE RURD P *** Rig Released @ Midnight from 1B- 10 ***. Continue to work RD checklist, call for fuel for halfway house, load out KDTH trucks. 0.0 0.0 10/17/2021 04:00 10/17/2021 05:00 1.00 MIRU, MOVE MOB P Trucks on location, PJSM w/crews, discuss communication, spotters, and walkarounds. Spot sows, weighted sows, off load dozer. 0.0 0.0 10/17/2021 05:00 10/17/2021 05:30 0.50 MIRU, MOVE MOB P Jack service & sow up. 0.0 0.0 10/17/2021 05:30 10/17/2021 06:00 0.50 MIRU, MOVE MOB P Pull service away from Sub, spot on pad in queue to head out. 0.0 0.0 10/17/2021 06:00 10/17/2021 06:30 0.50 MIRU, MOVE MOB P Drop sow from service, jeep up, sow up, attach weighted sow. 0.0 0.0 10/17/2021 06:30 10/17/2021 06:42 0.20 MIRU, MOVE MOB P Crew C/O, walka round, jack sub & sow up. 0.0 0.0 10/17/2021 06:42 10/17/2021 07:06 0.40 MIRU, MOVE MOB P Pull sub away from 1B-10, spot on pad in que to head out. 0.0 0.0 10/17/2021 07:06 10/17/2021 07:42 0.60 MIRU, MOVE MOB P Jeep up sub. Final walk arounds of convoy, load up crews, notify security / field. 0.0 0.0 10/17/2021 07:42 10/17/2021 08:30 0.80 MIRU, MOVE MOB P Move service followed by sub from 1B- 10 ~.6 miles to 1A-25 pad. 0.0 0.0 10/17/2021 08:30 10/17/2021 09:00 0.50 MIRU, MOVE MOB P On pad, drop weighted sows, sows and jeeps, re-sow sub. 0.0 0.0 10/17/2021 09:00 10/17/2021 09:42 0.70 MIRU, MOVE MOB P Swap out adapter, set herculite cellar pit liner square up Sub. 0.0 0.0 10/17/2021 09:42 10/17/2021 10:00 0.30 MIRU, MOVE MOB P Back Sub over 1A-25. 0.0 0.0 10/17/2021 10:00 10/17/2021 10:30 0.50 MIRU, MOVE MOB P Set matts under sub 0.0 0.0 10/17/2021 10:30 10/17/2021 10:42 0.20 MIRU, MOVE MOB P Take sub off jacks, de sow. 0.0 0.0 10/17/2021 10:42 10/17/2021 11:12 0.50 MIRU, MOVE MOB P Sow up, pull service to end of pad, back sevice to sub and spot while setting inside mats. 0.0 0.0 10/17/2021 11:12 10/17/2021 11:24 0.20 MIRU, MOVE MOB P Set outside mats under service mod 0.0 0.0 10/17/2021 11:24 10/17/2021 11:36 0.20 MIRU, MOVE MOB P Take service side off jacks, de sow. 0.0 0.0 10/17/2021 11:36 10/17/2021 14:00 2.40 MIRU, WHDBOP RURD P RU CDR3-AC to the well. Set BOP stack ***Rig accept 14:00 *** 0.0 0.0 10/17/2021 14:00 10/17/2021 19:30 5.50 MIRU, WHDBOP RURD P Continue to folow rig up checklist. Remove old choke and kill lines, replace with new hoses, MU transducers, install new gauge on IA 0.0 0.0 10/17/2021 19:30 10/18/2021 00:00 4.50 MIRU, WHDBOP RURD P Connect interconnect, remove inner reel iron, remove counter, lowered levelwind centered up and secured stack, dressed down hole end of coil for grapple install 0.0 0.0 10/18/2021 00:00 10/18/2021 01:00 1.00 MIRU, WHDBOP RURD P Finish removing inner reel iron and bulkhead, replace all 2" 1502 hardline gaskets 0.0 0.0 10/18/2021 01:00 10/18/2021 03:00 2.00 MIRU, WHDBOP RURD P Install grapple, PJSM for unstabbing coil. 0.0 0.0 10/18/2021 03:00 10/18/2021 04:00 1.00 MIRU, WHDBOP RURD P Unstab coil 0.0 0.0 10/18/2021 04:00 10/18/2021 06:00 2.00 MIRU, WHDBOP RURD P Set old storage reel on Sow, pick and hang new string in saddles 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 2/11 1A-25 Report Printed: 11/17/2021 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) 10/18/2021 06:00 10/18/2021 07:30 1.50 MIRU, WHDBOP RURD P Shim reel and install saddle clamps / bolster. 0.0 0.0 10/18/2021 07:30 10/18/2021 12:00 4.50 MIRU, WHDBOP RURD P Prep coil for internal grapple. Change out stripper brass and restring stabbing cable. Install reel house duck ponds. Stage hoses for reverse circulation. Install BOP risers and collect RKB's. Change out all riser 7" otis O-rings. Prepare for pull test on Internal grapple. 0.0 0.0 10/18/2021 12:00 10/18/2021 16:00 4.00 MIRU, WHDBOP RURD P PJSM, pull test grapple and re torque internal grapple. Remove shipping chains and stab coil through injector and stripper. Rig down stabbing equipment. Make up 2" 1502 HP hoses to managed pressure manifold for recirculation. Spot check torques in all connection in the cellar ( BOPs and choke and kill line) 0.0 0.0 10/18/2021 16:00 10/18/2021 18:00 2.00 MIRU, WHDBOP RURD P Add 10 gal of MetOH to stack, stab injector. Load coil backwards with meth spear and seawater taking returns via the managed pressure manifold to the shaker. Crew change 0.0 0.0 10/18/2021 18:00 10/18/2021 20:00 2.00 MIRU, WHDBOP RURD P Ramp pump rate through oil three times, hear wire move. Shut down bleed down. Find wire at managed pressure manifold. Break down hoses. Rig up inner reel iron and high pressure bulk head. 0.0 0.0 10/19/2021 00:00 10/19/2021 03:30 3.50 MIRU, WHDBOP RURD P Cut to find e-line, install/pull test CTC 35k, sim-ops prep for BOP test, service all valves after pumping N2, secure cellar, scaffolding in way of SSV, jack up and safe out scaffolding 0.0 0.0 10/19/2021 03:30 10/19/2021 04:45 1.25 MIRU, WHDBOP RURD P MU BHI upper quick, re-test e-line (good test), PT 4k (good test) 0.0 0.0 10/19/2021 04:45 10/19/2021 05:15 0.50 MIRU, WHDBOP RURD P Stab INJH, line up and bring mud pump #2 online, jet stack @ 2.0 bpm/3,860 psi, (45 bbls) 0.0 0.0 10/19/2021 05:15 10/19/2021 06:45 1.50 MIRU, WHDBOP RURD P Blow down, Unstab INJH, MU & bore- scope BOPE. 0.0 0.0 10/19/2021 06:45 10/19/2021 09:30 2.75 MIRU, WHDBOP RURD P Finish greasing valves R1 & R3, LD QTS and installed Bleeder on C4, 0.0 0.0 10/19/2021 09:30 10/19/2021 12:00 2.50 MIRU, WHDBOP BHAH P Test PDL's TT line, Install floats in upper quick connect. Make up BHA 1 Window milling BHA with 1° motor, 2.80 DSM, 2.79 swtring reamer., Load into ODS PDL 0.0 0.0 10/19/2021 12:00 10/19/2021 19:30 7.50 MIRU, WHDBOP BOPE P Perform shell test 4,000 psi/250 psi (good test), perform initial BOP test, witness waived by AOGCC (Lou Laubenstein), 4,000 psi high / 2,500 psi Annular. 0.0 0.0 10/19/2021 19:30 10/19/2021 21:00 1.50 MIRU, WHDBOP BOPE P Well Control choke C not holding any back pressure. Pull apart choke. Seat and needle look good. Recalibrate choke. Still not holding back pressure. Out of ten hour test window. Continue trouble shooting choke 0.0 0.0 10/19/2021 21:00 10/19/2021 22:30 1.50 MIRU, WHDBOP BHAH P PU/MU/Pressure deploy, Milling assembly BHA #1 with 1.0° fixed bend motor, 2.80" window mill and 2.79 sting reamer 0.0 0.0 10/19/2021 22:30 10/20/2021 00:00 1.50 MIRU, WHDBOP BHAH T Unable to get test on choke C. Stand by for parts 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 3/11 1A-25 Report Printed: 11/17/2021 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) 10/20/2021 00:00 10/20/2021 02:00 2.00 MIRU, WHDBOP BOPE T Trouble shoot repair choke C. Seat found abraided upon removal. Replace seat and test. Good 0.0 0.0 10/20/2021 02:00 10/20/2021 04:36 2.60 PROD1, WHPST WPST P PJSM, Run pre deploy valve check list. Make up mill, string reamer, and pup. Place in well. Make up coiltrak to motor. Surface test tool - Good. Strip on well make up lubricator. PT QTS to 4000 PSI. Open BOP. Tag up. Restart MWD computers 0.0 0.0 10/20/2021 04:36 10/20/2021 06:48 2.20 PROD1, WHPST WPST P Trip in well, EDC open pumping 1 BPM, switch to milling fluid 0.0 7,490.0 10/20/2021 06:48 10/20/2021 07:06 0.30 PROD1, WHPST DLOG P Log K1 for depth control minus 4.0' 7,490.0 7,519.0 10/20/2021 07:06 10/20/2021 08:06 1.00 PROD1, WHPST WPST P Continue displacing well to milling fluid, shut down pumps when muds at surface, obtain static BHP *** 11.7 ppg **** 7,519.0 7,638.0 10/20/2021 08:06 10/20/2021 09:36 1.50 PROD1, WHPST DLOG T RIH, tag pinch point, no wedge found, pull back up hole, log K1 again to confirm depth control minus 1', discuss with engineering team, desicion to RBIH to 7,700', no tag 7,638.0 7,700.0 10/20/2021 09:36 10/20/2021 10:48 1.20 PROD1, WHPST WPST T Open EDC, POOH 7,700.0 1,831.5 10/20/2021 10:48 10/20/2021 12:06 1.30 PROD1, WHPST WPST T Lost hydraulic pressure to the INJH, back up and running, continue OOH 1,831.5 1,831.5 10/20/2021 12:06 10/20/2021 13:24 1.30 PROD1, WHPST WPST T PJSM, PUD milling assembly BHA #1 0.0 0.0 10/20/2021 13:24 10/20/2021 14:24 1.00 PROD1, WHPST WPST T Perform Rig maint/service Standby for NS wedge 0.0 0.0 10/20/2021 14:24 10/20/2021 14:39 0.25 PROD1, WHPST WPST T NS Wedge on location load into rig and bring to the rig floor, find high side and place mark for picking up tools 0.0 0.0 10/20/2021 14:39 10/20/2021 16:27 1.80 PROD1, WHPST WPST T PD NS 3.5"x7" High Expansion Wedge (19.83') BHA #2 0.0 0.0 10/20/2021 16:27 10/20/2021 16:33 0.10 PROD1, WHPST WPST T Tag up, reset counters to zero 0.0 73.1 10/20/2021 16:33 10/20/2021 18:45 2.20 PROD1, WHPST WPST T RIH w/BHA #2 73.1 7,505.0 10/20/2021 18:45 10/20/2021 18:51 0.10 PROD1, WHPST WPST T 7490', Start gamma tie in to 7505 Log K1 for depth control -8' correction, PUW=29K 7,505.0 7,575.0 10/20/2021 18:51 10/20/2021 19:09 0.30 PROD1, WHPST WPST T Continue into set depth @ 7607.78 bit depth, Orintation @ 0° HS. Close EDC. Bring pumps on .5. Hesatate @ 1500 psi, 2000psi, 2500psi, 3000psi. Go to 4000 psi. Setting tool shifted @ 3800psi. Sety down 5K, PUW=29K 7,575.0 7,607.7 10/20/2021 19:09 10/20/2021 20:39 1.50 PROD1, WHPST WPST T Pick up off whipstock, PUW=29K. PUH 30 feet. Open EDC. POOH 7,607.0 7,607.0 10/20/2021 20:39 10/20/2021 23:00 2.35 PROD1, WHPST WPST T Tag up, space out. PJSM PUD BHA #2 whipstock setting tools. No iregularities with tool. PJSM PD BHA #3 to mill window. Surface test good. Strip on well 7,607.0 77.1 10/20/2021 23:00 10/21/2021 00:00 1.00 PROD1, WHPST WPST T Tag up. Trip in well, EDC open, min rate on milling fluid 77.1 7,500.0 10/21/2021 00:00 10/21/2021 00:00 0.00 PROD1, WHPST WPST T Tripping in, Midnight depth 7500' 7,500.0 7,500.0 10/21/2021 00:00 10/21/2021 00:24 0.40 PROD1, WHPST WPST T Continue tripping in, Min rate, EDC open 7,500.0 7,490.0 10/21/2021 00:24 10/21/2021 00:42 0.30 PROD1, WHPST WPST T Log Gamma tie into K1 marker for -8.5' correction. Close EDC, PUW=30K 7,490.0 7,516.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 4/11 1A-25 Report Printed: 11/17/2021 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) 10/21/2021 00:42 10/21/2021 00:54 0.20 PROD1, WHPST WPST T Continue in, dry tag pinch point @ 7596', PUW=30K. PUH to 9585 7,516.0 7,585.0 10/21/2021 00:54 10/21/2021 01:06 0.20 PROD1, WHPST WPST P Bring pump online 1.7 BPM @ 3480 PSI, WHP=458. Trip in to mill 7,585.0 7,596.5 10/21/2021 01:06 10/21/2021 05:06 4.00 PROD1, WHPST WPST P 7596.5. See motor work and DHWOB. Mill window per procedure / Northern Solutions rep OBM, 1.7 bpm @ 3,468 psi, start time milling 7,596.5 7,601.0 10/21/2021 05:06 10/21/2021 06:06 1.00 PROD1, WHPST WPST P Drilling rat hole 1.7 bpm/3,757 psi 7,601.0 7,616.0 10/21/2021 06:06 10/21/2021 07:06 1.00 PROD1, WHPST WPST P Ream window, ADTF, 30° ROHS, 30° ROHS, and 180°, PUH to above window, pump 10x10 sweep 7,616.0 7,573.0 10/21/2021 07:06 10/21/2021 07:24 0.30 PROD1, WHPST WPST P Dry drift window exit 7,573' - 7,616' 7,573.0 7,616.0 10/21/2021 07:24 10/21/2021 08:24 1.00 PROD1, WHPST WPST P PUH slowly waiting on sweep to come around 7,616.0 7,578.0 10/21/2021 08:24 10/21/2021 09:00 0.60 PROD1, WHPST WPST P Obtain stattic above window 11.75 ppg 7,578.0 7,578.0 10/21/2021 09:00 10/21/2021 10:30 1.50 PROD1, WHPST WPST P POOH w/open EDC 7,578.0 77.2 10/21/2021 10:30 10/21/2021 12:00 1.50 PROD1, WHPST WPST P Tag up at surface, space out, PJSM, PUD milling assembly 77.2 0.0 10/21/2021 12:00 10/21/2021 13:15 1.25 PROD1, WHPST WPST P LD tools in catwalk and clear RF Gauge Mills - WIndow Mill 2.79 no-go, String Reamer 2.79 no-go 0.0 0.0 10/21/2021 13:15 10/21/2021 14:00 0.75 PROD1, WHPST SVRG P Work on hydraulics, service rig, clean counter, inspect INJH, 0.0 0.0 10/21/2021 14:00 10/21/2021 15:30 1.50 PROD1, DRILL PULD P PJSM, PD Build Assembly BHA #4 0.0 72.2 10/21/2021 15:30 10/21/2021 16:48 1.30 PROD1, DRILL TRIP P Tag up, reset counter depths, RIH holding 11.9 ppg MP 72.2 7,475.0 10/21/2021 16:48 10/21/2021 17:06 0.30 PROD1, DRILL DLOG P Log K1 for depth control -9.0' Close EDC 7,475.0 7,505.0 10/21/2021 17:06 10/21/2021 18:00 0.90 PROD1, DRILL TRIP P RIH, stack out in window, PUH roll pump to index bit. Try different speeds and TF's up to 10Left and right. Try rolling trough window at min rate HS. Stacking in same place. Clean pick ups with no negative WOB. Consult town. 7,505.0 7,600.0 10/21/2021 18:00 10/21/2021 18:18 0.30 PROD1, DRILL TRIP P Continue to work through window. Pass through clean at 20L no pumps 7,600.0 7,616.0 10/21/2021 18:18 10/21/2021 19:42 1.40 PROD1, DRILL DRLG P 7616', DSrill ahead in build section. 1.7 BPM @ 3500 PSI FS, BHP=3760 7,616.0 7,681.0 10/21/2021 19:42 10/21/2021 19:48 0.10 PROD1, DRILL DRLG P PUH, PUW=29K. Bring pump rate to 1.85 BPM @ 3800 PSI. RIW=13.5K. Near bit indicates close to 47° DLS 7,681.0 7,681.0 10/21/2021 19:48 10/21/2021 22:30 2.70 PROD1, DRILL DRLG P 7681', Drill ahead 7,681.0 7,770.0 10/21/2021 22:30 10/21/2021 22:48 0.30 PROD1, DRILL WPRT P Wiper trip to window, PUW=34K. W/sweeps, Turn around @ 7620. Clean trip up and down 7,770.0 7,770.0 10/21/2021 22:48 10/22/2021 00:00 1.20 PROD1, DRILL DRLG P 7770', Drill ahead, 1.8 BPM @ 3910 BHP=3863, WHP=420 PSI Midnight depth 7813' in build section 7,770.0 7,813.0 10/22/2021 00:00 10/22/2021 03:00 3.00 PROD1, DRILL DRLG P 7813', Drill ahead, 1.8 BPM @ 3910 BHP=3863, WHP=420 PSI 7,813.0 7,970.0 10/22/2021 03:00 10/22/2021 03:24 0.40 PROD1, DRILL WPRT P 7970', Call end of build, PUW=33KK, Slight bobble coming up throug window. Slow to 5 FPM @ 1.9 BPM Jet 7 inch. 7,970.0 7,480.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 5/11 1A-25 Report Printed: 11/17/2021 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) 10/22/2021 03:24 10/22/2021 03:30 0.10 PROD1, DRILL WPRT P 7480', Stop and open EDC, Comtinue up hole, RIH to log K1, Pumping 2.4 BPM 7,480.0 7,470.0 10/22/2021 03:30 10/22/2021 03:54 0.40 PROD1, DRILL WPRT P 7470, Log K1 for +2' correction. Trip in to tie in RA / Jet 7". 7515 log RA marker. Clean pass through window at HS TF. Log RA @ 7601, TOWS-7594, TOW=7597, BOW=7601 7,470.0 7,630.0 10/22/2021 03:54 10/22/2021 05:18 1.40 PROD1, DRILL TRIP P Trip out, Jet 7" 10 FPM 2.2 BPM, PUW=34K 7,630.0 62.0 10/22/2021 05:18 10/22/2021 06:18 1.00 PROD1, DRILL BHAH P On surface, PUD BHA #4, PD BHA #5 lateral drilling BHA 62.0 0.0 10/22/2021 06:18 10/22/2021 07:36 1.30 PROD1, DRILL BHAH P Pressure deploy latirel assemby bha#5 0.0 78.3 10/22/2021 07:36 10/22/2021 07:48 0.20 PROD1, DRILL TRIP P Tag up re set counters & rih 78.3 7,480.0 10/22/2021 07:48 10/22/2021 08:06 0.30 PROD1, DRILL DLOG P Log k1 -10.0' 27k puw riw 13.6 k 7,480.0 7,511.0 10/22/2021 08:06 10/22/2021 08:51 0.75 PROD1, DRILL TRIP P Continue in hole though window 0° HS clean with no pumps Send new mud down hole 7,511.0 7,971.0 10/22/2021 08:51 10/22/2021 10:39 1.80 PROD1, DRILL DDRL P OBD, FS 4650 psi, drill ahead @ 70 fph 7,971.0 8,040.0 10/22/2021 10:39 10/22/2021 10:57 0.30 PROD1, DRILL WPRT P Mud all the way around, PUH PUW 30k FS 4,256 psi, AP 3,870, IA 636, OA 6 RBIH to drill 8,040.0 8,040.0 10/22/2021 10:57 10/22/2021 12:09 1.20 PROD1, DRILL DDRL P BOBD, 1.89 bpm/4,256 psi, drilling ahead 80 fph 8,040.0 8,170.0 10/22/2021 12:09 10/22/2021 12:21 0.20 PROD1, DRILL DDRL P PUH PUW 30 k RBIH Drilling ahead 8,170.0 8,170.0 10/22/2021 12:21 10/22/2021 13:45 1.40 PROD1, DRILL DDRL P BOBD 1.85 bpm / 4783 Drilling ahead 88 fpm 8,170.0 8,320.0 10/22/2021 13:45 10/22/2021 14:21 0.60 PROD1, DRILL WPRT P Wiper trip from 8320' toTT PUW 33k Perform Jog to the end of build 8,320.0 7,594.0 10/22/2021 14:21 10/22/2021 14:51 0.50 PROD1, DRILL WPRT P Open ECD pump max max rate 2.5 BPM 4000 PSI 7,594.0 7,506.0 10/22/2021 14:51 10/22/2021 15:03 0.20 PROD1, DRILL WPRT P Logging K 1 marker @ 7581' 7,506.0 7,506.0 10/22/2021 15:03 10/22/2021 15:09 0.10 PROD1, DRILL WPRT P Pump bottoms up 7,506.0 7,520.0 10/22/2021 15:09 10/22/2021 15:30 0.35 PROD1, DRILL WPRT P Down on pump close ECD RBIH pumping .5 bpm @ 2100 psi 8080' -8120' starting to see some stacking 7,520.0 7,520.0 10/22/2021 15:30 10/22/2021 18:30 3.00 PROD1, DRILL DDRL P BOBD Free spin 4405 @ 2 bpm, 8,320.0 8,504.0 10/22/2021 18:30 10/22/2021 18:36 0.10 PROD1, DRILL WPRT P BHA wiper, PUW=38K 8,504.0 8,504.0 10/22/2021 18:36 10/22/2021 19:54 1.30 PROD1, DRILL DRLG P Drill, 1.81 BPM @ 4250 PSI FS, BHP=3880 8,504.0 8,525.0 10/22/2021 19:54 10/22/2021 20:06 0.20 PROD1, DRILL WPRT P Mini wiper, 100' stacking weight 8,525.0 8,525.0 10/22/2021 20:06 10/22/2021 21:06 1.00 PROD1, DRILL DRLG P Drill, 1.82 BPM @ 4250 PSI FS, BHP=3880 8,525.0 8,720.0 10/22/2021 21:06 10/22/2021 22:06 1.00 PROD1, DRILL WPRT P 800' wiper trip #1. PUW=35K RBIH clean through 8050 to 8150 full pump rate. 40 FPM 8,720.0 8,720.0 10/22/2021 22:06 10/22/2021 23:06 1.00 PROD1, DRILL DRLG P Drill ahead, 1.88 BPM @ 4400 PSI FS, BHP=3900 8,720.0 8,823.0 10/22/2021 23:06 10/22/2021 23:12 0.10 PROD1, DRILL WPRT P BHP wiper, PUW=34K 8,823.0 8,823.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 6/11 1A-25 Report Printed: 11/17/2021 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) 10/22/2021 23:12 10/23/2021 00:00 0.80 PROD1, DRILL DRLG P Drill Ahead, 1.88 BPM @ 4450 PSI FS, BHP=3900 Midnight depth 8924' 8,823.0 8,924.0 10/23/2021 00:00 10/23/2021 02:24 2.40 PROD1, DRILL WPRT P BHA wiper 90181' 8,924.0 9,181.0 10/23/2021 02:24 10/23/2021 02:36 0.20 PROD1, DRILL DDRL P BOBD @ 9181' 9,181.0 9,375.0 10/23/2021 02:36 10/23/2021 06:15 3.65 PROD1, DRILL WPRT At from 9375' to TT PUW 35 K 9,375.0 7,970.0 10/23/2021 06:15 10/23/2021 07:30 1.25 PROD1, DRILL WPRT P Perform jog in the build section 7,970.0 7,550.0 10/23/2021 07:30 10/23/2021 08:00 0.50 PROD1, DRILL WPRT P Perform jog in 7" @ 7550 open ECD pump 2.8 bpm PUH to TT 7,550.0 7,550.0 10/23/2021 08:00 10/23/2021 09:00 1.00 PROD1, DRILL WPRT P Perform tie in log @ K1 +4' correction close ECD 7,480.0 7,570.0 10/23/2021 09:00 10/23/2021 09:06 0.10 PROD1, DRILL WPRT P RBIH pumps off run thru window @7745' seen a bobble continue in hole 7,570.0 7,570.0 10/23/2021 09:06 10/23/2021 10:12 1.10 PROD1, DRILL DDRL P BOBD @ 9374' 9,374.0 10/23/2021 00:00 10/23/2021 01:42 1.70 PROD1, DRILL DRLG P Drill Ahead, 1.88 BPM @ 4450 PSI FS, BHP=3900 8,924.0 9,120.0 10/23/2021 01:42 10/23/2021 02:24 0.70 PROD1, DRILL WPRT P Wiper trip 800' #2, PUW= 39K, Clean trip up and down 9,120.0 9,120.0 10/23/2021 02:24 10/23/2021 02:48 0.40 PROD1, DRILL DRLG P Drill Ahead, 1.88 BPM @ 4565PSI FS, BHP=3950 9,120.0 9,153.0 10/23/2021 02:48 10/23/2021 02:54 0.10 PROD1, DRILL WPRT P BHA Wiper, PUW=45K 9,153.0 9,153.0 10/23/2021 02:54 10/23/2021 02:54 PROD1, DRILL DRLG P Drill, 1.88 BPM @ 4550 PSI FS, BHP=3960 9,153.0 9,375.0 10/23/2021 02:54 10/23/2021 06:12 3.30 PROD1, DRILL WPRT P Wiper trip to 7.00". Jog the build area. Jog the 7.00" 9,375.0 7,552.0 10/23/2021 06:12 10/23/2021 08:12 2.00 PROD1, DRILL WPRT P Open ECD bring pump back online 2.8 bpm 7,552.0 7,252.0 10/23/2021 08:12 10/23/2021 08:57 0.75 PROD1, DRILL WPRT P Jet the 7.00" 7,552.0 7,480.0 10/23/2021 08:57 10/23/2021 09:03 0.10 PROD1, DRILL DLOG P Gamma ray tie in. Plus 4 feet correction RBIH 7,480.0 7,480.0 10/23/2021 09:03 10/23/2021 09:09 0.10 PROD1, DRILL WPRT P Close ECD RBIH run thru window with pump down continue in hole 7,480.0 4,780.0 10/23/2021 09:09 10/23/2021 10:24 1.25 PROD1, DRILL DRLG P BOBD 9,377.0 9,499.0 10/23/2021 10:24 10/23/2021 12:24 2.00 PROD1, DRILL WPRT P BHA wiper 9,499.0 9,499.0 10/23/2021 12:24 10/23/2021 12:30 0.10 PROD1, DRILL DRLG P BOBD free spin 4400 psi @ 1.8 bpm Hold 95.0 9,499.0 9,574.0 10/23/2021 12:30 10/23/2021 14:30 2.00 PROD1, DRILL WPRT P At 9574' wiper trip to 9076' RBIH 9,574.0 9,574.0 10/23/2021 14:30 10/23/2021 16:30 2.00 PROD1, DRILL DRLG P BOBD free spin 4475 @ 1.8 bpm Bleed IA pressure from 800 to 500 9,574.0 9,628.0 10/23/2021 16:30 10/23/2021 16:48 0.30 PROD1, DRILL WPRT P BHA Wiper, PUW=35K 9,628.0 9,628.0 10/23/2021 16:48 10/23/2021 20:00 3.20 PROD1, DRILL DDRL P Drill, 1.81 BPM @ 4691 PSI FS, BHA=3943 9,628.0 9,745.0 10/23/2021 20:00 10/23/2021 20:18 0.30 PROD1, DRILL WPRT P Stacking. PUH to reset. Clean pick up @ 34K. Unable to RBIH. Pull 500' wiper. Clean trip up and down. 9,745.0 9,745.0 10/23/2021 20:18 10/23/2021 23:18 3.00 PROD1, DRILL DRLG P Drill, 1.81 BPM @ 4610 PSI FS, BHP=4010, 9,745.0 9,798.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 7/11 1A-25 Report Printed: 11/17/2021 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) 10/23/2021 23:18 10/23/2021 23:54 0.60 PROD1, DRILL DRLG P Start mnew mud down CT, String weight -4K, DHWOB=600LBS System 1 out @ 1812' 9,798.0 9,810.0 10/23/2021 23:54 10/24/2021 00:00 0.10 PROD1, DRILL WPRT P Wiper trip to TT chasing new mud. PUW=40K Midnight depth 9500 9,810.0 9,500.0 10/24/2021 00:00 10/24/2021 02:54 2.90 PROD1, DRILL WPRT P Continue wiper trip to TT. Over pull @ 7740'. Jog back in hole Work up through 7740. Clean up through windod. Jet 7". Open EDC jet recip 7" again. Log K1 for +3.5. Set down in window tripping in. Roll TF to 20L Clean. Saw 7740 . PUH and work through. Bobble @ 9742. Stop and continue through 9,500.0 9,810.0 10/24/2021 02:54 10/24/2021 06:24 3.50 PROD1, DRILL DRLG P 9810', Drill, 1.8 BPM @ 4350 PSI FS. BHP=3975. String weight -4.5, DHWOB=1.4 short wiper 9,810.0 9,810.0 10/24/2021 06:24 10/24/2021 06:30 0.10 PROD1, DRILL DRLG P 9932' back onn bottom drilling 9,810.0 9,932.0 10/24/2021 06:30 10/24/2021 07:30 1.00 PROD1, DRILL WPRT P Wiper trip 200' from 9996' 9,932.0 9,969.0 10/24/2021 07:30 10/24/2021 08:30 1.00 PROD1, DRILL WPRT P 9,969', wiper up hole to 9,500' 9,969.0 9,969.0 10/24/2021 08:30 10/24/2021 09:00 0.50 PROD1, DRILL DDRL P BOBD, 1.7 bpm/4,256 psi, BHP 3,936 psi, IA 370, OA 12 9,969.0 9,969.0 10/24/2021 09:00 10/24/2021 09:15 0.25 PROD1, DRILL WPRT P Wiper trip to bottom of build section BHP 4,000 psi IA 288 oa 12 9,969.0 8,050.0 10/24/2021 09:15 10/24/2021 11:15 2.00 PROD1, DRILL WPRT P At 8050 at bottom of build RBIH 8,050.0 8,050.0 10/24/2021 11:15 10/24/2021 12:15 1.00 PROD1, DRILL DDRL P BOBD @ 9969' free spin 4358 psi @1.8 bpm IA 401 OA 11 9,969.0 10,141.0 10/24/2021 12:15 10/24/2021 16:45 4.50 PROD1, DRILL WPRT P perform 299' wiper trrip PUW 35 K 10,141.0 9,950.0 10/24/2021 16:45 10/24/2021 17:09 0.40 PROD1, DRILL DDRL P BOBD @ 10141 10,141.0 10,153.0 10/24/2021 17:09 10/24/2021 19:15 2.10 PROD1, DRILL WPRT P PUH stacking, Struggle to get back on bottom. Pull 800' wiper, Initial PUW=33K 10,153.0 10,153.0 10/24/2021 19:15 10/24/2021 19:45 0.50 PROD1, DRILL DRLG P Drill, 1.81 BPM @ 4356 PSI FS, BHP=3954, String weight=-2K, DHWOB=.7K 10,153.0 10,169.0 10/24/2021 19:45 10/24/2021 22:21 2.60 PROD1, DRILL WPRT P Stacked out. PUH, PUW=40K. Unable to RBIH. Pump 10X10. Chase to TT. Jog below window 7640. Come up through window clean up to 7574. Open EDC recip 7" at max rate. 10,169.0 7,475.0 10/24/2021 22:21 10/24/2021 22:27 0.10 PROD1, DRILL DLOG P Log K1 for +7.5' correction 7,475.0 7,500.0 10/24/2021 22:27 10/24/2021 23:15 0.80 PROD1, DRILL WPRT P Continue wiper trip to bottom. Close EDC, Clean trip past window @ HS. 7740 Clear tripping in 7,500.0 8,200.0 10/24/2021 23:15 10/25/2021 00:00 0.75 PROD1, DRILL WPRT P Pump one showing VFD communication fault code tripping out pump. Trounle shoot pump. Tripped out multiple times. Power back up. Pump two seems stable. Are able to swap to back up pump one. RBIH to drill 8,200.0 8,300.0 10/25/2021 00:00 10/25/2021 01:18 1.30 PROD1, DRILL WPRT P Pump stabilized. Continue in to drill 8,300.0 10,172.0 10/25/2021 01:18 10/25/2021 01:42 0.40 PROD1, DRILL DRLG P Drill, 1.8 BPM @ 4512, BHP=4090, RIW=.6 off bottom, DHWOB=.92, CT Weight 2.1K 10,172.0 10,191.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 8/11 1A-25 Report Printed: 11/17/2021 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) 10/25/2021 01:42 10/25/2021 02:42 1.00 PROD1, DRILL WPRT P Stack out, PUH PUW=45K, Unable to turn aroun. Mix up Alpine beads in Hi viss, Pill pit #1, 1 LB/BBl, Pump 10 BBl pill. Continue to work to bottom 10,191.0 10,191.0 10/25/2021 02:42 10/25/2021 06:12 3.50 PROD1, DRILL DRLG P 2 BBls beads out, Bring rate up to 1.81 @ 4512 PSI FS, BHP=4135. 2 BBls beads out ROP ~100 FPH w/2K string weight. , Pump second 10 BBl pill @ 10,215 10,191.0 10,382.0 10/25/2021 06:12 10/25/2021 07:06 0.90 PROD1, DRILL WPRT P Styacking, Pull BHA Wiper, PUW=32k 10,305.0 10,305.0 10/25/2021 07:06 10/25/2021 08:48 1.70 PROD1, DRILL DRLG P PUH 30' PUW 40 KPicking up hole often to get it to slide in hole , Continue to drill 10,305.0 10,356.0 10/25/2021 08:48 10/25/2021 09:36 0.80 PROD1, DRILL WPRT Short wiper trip, PUW=40K, Struggle to get back on bottom 10,356.0 10,356.0 10/25/2021 09:36 10/25/2021 13:36 4.00 PROD1, DRILL DRLG P At 10411 pumped a 10 bbl pill of new mud and it seems to be working 10,356.0 10,477.0 10/25/2021 13:36 10/25/2021 16:54 3.30 PROD1, DRILL WPRT P Perfgorm a 800' wiper @ 1.8 bpm 4667 psi IA 498 OA 13 PUW 30 K 10,477.0 10,477.0 10/25/2021 16:54 10/25/2021 20:48 3.90 PROD1, DRILL DRLG P Drill, 1.52 BPM @ 3760 PSI FS, BHP=3965. Drilling on hard spot. Geo reports ankorite in sample pumped up from 10478 10,477.0 10,493.0 10/25/2021 20:48 10/25/2021 22:06 1.30 PROD1, DRILL WPRT P Lost pump, PUH, PUW=36K. Work pipe to get back to bottom. Pump beaded pill to get back on bottom 10,493.0 10,493.0 10/25/2021 22:06 10/26/2021 00:00 1.90 PROD1, DRILL DRLG P Drill, 1.63 BPM @ 3970 PSI FS, BHP=3976. Pumping beaded pills as needed for weight transfer. Midnight 10,559' 10,493.0 10,559.0 10/26/2021 00:00 10/26/2021 00:30 0.50 PROD1, DRILL DRLG P Drill, 1.63 BPM @ 3970 PSI FS, BHP=3976. Pumping beaded pills as needed for weight transfer. 10,559.0 10,575.0 10/26/2021 00:30 10/26/2021 00:36 0.10 PROD1, DRILL WPRT P Stacking out. PUW=42K. Pump Beaded pill, Work to bottom 10,575.0 10,575.0 10/26/2021 00:36 10/26/2021 02:36 2.00 PROD1, DRILL DRLG P Drill, 1.65 BPM @ 3950PSI FS, BHP=3975 10,575.0 10,595.0 10/26/2021 02:36 10/26/2021 02:42 0.10 PROD1, DRILL WPRT P Stacking, P/U and reset 10,595.0 10,595.0 10/26/2021 02:42 10/26/2021 08:27 5.75 PROD1, DRILL DRLG P Drill, 1.64 BPM @ 3950 PSI FS, BHP=4001 10,595.0 10,670.0 10/26/2021 08:27 10/26/2021 08:42 0.25 PROD1, DRILL DDRL P Broke thru something ROP increased 10,670.0 10,690.0 10/26/2021 08:42 10/26/2021 11:42 3.00 PROD1, DRILL WPRT P Perform wiper to TT POW 40 K pump press 4500 pis @1.8 BPM IA 531 OA 10 WHP 425 jog EOB 10,690.0 7,581.0 10/26/2021 11:42 10/26/2021 12:27 0.75 PROD1, DRILL WPRT P Started packing off @ 7740' RBIH came thru window clean pump a sweep and pump sweep to surface 7,581.0 7,558.0 10/26/2021 12:27 10/26/2021 14:27 2.00 PROD1, DRILL WPRT P Open ECD and recip 7"@ 3 bpm tie into K1+ 11' lots of shale on shaker pump another sweep close ECD will not close 7,558.0 7,559.0 10/26/2021 14:27 10/26/2021 16:12 1.75 PROD1, DRILL TRIP T POOH the ECD will not close 7,559.0 0.0 10/26/2021 16:12 10/26/2021 16:42 0.50 PROD1, DRILL PULD T At 500' hold PJSM for BHA swap 0.0 0.0 10/26/2021 16:42 10/26/2021 18:42 2.00 PROD1, DRILL PULD T At surface lay down BHA #5 Lateral drilliing assembly #1 .5 AKO xtreme motor / HCC 3D bit SN# A265234 0.0 0.0 10/26/2021 18:42 10/26/2021 19:42 1.00 PROD1, DRILL CLEN P Flush Beads from surface lines and rams for function test 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 9/11 1A-25 Report Printed: 11/17/2021 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) 10/26/2021 19:42 10/26/2021 20:12 0.50 PROD1, DRILL BOPE P Function test BOPE's, 0.0 0.0 10/26/2021 20:12 10/26/2021 22:12 2.00 PROD1, DRILL PULD T Pick up and Pressure Deploy BHA# 6 Lateral drilling assembly # 2 , .5 AKO xtreme motor W/ BH Dynamus (TX25207) SN# 5290676 0.0 0.0 10/26/2021 22:12 10/27/2021 00:00 1.80 PROD1, DRILL TRIP T RIH W/EDC open to 500', Close EDC pump 1.85 bpm 4568 psi Diff 975 agitator test good , RIH T/ 7475 tie in for -10 correction, 0.0 7,500.0 10/27/2021 00:00 10/27/2021 01:30 1.50 PROD1, DRILL TRIP P RIH clean pass through window , sat down @ 7667 due to orientation of the bha , pu and RIH to 7770 sat down 100 psi motor work popped through, RIH T/10690' no issues 7,500.0 10,690.0 10/27/2021 01:30 10/27/2021 02:30 1.00 PROD1, DRILL DRLG P Drill F/ 10690' T/ 10759' FREE SPIN = 1.8 BPM 4420 PSI DIFF 920 CT WT 1.5K WHP 401 PSI 12 PPG EQ @ WINDOW // DRILLING = 1.8 IN 1.8 OUT MW 8.65/8.75 CT WT 0 WOB .5 K 72 FPH 10,690.0 10,759.0 10/27/2021 02:30 10/27/2021 02:36 0.10 PROD1, DRILL WPRT P P/U ran out of push BHA wiper PU wt 42k 10,759.0 10,759.0 10/27/2021 02:36 10/27/2021 04:36 2.00 PROD1, DRILL DRLG P Drill F/ 10759' T/ 10841.00' FREE SPIN = 1.8 BPM 4420 PSI DIFF 920 CT WT 1.5K WHP 401 PSI 12 PPG EQ @ WINDOW // DRILLING = 1.8 IN 1.8 OUT MW 8.65/8.75 CTWT= 0 DHWOB= .5 K ROP=72 FPH 10,759.0 10,841.0 10/27/2021 04:36 10/27/2021 04:42 0.10 PROD1, DRILL WPRT P 100' Wiper continue with short wipers as needed 10,841.0 10,841.0 10/27/2021 04:42 10/27/2021 09:27 4.75 PROD1, DRILL TRIP P Town called TD pump a 10 x 10 sweep / sweep is out of bit POOH TD 11030' pump sweeps at EOB and jog 10,841.0 11,030.0 10/27/2021 09:27 10/27/2021 12:12 2.75 PROD1, DRILL TRIP P Pulled thru build section and window clean continue OOH 11,030.0 7,594.0 10/27/2021 12:12 10/27/2021 14:27 2.25 PROD1, DRILL TRIP P Tagged up at surface RBIH for tie in and get bottom hole pressure for kill wait mud and confirm TD 7,594.0 78.0 10/27/2021 14:27 10/27/2021 19:27 5.00 PROD1, DRILL TRIP P Tie into k1 marker -9.5' bottom hole press 3654 WHP 863 MD 7500' 5880.8 TVD @ sensor confirm well at 11.79 ( 12.0 KWF), RIH window clean @ HS, Run through build clean no set downs continue to bottom to confirm TD @ 11033' 78.0 11,033.0 10/27/2021 19:27 10/27/2021 20:00 0.55 PROD1, DRILL CIRC P Pump 12 ppg Liner running pill 2 ppb beads 1.5% Low Torque and 1.5% 776 to bit 11,033.0 11,033.0 10/27/2021 20:00 10/27/2021 23:15 3.25 PROD1, DRILL TRIP P POOH laying liner running pill to window , 12 ppg KWF to surface 11,033.0 102.0 10/27/2021 23:15 10/27/2021 23:45 0.50 PROD1, DRILL OWFF P Flow check well confirm no flow at surface, PJSM laying down bha 102.0 102.0 10/27/2021 23:45 10/28/2021 00:00 0.25 PROD1, DRILL PULD P Pop injector off the well, check coil for flat spots, Lay down BHA# 6 Lateral drilling assembly # 2 102.0 0.0 10/28/2021 00:00 10/28/2021 01:00 1.00 PROD1, DRILL PULD P Lay down BHA# 6 Lateral Drilling Assembly 2 0.0 0.0 10/28/2021 01:00 10/28/2021 04:45 3.75 COMPZ1, CASING PUTB P PJSM, Pick up and run 36 jts 2-3/8 stl liner w/ solid bullnose and QCLL Receptical- L80 // Total footage 1112.25' 0.0 1,112.3 10/28/2021 04:45 10/28/2021 05:00 0.25 COMPZ1, CASING PUTB P Rig down liner running equipment prep to pick up BHI BHA 1,112.3 1,156.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 10/11 1A-25 Report Printed: 11/17/2021 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) 10/28/2021 05:00 10/28/2021 06:20 1.34 COMPZ1, CASING TRIP P RIH w / liner run #1 1,158.0 11,028.7 10/28/2021 06:20 10/28/2021 10:07 3.78 COMPZ1, CASING TRIP P Liner run #1 is on bottom @ 11028.7' CTMD MWD is shorted out PUH PUW 30 k set back down pump off liner POOH fil hole down BS 11,028.7 7,572.0 10/28/2021 10:07 10/28/2021 11:30 1.38 COMPZ1, CASING TRIP P At 7572' park coil perform a no flow good no flo continue OOH 7,572.0 25.0 10/28/2021 11:30 10/28/2021 13:30 2.00 COMPZ1, CASING PUTB P At surfacehold a PJSM for laying down BHA perform no flow ck WHP 0 / IA 73 / OA 11 GOOD NO FLOW after laying down tools the wire pull out of the E-line head re-head 25.0 0.0 10/28/2021 13:30 10/28/2021 16:00 2.50 COMPZ1, CASING PUTB P PJSM for picking up 71 joints of solid liner rig up floor for running liner 0.0 0.0 10/28/2021 16:00 10/28/2021 21:00 5.00 COMPZ1, CASING PUTB P , pick up disolvable bullnose and make up to solid liner , Pick up 71 jts 2-3/8" stl solid liner 0.0 2,238.0 10/28/2021 21:00 10/28/2021 22:00 1.00 COMPZ1, CASING PULD P PJSM, Pick up Baker Hughes Coil track BHA, Knuckle, and QCLL 2,238.0 2,238.0 10/28/2021 22:00 10/28/2021 23:00 1.00 COMPZ1, CASING PULD T BHA would not read ANN/Bore Press when powered up, Swab BHA 2,238.0 2,238.0 10/28/2021 23:00 10/29/2021 00:00 1.00 COMPZ1, CASING TRIP P RIH with liner run # 1 Knuckle jt, NSAK GS spear, NSAK Permanent QCLL, 71 jts 2-3/8" 4.7# L-80 Solid Linter = 2189.66, 2-3/8" Dissolvable Bull Nose 2,238.0 7,400.0 10/29/2021 00:00 10/29/2021 03:30 3.50 COMPZ1, CASING TRIP P RIH with liner run 2 , tie into EOP flag - 16.72' correction, pu wt = 30k pass through the window clean , set down at 9719' work pipe worked past spot , pu wt 40 k up wt , latch into 1st liner run @ 9911.81, pu wt 50k, set down pump off liner , pick up to 7709' subtract liner from bit depth TOL =7728.73 7,400.0 9,911.0 10/29/2021 03:30 10/29/2021 05:00 1.50 COMPZ1, CASING TRIP P Trip out of hole 9,911.0 0.0 10/29/2021 05:00 10/29/2021 06:00 1.00 COMPZ1, CASING PULD P At surface hold PJSM pop off well L?D MWD tools set up to pump slack management cut 184' and found wire hand cut coil and re-head total pipe cut 190' PULL TEST CTC to 35 k PT to 3500 ps displace seawater out of coil with 12 ppg kill weigth mud 0.0 0.0 10/29/2021 06:00 10/29/2021 11:45 5.75 COMPZ1, CASING PUTB P Open swab fill well took1 bbl to fill well pop off well pick up liner run #3 crew change hold another PJSM 0.0 0.0 10/29/2021 11:45 10/29/2021 14:00 2.25 COMPZ1, CASING TRIP P Liner is in the well stab injector on well RIH Nabors is having computer issues 344.6 7,000.0 10/29/2021 14:00 10/29/2021 16:00 2.00 COMPZ1, CASING TRIP P Tie into HRV shale -10.5' correction 7,000.0 7,000.0 10/29/2021 16:00 10/29/2021 17:30 1.50 COMPZ1, CASING CIRC P Set down at 7725.9' PUH 40k Top of liner at 7424.3' Circ out kill weight mud with seawater freeze protect with diesel from 2500' 7,000.0 7,000.0 10/29/2021 17:30 10/29/2021 18:45 1.25 DEMOB, WHDBOP TRIP P POOH to 2500' for freeze protect of well 7,000.0 2,500.0 10/29/2021 18:45 10/29/2021 20:00 1.25 DEMOB, WHDBOP CIRC P Rig up Little Red, Little Red stuck on the pad 15 min to get them spotted up , pressure test to 4500 psi , fill coil with 30 bbls diesel, 2,500.0 2,500.0 10/29/2021 20:00 10/29/2021 21:30 1.50 DEMOB, WHDBOP TRIP P POOH laying in diesel for freeze protect F/ 2500' T/ Surface taking returns to tiger tank 2,500.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 11/11 1A-25 Report Printed: 11/17/2021 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) 10/29/2021 21:30 10/29/2021 23:15 1.75 DEMOB, WHDBOP PULD P Pressure Un-Deploy BHA # 9 Swell packer bha , Diesel in stack take returns to tiger tank , lay down 0.0 0.0 10/29/2021 23:15 10/30/2021 00:00 0.75 DEMOB, WHDBOP CTOP P Make up nozzle and flush stack and surface lines with sea water, flush to tiger tank Blow down surface lines 0.0 0.0 10/30/2021 00:00 10/30/2021 04:00 4.00 DEMOB, WHDBOP RURD P RD, MT pits and off load TT, remove transducers, nipple down stack, break down dike around cellar (3"x12"), secure cellar for pulling off well, blow down steam, drain line blown down, secure reel, INJH, and PDL's for transport, Load out rig equipment on KDTH trucks *** Rig Released @ 0400 on 10/30/2021***. 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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 Melissa LeMay Melissa.LeMay@bakerhughes.com 15% &4FU 11/22/2021 By Abby Bell at 9:31 am, Nov 22, 2021 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-25L1 ConocoPhillips Alaska, LLC Permit to Drill Number: 221-070 Surface Location: 731' FSL, 311' FWL, SEC 5, T11N, R10E, UM Bottomhole Location: 90 FNL, 4589 FEL, SEC 8, T11N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced well. The permit is for a new wellbore segment of existing well Permit to Drill 190-167, API Number 50-029-22116-0-00. Production should continue to be reported as a function of the original API number stated above. 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 AOGCC within 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 September, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.09 09:41:31 -08'00' 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 11,950'TVD:6006' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 102' KB 15. Distance to Nearest Well Open Surface: x-540181 y- 5970819 Zone:4 67' GL to Same Pool:887' (1A-09) 16. Deviated wells:Kickoff depth: 7595 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3" 2-3/8" 4.7# L-80 ST-L/ HYD 511 4355' 7464' 5994' 11950' 6006' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): NA TVD 80' 3839' - 6459' 1269' Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: James Ohlinger Contact Email: Staff CTD Engineer Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Jeff Connelly Jeff.S.Connelly@ConocoPhillips.com 907-263-4112 10/15/2021 31000 ft (KPA boundary) 1278' 80' 4641' Effect. Depth TVD (ft): 7576-7618, 7662-7643, 7776-7783, 7797-7842 6082-6115, 6118-6134, 6234-6240, 6240-6283 KRU 1A-25L1 Kuparuk River Pool / Kuparuk River Oil Pool Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. - 8093' 5952180 Specifications 3906 Cement Volume MDSize Plugs (measured): (including stage data) Slottted / Solid Liner 8093 6459' 7" - Total Depth MD (ft):Total Depth TVD (ft): Casing NA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 3296 2656 FNL, 2656 FEL, SEC 8, T11N, R10E, UM 90 FNL, 4589 FEL, SEC 8, T11N, R10E, UM LONS 79-016 P.O. Box 100360 Anchorage, AK 99510-0360 ConocoPhillips Alaska, Inc. 731' FSL, 311' FWL, SEC 5, T11N, R10E, UM ADL 25647 ALK 465 2469 18. Casing Program:Top - Setting Depth - Bottom Authorized Title: Authorized Signature: 7" - 300 SX CLASS G 10 bbl AS1 neat, 115 bbl AS1, 2 bbl AS1 neat Production Production Tie-Back - 8058' 1234' Intermediate Authorized Name: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 4604' 224 SX AS I 9-5/8"1074 XS AS III, 453 SX CLASS G Effect. Depth MD (ft): Conductor/Structural 16"45' 8120 6478 Length s N ype of W l Class: os N s No s N o D s h s sD h h 59 o well is G S S 20 AA S S S s No s No S G y s No s o Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Samantha Carlisle at 2:01 pm, Aug 31, 2021 Digitally signed by James Ohlinger DN: CN=James Ohlinger, O=ConocoPhillips, OU=CTD, E=James.J.Ohlinger@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.31 09:56:01-08'00' Foxit PDF Editor Version: 11.0.0 James Ohlinger DSR-8/31/21 X DLB DLB 09/03/2021 X X X X 50-029-22116-60-00 X X VTL 9/8/21 221-070 X BOP test to 4000 psig Annular preventer test to 2500 psig dts 9/8/2021 9/9/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.09 09:41:58 -08'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Aug 25, 2021 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for a permit to drill one lateral out of the KRU 1A-25 (PTD# 190-167) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid-October 2021. The objective will be to drill one lateral, KRU 1A- 25L1, targeting the Kuparuk C-sand interval. Attached to permit to drill applications are the following documents: Permit to Drill Application Forms (10-401) for 1A-25L1 Detailed Summary of Operations Directional Plans for 1A-25L1 Current Wellbore Schematic Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, Jeff Connelly Coiled Tubing Drilling Engineer ConocoPhillips Alaska Digitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.08.31 06:22:15-08'00' Foxit PDF Editor Version: 11.0.0 Jeff Connelly Kuparuk CTD Lateral 1A-25L1 Application for Permit to Drill Document Page 1 of 6 August 25, 2021 1. Well Name and Classification......................................................................................................... 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) .................................................................................................................. 2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)) ................................................................................................................................................. 2 3. Blowout Prevention Equipment Information ................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ................................................................................................................................................ 2 4. Drilling Hazards Information and Reservoir Pressure .................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)) ................................................................................................................................................ 2 5. Procedure for Conducting Formation Integrity tests .................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ................................................................................................................................................. 2 6. Casing and Cementing Program .................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) ................................................................................................................................................. 3 7. Diverter System Information .......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................................. 3 8. Drilling Fluids Program................................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(8)) ................................................................................................................................................. 3 9. Abnormally Pressured Formation Information ............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)) ................................................................................................................................................. 4 10. Seismic Analysis ............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) ............................................................................................................................................... 4 11. Seabed Condition Analysis ............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11)) ............................................................................................................................................... 4 12. Evidence of Bonding ...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12)) ............................................................................................................................................... 4 13. Proposed Drilling Program ............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13)) ............................................................................................................................................... 4 Summary of CTD Operations .......................................................................................................................................... 4 Liner Running .................................................................................................................................................................. 5 14. Disposal of Drilling Mud and Cuttings ........................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14)) ............................................................................................................................................... 5 15. Directional Plans for Intentionally Deviated Wells ........................................................................ 6 (Requirements of 20 AAC 25.050(b)) ..................................................................................................................................................... 6 16. Attachments .................................................................................................................................... 6 Attachment 1: Directional Plans for the 1A-25L1 lateral ................................................................................................. 6 Attachment 2: Current Well Schematic for 1A-25 ........................................................................................................... 6 Attachment 3: Proposed Well Schematic for the 1A-25L1 lateral ................................................................................... 6 PTD Application: 1A-25L1 Page 2 of 6 August 25, 2021 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed lateral described in this document is 1A-25L1. The lateral will be classified as “Development” well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the C-Sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1A-25L1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations . Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Using the maximum formation pressure in the area of 3989 psi found in 1A-05 measured 9/28/2011 (i.e.12.32 ppg EMW), the maximum potential surface pressure in 1A-25, assuming a gas gradient of 0.1 psi/ft, would be 3296 psi. See the “Drilling Hazards Information and Reservoir Pressure” section for more details. The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1A-25 was measured at 3828 psi @ 6097’ TVD (12.1 ppg) on 8/28/2021. The maximum downhole pressure in the 1A-25 vicinity is 1A-05 at 3989 psi @ 6226 ’ TVD (12.32 ppg – Measured 9/28/2011). Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1A-25 have injected gas, so there is a possibility of encountering free gas while drilling the 1A-25 lateral. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1A-25 lateral will be formation instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1A-25 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. PTD Application: 1A-25L1 Page 3 of 6 August 25, 2021 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top MD Liner Btm MD Liner Top TVDSS Liner Btm TVDSS Liner Details 1A-25L1 ~7460’ 11,950’ 5889’ 5904’ 2-3/8", 4.7#, L-80, ST-L slotted liner, solid liner with swell packer, and 6’ polished bore with a liner-top packer Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16” 65 H-40 Welded 36’ 80’ 36’ 80’ 1640 670 Surface 9-5/8” 36.0 J-55 BTC 35’ 4641’ 35’ 3839’ 3520 2020 Production 7” 26.0 J-55 BTC 35’ 8093’ 35’ 6459’ 4980 4330 Liner 5” 18.0 TC-II TC-II 35’ 1278’ 35’ 1269’ 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System Window milling operations: Water-Based PowerVis milling fluid (8.6 ppg) Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. Completion operations: The well will be loaded with completion fluid in order to provide formation over- balance and well bore stability while running completions (NaBr up to 12.2 ppg or Potassium-Formate should it be required) Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 “Blowout Prevention Equipment Information”. In the 1A-25L1 lateral, operations will target a constant BHP of ~12.2 ppg EMW at the window (just over formation pressure). The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Note: Expected pressure of 12.3 ppg MWE in the Kuparuk will be handled with CTD MPD, see above. DLB PTD Application: 1A-25L1 Page 4 of 6 August 25, 2021 Pressure at the 1A-25 Window (7595’ MD, 6097’ TVD) Using MPD Pumps On (1.9 bpm) Pumps Off C-sand Formation Pressure (12.1 ppg) 3828 psi 3828 psi Mud Hydrostatic (8.6 ppg) 2727 psi 2727 psi Annular friction (i.e. ECD, 0.080 psi/ft) 608 psi 0 psi Mud + ECD Combined (no choke pressure) 3335 psi (underbalanced ~493 psi) 2727 psi (underbalanced ~1101 psi) Target BHP at Window (12.2 ppg) 3868 psi 3868 psi Choke Pressure Required to Maintain Target BHP 533 psi 1015 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of CTD Operations KRU well 1A-25 is equipped with 3-1/2” tubing and 7” production casing. The CTD sidetrack will utilize one lateral to target the C-sands to the north of 1A-25. CDR3-AC will mill a window in the 7” casing at ~7595’ MD and the 1A-25 lateral will be drilled to TD at 11,950’ MD, targeting the C-sands to the north. It will be completed with 2-3/8” slotted liner, solid liner with a swell packer, and a 6’ polished bore from TD up to ~7460’ MD. CTD Pre-Rig, Drill, and Complete 1A-25L1 Sidetrack: October 2021 Pre-CTD Work 1. Pre-CTD diagnostics 2. Slickline: Dummy whipstock drift, tag/record PBTD, c/o GLV’s, injectivity test 3. CTU: Mill XN nipple, pump cement 4. Slickline: Tag TOC & obtain SBHP 5. E-Line: Run caliper/GR 6. E-Line: Set High Expansion Wedge (HEW) PTD Application: 1A-25L1 Page 5 of 6 August 25, 2021 Rig Work 1. MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. 2. Drill 1A-25L1 Lateral (C-sand - North) i. Mill 2.80” window at ~7595’ MD. ii. Drill 3” bi-center lateral to TD of 11,950’ MD. iii. Run 2Ǫ” slotted liner, solid liner with swell-packer, & 6’ polished bore from TD up to ~7460’ MD (into tubing-tail) 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work 1. Set liner-top packer on 6’ polished bore 2. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, deployment rams (the annular preventer will serve as a secondary barrier during BHA pressure deployment), double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick-line. When the BHA is spaced out properly, the deployment rams are closed on the BHA to isolate reservoir pressure via the annulus (the annular preventer will serve as a secondary barrier during BHA pressure deployment). A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running The 1A-25 lateral will be displaced to an overbalancing fluid prior to running liner. See “Drilling Fluids” section for more details. While running 2-3/8” slotted liner, a joint of 2-3/8” non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8” rams will provide secondary well control while running 2-3/8” liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) x No annular injection on this well. x All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. PTD Application: 1A-25L1 Page 6 of 6 August 25, 2021 x Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. x All wastes and waste fluids hauled from the pad must be properly documented and manifested. x Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) The Applicant is the only affected owner. Please see Attachment 1: Directional Plans Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1A-25L1 31,000’ Distance to Nearest Well within Pool Lateral Name Distance Well 1A-25L1 887’ 1A-09 16. Attachments Attachment 1: Directional Plans for the 1A-25L1 lateral Attachment 2: Current Well Schematic for 1A-25 Attachment 3: Proposed Well Schematic for the 1A-25L1 lateral ConocoPhillips Alaska Inc_Kuparuk ConocoPhillipsAnticollisionReportfor1A-25-1A-25L1wp02Trav.CylinderNorthProximityScanonCurrentSurveyData(NorthReference)ReferenceDesign:Kuparuk1APad-1A-25-1A-25L1CTDSidetrack-1A-25L1wp02ScanRange:7,500.00to11,950.00usft.TrueVerticalDepth.ScanRadiusisUnlimited.ClearanceFactorcutoffisUnlimited.MaxEllipseSeparationis1,000.00usft@MeasuredDepth(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorSummaryBasedonMinimumMinimumDistance(usft)MeasuredDepth(usft)SiteNameComparisonWellName-WellboreName-DesignKuparuk1APad1A-06-1A-06-1A-061A-06-1A-06-1A-061A-09-1A-09-1A-091A-09-1A-09-1A-091A-11-1A-11-1A-117.857EllipseSeparation7.541ClearanceFactor6.466EllipseSeparation5.517ClearanceFactor10.752ClearanceFactorPass-Pass-Pass-Pass-Pass-9,000.008,928.6610,835.989,754.917,800.001,131.031,164.55887.25943.211,264.679,000.008,928.6610,835.989,754.917,800.00987.071,010.11750.03772.231,147.057,200.007,500.006,400.006,800.007,600.006.153CentreDistance5.858EllipseSeparation5.840ClearanceFactor1A-24-1A-24-1A-241A-24-1A-24-1A-241A-24-1A-24-1A-2410,000.0010,000.009,954.02913.32920.22934.2310,000.0010,000.009,954.02764.88763.14774.256,800.006,900.007,000.00Pass-Pass-Pass-SurveytoolprogramSurvey/PlanSurveyToolFrom(usft)To(usft)7,500.0011,950.00GYD-CT-CMSMWDOWSG200.007,500.001A-25L1wp02Ellipseerrortermsarecorrelatedacrosssurveytooltie-onpoints.Calculatedellipsesincorporatesurfaceerrors.Separationistheactualdistancebetweenellipsoids.DistanceBetweencentresisthestraightlinedistancebetweenwellborecentres.ClearanceFactor=DistanceBetweenProfiles/(DistanceBetweenProfiles-EllipseSeparation).AllstationcoordinateswerecalculatedusingtheMinimumCurvaturemethod.24August,2021-15:17Page2of4COMPASSKuparukRiverUnit_lSeparationWarning -3750-3000-2250-1500-7500South(-)/North(+) (750 usft/in)0 750 1500 2250 3000 3750 4500 5250 6000 6750West(-)/East(+) (750 usft/in)6200630063761A-25/1A-251A-05/1A-051A-06/1A-061A-07/1A-07620062651A-08/1A-0862006300640064391A-09/1A-091A-10/1A-101A-11/1A-111A-12/1A-121A-23/1A-231A-24/1A-2458901A-24/1A-24L11A-24/1A-24L1-016200630063761A-25/1A-251A-26/1A-261A-27/1A-271A-28/1A-2859041A-25/1A-25L1 CTD SidetrackProject:Kuparuk River Unit_1Site:Kuparuk 1A PadWell: 1A-25Wellbore:1A-25L1 CTD SidetrackPlan: 1A-25L1 wp02 (1A-25/1A-25L1 CTD Sidetrack)Azimuths to True NorthMagnetic North: 15.53°Magnetic FieldStrength: 57313.5nTDip Angle: 80.74°Date: 12/31/2020Model: BGGM2019TMMean Sea LevelWELLBORE DETAILS: 1A-25L1 CTD SidetrackParent Wellbore: 1A-25Tie on MD: 7500.00REFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well 1A-25, True NorthVertical (TVD) Reference:Mean Sea LevelSection (VS) Reference:Slot - (0.00N, 0.00E)Measured Depth Reference:1A-25 @ 102.00usft (1A-25)Calculation Method: Minimum Curvature 59506125SSTVD (350 usft/in)-3850 -3675 -3500 -3325 -3150 -2975 -2800 -2625 -2450 -2275 -2100 -1925 -1750 -1575 -1400 -1225 -1050 -875 -700 -525Vertical Section at 355.00° (350 usft/in)1A-25L1 T41A-25L1 T11A-25L1 T31A-25L1 T61A-25L1 T51A-25L1 T2.2-3600-3150-2700-2250-1800-1350-900South(-)/North(+) (900 usft/in)-450 0 450 900 1350 1800 2250West(-)/East(+) (900 usft/in)1A-25L1 T2.21A-25L1 T51A-25L1 T61A-25L1 T31A-25L1 T11A-25L1 T4SECTION DETAILSSecMD Inc Azi TVDss+N/-S+E/-W Dleg TFaceVSect1 7500.00 37.02 151.39 5920.65 -3334.58 2298.36 0.00 0.00-3522.202 7595.00 39.13 153.50 5995.43 -3386.52 2325.44 2.61 32.50 -3576.313 7624.00 44.35 153.50 6017.06 -3403.79 2334.05 18.00 0.00 -3594.274 7725.44 90.00 153.50 6055.38 -3485.27 2374.67 45.00 0.00-3678.985 7850.00 102.40 208.62 6040.83-3604.022373.20 45.00 75.00-3797.156 8000.00 91.10 275.81 6020.93 -3668.34 2248.78 45.00 94.00 -3850.387 8400.00 89.10303.746020.23 -3534.32 1876.11 7.00 94.00 -3684.398 8700.00 89.16 282.74 6024.85 -3416.61 1602.03 7.00 -90.00-3543.249 9100.00 91.13 310.67 6023.83 -3238.62 1248.25 7.00 86.00-3335.0910 9325.00 91.09 294.92 6019.45 -3117.16 1059.75 7.00 -90.00-3197.6611 9650.00 102.85 314.58 5979.69 -2935.10 796.08 7.00 58.00-2993.3212 9800.00 97.46 305.42 5953.20 -2840.42 683.07 7.00 -120.00 -2889.1513 9975.00 91.24 316.01 5939.89 -2726.77 551.11 7.00 120.00-2764.4314 10425.0090.54347.51 5932.71 -2335.36 340.87 7.00 91.00 -2356.1815 10725.00 96.86 7.58 5913.16 -2037.96 327.93 7.0072.00-2058.7916 10950.00 93.12 352.22 5893.47 -1814.54 327.46 7.00 -103.00 -1836.1717 11200.00 89.10 9.26 5888.59 -1565.58 330.72 7.00 103.00 -1588.4418 11500.00 88.87 354.26 5893.92-1266.62339.91 5.00 -91.00 -1291.4319 11950.00 88.58 16.77 5904.06 -821.69 382.86 5.00 91.00 -851.93WELL DETAILS: 1A-25Ground Level: 0.00+N/-S+E/-W Northing EastingLatittudeLongitude0.00 0.00 5970819.08 540180.2870° 19' 52.366 N149° 40' 26.719 WKuparuk River Unit_1Kuparuk 1A Pad1A-251A-25L1 CTD Sidetrack1A-25L1 wp02Reference Coordinate: Well 1A-25, True NorthReference TVD: Mean Sea LevelReference Section:Slot - (0.00N, 0.00E)Reference MD:1A-25 @ 102.00usft (1A-25)Calculation Method: Minimum CurvatureWELLBORE DETAILS1A-25L1 Parent Wellbore : 1A-25Tie On Depth (ft MD): 7500Azimuths to True NorthMagnetic North: 15.53°Magnetic FieldStrength: 57313.5nTDip Angle: 80.74°Date: 12/31/2020Model: BGGM2019TM Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 29' of Fill) 7,813.0 5/8/2019 1A-25 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled 2.81" CSA-2 Plug 4/27/2021 1A-25 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,641.1 Set Depth (TVD) … 3,838.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,093.3 Set Depth (TVD) … 6,459.3 Wt/Len (l… 26.00 Grade J-55 Top Thread ABMOD BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 1,278.1 Set Depth (TVD) … 1,269.0 Wt/Len (l… 26.00 Grade TC-ll Top Thread TC-ll Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.0 Set Depth (ft… 7,352.1 Set Depth (TVD) (… 5,902.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.04 Hanger McENVOY GEN IV TUBING HANGER 3.000 488.0 488.0 0.08 NIPPLE CAMCO 'DS' NIPPLE 2.875 7,241.8 5,811.1 34.19 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,248.8 5,816.9 34.16 PBR BAKER PBR 2.990 7,272.3 5,836.3 34.08 PACKER BAKER FHL PACKER 2.910 7,325.1 5,880.1 34.24 NIPPLE 'DS' NIPPLE 2.812 7,342.8 5,894.7 34.42 LOCATOR BAKER GBH-22 LOCATOR SUB 2.990 7,344.0 5,895.7 34.43 MULE SHOE 8 ' MULE SHOE, Spacer Tube w/1 FT Space out 2.990 Tubing Description TUBING 4"x3.5" Post 2013 WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,347.2 Set Depth (ft… 7,471.0 Set Depth (TVD) (… 5,999.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,347.2 5,898.3 34.47 PBR BAKER PBR, 10' STROKE 3.000 7,360.9 5,909.6 34.60 PACKER BAKER 'HB' RETRIEVABLE PACKER 2.870 7,458.6 5,989.4 36.18 NIPPLE OTIS XN NIPPLE 2.750 7,470.3 5,998.8 36.42 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,576.0 7,584.0 6,082.6 6,088.9 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,584.0 7,596.0 6,088.9 6,098.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,596.0 7,618.0 6,098.2 6,115.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,622.0 7,643.0 6,118.3 6,134.4 UNIT B, 1A-25 1/5/1992 4.0 APERF 180 deg Phase; HLS 2.5" 7,776.0 7,783.0 6,234.4 6,239.6 A-5, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT 7,797.0 7,842.0 6,249.9 6,282.7 A-4, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,982.1 2,601.2 43.65 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,216.0 7/20/2017 2 4,571.6 3,786.1 40.76 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 5/27/2020 3 5,760.5 4,680.8 42.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 4 6,596.9 5,300.1 41.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 5 7,185.6 5,764.6 34.30 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/19/2014 1A-25, 4/28/2021 4:07:35 PM Vertical schematic (actual) PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 SOS; 7,470.3 NIPPLE; 7,458.6 PACKER; 7,360.9 PBR; 7,347.2 MULE SHOE; 7,344.0 LOCATOR; 7,342.8 NIPPLE; 7,325.1 PACKER; 7,272.3 PBR; 7,248.8 SEAL ASSY; 7,241.8 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD KB-Grd (ft) 35.01 Rig Release Date 1/1/1991 1A-25 ... TD Act Btm (ftKB) 8,120.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211600 Wellbore Status PROD Max Angle & MD Incl (°) 47.19 MD (ftKB) 2,500.00 WELLNAME WELLBORE1A-25 Annotation Last WO: End Date 11/22/2014 H2S (ppm) 75 Date 8/10/2016 Comment SSSV: NIPPLE 1A-25 Proposed CTD Schematic3-1/2" Camco DS nipple @ 488' MD (2.875" min ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ 2982', 4572', 5760', 6597', 7186'Baker PBR @ 7249' MDBaker FHL Packer @ 7272' MDDS Nipple @ 7325' MD (2.812" ID)Baker Locator Sub @ 7343' MDMule Shoe @ 7344'MD_________________Baker PBR @ 7347' MDBaker HB Packer @ 7361' MD_________________3-1/2 Otis XN nipple @ 7459' MD (2.75" min ID, No-Go)9-5/8" 36# J-55 shoe @ 4641' MD7" 26# J-55 shoe @ 8093' MD16" 65# H-40 shoe @ 80' MDA-sand perfs 7776' - 7842' MDKOP @ 7595' MDC-sand perfs7576' - 7643' MDModified by JSC 8/30/20211A-25L1 wp02Plan TD: 11,950' MDWOB Limit: 10,600' MDLTP (~7464')Swell packer (depth TBD)TOC: 7759' RKB Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. X X 029-22116-00-00 KRU 1A-25L1 Kuparuk River Oil Kuparuk River 221-070 190-167 X X WELL PERMIT CHECKLISTCompanyConocoPhillips CompanyWell Name:KUPARUK RIV UNIT 1A-25L1Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2210700KUPARUK RIVER, KUPARUK RIV OIL - 490100NA1Permit 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 plat include, 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) (For NA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NAConductor set for KRU 1A-2518Conductor string providedNASurface casing set and cemented19Surface 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 an uncemented slotted/solid liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYesMax formation pressure is 3906 psi(12.1 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 3296 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 1A-Pad are H2S bearing. H2S measures required.35Permit 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]ApprDLBDate9/1/2021ApprVTLDate9/7/2021ApprDLBDate9/7/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03
