The URL can be used to link to this page

Home My WebLink About222-0291. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Pull LT Packer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet None feet true vertical feet None feet Effective Depth measured feet 8919'feet true vertical feet 6417' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6468' TVD Packers and SSSV (type, measured and true vertical depth) 8919' MD 2019' MD 6417' TVD 1796' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 324-008 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker S-3 Perm Packer SSSV: Camco TRDP-4E Sfty Vlv (locked out) Allen Echete allen.eschete@conocophillips.com (907) 265-6558Intervention Engineer 9096-9141' 6576-6616' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~ ~~ INJECTOR ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-029 50-029-22932-61-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0028242 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1C-15L2 Plugs Junk measured Length Production Liner 9354' 3282' Casing 2-3/8" 6209' 121'Conductor Surface Intermediate 16" 9-5/8" 80' 6249' 4488' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 12784' 6564' 12784' 6564' 9393' 12235' 6843' 6567' 8977' MD By Grace Christianson at 3:14 pm, Apr 22, 2024 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2024.04.22 08:26:06-08'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete DSR-4/23/24 DTTMSTART JOBTYP SUMMARYOPS 3/7/2024 OPTIMIZE WELL DRIFT TBG W/ 2.5" CENT, 1.75" S-BAILER TO LINER TOP PACKER @ 8840' RKB, NO OBSTRUCTIONS FOUND. LDFN, JOB IN PROGRESS. 3/8/2024 OPTIMIZE WELL MEASURE SBHP 5005 psi @ 8840' RKB, DRIFTED TBG W/ 2.75" GAUGE RING TO LTP @ 8840' RKB. LDFN, JOB IN PROGRESS. 3/12/2024 OPTIMIZE WELL MADE ATTEMPT TO PULL LTP @ 8840' RKB, SHEARED PULLING TOOL. RDMO TEMP - 36. JOB IN PROGRESS. 3/15/2024 OPTIMIZE WELL ATTEMPT TO PULL LTP @ 8840' RKB, JOB IN PROGRESS 3/16/2024 OPTIMIZE WELL ATTEMPT TO PULL LTP @ 8840' RKB, JOB SUSPENDED, WIll RETURN WITH .160 WIRE. 3/26/2024 OPTIMIZE WELL ATTEMPT TO PULL LTP W/ .160 WIRE @ 8840'RKB. JOB IN PROGRESS 3/28/2024 OPTIMIZE WELL PULLED LINER TOP PACKER ASSEMBLY @ 8840'RKB, RECOVERED ELEMENT DEBRIS FROM 8840'RKB. JOB COMPLETE 1C-15 Remove Liner Top Packer Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,320.0 1C-15 12/7/2011 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled LTP 1C-15 3/28/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.4 6,249.3 4,488.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,392.7 26.00 L-80 ABM-BTC WINDOW L1 7 6.00 9,142.0 9,147.0 6,621.5 26.00 L-80 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.6 Set Depth 8,976.5 Set Depth 6,468.1 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.6 36.6 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 2,019.3 1,796.2 49.18 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE (LOCKED OUT 7/16/2004) 2.812 3,324.9 2,602.4 51.58 GAS LIFT 5.500 CAMCO KBMM 2.920 5,349.2 3,907.5 50.32 GAS LIFT 5.500 CAMCO KBMM 2.920 6,592.1 4,709.3 49.76 GAS LIFT 5.500 CAMCO KBMM 2.920 7,553.6 5,339.8 48.22 GAS LIFT 5.500 CAMCO KBMM 2.920 8,330.6 5,905.9 35.35 GAS LIFT 5.500 CAMCO KBMM 2.920 8,826.5 6,333.3 26.13 GAS LIFT 5.500 CAMCO MMM 2.371 8,876.2 6,377.9 26.07 NIPPLE 4.540 CAMCO W NIPPLE 2.812 8,919.3 6,416.7 26.08 PACKER 5.968 BAKER S-3 PERMANENT PACKER 3.875 8,964.5 6,457.3 25.98 NIPPLE 4.470 CAMCO D NIPPLE 2.75" ID - MILLED OUT TO 2.80" ID 2/5/2003 2.800 8,975.6 6,467.3 25.94 SOS 4.520 BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) PATCH SURF CSG PATCH install from bottom of starter head to top of pup collar 1' 11.5", used 9 5/8" 40 #, .395 pipe for patch material 4/10/2009 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 5,349.2 3,907.5 50.32 2 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 6,592.1 4,709.3 49.76 3 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 7,553.6 5,339.8 48.22 4 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 8,330.6 5,905.9 35.35 5 GAS LIFT DMY BK-5 1 0.0 2/12/2003 0.000 8,826.5 6,333.3 26.13 6 GAS LIFT DMY RK 1 1/2 0.0 7/16/2004 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase 9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP 9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,096.0 9,142.0 1 FRAC 1/11/1999 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003 1C-15, 4/16/2024 2:49:42 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15 ... TD Act Btm (ftKB) 9,390.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293200 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,348.0 1C-15L1 6/28/2019 hazenmc Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: CUT LINER 1C-15L1 2/4/2022 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE 1C-15 CMT PLUG 4/15/2003 lmosbor NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER 2.38 1.92 8,845.3 11,111.0 4.43 L-80 STL Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long Northern Solutions HE 3/16/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,845.3 6,350.2 26.05 DEPLOY 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 11,072.7 O-RING 1.380 BAKER O-RING SUB 1.000 11,105.4 XO THREAD 2.380 XO 1.920 11,108.9 XO THREAD 2.380 XO 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,344.0 11,075.0 C-3, C-4, C-3, 1C-15L1 4/12/2003 4.0 SLOTS SLOTTED LINER 1C-15L1, 4/16/2024 2:49:43 PM Vertical schematic (actual) LINER; 8,845.3-11,111.0 SLOTS; 10,344.0-11,075.0 L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15L1 ... TD Act Btm (ftKB) 11,207.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293260 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End Date 4/13/2003 H2S (ppm) DateComment SSSV: LOCKED OUT Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 lateral 2 3/8 1.99 8,953.0 12,235.0 6,566.7 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,241.6 6,660.8 85.97 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686 10,118.5 6,588.3 85.52 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 11,192.9 6,599.4 92.89 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 1C-15L2, 4/16/2024 2:49:43 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15L2 ... TD Act Btm (ftKB) 12,784.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293261 Wellbore Status INJ Max Angle & MD Incl (°) 103.09 MD (ftKB) 9,278.41 WELLNAME WELLBORE1C-15 Annotation End DateH2S (ppm) DateComment 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull LT Packer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth TVD (ft): Effective Depth TVD: Junk (MD): None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-6558 Interventions Engineer KRU 1C-15L2 6564' 6564' None N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: allen.eschete@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8919' MD and 6417' TVD 8840' MD and 6345' TVD 2019' MD and 1796' TVD Allen Eschete STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028242, ADL0025649 222-029 P.O. Box 100360, Anchorage, AK 99510 50-029-22932-61-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 8977' MD 121' 4488' 121' 6249' 6843'9393' 16" 9-5/8" 80' 6209' 9096-9141' 9354' 2-3/8" 6576-6616' 7" Perforation Depth TVD (ft): 1/23/2024 12235'3282' 3-1/2" 6567' Packer: Baker S-3 Perm Packer Packer: NS AK Mono-Pak LT Packer SSSV: Camco TRDP-4E Safety Valve (Locked out) Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Total Depth MD (ft): 12784' Effective Depth MD: 12784' By Grace Christianson at 8:01 am, Jan 11, 2024 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2024.01.10 14:20:55-09'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete 324-008 DSR-2/15/24SFD 1/12/2024 12782' *SFD 10-404 *Per Completion Report received 4/25/2022 SFD X 1400 VTL 02/15/2024 12782' * SFD 6564' * SFD X *&:JLC 2/15/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.15 18:05:41 -06'00'02/15/24 RBDMS JSB 022124 KRU 1C-15 (PTD 198-229), KRU 1C-15L1 (PTD203-032), KRU 1C-15L2 (PTD 222-029) Well Work Juscaon & Objecves 1C-15 is a dual lateral CTD injector. The L2 lateral was drilled in April 2023, and a liner top packer was set to shut o the original L1 and focus injec#on into L2. Performance over the past year has been lackluster, and we want to reopen the L1 lateral to allow injec#on into both zones. This procedure is to harvest a SBHP in the isolated L2 fault block to help diagnose performance in this zone, before pulling the LTP to allow WAG injec#on into both laterals. Risks/Job Concerns • Min ID (1.781") is Northern Solu#ons AK Mono-Pak Liner Top Packer with 1.781" RX nipple @ 8840' RKB • Last tag was in L2 during CT FCO. Note break in liner in L2 from 10,002' to 10,118' RKB • Max inclina#on and dog leg are given for L2 liner, no need to access these during this work. Slickline 1. Verify with PE that well has been SI for 3 days minimum (72 hours) 2. MIRU SL, D&T with bailer as deep as possible. Note tag depth, suspected reasons for high tag, nature of Dll/bailer returns, and any other details in WSR, as applicable. 3. Obtain SBHP with dual SPARTEK gauges a) Perform 10 minute lubricator stop b) 30 minute stop @ 8840' RKB (6345' TVD) c) Pull up 100' TVD to 8728' RKB (6245' TVD) for 15 minute gradient stop d) Record Dndings on WSR 4. Pull Northern Solu#ons AK Mono-Pak Liner Top Packer from top of liner at 8840' RKB. 5. POOH, RD. Return well to DSO to BOL when ready. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,320.0 1C-15 12/7/2011 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Liner Top Packer 1C-15 3/30/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.4 6,249.3 4,488.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,392.7 26.00 L-80 ABM-BTC WINDOW L1 7 6.00 9,142.0 9,147.0 6,621.5 26.00 L-80 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.6 Set Depth … 8,976.5 Set Depth … 6,468.1 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.6 36.6 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 2,019.3 1,796.2 49.18 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE (LOCKED OUT 7/16/2004) 2.812 3,324.9 2,602.4 51.58 GAS LIFT 5.500 CAMCO KBMM 2.920 5,349.2 3,907.5 50.32 GAS LIFT 5.500 CAMCO KBMM 2.920 6,592.1 4,709.3 49.76 GAS LIFT 5.500 CAMCO KBMM 2.920 7,553.6 5,339.8 48.22 GAS LIFT 5.500 CAMCO KBMM 2.920 8,330.6 5,905.9 35.35 GAS LIFT 5.500 CAMCO KBMM 2.920 8,826.5 6,333.3 26.13 GAS LIFT 5.500 CAMCO MMM 2.371 8,876.2 6,377.9 26.07 NIPPLE 4.540 CAMCO W NIPPLE 2.812 8,919.3 6,416.7 26.08 PACKER 5.968 BAKER S-3 PERMANENT PACKER 3.875 8,964.5 6,457.3 25.98 NIPPLE 4.470 CAMCO D NIPPLE 2.75" ID - MILLED OUT TO 2.80" ID 2/5/2003 2.800 8,975.6 6,467.3 25.94 SOS 4.520 BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,840.0 6,345.4 26.05 PACKER Set NothernSolutions AK Mono-Pak Liner Top Packer w/ 1.781" RX nipple @ 8848' RKB (See Attachments) A2242 7201- R00 3/30/2022 1.781 PATCH SURF CSG PATCH install from bottom of starter head to top of pup collar 1' 11.5", used 9 5/8" 40 #, .395 pipe for patch material 4/10/2009 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 5,349.2 3,907.5 50.32 2 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 6,592.1 4,709.3 49.76 3 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 7,553.6 5,339.8 48.22 4 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 8,330.6 5,905.9 35.35 5 GAS LIFT DMY BK-5 1 0.0 2/12/2003 0.000 8,826.5 6,333.3 26.13 6 GAS LIFT DMY RK 1 1/2 0.0 7/16/2004 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase 9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP 9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,096.0 9,142.0 1 FRAC 1/11/1999 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003 1C-15, 1/9/2024 12:16:52 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev… 1C-15 ... TD Act Btm (ftKB) 9,390.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293200 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,348.0 1C-15L1 6/28/2019 hazenmc Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: CUT LINER 1C-15L1 2/4/2022 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE 1C-15 CMT PLUG 4/15/2003 lmosbor NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER 2.38 1.92 8,845.3 11,111.0 4.43 L-80 STL Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long Northern Solutions HE 3/16/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,845.3 6,350.2 26.05 DEPLOY 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 11,072.7 O-RING 1.380 BAKER O-RING SUB 1.000 11,105.4 XO THREAD 2.380 XO 1.920 11,108.9 XO THREAD 2.380 XO 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,344.0 11,075.0 C-3, C-4, C-3, 1C-15L1 4/12/2003 4.0 SLOTS SLOTTED LINER 1C-15L1, 1/9/2024 12:16:55 PM Vertical schematic (actual) LINER; 8,845.3-11,111.0 SLOTS; 10,344.0-11,075.0 PRODUCTION; 38.5-9,392.7 L2 lateral; 8,953.0-12,235.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev… 1C-15L1 ... TD Act Btm (ftKB) 11,207.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293260 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End Date 4/13/2003 H2S (ppm) DateComment SSSV: LOCKED OUT Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 lateral 2 3/8 1.99 8,953.0 12,235.0 6,566.7 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,241.6 6,660.8 85.97 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686 10,118.5 6,588.3 85.52 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 11,192.9 6,599.4 92.89 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 1C-15L2, 1/9/2024 12:16:55 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev… 1C-15L2 ... TD Act Btm (ftKB) 12,784.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293261 Wellbore Status INJ Max Angle & MD Incl (°) 103.09 MD (ftKB) 9,278.41 WELLNAME WELLBORE1C-15 Annotation End DateH2S (ppm) DateComment DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-22932-61-00Well Name/No.KUPARUK RIV UNIT 1C-15L2 Completion Status WAGINCompletion Date 3/27/2022 Permit to Drill 2220290 Operator ConocoPhillips Alaska, Inc. MD 12782 TVD 6564 Current Status WAGIN 7/19/2023 UIC Yes Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:GR/Res NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 4/27/20228900 12782 Electronic Data Set, Filename: 1C-15L2 GAMMA RES.las 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2 2MD Final Log.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 5MD Final Log.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 5TVDSS Final Log.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 10.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 11.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 12.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 13.cgm36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 GAMMA RES.ASC36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Digital Data_Run 10.ASC 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Digital Data_Run 11.ASC 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Digital Data_Run 12.ASC 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Digital Data_Run 13.ASC 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2 2MD Final Log.PDF36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 5MD Final Log.PDF36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 5TVDSS Final Log.pdf36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 10.PDF36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 11.PDF36487EDDigital Data Wednesday, July 19, 2023AOGCC Page 1 of 5 1C-15L2 GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-22932-61-00Well Name/No.KUPARUK RIV UNIT 1C-15L2 Completion Status WAGINCompletion Date 3/27/2022 Permit to Drill 2220290 Operator ConocoPhillips Alaska, Inc. MD 12782 TVD 6564 Current Status WAGIN 7/19/2023 UIC Yes DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 12.PDF36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 13.PDF36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 NAD27 Definitive Surveys.pdf 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2 NAD27 Definitive Surveys.txt 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2 NAD83 Definitive Surveys.pdf 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2 NAD83 Definitive Surveys.txt 36487ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2 2MD Final Log.tif36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 5MD Final Log.tif36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2 5TVDSS Final Log.tif36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 10.tif36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 11.tif36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 12.tif36487EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2_PWD Log_Run 13.tif36487EDDigital Data DF 4/27/20228900 10776 Electronic Data Set, Filename: 1C-15L2PB1 GAMMA RES.las 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 2MD Final Log.cgm36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 5MD Final Log.cgm36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 5TVDSS Final Log.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 01.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 02.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 03.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 04.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 05.cgm 36488ED Digital Data Wednesday, July 19, 2023AOGCC Page 2 of 5 1C-15L2PB1 GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-22932-61-00Well Name/No.KUPARUK RIV UNIT 1C-15L2 Completion Status WAGINCompletion Date 3/27/2022 Permit to Drill 2220290 Operator ConocoPhillips Alaska, Inc. MD 12782 TVD 6564 Current Status WAGIN 7/19/2023 UIC Yes DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 06.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 07.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 08.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 09.cgm 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 GAMMA RES.ASC36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 1.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 2.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 3.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 4.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 5.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 6.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 7.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 8.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Digital Data_Run 9.ASC 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 2MD Final.pdf36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 5MD Final.pdf36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 TVDSS Final.pdf36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 01.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 02.PDF 36488ED Digital Data Wednesday, July 19, 2023AOGCC Page 3 of 5 DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-22932-61-00Well Name/No.KUPARUK RIV UNIT 1C-15L2 Completion Status WAGINCompletion Date 3/27/2022 Permit to Drill 2220290 Operator ConocoPhillips Alaska, Inc. MD 12782 TVD 6564 Current Status WAGIN 7/19/2023 UIC Yes DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 03.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 04.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 05.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 06.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 07.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 08.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 09.PDF 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 NAD27 Definitive Surveys.pdf 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 NAD27 Definitive Surveys.txt 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 NAD83 Definitive Surveys.pdf 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 NAD83 Definitive Surveys.txt 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 2MD Final Log.tif36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 5MD Final Log.tif36488EDDigital Data DF 4/27/2022 Electronic File: 1C-15L2PB1 5TVDSS Final Log.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 01.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 02.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 03.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 04.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 05.tif 36488ED Digital Data Wednesday, July 19, 2023AOGCC Page 4 of 5 DATA SUBMITTAL COMPLIANCE REPORT API No.50-029-22932-61-00Well Name/No.KUPARUK RIV UNIT 1C-15L2 Completion Status WAGINCompletion Date 3/27/2022 Permit to Drill 2220290 Operator ConocoPhillips Alaska, Inc. MD 12782 TVD 6564 Current Status WAGIN 7/19/2023 UIC Yes Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date: 3/27/2022 Release Date:3/11/2022 DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 06.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 07.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 08.tif 36488ED Digital Data DF 4/27/2022 Electronic File: 1C-15L2PB1_PWD Log_Run 09.tif 36488ED Digital Data Wednesday, July 19, 2023AOGCC Page 5 of 5 M. Guhl 7/19/2023 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA April 13, 2022 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. 1C-15L2PB1 Kuparuk River API #: 50-029-22932-70-00 Permit No: 222-029 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jerissa Hampton jerissa.hampton@conocophillips.com A. Carolina Martinez Arelys.Martinez@bakerhughes.com 222-029 36488 Kayla Junke Digitally signed by Kayla Junke Date: 2022.04.27 11:50:46 -08'00' T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA April 13, 2022 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. 1C-15L2 Kuparuk River API #: 50-029-22932-61-00 Permit No: 222-029 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jerissa Hampton jerissa.hampton@conocophillips.com A. Carolina Martinez Arelys.Martinez@bakerhughes.com 222-029 36487 Kayla Junke Digitally signed by Kayla Junke Date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y Meredith Guhl at 3:47 pm, Apr 25, 2022 Completed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igitally signed by Shane GermannDN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I have reviewed this documentLocation: your signing location hereDate: 2022.04.25 11:56:55-08'00' Foxit PDF Editor Version: 11.2.1 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,320.0 12/7/2011 1C-15 ninam Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Liner Top Packer 3/30/2022 1C-15 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (lb… 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 40.4 Set Depth (ftKB) 6,249.3 Set Depth (TVD) … 4,488.5 Wt/Len (lb… 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.5 Set Depth (ftKB) 9,392.7 Set Depth (TVD) … Wt/Len (lb… 26.00 Grade L-80 Top Connection ABM-BTC Casing Description WINDOW L1 OD (in) 7 ID (in) 6.00 Top (ftKB) 9,142.0 Set Depth (ftKB) 9,147.0 Set Depth (TVD) … 6,621.5 Wt/Len (lb… 26.00 Grade L-80 Top Connection Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 3 1/2 ID (in) 2.99 Top (ftKB) 36.6 Set Depth (ft… 8,976.5 Set Depth (TVD… 6,468.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 36.6 36.6 0.00 HANGER 3.500 8.000 2,019.3 1,796.2 49.18 SAFETY VLV 2.812 5.250 3,324.9 2,602.4 51.58 GAS LIFT 2.920 5.500 CAMCO KBMM 5,349.2 3,907.5 50.32 GAS LIFT 2.920 5.500 CAMCO KBMM 6,592.1 4,709.3 49.76 GAS LIFT 2.920 5.500 CAMCO KBMM 7,553.6 5,339.8 48.22 GAS LIFT 2.920 5.500 CAMCO KBMM 8,330.6 5,905.9 35.35 GAS LIFT 2.920 5.500 CAMCO KBMM 8,826.5 6,333.3 26.13 GAS LIFT 2.371 5.500 CAMCO MMM 8,876.2 6,377.9 26.07 NIPPLE 2.812 4.540 8,919.3 6,416.7 26.08 PACKER 3.875 5.968 8,964.5 6,457.3 25.98 NIPPLE 2.800 4.470 8,975.6 6,467.3 25.94 SOS 3.000 4.520 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,840.0 6,345.4 26.05 PACKER Set NothernSolutions AK Mono-Pak Liner Top Packer w/ 1.781" RX nipple @ 8848' RKB (See Attachments) 3/30/2022 1.781 A22427201- R00 PATCH SURF CSG PATCH install from bottom of starter head to top of pup collar 1' 11.5", used 9 5/8" 40 #, .395 pipe for patch material 4/10/2009 Mandrel Inserts : excludes pulled 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 3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 2 5,349.2 3,907.5 50.32 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 3 6,592.1 4,709.3 49.76 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 4 7,553.6 5,339.8 48.22 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 5 8,330.6 5,905.9 35.35 1 GAS LIFT DMY BK-5 0.000 0.0 2/12/2003 6 8,826.5 6,333.3 26.13 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/16/2004 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase 9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP 9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 1/11/1999 9,096.0 9,142.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003 Notes: General & Safety End Date Annotation 11/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/15/2003 NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 1C-15, 4/20/2022 4:55:52 PM Vertical schematic (actual) PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 L2 lateral; 8,953.0-12,235.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev… 1C-15 ... TD Act Btm (ftKB) 9,390.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293200 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,348.0 6/28/2019 1C-15L1 hazenmc Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CUT LINER 2/4/2022 1C-15L1 bworthi1 Casing Strings Casing Description LINER OD (in) 2.38 ID (in) 1.92 Top (ftKB) 8,845.3 Set Depth (ftKB) 11,111.0 Set Depth (TVD) … Wt/Len (lb… 4.43 Grade L-80 Top Connection STL Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,845.3 6,350.2 26.05 DEPLOY BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 11,072.7 O-RING BAKER O-RING SUB 1.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long 3/16/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,344.0 11,075.0 C-3, C-4, C-3, 1C-15L1 4/12/2003 4.0 SLOTS SLOTTED LINER Notes: General & Safety End Date Annotation 4/15/2003 NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE 1C-15 CMT PLUG 4/15/2003 NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 1C-15L1, 4/20/2022 4:55:52 PM Vertical schematic (actual) LINER; 8,845.3-11,111.0 SLOTS; 10,344.0-11,075.0 PRODUCTION; 38.5-9,392.7 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 L2 lateral; 8,953.0-12,235.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev… 1C-15L1 ... TD Act Btm (ftKB) 11,207.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293260 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End Date 4/13/2003 H2S (ppm) DateComment SSSV: LOCKED OUT Casing Strings Casing Description L2 lateral OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 8,953.0 Set Depth (ftKB) 12,235.0 Set Depth (TVD) … 6,566.7 Wt/Len (lb… 4.70 Grade L-80 Top Connection ST-L 1C-15L2, 4/20/2022 4:55:53 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 LINER; 8,845.3-11,111.0 WHIPSTOCK; 9,108.0 IPERF; 9,106.0-9,126.0 FRAC; 9,096.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP SVC KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev… 1C-15L2 ... TD Act Btm (ftKB) 17,782.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293261 Wellbore Status SVC Max Angle & MD Incl (°) 103.09 MD (ftKB) 9,278.41 WELLNAME WELLBORE1C-15 Annotation End DateH2S (ppm) DateComment Page 1/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/11/2022 00:00 3/11/2022 01:00 1.00 MIRU, MOVE CTOP P BHI head up UQC - test wire Good 0.0 0.0 3/11/2022 01:00 3/11/2022 02:00 1.00 MIRU, MOVE CTOP P LRS on location. MIRU spot 5 BBl meth spear in coil 0.0 0.0 3/11/2022 02:00 3/11/2022 05:30 3.50 MIRU, MOVE CTOP P Follw meth with seawater down CT. Min rate pump trips set low, fill coil 0.0 0.0 3/11/2022 05:30 3/11/2022 06:00 0.50 MIRU, MOVE CTOP P PT Coil Connection and BHI upper quick to 4,000 psi (good test) 0.0 0.0 3/11/2022 06:00 3/11/2022 14:00 8.00 MIRU, MOVE CTOP P PJSM, inspect and changeout drag chain cuttings trough. Sim-ops secure cellar, nipple down stack 0.0 0.0 3/11/2022 14:00 3/11/2022 19:00 5.00 MIRU, MOVE CTOP P Inspect INJH, and reel drive system 0.0 0.0 3/11/2022 19:00 3/12/2022 00:00 5.00 MIRU, MOVE RGRP P Continue with drag chain rebuild. Cuttings trough UHMP replacement 0.0 0.0 3/12/2022 00:00 3/12/2022 06:00 6.00 MIRU, MOVE RGRP P Continue with drag chain service, Work rig down check lists 0.0 3/12/2022 06:00 3/12/2022 10:00 4.00 MIRU, MOVE MOB P Load shop, trucks on standby. confirm fuel in shop and halfway house. Blow down steam, remove steam traps, demobe and secure PUTZ. Secure cellar. 3/12/2022 10:00 3/12/2022 10:18 0.30 MIRU, MOVE MOB P PJSM, w / NES truck crew. 3/12/2022 10:18 3/12/2022 11:18 1.00 MIRU, MOVE MOB P Jack up, walk around, Pull pits off& take to end of pad turn around. 3/12/2022 11:18 3/12/2022 12:18 1.00 MIRU, MOVE MOB P Pull Sub off well. Demobe around well head 3/12/2022 12:18 3/12/2022 13:00 0.70 MIRU, MOVE MOB P Install Jeeps, obtain signed environmental form from pad operator. Clean up all plywood and load rig mats, dress up around well 3/12/2022 13:00 3/12/2022 17:00 4.00 MIRU, MOVE MOB P Notify security Kuparuk Field - depart pad at 13:00 3/12/2022 17:00 3/12/2022 18:30 1.50 MIRU, MOVE MOB P Stop at Oligtok Y for field change out / Rig crew change out 3/12/2022 18:30 3/12/2022 22:00 3.50 MIRU, MOVE MOB P Continue on to 1C pad 3/12/2022 22:00 3/12/2022 23:00 1.00 MIRU, MOVE MOB P On 1 C pad - remove Jeeps, Gravel work complete, Herculite spred out. Scaffolding erected. Pad operator hee with little red services pickling flow line 3/12/2022 23:00 3/13/2022 00:00 1.00 MIRU, MOVE MOB P Shut in gas injector 1C-20 Spot drilling module. Unable to close doors due to flowline coming in well off center. Angle module on well for rear door closure 3/13/2022 00:00 3/13/2022 02:00 2.00 MIRU, MOVE MOB P Continue spotting modules / Laying riig mats 0.0 0.0 3/13/2022 02:00 3/13/2022 07:00 5.00 MIRU, MOVE RURD P Modules spotted, Get stairs and walkway set, Safe out rig, 05:00 Halfway shop/Mechanic Shop on location, spot onto pad. 0.0 0.0 3/13/2022 07:00 3/13/2022 12:00 5.00 MIRU, MOVE RURD P Work post-move checklist, highline crew on location pulling wire, valve crew called out to service wellhead, swap out 2" gripper blocks. Tie in tiger/kill tank line to rig 0.0 0.0 3/13/2022 12:00 3/13/2022 13:00 1.00 MIRU, WHDBOP NUND P Nipple up BOPE equipment, RIG ACCEPT 12:00 0.0 0.0 3/13/2022 13:00 3/13/2022 16:00 3.00 MIRU, WHDBOP RURD P Fluid on location, load pits, fluid pack surface lines, MU tiger tank line, 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 2/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/13/2022 16:00 3/13/2022 16:30 0.50 MIRU, WHDBOP CTOP P Obtain good Shell test 250/4,000 psi 0.0 0.0 3/13/2022 16:30 3/13/2022 22:00 5.50 MIRU, WHDBOP BOPE P Start BOPE test. Test witnessed by Lou Laubenstein, AOGCC Test one Pass Test two Pass Test three Lower 2 3/8" door seal leaking / replace door seal attempt test - No good on retest. appears upper door seal leaking. Mechnic on location. C/O lower set upper door seal. Fill stackstill fail on upper door seal. Pull door inspect sealing area replace seal. Refill and test. Leaking water out of bonnet weep hole on ODS 2 3/8: actuator. 0.0 0.0 3/13/2022 22:00 3/14/2022 00:00 2.00 MIRU, WHDBOP BOPE T Formulate plan forward. Get redressed bonnet from NOC Deadhorse. Continue abriveated test. Lower 2", Tango one, R1, BL1 0.0 0.0 3/14/2022 00:00 3/14/2022 02:30 2.50 MIRU, WHDBOP BOPE T . Continue abriveated test. Lower 2", Tango two, R1, BL1 Test Tango 0.0 3/14/2022 02:30 3/14/2022 05:30 3.00 MIRU, WHDBOP BOPE T PJSM, Rig up to remove and lower BOPE bonnet actuator and replace 0.0 0.0 3/14/2022 05:30 3/14/2022 08:00 2.50 MIRU, WHDBOP BOPE T Fluid pack all surface lines, begin testing BOPE, test #3 pass, test #4 pass, Test #5 fail, Trouble shoot, unable to get blind shear rams to hold, discuss with Nabors managment, 0.0 0.0 3/14/2022 08:00 3/14/2022 10:00 2.00 MIRU, WHDBOP BOPE T Trouble shoot, unable to get blind shear rams to hold, discuss with Nabors managment and COP Town Team, decision was made to open up BOP's and inspect. 0.0 0.0 3/14/2022 10:00 3/14/2022 20:30 10.50 MIRU, WHDBOP BOPE T Bleed pressure off system, lockout tagout koomey unit, fill out proper permits, remove ram doors, found blind shear ram seals to be compromised, more alpine beads found, pressure wash cavities, redress ram bodies, and insert. 0.0 0.0 3/14/2022 20:30 3/14/2022 21:00 0.50 MIRU, WHDBOP BOPE T Perform valve checklist, fluid pack all surface lines 0.0 0.0 3/14/2022 21:00 3/14/2022 22:45 1.75 MIRU, WHDBOP BOPE T Perform shell test, door seal leaking on lower 2" combi, bleed pressured, drain stack, replace door seal 0.0 0.0 3/14/2022 22:45 3/14/2022 23:45 1.00 MIRU, WHDBOP BOPE T Fluid pack surface lines and stack, attempt to get a shell test, Get good shell test 0.0 0.0 3/14/2022 23:45 3/15/2022 00:00 0.25 MIRU, WHDBOP BOPE T Servece B5, 6, 7 & 8 0.0 0.0 3/15/2022 00:00 3/15/2022 02:30 2.50 MIRU, WHDBOP BOPE T Conyinue testing BOPE test #7 2" lower pipe slips Test 8 Upper 2 ", B8 & B5 Test 9 B6 and B7 Test 10 2 3/8 Pipe slips 11 Test Annular 0.0 0.0 3/15/2022 02:30 3/15/2022 03:00 0.50 MIRU, WHDBOP BOPE T Draw down test on Koomy 0.0 0.0 3/15/2022 03:00 3/15/2022 04:30 1.50 MIRU, WHDBOP BOPE T Lay down test joint. Skid injector to floor. Change out pack offs. Stab on. Test inner rrel iron / Inner reel valve, Good test BOPE test complete 0.0 0.0 3/15/2022 04:30 3/15/2022 06:00 1.50 MIRU, WHDBOP PRTS P Skid injector off floor. Rig up to test PDL's TT line 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 3/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/15/2022 06:00 3/15/2022 08:00 2.00 SLOT, WELLPR PULD P Crew change, Perform valve check list M/U BHA #1 to retrieve liner 0.0 0.0 3/15/2022 08:00 3/15/2022 10:12 2.20 SLOT, WELLPR PULD P PJSM, PD BHA #1. Make up to coil and surface test 0.0 50.0 3/15/2022 10:12 3/15/2022 14:00 3.80 SLOT, WELLPR TRIP P RIH, BHA #1, Stop @ 6900'. Lock out reel, Inspect inner reel iron. Torque saddle clamps, check reel hubs, check reel shims. Inspect injector gripper blocks 50.0 8,500.0 3/15/2022 14:00 3/15/2022 14:24 0.40 SLOT, WELLPR DLOG P Start logging down for gamma tie in. -3' correction 8,500.0 8,620.0 3/15/2022 14:24 3/15/2022 14:54 0.50 SLOT, WELLPR CIRC P Trip in to 8792', Circulate seawater @ 2 BPM 1 for 1. Out density has stabilized 8,620.0 8,792.0 3/15/2022 14:54 3/15/2022 16:18 1.40 SLOT, WELLPR PRTS P Shut down pump. Pereform 30 min staic BHP test. Final pressure 3609 @ 6182' TVD SS or 11.2 at 6284. Work KWF in pits from 11.7 to 11.5 PPG 8,792.0 8,792.0 3/15/2022 16:18 3/15/2022 18:18 2.00 SLOT, WELLPR CIRC P 11.5 PPG KWF ready to go in pits. Start pumping down hole 11.5PPG NaBr // circulate and kill 8,792.0 8,792.0 3/15/2022 18:18 3/15/2022 19:12 0.90 SLOT, WELLPR FISH P Latch into fish // PU to 50 K fish not free // Jar up 8 times // PU 40K fish free // 8,792.0 9,136.0 3/15/2022 19:12 3/15/2022 21:06 1.90 SLOT, WELLPR TRIP P POOH with Fish 9,136.0 300.0 3/15/2022 21:06 3/15/2022 21:21 0.25 SLOT, WELLPR OWFF P Flow check well to confirm well dead // PJSM for laying down BHA and Liner on dead well 300.0 300.0 3/15/2022 21:21 3/15/2022 22:09 0.80 SLOT, WELLPR PULD P Lay down BOT and BHI bha over dead well BHA# 1 300.0 300.0 3/15/2022 22:09 3/15/2022 23:33 1.40 SLOT, WELLPR PULD P Lay down 9.9' Pup, 9 jts solid liner, and 6' cut jt 300.0 0.0 3/15/2022 23:33 3/16/2022 00:00 0.45 SLOT, WELLPR PULD P PJSM and pick up caliper 0.0 20.0 3/16/2022 00:00 3/16/2022 00:30 0.50 SLOT, WELLPR PULD P Pick up BHA# 2 , HES caliper run 20.0 21.5 3/16/2022 00:30 3/16/2022 02:42 2.20 SLOT, WELLPR TRIP P Tag up and set depth, RIH with caliper run 21.5 8,500.0 3/16/2022 02:42 3/16/2022 03:30 0.80 SLOT, WELLPR DLOG P Log HRZ for depth corilation 5'/min 8,500.0 8,800.0 3/16/2022 03:30 3/16/2022 04:42 1.20 SLOT, WELLPR TRIP P RIH to logging depth for caliper could not get past 9136.4' 8,800.0 9,136.4 3/16/2022 04:42 3/16/2022 05:06 0.40 SLOT, WELLPR DLOG P Caliper up to 8900 9,136.4 8,900.0 3/16/2022 05:06 3/16/2022 05:42 0.60 SLOT, WELLPR TRIP P POOH 8,900.0 8,406.0 3/16/2022 05:42 3/16/2022 10:30 4.80 SLOT, WELLPR TRIP T Injector drive coupler failed. Stop and repair, NAD 4.5 Hrs downtime 8,406.0 8,406.0 3/16/2022 10:30 3/16/2022 12:30 2.00 SLOT, WELLPR TRIP P Continue out of well 8,406.0 8.0 3/16/2022 12:30 3/16/2022 13:12 0.70 SLOT, WELLPR PULD P Ar surface, Flow check well, PJSM lay down BHA #2 8.0 0.0 3/16/2022 13:12 3/16/2022 14:30 1.30 PROD1, WHPST PULD P M/U BHA #3 whipstock, Put in well. Make up coiltrack to coil and surface test 0.0 73.0 3/16/2022 14:30 3/16/2022 15:24 0.90 PROD1, WHPST TRIP P RIH BHA #3 73.0 1,232.0 3/16/2022 15:24 3/16/2022 16:24 1.00 PROD1, WHPST TRIP T Injector chattering, Troubleshoot. Change out injector drive encoders. 1 Hour NAD NPT 1,232.0 1,232.0 3/16/2022 16:24 3/16/2022 18:00 1.60 PROD1, WHPST TRIP P Continue in well 1,232.0 8,900.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 4/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/16/2022 18:00 3/16/2022 21:00 3.00 PROD1, WHPST DLOG T Tie in discepencies // CCL F/ 8990 - 9090 Bit Depth CCL 61.22' back on tool // Tie in K1 CBL from 2003 8928' // CCL 8,990.0 9,090.0 3/16/2022 21:00 3/16/2022 21:30 0.50 PROD1, WHPST WPST P Set WS per plan @ 9108' TOWS 0° ROHS // BHI tools failed on set // 2300 psi set 5k coil wt on WS // Good Set 9,090.0 9,116.0 3/16/2022 21:30 3/16/2022 23:00 1.50 PROD1, WHPST TRIP P POOH for window mill assembly 9,116.0 80.0 3/16/2022 23:00 3/17/2022 00:00 1.00 PROD1, WHPST PULD P PJSM // Lay down BHA# 3 WS setting tool over dead well 80.0 0.0 3/17/2022 00:00 3/17/2022 00:42 0.70 PROD1, WHPST PULD P Pick up BHA# 4 Window milling assembly // 1° AKO NS Fix bend motor 0.0 71.0 3/17/2022 00:42 3/17/2022 02:27 1.75 PROD1, WHPST TRIP P Tag up and set counters // RIH w/ window mill assembly 71.0 8,950.0 3/17/2022 02:27 3/17/2022 03:15 0.80 PROD1, WHPST DLOG P Log K1 // wheel gummed up and slipped so missed K1 // clean wheel and tie into K1 for +32 correction 8,950.0 9,006.0 3/17/2022 03:15 3/17/2022 03:30 0.25 PROD1, WHPST TRIP P RIH and dry tag WS @ 9112 pinch point putting TOWS @ 9108' 9,006.0 9,090.0 3/17/2022 03:30 3/17/2022 04:24 0.90 PROD1, WHPST DISP P Displace well to milling fluid 9,090.0 9,108.0 3/17/2022 04:24 3/17/2022 08:54 4.50 PROD1, WHPST MILL P Mill window F/ 9111.84 1.8 bpm // 4400psi // 640 diff // WHP 337 // Ann 4054 9,108.0 9,114.9 3/17/2022 08:54 3/17/2022 09:00 0.10 PROD1, WHPST MILL P Stacked out, High WOB low diff pressure, Pick up and re set, PUW=31K 9,114.9 9,114.3 3/17/2022 09:00 3/17/2022 10:06 1.10 PROD1, WHPST MILL P Milling window, 1.77 BPM @ 4405 PSI FS, BHP=4072 9,114.3 9,115.0 3/17/2022 10:06 3/17/2022 11:48 1.70 PROD1, WHPST MILL P Call BOW, Milling rathole, 1.77 BPM @ 4609 PSI FS, BHP 9,115.0 9,130.0 3/17/2022 11:48 3/17/2022 13:00 1.20 PROD1, WHPST REAM P Ream window per procedure, HS, 30L, 30R, PUW=32K. Dry drift - Good 9,130.0 9,130.0 3/17/2022 13:00 3/17/2022 14:30 1.50 PROD1, WHPST TRIP P 9130, PUH through window, Open EDC, Jet 2 BPM up to 8990, Reduce rate to 1,3 BPM, POOH 9,130.0 65.0 3/17/2022 14:30 3/17/2022 17:00 2.50 PROD1, WHPST PULD P Tag up, space out, PJSM PUD BHA #4, Mill out at 2.80 No Go 65.0 0.0 3/17/2022 17:00 3/17/2022 19:00 2.00 PROD1, WHPST CTOP P Skid injector to floor, Make up nozzle to jet stack post window milling. Fluch micro motion 0.0 0.0 3/17/2022 19:00 3/17/2022 20:18 1.30 PROD1, DRILL PULD P Pressure Deploy BHA# 5 Build assembly 0.0 80.0 3/17/2022 20:18 3/17/2022 22:18 2.00 PROD1, DRILL TRIP P Tag up // Set counters // RIH with Build BHA# 5 80.0 8,910.0 3/17/2022 22:18 3/17/2022 22:30 0.20 PROD1, DRILL DLOG P Log K1 for correction -11 correction 8,910.0 8,959.0 3/17/2022 22:30 3/17/2022 22:45 0.25 PROD1, DRILL TRIP P Trip in to window to drill build RIHW 13K PU Wt. 34K 8,959.0 9,130.0 3/17/2022 22:45 3/18/2022 00:00 1.25 PROD1, DRILL DRLG P Drilling build section F/ 9130 T/ 9216 1.8 bpm // 4684 psi // 427 diff 9,130.0 9,216.0 3/18/2022 00:00 3/18/2022 00:30 0.50 PROD1, DRILL DRLG P Drilling build section F/ 9216 T/ 9280 1.8 bpm // 4684 psi // 427 diff 9,216.0 9,280.0 3/18/2022 00:30 3/18/2022 02:54 2.40 PROD1, DRILL TRIP P Pump 5X5 sweeps , pooh clean up 7", pooh for lateral assembly // Jog Build and 7 " pump sweeps @ TD and 7" POOH, Tag up and space out for pressure un-deploy 9,280.0 80.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Call BOW, Milling rathole, Mill window F/ 9111.84 Set WS per plan @ 9108' TOWS Page 5/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2022 02:54 3/18/2022 04:24 1.50 PROD1, DRILL PULD P PUD BHA# 5 Build assembly 80.0 0.0 3/18/2022 04:24 3/18/2022 06:48 2.40 PROD1, DRILL PULD P Pick up and Deploy BHA# 6 ER lateral assembly .6° AKO w/ Hyc A3 bit // Quadco agitator in string. PD Make up to coil and surface test tool, 0.0 76.0 3/18/2022 06:48 3/18/2022 09:30 2.70 PROD1, DRILL TRIP P RIH, Shallow test BHA @ 500'. 1.87 BPM @ 5400 PSI, 1775 PSI Diff. Manageable, Open EDC, Continue in 76.0 8,935.0 3/18/2022 09:30 3/18/2022 09:42 0.20 PROD1, DRILL DLOG P Log K1 tie in for -10', Close EDC 8,935.0 8,971.0 3/18/2022 09:42 3/18/2022 10:12 0.50 PROD1, DRILL TRIP P Continue in, Clean pass through window, Log RA @ 9116', TOWS=9109, TOW=9113, BOW=9116, Continue in MADD pass build 8,971.0 9,270.0 3/18/2022 10:12 3/18/2022 11:54 1.70 PROD1, DRILL DRLG P 9270, Stack out, PUH, Bring pump online 1.7 BPM @ 5825 PSI FS. RIH to 9280', Drill ahead. Swap mud, new mud @ bit 9300' Dropped 250 PSi pump pressure 9,270.0 9,350.0 3/18/2022 11:54 3/18/2022 12:06 0.20 PROD1, DRILL WPRT P Pull BHA wiper to obtain new pressures, 1.71 BPM @ 5305 PSI FS, BHP=4153, PUW=37K 9,350.0 9,350.0 3/18/2022 12:06 3/18/2022 15:48 3.70 PROD1, DRILL DRLG P OBD, 1.71 BPM @ 5305 PSI FS, BHP=4153 9,350.0 9,700.0 3/18/2022 15:48 3/18/2022 16:12 0.40 PROD1, DRILL WPRT P Wiper trip #1 to EOB with sweeps, PUW=36K. Clean trip up and down 9,700.0 9,700.0 3/18/2022 16:12 3/18/2022 22:42 6.50 PROD1, DRILL DRLG P OBD, 1.81 BPM @ 5275 PSI FS, BHP=4149 9,700.0 9,900.0 3/18/2022 22:42 3/18/2022 23:30 0.80 PROD1, DRILL TRIP T POOH to check bit pump 5X5 sweeps and jet 7" 9,900.0 9,100.0 3/18/2022 23:30 3/18/2022 23:42 0.20 PROD1, DRILL CTOP T Perform Static pressure test @ window 9098.81 MD 6538.14 TVD 6436.84 SSTVD 3904 Ann = 11.48ppg equiv. 9,100.0 9,100.0 3/18/2022 23:42 3/19/2022 00:00 0.30 PROD1, DRILL TRIP P POOH to check bit 9,100.0 7,200.0 3/19/2022 00:00 3/19/2022 01:18 1.30 PROD1, DRILL TRIP T POOH to check bit 7,200.0 80.0 3/19/2022 01:18 3/19/2022 02:30 1.20 PROD1, DRILL PULD T Tag up space out 1.2' // PJSM // Pressure Un-Deploy BHA# 6 ER Lateral Assembly 80.0 0.0 3/19/2022 02:30 3/19/2022 03:30 1.00 PROD1, DRILL PULD T PD BHA# 7 .6° Ako , Quadco Agitator w/ HCC Bit 0.0 76.0 3/19/2022 03:30 3/19/2022 05:18 1.80 PROD1, DRILL TRIP T RIH with BHA# 7 Shallow test agitator1.8 BPM @ 4600 PSI 76.0 8,935.0 3/19/2022 05:18 3/19/2022 05:24 0.10 PROD1, DRILL DLOG T Tie into K1 for -10' correction, 8,935.0 8,971.0 3/19/2022 05:24 3/19/2022 05:54 0.50 PROD1, DRILL TRIP T Continue in, Clean pass through window down to bottom @ 9904 8,971.0 9,904.0 3/19/2022 05:54 3/19/2022 07:42 1.80 PROD1, DRILL DRLG T Bring pump online 1.79 BPM @ 4850 PSI FS. Set down. Not making progress, Attempt different WOB and pump rates 9,904.0 9,904.0 3/19/2022 07:42 3/19/2022 09:18 1.60 PROD1, DRILL DRLG T Recip pipe into bottom, Try to stall motor, No stall, Try lower pump rate and high WOB. 9,904.0 9,904.0 3/19/2022 09:18 3/19/2022 09:42 0.40 PROD1, DRILL DRLG T Back ream BHA length 180° out of as drilled twice. No good. Go to 1.3 BPM again trying to get stall. No good 9,904.0 9,904.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 6/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/19/2022 09:42 3/19/2022 11:54 2.20 PROD1, DRILL DRLG T POOH to inspect CTC, UQC, and BHA Had overpull at SSSV popped free. 9,904.0 61.7 3/19/2022 11:54 3/19/2022 13:24 1.50 PROD1, DRILL PULD T At surface, Tag up - space out, PJSM, PUD BHA #7. PT CTC & UQC to 4K, Goog. Continue PUD, Observed agitator wash out. Change out agitator and motor. 61.7 0.0 3/19/2022 13:24 3/19/2022 14:54 1.50 PROD1, DRILL PULD T PD BHA #8. Same bit. Make up to coil and surface test 0.0 74.0 3/19/2022 14:54 3/19/2022 16:24 1.50 PROD1, DRILL TRIP T RIH BHA #8. Shallow test agitator 1.84 BPM @ 5000 PSI. Continue in below SSSV. PUH. Unable to come up through valve. Hook up to control line. Shut in with 3500 PSI on it. Pressure up to 5K. Unable to come up. Pressure up to 5500 PSI. No Go. Pressure up to 5800 PSI, pump 1.5 BPM down back side. Come up through valve. RBIH drift valve good. 74.0 2,100.0 3/19/2022 16:24 3/19/2022 18:42 2.30 PROD1, DRILL TRIP T RIH to drill 2,100.0 9,900.0 3/19/2022 18:42 3/19/2022 23:00 4.30 PROD1, DRILL DRLG P BOBD F/ 9900 T/ 10284 1.8 bpm // 5990psi // 1713 diff // Ann 4115 9,900.0 10,284.0 3/19/2022 23:00 3/20/2022 00:00 1.00 PROD1, DRILL WPRT P Wiper to 9400 10,284.0 10,284.0 3/20/2022 00:00 3/20/2022 03:36 3.60 PROD1, DRILL DRLG P BOBD F/ 10284 T/ 10710 1.8 bpm // 5990psi // 1613 diff // Ann 4215 10,284.0 10,710.0 3/20/2022 03:36 3/20/2022 04:06 0.50 PROD1, DRILL WPRT P Pump 5 X 5 sweeps perform wiper to 9860' 10,710.0 10,710.0 3/20/2022 04:06 3/20/2022 05:36 1.50 PROD1, DRILL DRLG P BOBD F/ 10710 T/ 10,755 1.8 bpm // 5990psi // 1260 diff // Ann 4264 10,710.0 10,755.0 3/20/2022 05:36 3/20/2022 07:24 1.80 PROD1, DRILL WPRT P Pull wiper to window, PUH through window, Jet 7" with additional sweeps 10,755.0 8,928.0 3/20/2022 07:24 3/20/2022 07:30 0.10 PROD1, DRILL DLOG P Log K1 for +8 8,928.0 8,956.0 3/20/2022 07:30 3/20/2022 08:36 1.10 PROD1, DRILL WPRT P Wiper back to bottom, 9640 to 10,188, Small intervals of taking weight. Mitigated with reduced pump rate 8,956.0 10,755.0 3/20/2022 08:36 3/20/2022 09:24 0.80 PROD1, DRILL DRLG P Drill, 1.7 BPM @ 5650 PSI FS, BHP=4551. Not able to generate differential pressure. Low ROP. Free spin has been dropping all night 1718 PSI when we started drilling, 1260 PSI @ 04:50 10,755.0 10,776.0 3/20/2022 09:24 3/20/2022 10:48 1.40 PROD1, DRILL TRIP P Trip for BHA inspecdtion, PUW=38K, Pump sweeps, Jet 7" with additional sweeps. Circulate sweeps to surface 10,776.0 9,093.0 3/20/2022 10:48 3/20/2022 11:24 0.60 PROD1, DRILL PRTS P Perform 30 Min BHSP test. In at 12.16 EMW 9,093.0 9,093.0 3/20/2022 11:24 3/20/2022 13:18 1.90 PROD1, DRILL TRIP P Continue out of well, EDC faulted on opening sequence, Code 4 position error 9,093.0 58.0 3/20/2022 13:18 3/20/2022 14:30 1.20 PROD1, DRILL PULD P On surface, Tag up space out, PJSM PUD BHA # 8. No external wash out on agitator. Lay down tools 58.0 0.0 3/20/2022 14:30 3/20/2022 16:30 2.00 PROD1, DRILL PULD T Revise plan forward. M/U open hole anchor billet, PD 0.0 72.9 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 7/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/20/2022 16:30 3/20/2022 19:30 3.00 PROD1, DRILL TRIP T Trip in hole BHA #9 open hole anchor billet// tie in -10' correction // RIH T/ 10450 TOB Set OHAB @ 10450' TOB 4200 psi 1960 Diff .8 DHWOB Set down 2.7 K anchor set 72.9 10,450.0 3/20/2022 19:30 3/20/2022 21:30 2.00 PROD1, DRILL TRIP T POOH for Lateral ER Assembly 10,450.0 80.0 3/20/2022 21:30 3/20/2022 22:45 1.25 PROD1, DRILL PULD T PULD BHA# # 9 OHAB Setting Tool 80.0 0.0 3/20/2022 22:45 3/21/2022 00:00 1.25 PROD1, DRILL PULD T PU and Deploy BHA# 10 ER Lateral Assembly, .6°ako, NOV agitator, and HYC A3 bit 0.0 80.0 3/21/2022 00:00 3/21/2022 00:30 0.50 PROD1, DRILL PULD T PU and Deploy BHA# 10 ER Lateral Assembly, .5°ako, NOV agitator, and HYC A3 bit // change checks in upper quick // check packoffs 80.0 80.0 3/21/2022 00:30 3/21/2022 03:00 2.50 PROD1, DRILL TRIP T Tag up set counters// RIH 100'/min pump min rate // close edc test agitator// 1.8 5340psi 860 diff // tie in k1 -6' correction // RIH to bottom // Dry tag billet @ 10450.7 80.0 10,450.0 3/21/2022 03:00 3/21/2022 04:06 1.10 PROD1, DRILL MILL T Mill billet 1-2-3 180° ROHS, 1.81 BPM @ 5170 PSI FS, BHP=4253 10,450.0 10,452.0 3/21/2022 04:06 3/21/2022 05:54 1.80 PROD1, DRILL MILL T Stall @ 10452 multiple time. PUH to 10,450 and restart time milling sequence 10,452.0 10,453.0 3/21/2022 05:54 3/21/2022 06:12 0.30 PROD1, DRILL DRLG T Drill, 1.82 BPM @ 5385 PSI FS, BHP=43250 10,453.0 10,500.0 3/21/2022 06:12 3/21/2022 06:24 0.20 PROD1, DRILL WPRT T PUH to dry drift billet area, PUW=33K 10,500.0 10,500.0 3/21/2022 06:24 3/21/2022 07:54 1.50 PROD1, DRILL DRLG T OBD, 1.82 BPM @ 5490 PSI FS, BHP=4361 10,500.0 10,755.0 3/21/2022 07:54 3/21/2022 09:30 1.60 PROD1, DRILL DRLG P 10755, Off Trouble time 10,755.0 10,899.0 3/21/2022 09:30 3/21/2022 09:42 0.20 PROD1, DRILL WPRT P Hard spot, Pull BHA wiper, PUW=45K 10,899.0 10,899.0 3/21/2022 09:42 3/21/2022 09:54 0.20 PROD1, DRILL DRLG P Drill 1.82 BPM @ 5485 PSI FS, BHP=4348 10,899.0 10,903.0 3/21/2022 09:54 3/21/2022 11:42 1.80 PROD1, DRILL WPRT P Low ROP, Poor weight transfer. Pull early wiper trip #1 to TT, PUW=44K Make two passes in 7" 10,903.0 8,930.0 3/21/2022 11:42 3/21/2022 11:54 0.20 PROD1, DRILL DLOG P Log K1 for +5' 8,930.0 8,964.7 3/21/2022 11:54 3/21/2022 13:06 1.20 PROD1, DRILL WPRT P Continue wiper trip back to bottom to drill 8,964.7 10,903.0 3/21/2022 13:06 3/21/2022 17:06 4.00 PROD1, DRILL DRLG P Drill, 1.79 BPM @ 5415 PSI FS, BHP=4359, Start new mud system #2down CT, New mud at bit @ 11,038 10,903.0 11,180.0 3/21/2022 17:06 3/21/2022 17:36 0.50 PROD1, DRILL WPRT P Pull DD wiper, PUW=40K, discuss options with town. Will be close to going out of polygon, 11,180.0 11,180.0 3/21/2022 17:36 3/21/2022 19:24 1.80 PROD1, DRILL DRLG P Get back to drilling1.64 BPM @ 5079 PSI, BHP=4393 11,180.0 11,308.0 3/21/2022 19:24 3/21/2022 20:24 1.00 PROD1, DRILL WPRT P Wiper trip, PUW=46K, 850' wiper #2 to 10,474' 11,308.0 11,308.0 3/21/2022 20:24 3/21/2022 22:36 2.20 PROD1, DRILL DRLG P OBD, 1.68 BPM @ 4830 PSI FS Send beaded pill down hole @ 11,310 for poor weight transfer, lack of ROP. ROP up to 150 FPH 11,308.0 11,445.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 8/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/21/2022 22:36 3/21/2022 22:48 0.20 PROD1, DRILL WPRT P BHA Wiper, PUW=46K 11,445.0 11,445.0 3/21/2022 22:48 3/22/2022 00:00 1.20 PROD1, DRILL DRLG P OBD, 1.61 BPM @ 4800 PSI, BHP=4382. Reduced rate to help turn BHA Wiper, PUW=39K. Bring rate back up to 1.85 BPM @ 5530 PSI FS, BHP=4462, Beaded sweep as needed to drill, 1 LBs/BBl New mud at bit 11038' 11,445.0 11,510.0 3/22/2022 00:00 3/22/2022 01:30 1.50 PROD1, DRILL DRLG P OBD, 1.81 BPM @ 5200 PSI, BHP=4400 11,510.0 11,700.0 3/22/2022 01:30 3/22/2022 03:30 2.00 PROD1, DRILL WPRT P Wiper to window to clean 7" and tie in RA +9.5' correction 11,700.0 8,976.0 3/22/2022 03:30 3/22/2022 05:30 2.00 PROD1, DRILL TRIP P Trip back to bottom 8,976.0 11,700.0 3/22/2022 05:30 3/22/2022 07:30 2.00 PROD1, DRILL DRLG P OBD, 1.81 BPM @ 5200 PSI, BHP=4400 11,700.0 12,100.0 3/22/2022 07:30 3/22/2022 08:30 1.00 PROD1, DRILL WPRT P Wiper 800' 12,100.0 12,100.0 3/22/2022 08:30 3/22/2022 10:30 2.00 PROD1, DRILL DRLG P OBD 1.8 bpm @ 5500 psi BHP=4460 12,100.0 12,263.0 3/22/2022 10:30 3/22/2022 12:30 2.00 PROD1, DRILL WPRT P Wiper to tubing tail to clean up 7" casing // Tie in for +7' correction 12,263.0 8,976.0 3/22/2022 12:30 3/22/2022 15:15 2.75 PROD1, DRILL TRIP P RIH to bottom 8,976.0 12,263.0 3/22/2022 15:15 3/22/2022 18:00 2.75 PROD1, DRILL DRLG P BOBD 1.78 bpm 5730 psi 900 diff ann 4737 12,263.0 12,425.0 3/22/2022 18:00 3/22/2022 21:00 3.00 PROD1, DRILL DRLG P OBD 1.78 bpm 5730 psi 900 diff ann 4975 Had been holding 13.5 ppg at window nad 14.4 ppg at bit, started steppping down choke pressure while monitoring returns. ROP over interval 30 ft/hr 12,425.0 12,515.0 3/22/2022 21:00 3/23/2022 00:00 3.00 PROD1, DRILL DRLG P OA 81 psi, IA 229 psi, WH 522 psi, CT5,982 psi @ 1.82 bpm in & 1.76 bpm out, Annular 4645 psi, CT Wt -9 k lbs, WOB 1-0.2 k lbs, ROP over interval 31 ft/hr Reduced target pressure at the window in stages to 12.28 ppg EMW, Observed light mud coming back at 12.28 ppg. Pinched choke. **Well controlled at 13.3 ppg at the bit - 12.2 ppg at the window 12,515.0 12,609.0 3/23/2022 00:00 3/23/2022 01:12 1.20 PROD1, DRILL DRLG P OBD, OA 83 psi, IA 233 psi, WH 442 psi, CT5,678 psi @ 1.81 bpm in & 1.79 bpm out, Annular 4510 psi, CT Wt -9 k lbs, WOB 0.5-0.2 k lbs, ROP over interval ft/hr ** Clean PU Wt 39-40 k lbs. 12,609.0 12,632.0 3/23/2022 01:12 3/23/2022 02:36 1.40 PROD1, DRILL WPRT P PU Wt 43 lbs, PUH on long wiper to window. Wipe early due to weight transfer Increase wellhead pressure from 12.3 ppg at the window to 13 ppg at the window from 10,000' and shallower. Jog build, window clean. 12,632.0 9,074.0 3/23/2022 02:36 3/23/2022 03:06 0.50 PROD1, DRILL CIRC P Jet 7" - holding ~ 13.1 EMW to maintain 1 for 1 9,074.0 8,924.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Page 9/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/23/2022 03:06 3/23/2022 03:18 0.20 PROD1, DRILL DLOG P Tie into the K1 for +6' correction. 8,924.0 8,964.7 3/23/2022 03:18 3/23/2022 03:48 0.50 PROD1, DRILL DLOG P Park and measure BHP - 13.1 ppg EMW MD 9075.3 TVD 6513.2 Trap 4441 psi and monitor Time Pressure EMW 1:00 4,428 13.1 2:00 4,424 5:00 4,429 10:00 4,418 15:00 4,417 20:00 4,417 13.05 Bleed off some well head, annular pressure climbed back to 4,417 psi 8,964.7 9,075.3 3/23/2022 03:48 3/23/2022 05:36 1.80 PROD1, DRILL TRIP P RBIH, load coil w 20 bbls 1 ppb alpine beads, time beads to exit ~10,000' , lost all positive coil weight at 10,040 got it back at 10,060'? 9,075.3 12,632.0 3/23/2022 05:36 3/23/2022 07:21 1.75 PROD1, DRILL DRLG P OBD 1.8 bpm 5200 psi Coil wt deminished pumping beaded sweeps 12,632.0 12,784.0 3/23/2022 07:21 3/23/2022 09:21 2.00 PROD1, DRILL TRIP P POOH to window for pressure survey // Jet 7" // Tie in for +5' correction 12,784.0 9,100.0 3/23/2022 09:21 3/23/2022 10:33 1.20 PROD1, DRILL OWFF P Pressure Survey for KWF Bit Depth 9100.28' MD Pressure Sensor TVD 6535.67' (not sub sea) Trap 4485 @ 09:26 1:00 4,481 2:00 4,478 4:00 4,461 6:00 4,454 10:00 4,443 15:00 4,436 20:00 4,430 25:00 4,426 30:00 4,423 45:00 4,423 55:00 4,423 1:00:00 4,423 9,100.0 9,100.0 3/23/2022 10:33 3/23/2022 11:15 0.70 PROD1, DRILL WPRT P Perform swab wiper 9,100.0 5,000.0 3/23/2022 11:15 3/23/2022 12:15 1.00 PROD1, DRILL EQRP T Replace encoder on injector , encoder bearings going out causing motor to be derated 5,000.0 5,000.0 3/23/2022 12:15 3/23/2022 13:21 1.10 PROD1, DRILL WPRT P Wiper to swab tag up set counters 5,000.0 75.0 3/23/2022 13:21 3/23/2022 15:33 2.20 PROD1, DRILL TRIP P RIH to window // Tie in K1 for +5' correction 75.0 9,100.0 3/23/2022 15:33 3/24/2022 00:00 8.45 PROD1, DRILL WAIT T Wait on Densemax 13.3 KWF to be mixed 9,100.0 9,100.0 3/24/2022 00:00 3/24/2022 12:00 12.00 PROD1, DRILL WAIT T Wait on Densemax 13.3 KWF to be mixed Phase 2 9,100.0 9,100.0 3/24/2022 12:00 3/24/2022 14:00 2.00 PROD1, DRILL TRIP P RIH to confirm TD @ 12782' 9,100.0 12,782.0 3/24/2022 14:00 3/24/2022 14:30 0.50 PROD1, DRILL CIRC P Pump LRP to bit 12,782.0 12,782.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 OBD 12,782.0 12,784.0 RIH to confirm TD @ 12782' Page 10/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/24/2022 14:30 3/24/2022 17:30 3.00 COMPZ1, CASING DISP P Lay in 30 bbls LRP , Displace well F/9900 T/ Surface w/ 13.2+ Densemax // Paint Yellow TD flag @ 11768.42' // Window Flag @ 7978.58 12,782.0 90.0 3/24/2022 17:30 3/24/2022 18:00 0.50 COMPZ1, CASING OWFF P Flow check - good. Crew change, PJSM fill stack 1.8 bbls in 30 min ***Static losses 3.6 bph 90.0 90.0 3/24/2022 18:00 3/24/2022 19:30 1.50 COMPZ1, CASING DISP P Un Stab injector over a dead well, inspect pipe for flat spots - good. Lay down BHA #10, bit graded out at 1-1. 90.0 0.0 3/24/2022 19:30 3/24/2022 19:48 0.30 COMPZ1, CASING BOPE P Perform BOP function test 90.0 0.0 3/24/2022 19:48 3/24/2022 20:06 0.30 COMPZ1, CASING CTOP P Prep floor for picking up liner 90.0 0.0 3/24/2022 20:06 3/24/2022 22:42 2.60 COMPZ1, CASING PUTB P Fill stack - 4.2 bbls - static loss rate 2.1 bbl/hr. PJSM, pick up L2 lower completion, 34 joints 4.6 # ST-L range 2 slotted liner over a solid bull nose ( LOA 1042.07') Check hole at 5 stands fill 1.1 bbl - 20:50, 1.5 @ 10 stands. ** ~ 4.59 min per joint 0.0 1,042.1 3/24/2022 22:42 3/24/2022 23:24 0.70 COMPZ1, CASING PULD P PU BHA #11 Lower L2 completion running assembly - tag up set counters. 1,042.1 1,085.8 3/24/2022 23:24 3/25/2022 00:00 0.60 COMPZ1, CASING RUNL P RIH with Lower L2 completion, @ 60 ft/min and pumping min rate down the coil losing 0.25 bpm. Lost 5 bbls to 1,800'. Cut pump and continue to RIH. Increase RIH speed to 80- ft/min get close to pipe displacement back for a short time. Switch to intermittently filling over the top. 1,085.8 3,363.0 3/25/2022 00:00 3/25/2022 01:12 1.20 COMPZ1, CASING RUNL P Continue to RIH with Lower L2 completion. 3,363.0 8,986.1 3/25/2022 01:12 3/25/2022 01:18 0.10 COMPZ1, CASING DLOG P Tie into white window flag at 8,986.1' for a -21' correction. PU Wt 38 k lbs, WOB -8 k lbs 8,986.1 8,986.1 3/25/2022 01:18 3/25/2022 01:54 0.60 COMPZ1, CASING RUNL P Continue to run lower L2 completion in open hole. Set down @ 10,300 PU Wt 43 k lbs, continue to RIH - section of hole where we inverted. S/D 11,044 - PU Wt 42 k lbs - fault #1 8,986.1 11,044.0 3/25/2022 01:54 3/25/2022 02:54 1.00 COMPZ1, CASING RUNL P Set down multiple times @ 11,044 - PU Wt 42 k lbs - fault #1 Work pipe at various speeds and pump rates Worked through 19 th attempt 11,044.0 11,044.0 3/25/2022 02:54 3/25/2022 03:30 0.60 COMPZ1, CASING RUNL P Continue to RIH S/D 11,882 PU Wt 39 k lbs, continue in hole S/D 11,927 PU Wt 39 k lbs, continue in hole 11,044.0 12,268.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 RIH with Lower L2 completion, PU BHA #11 Lower L2 completion running assembly Page 11/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2022 03:30 3/25/2022 07:45 4.25 COMPZ1, CASING RUNL P Set down multiple times @ 12,268' - PU Wt 46 k lbs Work pipe at various speeds and pump rates Release Liner @ 12265' TOL 11223 12,268.0 12,268.0 3/25/2022 07:45 3/25/2022 10:30 2.75 COMPZ1, CASING TRIP P POOH filling over the top 12,268.0 25.0 3/25/2022 10:30 3/25/2022 11:00 0.50 COMPZ1, CASING CTOP P Flow check well, well dead , pjsm for laying down bha and picking up liner 25.0 25.0 3/25/2022 11:00 3/25/2022 11:30 0.50 COMPZ1, CASING PULD P Lay down BHA# 11 1st liner run bha 25.0 0.0 3/25/2022 11:30 3/25/2022 11:45 0.25 COMPZ1, CASING CTOP P Prep for picking up liner 0.0 0.0 3/25/2022 11:45 3/25/2022 13:30 1.75 COMPZ1, CASING PUTB P Pick up liner 35 jts 2-3/8" STL slotted liner // Liner Length 1073.21' // Kick while running liner drill 0.0 1,073.2 3/25/2022 13:30 3/25/2022 14:15 0.75 COMPZ1, CASING PULD P Pick up BHA# 12 Liner run 2 BHA 1,073.2 1,090.0 3/25/2022 14:15 3/25/2022 18:27 4.20 COMPZ1, CASING RUNL P Run liner run # 2, tie into window flag for +9.5' correction PU Wt 36 k lbs, WOB - 5.5 k lbs. Tie in again to the K1 for a - 26' correction. Set down hard multiple times, PU weight from 40 k to 61 k lbs, latched in. Stack -1 k CT Wt 2 k WOB, pump 1.5 bpm, diff 800 psi, PU wt 35 k lbs, liner released ***TOL 10,117.8' 1,090.0 11,192.0 3/25/2022 18:27 3/25/2022 18:57 0.50 COMPZ1, CASING TRIP P PUH, park reset depth, line up over the top, PUH 11,192.0 8,915.0 3/25/2022 18:57 3/25/2022 19:33 0.60 COMPZ1, CASING TRIP P Tie into the K1 +3' - paint yellow TD flag and white window flag at 8948.76' and 7843.76' respectively. 8,915.0 8,948.9 3/25/2022 19:33 3/25/2022 21:09 1.60 COMPZ1, CASING TRIP P POOH filling over the top, minimal losses 8,948.9 60.0 3/25/2022 21:09 3/25/2022 21:39 0.50 COMPZ1, CASING OWFF P Flow check during PJSM. ~ 2 bbl per hr static losses 60.0 60.0 3/25/2022 21:39 3/25/2022 22:27 0.80 COMPZ1, CASING PULD P Un Stab injector over a dead well, inspect pipe for flat spots - good. Lay down BHA #12 60.0 0.0 3/25/2022 22:27 3/25/2022 22:45 0.30 COMPZ1, CASING CTOP P Prep floor for running liner 60.0 0.0 3/25/2022 22:45 3/26/2022 00:00 1.25 COMPZ1, CASING PUTB P PJSM, Fill stack - 1.2 bbls - static loss rate 2 bbl/hr. PJSM, pick up L2 Upper completion, 28 joints 4.6 # ST-L range 2 slotted liner, pup, swell packer, 9 joints 4.6 # ST-L range 2 solid liner and deployment sleeve, ( LOA 1165.57') 0.0 1,165.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 Lay down BHA# 11 1st liner run bha Pick up BHA# 12 Liner run 2 BHA Page 12/12 1C-15 Report Printed: 3/28/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/26/2022 00:00 3/26/2022 00:54 0.90 COMPZ1, CASING PUTB P PJSM, Fill stack - 1.2 bbls - static loss rate 2 bbl/hr. PJSM, pick up L2 Upper completion, 28 joints 4.6 # ST-L range 2 slotted liner, pup, swell packer, 9 joints 4.6 # ST-L range 2 solid liner and deployment sleeve, ( LOA 1165.57') ***sank swell packer @ 00:19 ** ~ 2.33 min per joint 0.0 1,165.0 3/26/2022 00:54 3/26/2022 01:48 0.90 COMPZ1, CASING PULD P PU BHA #13 Upper L2 completion running assembly, check pack offs. - tag up set counters. 1,165.0 1,209.3 3/26/2022 01:48 3/26/2022 03:42 1.90 COMPZ1, CASING RUNL P RIH with Upper L2 completion, @ 60 ft/min and pumping min rate down the coil losing 0.25 bpm. Lost 5 bbls to 1,800'. Cut pump and continue to RIH. Increase RIH speed to 80- ft/min get close to pipe displacement back for a short time. Switch to intermittently filling over the top. 1,209.3 8,915.0 3/26/2022 03:42 3/26/2022 03:54 0.20 COMPZ1, CASING DLOG P Tie into window flag for -51' correction PU Wt 35 k lbs, WOB -4 k lbs 8,915.0 9,084.0 3/26/2022 03:54 3/26/2022 05:54 2.00 COMPZ1, CASING RUNL P Continue to RI open hole with upper L2 completion. // High negative diff pressure stop to pump down pipe // liner became stuck@ 9960 // worked pipe no progress 9,084.0 9,960.0 3/26/2022 05:54 3/26/2022 06:30 0.60 COMPZ1, CASING DLOG P Release from liner to log K1 // +47' Correction // 9,960.0 9,960.0 3/26/2022 06:30 3/26/2022 06:48 0.30 COMPZ1, CASING TRIP P RIH and Latch into Liner // TOL @ 8837' // 9,960.0 10,002.0 3/26/2022 06:48 3/26/2022 07:18 0.50 COMPZ1, CASING WAIT P Wait on orders from engineer 10,002.0 10,002.0 3/26/2022 07:18 3/26/2022 10:03 2.75 COMPZ1, CASING DISP P Pump off liner and circulate well to Sea water // Try to move liner no movement 10,002.0 8,824.0 3/26/2022 10:03 3/26/2022 10:18 0.25 COMPZ1, CASING WAIT P Circulate sea water and wait on decision from asset // Final Pressure 12.95 ppg equiv @ window 8,824.0 8,600.0 3/26/2022 10:18 3/26/2022 12:18 2.00 COMPZ1, CASING TRIP P POOH for freeze protect // Freeze Protect F/ 2500' to surface // Tag up space out 1.2' 8,600.0 43.0 3/26/2022 12:18 3/26/2022 13:42 1.40 COMPZ1, CASING PULD P PJSM pressure un-deploy with diesle // PUD BHA# 13 43.0 0.0 3/26/2022 13:42 3/26/2022 13:57 0.25 COMPZ1, CASING CTOP P Lay down BHA# 13 0.0 0.0 3/26/2022 13:57 3/26/2022 15:12 1.25 DEMOB, WHDBOP CTOP P Pull checks // Install nozzle // Flush Stack and surface lines 0.0 0.0 3/26/2022 15:12 3/26/2022 16:12 1.00 DEMOB, WHDBOP RURD P Blow down surface lines, vac stack and freeze protect tree with methanol 0.0 0.0 3/26/2022 16:12 3/27/2022 00:00 7.80 DEMOB, WHDBOP RURD P De inventory pits, grease stack/ nipple down/ choke, nipple down, work RD checklist ***Rig release at midnight 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 3/27/2022 RIH and Latch into Liner // TOL @ 8837' // RIH with Upper L2 completion, ! "#$ 50-029-22932-61 %& ' & $"! & () & & *+, -& -.& /!& ! ! "#$%# &' ,&. &()* / &"#$%# &' & +** ) / '& 0'& % / 1& ''&*,-&(./ * ' ,-&00' 1 2** 1 * 3#4 * 5+** / 55/ /*/ - - $,!& $!& 2 ,& ,& 324"- 34" 0!$& #$## #$## 1,6716#$ 614-$ #$##-!2& #$## -#8,9,$#, 4,8,94$,,+ -. 567 8!, 5(7 ' , 567 /!'/, :;; # %<#<# $#, 7#$6, -14-$% &) & ! & , $# ) )& 8'5()7 5 7 34" 5 7 567 324"- 5 7 (9 &#14%#$7, -#$###$###$##4$## 8' 5 7 ,' ('5-.7 ( 5 7 4<<# +0+; 0+; + $## ,1##$- &'7<<###=##= +0+; 0+; + ,1#,$## #14%#$7, :&:'%<#<#=#-= +0+; 0+; + #14#$## 1-7$## &'4<7<#%=,=## / 5 7 : 567 ; 567 324"- 5 7 34" 5 7 () 5 7 () 5 7 / , 5 7 / 2 , 5 7 ) 5 7 $ 564<7 (' #14%#$7, ,%$6, -4$7 61,$% 144$#- 61-47$%,614,%$,% 1,-1#-4$77 671,-4$64 7$ -16-$#- +0+;&' (: '"#$* #14#$## ,%$- -4$,% 61,4$## 14,$# 61-66$7#614,$-# 1,-1#7#$# 671,,%$# #$64 -176$#7 +0+;&%' 9"( * #147$ 7,$ -$% 61,%$% 14-$## 61-,6$,6614,$,% 1,-1#77$ 6,1#%$# 4$76 -1-$4 +0+;&%' #1$ 77$ -7$6- 61,%$,% 14%%$6, 6176$%614,$6% 1,-1#,$4 6,1#$ #$,# -146$74 +0+;&%' #14$%- ,#$- 7%$% 61,4$ 14%7$%6 617$,7614,$, 1,-1##$#6 6,1#7$# 7$#- -1-6$47 +0+;&%' #1-$ 7,$%, 76$4 61,4$7 144#$,4 6177$-#614,$77 1,-1#$7, 6,1$- $# -1%#$, +0+;&%' #16#$#% ,#$7 ,$#- 61,4$- 144$6 61,$614,$,- 1,-1#%$-6 6,14$ $47 -1%%%$ +0+;&%' #16%$%% 7,$% ,4$6# 61,4$%- 144#$#6 61,4$-6614,%$#- 1,-1#$ 6,1-$-- $#- -1%6$4% +0+;&%' #166$ 77$%- ,7$% 61,4$,- 14%6$- 61,-$%4614,%$6- 1,-1#,,$4# 6,1#$%- $,, -1%77$#7 +0+;&%' #16,$, 7,$4 #4$ 61,$ 14%#$- -1##4$7614,4$ 1,-1#,%$67 6,1%#$77 #$7- -14%$-% +0+;&%' %& ' & $"! & () & & *+, -& -.& /!& ! ! "#$%# &' ,&. &()* / &"#$%# &' & +** ) / 5 7 : 567 ; 567 324"- 5 7 34" 5 7 () 5 7 () 5 7 / , 5 7 / 2 , 5 7 ) 5 7 $ 564<7 (' #1-$%, 7,$- #,$ 61,$76 14$,# -1#%%$6-614,4$6 1,-1#7$#7 6,1,$7 6$-# -14%-$7% +0+;&%' #1-#$6, 77$- %$,4 61,6$4 14$# -1#6#$7-614,$ 1,-1#-4$46 6,17-$ $#6 -14,$67 +0+;&%' #1-7$#4 77$67 4$4# 61,-$# 1%,7$6% -1#77$6614,$7# 1,-1#6$6 6,1%4$7, $ -147$44 +0+;&%' #17$4 ,#$- 4$ 61,-$6 1%76$#7 -16$%614,$,6 1,-1#4,$,4 6,1%4$-7 6$67 -1#%$- +0+;&%' #174#$- ,#$- %$4 61,6$,# 1%-4$47 -14$6%614,$6# 1,-1#%7$6 6,1%6,$6 $-7 -14$## +0+;&%' #17-$% ,$4 $44 61,6$4# 1%6$%, -1-$%614,$# 1,-1#6$- 6,1%,-$7 %$4 -146$-% +0+;&%' #1,##$, ,$4 $#- 61,$7 1%$7 -1,7$6614,4$ 1,-1#$-% 6,14$% $ -167$6% +0+;&%' #1,%$67 7-$, #,$## 61,6$#- 1%4#$%, -1-$4614,4$-- 1,-1##$7 6,144$ 4$47 -1,$# +0+;&%' #1,6$%, 7-$- #6$7# 61,-$4 1%%$- -1$66614,$,4 1,-#1,,6$%# 6,147$% -$4, -16$4% +0+;&%' #1,,$- 76$6 #%$7# 61,7$- 1%%$4 -174$%4614,-$4 1,-#1,77$6, 6,1$7 #$ -16%,$-# +0+;&%' 1#$#- 7-$-, #$, 616##$ 1%6$6# -1%%$4614,7$, 1,-#1,7$ 6,14#$4# $6% -1664$6, +0+;&%' 1##$6- 7,$% ,,$4 616##$, 1%$#% -1%4$4-614,,$6 1,-#1,-6$-7 6,16,$# $- -16,#$#, +0+;&%' 1#7#$4, 7,$,- ,6$7 616#$4 1%#6$77 -1%-$##614,,$74 1,-#1,-$77 6,1,,$#6 -$,7 -1-6$4 +0+;&%' 1#$%, 7,$- ,4$ 616#$ 1%#%$, -14#$-614,,$, 1,-#1,-#$6 6,167$7% -$7% -1-4%$%6 +0+;&%' 14#$%7 ,$44 ,%$, 616##$,# 1%#$77 -14%$6-614,,$6# 1,-#1,67$%- 6,167$-6 6$,- -1--#$-- +0+;&%' 1-#$4# ,$% ,#$64 616##$# 1%##$7 -146$66614,7$,# 1,-#1,6-$, 6,1677$-6 7$7 -1-,7$6# +0+;&%' 1##$%, ,%$44 7,$-7 61,7$,7 1%##$-4 -14,$6614,-$67 1,-#1,6-$-% 6,1-7$- -$, -176$- +0+;&%' 1%%$- ,$44 77$%, 61,6$4% 1%#$6 -14$4#614,$% 1,-#1,67$ 6,1-$47 -$4# -17-$-# +0+;&%' 16#$-, ,4$- 7$,7 61,4$# 1%#$6 -1$-7614,$7# 1,-#1,-#$# 6,1--7$7 ,$- -177%$7, +0+;&%' 1,#$74 ,4$%% 7%$77 61,$7 1%#$6 -17$6%614,#$ 1,-#1,-$,, 6,17#7$6- 6$,- -1,$7 +0+;&%' 1%#$, ,$44 7$4 617,$, 1%#7$7# -16$46147-$,, 1,-#1,-6$-7 6,17%7$4% $-- -1,4$# +0+;&%' 1%#$,# ,$%6 7#$ 6176$4- 1%%$- -164#$,#6147$- 1,-#1,7$# 6,176-$7- -$- -1,-$7 +0+;&%' 1%7#$,, ,4$%, -7$% 617%$, 1%7$7 -16-#$%6147$6 1,-#1,7-$% 6,17,-$- -$#- 71###$7- +0+;&%' 14#$% ,4$#, -$- 617$-4 1%$4 -16,7$76147#$44 1,-#1,,4$% 6,1,$- 7$,% 71#,$,# +0+;&%' 144$4 ,4$7# -%$- 61-,$% 1%%%$% -1-7$4,614-7$# 1,-1##$47 6,1,$7 6$7- 71#6#$ +0+;&%' 14-#$,6 ,$7- -$- 61-6$7 1%4$% -1-6$74614-$7 1,-1#$% 6,1,7%$ -$7 71#,#$- +0+;&%' 1#$ ,4$, 6,$47 61-%$64 1%$-# -1-76$614-$%4 1,-1#$% -#1#$74 -$- 71$% +0+;&%' 1%$7 ,%$# 67$4- 61-$6 1%6%$# -17%$%614-#$% 1,-1#%$7 -#1#4#$#6 -$%6 71#$7 +0+;&%' 16$66 ,%$#- 66$ 61-#$# 1%-4$6, -174$761467$- 1,-1#44$- -#1#6-$- 6$47 717#$7 +0+;&%' 1,$#% ,%$#4 6%$ 6167$4 1%7-$ -176-$76146-$ 1,-1#-$ -#1#,4$ $ 71#,$-, +0+;&%' 16$4 7,$, 6$4 616-$66 14#$% -17,4$7%61466$%6 1,-1#-$64 -#1$#% $7% 714#$# +0+;&%' 16$4% ,#$-4 6#$,4 616-$4, 146$ -1,$7,61466$, 1,-1#76$-6 -#14-$,- %$#, 71-#$% +0+;&%' 167$#4 ,$ 7$ 616-$# 14%$4 -1,4-$46146$- 1,-1#$7, -#1-%$4 7$%# 71,,$66 +0+;&%' 1-$7 ,$# 6$- 6166$4 144-$ -1,-$46146$ 1,-17$7 -#1,7$%6 -$7 71%7$-4 +0+;&%' 1-44$% ,#$ $4# 6166$#% 1466$- -1,,7$,#61464$-% 1,-1%-$% -#14$6 $# 71%,$,, +0+;&%' 1--$66 ,#$4% 4,$ 616$7, 147%$44 71##$#,61464$, 1,-14$-, -#14$6# $- 71%7$7 +0+;&%' 17#$6% 7,$- 4$% 616$7, 1#%$-- 71#4$61464$, 1,-1-$, -#16-$44 %$46 714%$4 +0+;&%' 17%$%% 77$- 4$% 6166$%% 14$64 71#6%$%6146$#% 1,-1,6$%4 -#177$%, $,# 7144#$4% +0+;&%' 176$ ,#$4% 4,$, 6166$6 14$# 71#7$46146$6 1,-16$,7 -#1%#$%, 4$4 71467$- +0+;&%' 17,$- ,#$#, $%6 6166$4 164$%7 71#7$666146$ 1,-1%6$46 -#1%%%$47 6$,4 714,6$- +0+;&%' %& ' & $"! & () & & *+, -& -.& /!& ! ! "#$%# &' ,&. &()* / &"#$%# &' & +** ) / 5 7 : 567 ; 567 324"- 5 7 34" 5 7 () 5 7 () 5 7 / , 5 7 / 2 , 5 7 ) 5 7 $ 564<7 (' 1,#$,% 7,$6 4$ 6166$, 17$#- 71%$,#6146$, 1,-14$%% -#1%6$7 ,$7% 714$6 +0+;&%' 1,4$# ,#$7 -$# 6166$- 16##$-% 71,$6146$4 1,-1-%$ -#1%7%$-4 ,$7% 716$66 +0+;&%' 1,7-$% 7,$- 6#$# 6166$- 16-$,7 717-$476146$4 1,-1,#$-# -#14$7 7$64 717,$ +0+;&%' 1##$6 7,$-, 6$#7 6166$7 16,$%6 71#7$#66146$ 1,-1%#$ -#14%$%% 7$7# 716$% +0+;&%' 1#4$4 ,#$#, 64$ 6166$74 164%$- 71%6$%,6146$4 1,-1%6$7% -#146#$4 6$-- 7164%$77 +0+;&%' 1#-#$4 7,$4 64$, 6166$, 16$, 716$6%6146$6 1,-1%,$4 -#147$67 $7 716-$-- +0+;&%' 1#$6 ,#$- 6$66 6166$, 166,$ 717,$766146$6 1,-1%4$67 -#1%$-, 6$ 71-#$7 +0+;&%' 1%$ ,#$7 6$4 6166$67 167$ 71%-$6146$%7 1,-1%$% -#14#$,% $,6 71-%$66 +0+;&%' 16#$- 7,$66 6$ 6166$- 16,%$- 71%4%$,6146$4 1,-1%6-$- -#16-$% $,, 71-6$- +0+;&%' 1,$4, 7,$4 6$-# 6166$,- 1-#6$ 71%-$76146$6- 1,-1%7#$- -#1,$# $, 71-,$4# +0+;&%' 1#$6 ,#$7# 6$76 6166$, 1-7$46 71%,7$46146$6 1,-1%,$, -#16$6 4$-- 717$44 +0+;&%' 1#$4 ,$# 66$4% 6166$4% 1-%#$ 714$4#6146$% 1,-14#$, -#1647$7 $#, 717$7 +0+;&%' 17#$,- 7,$#7 6$, 6166$%, 1-4%$#% 714%$-6146$#, 1,-14-$,4 -#16-6$- -$6 7177$64 +0+;&%' 1%#7$6- 7,$ 6%$ 6166$-% 1-$# 714-7$46146$4% 1,-14%#$% -#1-#$4% 6$ 71,#,$ +0+;&%' 1%4$#, ,#$4, 6$7- 6166$-% 1-67$76 71#-$6146$4% 1,-1444$ -#1-%#$6% -$-- 71,4$4, +0+;&%' 1%-#$7 ,#$46 6$,# 6166$4, 1-7#$-, 71%4$,6146$, 1,-146$%6 -#1--$- #$ 71,-#$6# +0+;&%' 14##$4 ,#$#, 64$# 6166$% 1-,%$4 716$46146$# 1,-146,$ -#1-74$4 4$7 ,1###$6 +0+;&%' 14%#$6- ,#$46 64$#, 6166$# 17#6$ 7177$761464$,# 1,-147$- -#17$6 $7% ,1#%#$-% +0+;&%' 146$, 7,$7 6%$4- 6166$ 17#$#7 7166$-61464$7 1,-14,6$%% -#17%7$, $74 ,1#6$- +0+;&%' 147$7 ,#$%- 6$, 6166$#- 17%$44 716%7$##61464$-- 1,-1#-$7- -#176#$4 ,$4 ,1#7$4- +0+;&%' 1#$- 7,$4 ,$76 6166$# 1747$% 7166-$,61464$7# 1,-1$## -#17,#$% 4$7 ,1,$%- +0+;&%' 1#$ ,$# ,$7- 616$,% 176%$%6 716,%$7%61464$6% 1,-14#$ -#1,6$# $ ,147$7 +0+;&%' 17#$46 ,#$#% ,$, 616$6% 17-7$7 71-#$#-61464$%% 1,-1$67 -#1,4$ %$% ,1-7$- +0+;&%' 16$7 7,$# ,$% 616$7, 17,4$% 71-46$,61464$, 1,-1-$64 -#1,67$, %$-, ,1#,$%% +0+;&%' 164$6% 7,$6% 6#$67 6166$ 1,#,$%4 71--$,461464$, 1,-176$77 -#1,,4$7 4$,, ,1%7$, +0+;&%' 16-#$- ,#$4# 6%$#- 6166$4 1,%$#- 71-,7$661464$,4 1,-16##$7 -1##$%7 7$6 ,16-$-4 +0+;&%' 1-#$ ,#$%4 6$ 6166$#4 1,%6$6- 7176$7761464$-4 1,-164$6 -1#47$ -$7 ,1,7$, +0+;&%' 1-%#$46 ,$6# 66$4 616$6 1,47$ 717$-661464$6 1,-166$4 -1#-4$%# $46 ,1%-$ +0+;&%' 1-4-$, ,$,- 66$4 616$# 1,$# 71767$-76146%$- 1,-16%%$% -1#,#$6 $ ,1%44$6- +0+;&%' 1-7$## ,$,- 66$4 616%$74 1,67$7 717,,$,-6146$4 1,-164-$4# -1$%4 #$## ,1%-7$6% +0+;&%' %( ! "#$% 50-029-22932-70 &' ( ' $"! ' )* ' ' %+, -' -.' /!'!" " #$%&$ '( ,' . ')*+ / '#$%&$ '( ' ,++ * / (' 0(' & / 1' (('+-.')/0 + ( -.'11( 2 3++ 2 + 4$5 !+ 6,++ 0 660 0+0 - - $,!' $!' 2 ,' ,' 324"- 34" 0!$' $%$$ $%$$ 2-7827$% 725.% $%$$-!2' $%$$ .$9-:-%$- 5-9-:5%--, -. 567 8!, 5)7 ( , 567 /!(/, ;;!$ &<<$ %$ 8$%7- .258% '* ' ! ' , %$ * *' 8(5)*7 5 7 34" 5 7 567 324"- 5 7 )9 '-2$$%. .$%$$$%$$$%$$5%$$ 8( 5 7 ,( )(5-.7 ) 5 7 5<<$ !,1,; 1,;!, %$$ -2$$%. '(8<<$$$=$$= !,1,; 1,;!, -2$-%$$ $2..7%$$ ' (&<$<$=$.= / 5 7 : 567 ; 567 324"- 5 7 34" 5 7 )* 5 7 )* 5 7 / , 5 7 / 2 , 5 7 * 5 7 $ 564<7 )( -2$$%. %.- .$%&8 72$.%87 2-%$ 2&%8-725$7%7 2-.$2.&%$ 7.2.77%&8 $%55 28-%5. !,1,;'( )"" ("# -2$-%$$ %8$ .$%$ 728.%& 2-&% 2.%$772587%$ 2-.$287%. 7.28$%5& $%$- 28-.%88 !,1,;'( 9") - -2&$%-5 &%5 .$%$$ 727$7%$ 2-&8%.- 28%$-72$%$ 2-.$28-%-- 7.28%5& &$%& 2-$8% !,1,;'( : !;( -27% 5.%$- 7%&- 727-%. 2-57% 2--%-$728%5 2-.$2-.%. 7.28&$%8 5-%& 2-.%8& !,1,;'( : !;( -2-$%8$ 7%5- 7%7 72757%-5 2-7%.. 27%5725%75 2-.$27$8%&$ 7.28%7$ 5-% 2-%77 !,1,;'( -2%88 .-%$- -%&$ 7278%. 2-.%.- 27$%572.%5 2-.$275% 7.288$%- $%-5 2-85%& !,1,;'( -2$%87 -$%$& .%.& 7277%$- 2-8%.7 27.%&72-%.- 2-.$27&.%7- 7.2-$% 55%5 72$$8%57 !,1,;'( -2.8%5 $&%$- .% 727.%- 2$$$%55 27-5%&5727%7 2-.$27%7 7.2-5%7 5.%55 72$&% !,1,;'( -2&%.- $%8. 7%7$ 7275-%8. 2$-%$ 2.%.7258%. 2-.$27.%&8 7.2-%5 %-$ 72$.$%-8 !,1,;'( &' ( ' $"! ' )* ' ' %+, -' -.' /!'!" " #$%&$ '( ,' . ')*+ / '#$%&$ '( ' ,++ * / 5 7 : 567 ; 567 324"- 5 7 34" 5 7 )* 5 7 )* 5 7 / , 5 7 / 2 , 5 7 * 5 7 $ 564<7 )( -2&8%7 $%7 75%-- 7275%8 2$&.%87 2.7&%&72&-%-8 2-.$27-$% 7.2--%.& .%88 72%7 !,1,;'( -2&8%-- $$%. 78%8$ 727&7%$7 2$58%5$ 2.8.%-572&5%.7 2-.$2.$%- 782$.%&5 &%8 72&-%58 !,1,;'( -25%- $%$ .$%85 727&$%5 2$8%& 28%72-% 2-.$2.%7 782$55%8& 7%.- 7278%87 !,1,;'( -2557%8 $$% .&%7. 7275%7 2$7.%8$ 2855%5772&%& 2-.$2.% 782$.&%.$ -%& 72--% !,1,;'( -25.7%$ $$%58 .%78 727-%7 2$.%5 28.%-72.%-7 2-.$2.-%$ 782$%57 7%.5 72.%-8 !,1,;'( -2$%-& --%. 8%. 7275%$& 2$8%5 2-$$%-.72%.& 2-.$2.&5%-. 782&$%$ $% 727%-$ !,1,;'( -2&7%& --%7 85%$& 727$8%-5 2$85%8 2-&$%7-72$.%75 2-.$2.&8%- 782-%.8 .%5& 7287%$- !,1,;'( -277%$5 $$%$ 8&%8 727$&%8. 2$8.%-5 2--%872$%. 2-.$2.5%7 78288%88 %. 72&5% !,1,;'( -2-7%- --%-7 8%-. 72-8%7 2$-%&7 2-8-%5725-.%& 2-.$2.5%- 7828%55 %88 72&5&%$ !,1,;'( -277%8& --%8 8$%&. 72-&% 2$-%.& 72$-%725-% 2-.$2.$%& 78258%- 8%78 72&.%-8 !,1,;'( -277%7$ $$%.. 8$%- 7288%&& 2$$%7 72$58%$7258.%$& 2-.$2.%7- 782..%$5 %$ 725$%8 !,1,;'( -2787%. $$%7 .8%7 728%.5 2$7%7 72$..%.7258%55 2-.$2.7%55 782&$7%$7 7%75 725&%$ !,1,;'( -2.%. -8%& .7%.7 72..%-- 2% 72$5%7.725.7%7- 2-.$2.7.%.7 782&&&%$ 8%-7 7258%-5 !,1,;'( -2.57%5 -5%&- .&%- 72.5%5- 2$%. 72&5%5725.&%- 2-.$2..7%$& 782&7&%&$ .% 7258-%. !,1,;'( -2..%. -&%77 .%8 72.%5& 2-% 727%&.725.%& 2-.$2.8%$ 782&-%$7 .%8 728%-. !,1,;'( -28$$%7$ -% 7.%. 72.%&- 2&.%-. 728%7&725.$%$- 2-.$2.-5% 78255%5 .%. 725&%8 !,1,;'( -28&$%- -$%. 75%8$ 72.$%- 25-%- 72%.$7257-%7 2-.$28$7%& 78255% -%57 72.&%&5 !,1,;'( -287$%&& 88% 7%7- 72.%& 27&%5 72&-%.7257-%8& 2-.$28-%8. 782578% $%$- 727$&%- !,1,;'( -28-5%$& 88%$$ 7%8 72.% 2.8%8& 727-%8725.$%8 2-.$28&%.$ 7825-.%8 %7 727&7%7- !,1,;'( -2-$%& 8.%8 7%7 72.&% 2-% 72-%.8725.%8 2-.$2858%8 782$%-5 %. 7277%. !,1,;'( -2-5%& 85% -%87 72.%&8 2$.%.8 72&%&5725.5%$8 2-.$287%$- 782$%& $%-- 727-7%7 !,1,;'( -2-8$%7& 85%.5 7$%$ 72..%85 2$%-$ 72&5%$725.7%5 2-.$28.8%&- 782.%-& %$ 72.%-7 !,1,;'( $2$% 8%$ 8%& 728$% 2&7%7- 72&.%55725.-% 2-.$28-5%&- 782--%$ 7%$7 72.%8 !,1,;'( $2$5%75 8%88 .%5. 728%8- 2%7. 72&-7%877258%- 2-.$2-$%8 78275%5- &%&8 72.8%5 !,1,;'( $2$77%$ 87%7 8% 7285%- 27%7& 725.%5.7258&%- 2-.$2-&%. 78275%$$ &%. 728$%&5 !,1,;'( $2$%.8 8%8 -%-7 728.% 285%5 72558%-7258%8 2-.$2-5%.- 7827.7%. 5%8$ 7285%& !,1,;'( $2&%& 8%& 7$%77 728-%55 2-8%-- 725.5%572588%5 2-.$2-.%5 782.$%77 &%. 728.$%7 !,1,;'( $27%- 85%$7 7%- 72-% 2&%8- 725--%.-725-$%8 2-.$2-.%7 782.7%- %-$ 728-8%87 !,1,;'( $2-%- 85%$7 7%- 72-%& 2&.%&7 727%-725-5%$ 2-.$2-87%&5 782.&%-$ $%$& 72--%- !,1,;'( $2$%8 88%5$ 7$%7 72-.%& 2&5%$8 72%-725-%-& 2-.2$$$%. 782..8%8& %.8 72-.% !,1,;'( $2%7& 8.%.$ 7%5 72-8%5 2&7%-& 728%-725-.% 2-.2$7%&. 7828$-%77 &%$ 72--%$& !,1,;'( $2.7% 8-%8 78%& 72-8%8 2&7%$- 727$%85725-.% 2-.2$5%7- 78288% 8% .2$%7 !,1,;'( $2&$7%. -%-$ .$%5 72-8%&- 2&.%.- 727&$%$725-.%$- 2-.2$&%7& 78287%.8 -%8. .2$5%- !,1,;'( $2&57%7 -$%-8 .%7$ 72-.%&8 2&88%8& 72778%$-725-7%$8 2-.2$58%-8 7828-5%7 &%. .2$8%-8 !,1,;'( $2&.%$& -$% .$%-$ 72-.% 2&-7%7. 727-%.725-%8 2-.2$.%$ 782-.%. 5% .2$.%& !,1,;'( $25$%- -%8 .&%& 72-7%7& 25$7%$ 72.$%725-%&& 2-.2$77%7 782-57%. -%.5 .2&.%88 !,1,;'( $25&$%8- -&%7- .5%8 72-%& 255%$. 72.58%&-725-&%-& 2-.2$.5%88 782-.5%75 8% .27.%$. !,1,;'( $257%87 -&%. .%$$ 72-&%& 25% 72..8%&725-%-& 2-.2$8&%8 7-2$$5%5 $%7 .2-.%8. !,1,;'( $25-%-. -%-& .5%$- 72-%7- 25&$%5$ 728$8%8725-$%&- 2-.2$-%. 7-2$&5%8 7%5 .28%85 !,1,;'( $2%. -&%7 .$%5 72-$%&5 25&-%$7 728&%$87258-%$5 2-.2$$%8 7-2$7% 5%.7 .2.%$8 !,1,;'( &' ( ' $"! ' )* ' ' %+, -' -.' /!'!" " #$%&$ '( ,' . ')*+ / '#$%&$ '( ' ,++ * / 5 7 : 567 ; 567 324"- 5 7 34" 5 7 )* 5 7 )* 5 7 / , 5 7 / 2 , 5 7 * 5 7 $ 564<7 )( $2$%.$ -%$ .7%- 7288%5 255.%&5 7287&%72587%85 2-.2$-%$ 7-2$8-%. &%7 .287%& !,1,;'( $28%& -5%8 .7%- 728% 255%5 728-%-772585% 2-.27%5 7-28%87 $%7 .2&7%7. !,1,;'( $27$%57 -&%5. .%7 728&%5 257% 72-%.7258% 2-.2&%&7 7-25.%$$ 7%& .2&5% !,1,;'( $275% -&%.5 .%5 728%5. 257-% 72-$%.7258$%. 2-.2&%$5 7-2.7%58 -%-- .2&.7%. !,1,;'( $27.%85 -5%- .7% 72.-%7 25..%.7 72-8$%$-725..%87 2-.25$%58 7-2$%.8 %78 .25$7%8 !,1,;'( $2.$%$ -5%87 8$%5& 72.7%78 258&%7& .2$$8%5725.%&8 2-.257%- 7-2&5%8 5%8 .25&%&& !,1,;'( $2.&$%$ -&%.. 8%78 72.5%58 2588%7 .2$&.%&$725.&%8 2-.2%& 7-27%8- %7. .257&%-$ !,1,;'( $2..7%$$ -&%.. 8%78 72.%5. 25-5%.. .2$8%725.$%. 2-.28%&5 7-2&$8%$ $%$$ .2$8%7 !,1,;'( &) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1C-15L2 JBR 04/01/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 BOP Misc, 2 are their piper valves they use for testing and 1 is a swab valve. The others are door seal failures on the lower 2" and Lower 2 3/8" rams. The seals on the lower 2 3/8 ram assemble failed and the whole door/Ram had to be changed. The gas head on the Shaker wouldn’t give an audible alarm and the head was changed out. Operator completed testing 3/15/22. Test Results TEST DATA Rig Rep:Coyne/EnfeildOperator:ConocoPhillips Alaska, Inc.Operator Rep:Newell/Kiser Contractor/Rig No.:Nabors CDR3AC PTD#:2220290 DATE:3/13/2022 Type Operation:DRILL Annular: 250/2500Type Test:INIT Valves: 250/4000 Rams: 250/4000 Test Pressures:Inspection No:bopLOL220321081345 Inspector Lou Laubenstein Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12 MASP: 3283 Sundry No: Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 NT Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 NTManual Chokes 1 NTHydraulic Chokes 0 NACH Misc Stripper 1 2"NT Annular Preventer 1 7 1/16"NT #1 Rams 1 Blind/shear P #2 Rams 1 2" combi NT #3 Rams 1 2 3/8" combi NT #4 Rams 1 2" conbi NT #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"NT HCR Valves 2 2 1/16"NT Kill Line Valves 5 2 1/16"P Check Valve 0 NA BOP Misc 5 piper/swab/d FP System Pressure NT Pressure After Closure NT 200 PSI Attained NT Full Pressure Attained NT Blind Switch Covers:NT Nitgn. Bottles (avg):NT ACC Misc NT P PTrip Tank P PPit Level Indicators P PFlow Indicator P FPMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 NT 9 9 99 9 9 9 9 9 9 9 17,QVSHFWRUGLGQRWZLWQHVVGXHWRUDPFRPSRQHQW IDLOXUHVUHSDLUV2SHUDWRUUHSRUWVKRZVKU%23( WHVWLQFOXGLQJUHSDLUVZLWKDGGLWLRQDOIDLOXUHV EDOOW\SHIORRUVDIHW\YDOYHGHSOR\PHQWOLQH+&5 9 NT NT NT NT NT NT NT NT FP NT NT NT NT NT NT NT NT NT NT door seal failures on the lower 2" and Lower 2 3/8" rams. gas head on the Shaker wouldn’t give an audible alarm FP TIME STATE °'ALASKA GOVERNORMICHAEL J. DUNLEAVY 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 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-15L2 ConocoPhillips Alaska, Inc Permit to Drill Number: 222-029 Surface Location: 1633' FNL, 4041' FEL, Sec. 12, T11N, R10E, UM Bottomhole Location: 3640' FNL, 4892' FEL, Sec. 5, T11N, RI IE, 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 No. 198-229, API No. 50-029- 22935-00-00. 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, Digitally signed by Jeremy Price Jeremy Price Date: 2022.03.11 15:20:59 -09,00, Jeremy M. Price Chair DATED this 11 day of March, 2022. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED By Samantha Carlisle at 11:28 am, Feb 28, 2022 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service- WAG Service - Disp ❑ 1c. Specify if well is proposed for: Drill ] Lateral 0 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 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 1C-15L2 3. Address: P.O. Box 100360 6. Proposed Depth: TVD:6568' TVD 12. Field/Pool(s): Anchorage, AK 99510 MD: 13200' MD TVD: 6466' TVDSS Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: DLB Surface: 1633' FNL, 4041' FEL, Sec. 12, T11 N, R10E, UM ADL025649 DLB ADL 028242 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 302' FSL, 1539' FWL, Sec. 6, T11N, R11E, UM ALK 2292 4/1/2022 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 3640' FNL, 4892' FEL, Sec. 5, T11 N, R11 E, UM 2560 4850' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 101.50' 15. Distance to Nearest Well Open Surface: x- 5968605 y- 562247 Zone-4 GL / BF Elevation above MSL (ft): 0.00, to Same Pool: 497' to 1 C-14A 16. Deviated wells: Kickoff depth: 9125' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 104.75 degrees Downhole: 3943 psi @5113' TVD Surface: 3283 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST-L 4250' 8950' 6343' 13200' 6466' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 9390' 6840' 9141' 9141' 6616' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 9 cu yds High Early 121' 121' Surface 6209' 9-5/8" 850 sx AS III LW, 610 sx Class G 6249' 4489' Intermediate Production 9354' 7" 178 sx Class G 9393' 6843' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Alternating Slotted/Solid Liner @ 8950' - 13200' MD Alternating Slotted/Solid Liner @ 6343' - 6466' TVD Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments: Property Plat V BOP Sketch Lj Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Lj Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: James Ohlinger Authorized Name: James Ohlinger Contact Email: marries. i.ohIinger(a)conocophillips.com Authorized Title: Staff CTD Engineer Contact Phone: (907) 265-1102 Authorized Signature: ,I, J. Ohlinger- ",9 ".,ame=, Date: Commission Use Only Permit to Drill Number: API Number: Permit Approval 3/ 1 1 /22 Date: See cover letter for other requirements. 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: BOP test to 4000 psig Samples req'd: Yes ❑ No[Xj Mud log req'd: Yes❑ NoLgj Annular preventer test to 2500 psig Spacing H2S measures: Yes [S1 No❑ Directional svy req'd: Yes ® No❑ exception req'd: Yes ❑ No® Inclination -only svy req'd: Yes ❑ NoLk A variance to 20 AAC 25.015(b) is granted to allow the kickoff point to be any point along t�ie�pareriPCaera� req'd: Yes❑ No)(] Digitally signed by Jeremy Price Approved by: Jeremy Price Date: 2022.03.11152114 -0900' APPROVED BY COMMISSIONER THE COMMISSION Date: 3/11/22 Comm.dts 3/11/2022 CommJLC 3/11/2022 Sr Pet EngVTL 03/11/2022 Sr Pet Geo DLB 03/10/2022 Sr Res Eng Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) `� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 24, 2022 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 a lateral out of the KRU 1 C-15 (PTD# 198-229) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in March 2022. The objective will be to drill a lateral, KRU 1 C-151-2 targeting the Kuparuk C-sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to permit to drill applications are the following documents: — Permit to Drill Application Form (10-401) for 1 C-151_2 — Detailed Summary of Operations — Directional Plans for 1 C-151-2 — Current Wellbore Schematic — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-1102. Sincerely, JamesJ Digitally signed by James J; Ohlinger -Coiled Tubing Drrili g, CN=JameshJipOshOge,, . E=Jamas.J.Ohlinger@cop.com O h l i n g e r Reason: I am the author of this document Data J 28111 i09'0g' to 2.22PDF 23 Foxit James Ohlinger Coiled Tubing Staff Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 1 C-15L2 Application for Permit to Drill Document 1. Well Name and Classification......................................................................................................... 2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)).................................................................................................................. 2 2. 3. 4. 5. 6. 7. 8. 9. 10 11 LocationSummary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))................................................................................................................................................. 2 Blowout Prevention Equipment Information.................................................................................2 (Requirements of 20 AAC 25.005 (c)(3))................................................................................................................................................ 2 Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4))................................................................................................................................................ 2 Procedure for Conducting Formation Integrity tests.................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))................................................................................................................................................. 2 Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))................................................................................................................................................. 3 DiverterSystem Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))................................................................................................................................................. 3 DrillingFluids Program................................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(8))................................................................................................................................................. 3 Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9))................................................................................................................................................. 4 SeismicAnalysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))............................................................................................................................................... 4 SeabedCondition 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 Summaryof CTD Operations.......................................................................................................................................... 4 LinerRunning.................................................................................................................................................................. 5 14. Disposal of Drilling Mud and Cuttings........................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))............................................................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells........................................................................ 6 (Requirements of 20 AAC 25.050(b))..................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 6 Attachment 1 Attachment 2 Attachment 3 Directional Plans for the 1 C-15L2 lateral ..................................................Error! Bookmark not defined. Current Well Schematic for 1C-15 and 1C-15L1 ......................................Error! Bookmark not defined. Proposed Well Schematic for the 1 C-151-2 lateral....................................Error! Bookmark not defined. Page 1 of 6 February 23, 2022 PTD Application: 1C-151-2 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 1 C-151-2. The lateral will be classified as "Service" 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 1 C-151-2. 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 4,000 psi. Using the maximum formation pressure in the area of 3943 psi found in 1C-14A measured 7/16 (i.e.14.83 ppg EMW), the maximum potential surface pressure in 1 C-15, assuming a gas gradient of 0.1 psi/ft, would be 3283 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 1 C-15 was measured at 3737 psi @ 6350' TVD (11.32 ppg) on 1112122. The maximum downhole pressure in the 1 C-15 vicinity is 1 C-14A at 3943 psi @ 5113' TVD (14.83 ppg — Measured 712016). Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells are reported to have MI in the past, but there is a low possibility of encountering free gas while drilling the 1 C-15 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 1 C-15 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 1 C-15 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 November 22, 2021 PTD Application: 1 C-151_2 6. Casing and Cementing Program (Requirements of 20 AA 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name MD MD TVDSS TVDSS Liner Details 1 C-15L2 —8950' 13,200' 6343' 6466' 2-3/8", 4.7#, L-80, ST-L slotted liner, solid liner with seal -bore assembly Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 63 H-40 Welded 41' 121' 121' 121' 1640 670 Surface 9-5/8" 40 L-80 BTC-M 40' 6249' 4489' 4488' 5750 3090 Production 7" 26 L-80 BTC-M 38.5' 9393' 6843' 6843' 7240 5410 Tubing 3-1/2" 9.30 L-80 EUE 36.6' 8977' 6622' 6469' 10160 10540 7. Diverter System Information (Requirements of 20 AA 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 AA 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 —11.8 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. 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". DLB IIn the 1 C-15 lateral, operations will target a constant BHP of —11.8 ppg EMW at the window. 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. Page 3 of 6 November 22, 2021 PTD Application: 1C-151-2 Pressure at the 1C-15 Window (9125' MD, 6602' TVD) Using MPD Pumps On 1.9 b m Pumps Off A/C -sand Formation Pressure 11.13 3737 psi 3737 psi Mud Hydrostatic 8.6 2952 psi 2952 psi Annular friction i.e. ECD, 0.080 si/ft 730 psi 0 psi Mud + ECD Combined no chokepressure) 3682 psi underbalanced -55 psi 2952 psi underbalanced -876 psi Target BHP at Window 11.8 pp 4051 psi 3880 psi Choke Pressure Required to Maintain Target BHP 369 psi 1052 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 1 C-15 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize a single lateral to target the C-sands to the east of 1 C-15. CDR3-AC will mill a window in the 7" casing at -9125' MD and the 1 C-151-2 lateral will be drilled to TD at 13,200' MD, targeting the C-sands to the east. It will be completed with 2-3/8" slotted liner up to -8950' MD. CTD Pre -Rig, Drill, and Complete 1C-15L2 Lateral Pre-CTD Work • Pre-CTD diagnostics • Eline: • Service CTU: Chemical cut 1 C-151-1 liner -9150' MD Confirm liner cut Page 4 of 6 November 22, 2021 PTD Application: 1C-151-2 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. Drill 1 C-15L2 Lateral (C-sand) a. Pull —300' of L1 liner out of hole b. Caliper 7" casing 9140' to 8900' MD c. Set HEW —9125' MD d. Mill 2.80" window at --9125' MD. e. Drill 3" bi-center lateral to TD of 13,200' MD. f. Run 2%" slotted liner up to--8950' MD 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to service 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 1 C-15 lateral will be displaced to an overbalancing fluid (-11.8 ppg NaBr) 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. Page 5 of 6 November 22, 2021 PTD Application: 1C-151-2 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. — Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. — All wastes and waste fluids hauled from the pad must be properly documented and manifested. — Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (659-7212). 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 1 C-15L2 4850' • Distance to Nearest Well within Pool Lateral Name Distance Well 1 C-1511_2 497' 1 C-14A 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) KRU 1 C-15, L 1, L2 (motherbore injector) — Completed with 7", 26#, L-80 casing on 12/15/1998. — 3 Bow Spring & 34 Spiraglider Centralizers: One Bow Spring on Jt #1 & Jt #3 on stop ring — 18 Centering Guides: Slip one on every 3rd joint as follows: Joints #169, 172, 175, 178, 181, 184, 187, 190, 193, 196, 199, 202, 205, 208, 211, 214, 217, & 220. — C-sand perf'd 9096'-9141'. The tubing tail is at 8976' MD with the packer at 8919' MD. — The cement bond log shows cement up to and above the perforations. Well was put on injection in 2004 with state's knowledge. The well has a history of passing state -witnessed MIT-IA's and no reporting of abnormal 9-5/8" casing pressure. The proposed kick-off point for the CTD sidetrack is in the C-sand perforations of the 7" casing and should not compromise existing conformance. The 1 C-151-1 lateral has been injecting to the north of 1 C-15 since it's been drilled in 2003. KRU Surrounding Wells See attached Table for review wells 17. Attachments Attachment 1: Directional Plans for IC-15L2lateral Attachment 2: Current Well Schematic for 1 C-15 Attachment 3: Proposed Well Schematic for 1 C-15L2 lateral Page 6 of 6 November 22, 2021 1C-151-2 Quarter Mile Injection Review Well Name Status Casing Top of C Sand Top of C-Sand Oil Top of Cement Top of Cement Top of Cement Reservoir Status Zonal Isolation Cement Operations Mechanical Integrity Size oil pool (MD) Pool (TVDSS) (MD) (TVDSS) Determined By Summary 1C-14 & 1C-14A Injector 7" 11,999' 6474' 10,400' 6231' Log Injector open to only C- Packer at 10,300' and cei 130 sx Class G Cement MITIA passed @1880 Sand through slotted psi 5/13/18 liner. 1C-22 Injector 7" 14,340' 6540' 14,070' 6357' Log Injector open only to Packer at 14047', and 230 sx Class G cement MITIA passed @1790 the C-sand ; cement psi 9/15/18 perforations 14340- OMIT-T+IA passed 14365' @2500 psi 9/02/18 1C-23,A,ALI,AL2, AI-2- Producing 7" 13,595' 6459' 13,437' 9392' CTD cement prep Producer open only to C Packer at 13,437', the 300 sx Class G cement CMIT-T+IA passed 01, AI2-02 Sand through CTD motherbore has been @2500 psi 6/14/17 sidetrack completed cemented to above the with slotted liner. tubing tail. 1C-251-1 Injector 7" 9788' 6342' 9450' 6139' Log Injector open only to C- Packer at 9417' 170 sx Class G sand, slotted pipe 9775- MITIA passed @1810 10454 psi12/30/20 ConocoPhillips Project: Kuparuk River Unit-1 Site: Kuparuk 1C Pad Well: 1C-15 Wellbore: 1C-151_2 Plan: 1C-15L2 wp01 T M Azimuths to True North Magnetic North: 15.11" Magnetic Field Strength: 57249.9nT Dip Angle: 80.70" Date: 3/1/2022 Model: BGGM2021 �IyELLBORE DETAILS: 1 C-15L2 REFERENCE INFORMATION Coorrtical (TVD) Reference: Well Sea True North Vertical TVD Reference: Mean Sea Level ( ) Section (VS) Reference: Slot - (O.00N, O.00E) Measured Depth Reference: 1C-151-1: @ 101.50usft (1C-15L1:) Calculation Method: Minimum Curvature Parent Wellbore: 1 C-15 Tie on MD: 9119.72 WELL DETAILS: 1C-15 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5968605.15 562247.15 70' 19' 29.109 N 149' 29' 42.919 W SECTION DETAILS Sec MD Inc Azi TVDss +N/-S +E/-W Dleg TFace VSect 1 9119.72 25.80 70.18 6495.52 1936.70 5576.36 0.00 0.00 5902.46 2 9125.00 25.82 70.16 6500.27 1937.48 5578.52 0.41 -23.94 5904.76 3 9154.00 31.04 70.16 6525.76 1942.17 5591.51 18.00 0.00 5918.56 4 9316.13 104.00 70.16 6583.65 1989.65 5723.10 45.00 0.00 6058.45 5 9500.00 104.75 83.43 6537.81 2030.27 5896.05 7.00 85.00 6234.87 6 9740.00 104.11 66.09 6477.55 2091.17 6119.33 7.00 -90.00 6465.51 7 9975.00 89.77 57.95 6449.18 2200.47 6324.50 7.00-150.00 6695.69 8 10350.00 83.65 83.53 6471.05 2323.13 6674.72 7.00 104.00 7066.74 9 10700.00 89.95 59.80 6490.87 2432.42 7003.82 7.00 -76.00 7413.38 10 10950.00 94.70 76.66 6480.66 2524.75 7234.88 7.00 74.00 7662.08 11 11300.00 94.28 52.09 6452.82 2674.50 7547.04 7.00 -90.00 8006.63 12 11675.00 89.45 77.91 6440.43 2831.41 7883.80 7.00 100.00 8376.75 13 11875.00 83.81 65.07 6452.23 2894.57 8072.68 7.00-114.00 8575.83 14 12150.00 84.16 84.42 6481.31 2966.16 8335.25 7.00 90.00 8847.06 15 12550.00 91.78 57.44 6495.74 3095.67 8709.23 7.00 -75.00 9242.78 16 12950.00 92.98 85.44 6478.80 3221.65 9084.31 7.00 87.00 9638.32 17 13200.00 92.84 67.92 6466.01 3278.95 9326.32 7.00 -90.00 9885.34 6001 6201 c :5 6401 0 CD E. 6601 0 0 U 6801 0) 2 H 7001 5001 c 4001 U) 0 0 N 3001 Z 2001 E Z) U) 100( c Baker Hughes 1 C-1 L2 wpOl I � I KOP C� �. TIP from 1C-15 0 0 0 0 0 0 O O o O O o o O o O o 0 0 00 O O O o West( -)/East(+) (2000 usft/in) 1 -15L wp 1 I T -in-Point from 1 C- 5 ^ KO - Top ol Whipstock D I -' l/ r a � I co N O O A co Iv 6) O A cc N 6) O O O � 8 N N O O O O O CD CD CD O O O O O ? W N T O ? O O O O O O O O O O O O O O O O O O O O O O O O O O O Vertical Section at 70.00' (800 usft/in) ConocoPhillips 7500- 6750- 6000- 5250- 4500- 0 7 _ O CD L _ 0 3000— Z 0 2250- 1500- 750- 0- Project: Kuparuk River Unit-1 Site: Kuparuk 1C Pad Well: 1C-15 Wellbore: 1C-151-2 Plan: 1C-15L2 wp01 T M Azimuths to True North Magnetic North: 15.11" Magnetic Field Strength: 57249.4nT Dip Angle: 80.690 Date: 3/1/2022 Model: BGGM2021 �IyELLBORE DETAILS: 1 C-15L2 REFERENCE INFORMATION Coorrtical (TVD) Reference: Well Sea True North Vertical TVD Reference: Mean Sea Level ( ) Section (VS) Reference: Slot - (O.00N, O.00E) Measured Depth Reference: 1C-151-1: @ 101.50usft (1C-15L1:) Calculation Method: Minimum Curvature Parent Wellbore: 1 C-15 Tie on MD: 9119.72 West( -)/East(+) (1500 usft/in) N W w ? Cn O O J co Cfl Cfl O N N w A Cn N O J Ul N O J cn N O J Cn N O J cn N O c11 O CT O CP O cn O Ul O 01 O U1 O cT O cn O O O O O O O O O O O O O O O O O O O Baker Hughes 1 -19L 1 C-15L w 01 ww S000 Np o "o A. oom o �i ar o o TD ti P 23 \ 2 o� rn , G 23P� 6 moo 0 ©o 0 o w KOP - p of Whipst k h^ b Tie-in Point from 1 -15 o O n 0 0 ........ o P b o roo d h 0 o o w gQ53 Ci ? o 0 0 0 W 0 0 o 0 0 m N N 1 w w A U1 O O J Co CD n O CA O J CD J ND N Cn N CO Cr CD Cn Cn U1 O Cn N O J 0 N CD O O O O O CD O O O O 0 cP O Cn O Cn O O O O O O O O West( -)/East(+) (1500 usft/in) —7500 —6750 —6000 —5250 —4500 0 —3750 0 —3000 cn CD CIO 2250 j —1500 —750 —0 --750 ConocoPhillips NADConversion Kuparuk River Unit _1 Kuparuk 1C Pad 1 C-15 1 C-15L2 Plan: 1 C-151-2 wp01 Standard Planning Report 23 February, 2022 Baker Hughes Baker Hughes ConocOflillips Planning Report Baker Hughes Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well 1C-15 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit_1 MD Reference: 1C-151-1: @ 101.50usft (1C-151-1:) Site: Kuparuk 1C Pad North Reference: True Well: 1C-15 Survey Calculation Method: Minimum Curvature Wellbore: 1 C-15L2 Design: 1C-15L2 wp01 Project Kuparuk River Unit_1, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1C Pad Site Position: Northing: 5,968,522.46 usft Latitude: 70° 19' 28.285 N From: Map Easting: 562,372.05usft Longitude: 149' 29' 39.293 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.48 ° Well 1 C-15 Well Position +N/-S 0.00 usft Northing: 5,968,605.15 usft Latitude: 70° 19' 29.109IN+E/-W 0.00 usft Easting: 562,247.15 usft Longitude: 149° 29'42.919Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00u Wellbore 1C-151-2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength n ME" (1) (nT) AL BGGM2021 3/1/2022 15.11 80.70 57,249.87 Design 1C-151-2wp01 Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 9,119.72 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (I -60.30 0.00 0.00 70.00 2/23/2022 2:35:54PM Page 2 COMPASS 5000.15 Build 91E Baker Hughes ConocOPhillips Planning Report Baker Hughes Database: EDT 15 Alaska Prod Company: NADConversion Project: Kuparuk River Unit_1 Site: Kuparuk 1C Pad Well: 1C-15 Wellbore: 1 C-15L2 Design: 1C-15L2 wp01 Plan Sections Measured TVD Below Depth Inclination Azimuth System (usft) (°) (°) (usft) 9,119.72 25.80 70.18 6,495.52 9,125.00 25.82 70.16 6,500.27 9,154.00 31.04 70.16 6,525.76 9,316.13 104.00 70.16 6,583.65 9,500.00 104.75 83.43 6,537.81 9,740.00 104.11 66.09 6,477.55 9,975.00 89.77 57.95 6,449.18 10,350.00 83.65 83.53 6,471.05 10,700.00 89.95 59.80 6,490.87 10,950.00 94.70 76.66 6,480.66 11,300.00 94.28 52.09 6,452.82 11,675.00 89.45 77.91 6,440.43 11,875.00 83.81 65.07 6,452.23 12,150.00 84.16 84.42 6,481.31 12,550.00 91.78 57.44 6,495.74 12,950.00 92.98 85.44 6,478.80 13,200.00 92.84 67.92 6,466.01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-15 Mean Sea Level 1C-151-1: @ 101.50usft (1C-151-1:) True Minimum Curvature Dogleg Build Turn +N/-S +E/-W Rate Rate Rate TFO (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 1,936.70 5,576.36 0.00 0.00 0.00 0.00 1,937.48 5,578.52 0.41 0.38 -0.39 -23.94 1,942.17 5,591.51 18.00 18.00 0.00 0.00 1,989.65 5,723.10 45.00 45.00 0.00 0.00 2,030.27 5,896.05 7.00 0.41 7.21 85.00 2,091.17 6,119.33 7.00 -0.27 -7.22 -90.00 2,200.47 6,324.50 7.00 -6.10 -3.46 -150.00 2,323.13 6,674.72 7.00 -1.63 6.82 104.00 2,432.42 7,003.82 7.00 1.80 -6.78 -76.00 2,524.75 7,234.88 7.00 1.90 6.74 74.00 2,674.50 7,547.04 7.00 -0.12 -7.02 -90.00 2,831.41 7,883.80 7.00 -1.29 6.89 100.00 2,894.57 8,072.68 7.00 -2.82 -6.42 -114.00 2,966.16 8,335.25 7.00 0.13 7.04 90.00 3,095.67 8,709.23 7.00 1.90 -6.75 -75.00 3,221.65 9,084.31 7.00 0.30 7.00 87.00 3,278.95 9,326.32 7.00 -0.06 -7.01 -90.00 Target 2/23/2022 2:35:54PM Page 3 COMPASS 5000.15 Build 91E Baker Hughes ConocOPlillips Planning Report Baker Hughes Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well 1C-15 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit_1 MD Reference: 1C-151-1: @ 101.50usft (1C-151-1:) Site: Kuparuk 1C Pad North Reference: True Well: 1C-15 Survey Calculation Method: Minimum Curvature Wellbore: 1 C-15L2 Design: 1C-151-2 wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +El-W Section Rate Azimuth Northing Easting (usft) V) (°) (usft) (usft) (usft) (usft) (°I100usft) (°) (usft) (usft) 9,119.72 25.80 70.18 6,495.52 1,936.70 5,576.36 5,902.46 0.00 0.00 5,970,587.85 567,806.72 Tie -in -Point from 1 C-15 9,125.00 25.82 70.16 6,500.27 1,937.48 5,578.52 5,904.76 0.41 -23.94 5,970,588.65 567,808.88 KOP - Top of Whipstock 9,154.00 31.04 70.16 6,525.76 1,942.17 5,591.51 5,918.56 18.00 0.00 5,970,593.44 567,821.82 9,200.00 51.74 70.16 6,560.09 1,952.43 5,619.96 5,948.81 45.00 0.00 5,970,603.94 567,850.19 9,300.00 96.74 70.16 6,586.56 1,984.26 5,708.18 6,042.59 45.00 0.00 5,970,636.50 567,938.13 9,316.13 104.00 70.16 6,583.65 1,989.65 5,723.10 6,058.45 45.00 0.00 5,970,642.01 567,953.00 9,400.00 104.44 76.20 6,563.04 2,013.16 5,800.88 6,139.58 7.00 85.00 5,970,666.17 568,030.57 9,500.00 104.75 83.43 6,537.81 2,030.27 5,896.05 6,234.87 7.00 86.48 5,970,684.06 568,125.60 9,600.00 104.64 76.19 6,512.40 2,047.38 5,991.18 6,330.11 7.00 -90.00 5,970,701.95 568,220.57 9,700.00 104.31 68.97 6,487.38 2,076.35 6,083.50 6,426.77 7.00 -91.84 5,970,731.69 568,312.63 9,740.00 104.11 66.09 6,477.55 2,091.17 6,119.33 6,465.51 7.00 -93.65 5,970,746.80 568,348.34 9,800.00 100.47 63.95 6,464.79 2,115.93 6,172.45 6,523.89 7.00 -150.00 5,970,772.00 568,401.25 9,900.00 94.36 60.50 6,451.89 2,162.12 6,260.12 6,622.08 7.00 -150.45 5,970,818.92 568,488.53 9,975.00 89.77 57.95 6,449.18 2,200.47 6,324.50 6,695.69 7.00 -150.90 5,970,857.79 568,552.57 10,000.00 89.35 59.65 6,449.37 2,213.42 6,345.88 6,720.21 7.00 104.00 5,970,870.91 568,573.84 10,100.00 87.66 66.44 6,451.99 2,258.71 6,434.92 6,819.37 7.00 103.99 5,970,916.94 568,662.50 10,200.00 86.01 73.26 6,457.51 2,293.09 6,528.60 6,919.16 7.00 103.81 5,970,952.09 568,755.88 10,300.00 84.42 80.10 6,465.86 2,316.05 6,625.51 7,018.07 7.00 103.43 5,970,975.85 568,852.58 10,350.00 83.65 83.53 6,471.05 2,323.13 6,674.72 7,066.74 7.00 102.86 5,970,983.34 568,901.74 10,400.00 84.51 80.12 6,476.21 2,330.20 6,723.94 7,115.41 7.00 -76.00 5,970,990.82 568,950.89 10,500.00 86.28 73.32 6,484.25 2,353.09 6,820.89 7,214.34 7.00 -75.65 5,971,014.51 569,047.63 10,600.00 88.10 66.56 6,489.17 2,387.33 6,914.65 7,314.16 7.00 -75.10 5,971,049.53 569,141.10 10,700.00 89.95 59.80 6,490.87 2,432.42 7,003.82 7,413.38 7.00 -74.77 5,971,095.35 569,229.89 10,800.00 91.87 66.53 6,489.28 2,477.53 7,092.99 7,512.59 7.00 74.00 5,971,141.19 569,318.66 10,900.00 93.77 73.28 6,484.35 2,511.82 7,186.72 7,612.41 7.00 74.11 5,971,176.26 569,412.11 10,950.00 94.70 76.66 6,480.66 2,524.75 7,234.88 7,662.08 7.00 74.44 5,971,189.58 569,460.15 11,000.00 94.69 73.15 6,476.56 2,537.73 7,282.98 7,711.72 7.00 -90.00 5,971,202.95 569,508.13 11,100.00 94.62 66.13 6,468.43 2,572.38 7,376.36 7,811.32 7.00 -90.29 5,971,238.38 569,601.22 11,200.00 94.49 59.11 6,460.48 2,618.20 7,464.82 7,910.12 7.00 -90.86 5,971,284.93 569,689.28 11,300.00 94.28 52.09 6,452.82 2,674.50 7,547.04 8,006.63 7.00 -91.42 5,971,341.90 569,771.03 11,400.00 93.04 58.99 6,446.44 2,730.93 7,629.27 8,103.20 7.00 100.00 5,971,399.01 569,852.78 11,500.00 91.75 65.88 6,442.26 2,777.13 7,717.79 8,202.19 7.00 100.44 5,971,445.94 569,940.90 11,600.00 90.44 72.76 6,440.35 2,812.42 7,811.27 8,302.10 7.00 100.73 5,971,482.00 570,034.08 11,675.00 89.45 77.91 6,440.43 2,831.41 7,883.80 8,376.75 7.00 100.86 5,971,501.58 570,106.44 11,700.00 88.73 76.31 6,440.83 2,836.98 7,908.17 8,401.55 7.00 -114.00 5,971,507.35 570,130.76 11,800.00 85.90 69.90 6,445.51 2,865.98 8,003.69 8,501.23 7.00 -113.97 5,971,537.14 570,226.03 11,875.00 83.81 65.07 6,452.23 2,894.57 8,072.68 8,575.83 7.00 -113.67 5,971,566.30 570,294.77 11,900.00 83.82 66.83 6,454.92 2,904.70 8,095.37 8,600.62 7.00 90.00 5,971,576.62 570,317.37 12,000.00 83.89 73.87 6,465.65 2,938.11 8,188.94 8,699.98 7.00 89.81 5,971,610.80 570,410.66 12,100.00 84.05 80.91 6,476.18 2,959.81 8,285.92 8,798.54 7.00 89.06 5,971,633.31 570,507.45 12,150.00 84.16 84.42 6,481.31 2,966.16 8,335.25 8,847.06 7.00 88.31 5,971,640.07 570,556.71 12,200.00 85.08 81.03 6,486.01 2,972.47 8,384.62 8,895.61 7.00 -75.00 5,971,646.78 570,606.02 12,300.00 86.95 74.27 6,492.96 2,993.80 8,482.00 8,994.41 7.00 -74.68 5,971,668.91 570,703.22 12,400.00 88.88 67.53 6,496.60 3,026.48 8,576.38 9,094.27 7.00 -74.21 5,971,702.37 570,797.31 12,500.00 90.81 60.81 6,496.87 3,070.02 8,666.33 9,193.69 7.00 -73.97 5,971,746.65 570,886.89 12,550.00 91.78 57.44 6,495.74 3,095.67 8,709.23 9,242.78 7.00 -73.95 5,971,772.66 570,929.57 12,600.00 91.96 60.94 6,494.11 3,121.26 8,752.14 9,291.86 7.00 87.00 5,971,798.60 570,972.26 12,700.00 92.30 67.94 6,490.40 3,164.36 8,842.23 9,391.25 7.00 87.11 5,971,842.44 571,061.99 12,800.00 92.60 74.93 6,486.12 3,196.15 8,936.88 9,491.07 7.00 87.37 5,971,875.01 571,156.36 12,900.00 92.86 81.94 6,481.35 3,216.16 9,034.68 9,589.81 7.00 87.67 5,971,895.83 571,253.98 12,950.00 92.98 85.44 6,478.80 3,221.65 9,084.31 9,638.32 7.00 88.01 5,971,901.73 571,303.55 2/23/2022 2:35:54PM Page 4 COMPASS 5000.15 Build 91E Baker Hughes Fl CaaC0Phillips Planning Report Baker Hughes Database: EDT 15 Alaska Prod Company: NADConversion Project: Kuparuk River Unit_1 Site: Kuparuk 1C Pad Well: 1C-15 Wellbore: 1 C-15L2 Design: 1C-151-2 wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-15 Mean Sea Level 1C-151-1: @ 101.50usft (1C-151-1:) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) V) V) (usft) (usft) (usft) (usft) ('/100usft) V) (usft) (usft) 13,000.00 92.97 81.94 6,476.21 3,227.13 9,133.93 9,686.83 7.00 -90.00 5,971,907.63 571,353.12 13,100.00 92.93 74.93 6,471.05 3,247.15 9,231.70 9,785.55 7.00 -90.18 5,971,928.45 571,450.72 13,200.00 92.84 67.92 6,466.01 3,278.95 9,326.31 9,885.33 7.00 -90.54 5,971,961.03 571,545.05 TD Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 13,200.00 6,466.01 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,119.72 6,495.52 1,936.70 5,576.36 Tie -in -Point from 1C-15 9,125.00 6,500.27 1,937.48 5,578.52 KOP - Top of Whipstock 13,200.00 6,466.01 3,278.95 9,326.31 TD 2/23/2022 2:35:54PM Page 5 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Alaska Inc _Kuparuk Kuparuk River Unit _1 Kuparuk 1 C Pad 1 C-15 1 C-15L2 1 C-15L2 wp01 Anticollision Summary Report 23 February, 2022 Baker Hughes 5�1 Baker Hughes ConocoPhillips Anticollision Summary Report Baker Hughes Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit-1 Reference Site: Kuparuk 1C Pad Site Error: 0.00 usft Reference Well: 1C-15 Well Error: 0.00 usft Reference Wellbore 1C-151-2 Reference Design: 1C-151-2 wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-15 Mean Sea Level 1C-151-1: @ 101.50usft (1C-15L1:) True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Offset Datum Reference 1 C-151-2 wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,119.72 to 13,200.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 2/23/2022 From To (usft) (usft) Survey (Wellbore) Tool Name Description 121.20 9,119.72 1C-15 (lC-15) MWD OWSG OWSG MWD - Standard 9,119.72 13,200.00 1C-15L2 wp01 (1C-15L2) MWD OWSG OWSG MWD - Standard Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1C Pad 1C-14 - 1C-14 - 1C-14 11,434.64 10,750.00 468.66 458.66 46.866 CC, ES, SF, 10 ft. DISPNSA 1C-14 - 1C-14A- 1C-14A 12,566.72 11,900.00 396.07 386.07 39.607 CC, ES, SF, 10 ft. DISPNSA 1C-15 - 1C-15 - 1C-15 9,125.20 9,125.00 0.00 -101.74 0.000 Normal Operations, CC, ES, 1C-15 - 1C-15 - 1C-15 9,125.20 9,125.00 0.00 -0.99 0.000 Normal Operations, CC, ES, 1C-15 - 1C-151-1 - 1C-151-1 9,125.00 9,125.00 0.00 -470.25 0.000 Normal Operations, CC, ES, 1C-15 - 1C-151-1 - 1C-151-1 9,125.00 9,125.00 0.00 -1.44 0.002 Normal Operations, CC, ES, 1C-19 - 1C-191-1 - 1C-191-1 Out of range 1 C-20 - 1 C-20 - 1 C-20 Out of range 1 C-20 - 1 C-20 - 1 C-20 Out of range 1 C-20 - 1 C-20PB1 - 1 C-20PB1 Out of range 1 C-20 - 1 C-20PB1 - 1 C-20PB1 Out of range 1C-21 - 1C-21 - 1C-21 Out of range 1C-21 - 1C-21 - 1C-21 Out of range 1 C-21 - 1 C-21 L3 - 1 C-21 L3 Out of range 1 C-21 - 1 C-21 L3 - 1 C-21 L3 Out of range 1C-22 - 1C-22 - 1C-22 13,180.03 11,575.00 1,386.15 1,025.64 3.845 CC, ES, SF 1 C-23 - 1 C-23 - 1 C-23 12,350.00 11,325.00 2,239.94 1,602.46 3.514 CC 1 C-23 - 1 C-23 - 1 C-23 13,150.00 12,075.00 2,255.75 1,514.04 3.041 ES 1 C-23 - 1 C-23 - 1 C-23 13,200.00 12,250.00 2,272.81 1,518.63 3.014 SF 1C-23 - 1C-23A- 1C-23A 13,068.89 16,499.00 2,183.71 1,297.67 2.465 Normal Operations, CC, ES, 1C-23 - 1C-23AL1 - 1C-23AL1 12,350.00 11,325.00 2,239.94 1,571.86 3.353 CC 1C-23 - 1C-23AL1 - 1C-23AL1 13,150.00 12,075.00 2,255.75 1,478.08 2.901 Normal Operations, ES 1C-23 - 1C-23AL1 - 1C-23AL1 13,200.00 12,250.00 2,272.81 1,482.04 2.874 Normal Operations, SF 1C-23-1C-23AL2-1C-23AL2 12,350.00 11,325.00 2,239.94 1,571.86 3.353 CC 1C-23 - 1C-23AL2 - 1C-23AL2 13,150.00 12,075.00 2,255.75 1,478.08 2.901 Normal Operations, ES 1C-23 - 1C-23AL2 - 1C-23AL2 13,200.00 12,250.00 2,272.81 1,482.04 2.874 Normal Operations, SF 1C-23 - 1C-23AL2-01 - 1C-23AL2-01 12,350.00 11,325.00 2,239.94 1,571.86 3.353 CC 1C-23 - 1C-23AL2-01 - 1C-23AL2-01 13,150.00 12,075.00 2,255.75 1,478.08 2.901 Normal Operations, ES 1C-23 - 1C-23AL2-01 - 1C-23AL2-01 13,200.00 12,250.00 2,272.81 1,482.04 2.874 Normal Operations, SF 1C-23-1C-23AL2-02-1C-23AL2-02 12,350.00 11,325.00 2,239.94 1,571.86 3.353 CC 1C-23 - 1C-23AL2-02 - 1C-23AL2-02 13,150.00 12,075.00 2,255.75 1,478.08 2.901 Normal Operations, ES 1C-23-1C-23AL2-02-1C-23AL2-02 13,200.00 12,250.00 2,272.81 1,482.04 2.874 Normal Operations, SF 1 C-25 - 1 C-25 - 1 C-25 9,625.60 9,125.00 2,022.95 1,520.90 4.029 CC 1 C-25 - 1 C-25 - 1 C-25 9,650.00 9,250.00 2,026.70 1,515.30 3.963 ES CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/23/2022 2:50:04PM Page 2 COMPASS 5000.15 Build 91E Baker Hughes ConocoPhillips Anticollision Summary Report Baker Hughes Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit-1 Reference Site: Kuparuk 1C Pad Site Error: 0.00 usft Reference Well: 1C-15 Well Error: 0.00 usft Reference Wellbore 1C-151-2 Reference Design: 1C-151-2 wp01 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1C Pad 1 C-25 - 1 C-25 - 1 C-25 1 C-25 - 1 C-25L1 - 1 C-25L1 1 C-26 - 1 C-26 - 1 C-26 1 C-26 - 1 C-26 - 1 C-26 1 C-26 - 1 C-26 - 1 C-26 1 C-27 - 1 C-27 - 1 C-27 1 C-27 - 1 C-27 - 1 C-27 1 C-27 - 1 C-27 - 1 C-27 1 C-28 - 1 C-28 - 1 C-28 1 C-28 - 1 C-28 - 1 C-28 1 C-28 - 1 C-28 - 1 C-28 1 C-28 - 1 C-28L1 - 1 C-28L1 1 C-28 - 1 C-28L1 - 1 C-28L1 1 C-28 - 1 C-28L1 - 1 C-28L1 1C-28 - 1C-28PB1 - 1C-28PB1 1C-28 - 1C-28PB1 - 1C-28PB1 1C-28 - 1C-28PB1 - 1C-28PB1 Kuparuk W.Sak W SAK 24 - W SAK 24 - W SAK 24 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-15 Mean Sea Level 1C-151-1: @ 101.50usft (1C-151-1:) True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Offset Datum Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 9,700.00 9,475.00 2,049.50 1,524.81 3.906 SF 9,550.00 10,975.00 1,500.53 954.15 2.746 Normal Operations, CC, ES, 9,700.00 9,150.00 2,389.95 1,885.12 9,740.00 9,325.00 2,396.52 1,879.96 10,450.00 9,950.00 2,528.03 1,949.83 12,918.71 7,050.00 787.31 320.35 Out of range Out of range Out of range 4.734 CC 4.639 ES 4.372 SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 1.686 Normal Operations, CC, ES, CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/23/2022 2:50:04PM Page 3 COMPASS 5000.15 Build 91E `, Baker Hughes ConocoPhillips Anticollision Summary Report Baker Hughes 5�t Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: ConocoPhillips Alaska Inc Kuparuk Kuparuk River Unit-1 Kuparuk 1C Pad 0.00 usft 1C-15 0.00 usft 1C-15L2 1C-151-2 wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-15 Mean Sea Level 1C-151-1: @ 101.50usft (1C-151-1:) True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Offset Datum Reference Depths are relative to 1C-15L1: @ 101.50usft (1C-15L1:) Coordinates are relative to: 1C-15 Dffset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4 entral Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: 0.47' Ladder Plot 3600 ------------------------------------------ ---------------- 2700 m 1800 0 900 ------------------------------------ - - - - ----- - - - - -- 0 0 2500 5000 7500 10000 12500 15000 Measured Depth LEGEND iC-23, iC-23AL2, iC-23AL2 V0 —4li 1C-22, iC-22, 1-2- 5 = iC-15, iC-i5L1, iC-15Li V1 1C-23A -' 1C-23AL2o1 V0 + 1C- ..1C-25,1 -25V0 1C-15, 1C-15, 1C-15V0 1C-23, 1C-23,1C-23V2 � 1C-,,1C-25L1, 1C-25L1 V1 11111, 11111, W 1111 V5 iC-23, 1C-23A, 1C-YfA VO 1C-14, IC-14, 1C-14 V1 1 -15, iC-15, 1C- - 1C-23, 1C33AL2-02, 1C-AL202 V0 1C-14, iG14A, 1C-14A V 1 1C-15, —15L1, iC-15L1 V 1 iC-P3, 1-23AL1, 1C-1 V0 i-7, 1C- . 1421 V1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/23/2022 2:50:04PM Page 4 COMPASS 5000.15 Build 91E `, Baker Hughes ConocoPhillips Anticollision Summary Report Baker Hughes 5�t Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: ConocoPhillips Alaska Inc Kuparuk Kuparuk River Unit-1 Kuparuk 1C Pad 0.00 usft 1C-15 0.00 usft 1C-15L2 1C-151-2 wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-15 Mean Sea Level 1C-151-1: @ 101.50usft (1C-151-1:) True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Offset Datum Reference Depths are relative to 1C-151-1: @ 101.50usft (1C-151-1:) Coordinates are relative to: 1C-15 Dffset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4 central Meridian is 150° 0' 0.000 W Grid Convergence at Surface is: 0.47° Separation Factor Plot 9.00 i CO 6.00— LL co N Normal Operations 3.00 Caution - Monitor Closely Take Immediate Action i STOP Drilling 0.00 0 2500 5000 7500 10000 12500 Measured Depth LEGEND 1—.1-23AL2, 1c-2:V1L2VO —0— 1 -22,1 -22,1 -22V5 :r iC-15. 1C- 0.1C-15L1 V1 ♦� 1C-23.1-23-1.1-23AL201 VO + 1C-25,1-5,1C-25V0 �� iC-15. 1C-15.1 -15Vo 1C-23, iC-23,1C-23V2 x 1C-25, iC-25L1, 1-1 V1 WSAK 2A,WSAK 26,W SAK26 V5 i Ic-23A, 1C-23A Vo 1 - 4, 1C-14, 10-14 V1 1`151 iC-151 iC-15 Vo 1 C-23, 1C-23AL2U1, 1C-23AL202 VO iC-14, 1C-14A, 1C-14A V1 1C-15. 1C-15L1, 1C-15L1 V1 1C-23AL1, 1-1 VO iC-Z!, 1 -2], 1-1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 212312022 2:50:04PM Page 5 COMPASS 5000.15 Build 91E KUP INJ WELLNAME 1C-15 WELLBORE 1C-15 ConocoPhillips Alaska, Ino. ... Well Attributes Max Angle & MD TD Field Name Wellbore API/UWI Wellbore Status KUPARUK RIVER UNIT 500292293200 INJ I cl (°) 2.92 MD (ftKB) 2,783.33 Act Bim (ftKB) 9,390.0 Comment H2S (ppm) Date Annotation End Date SSSV: LOCKED OUT Last WO: KB-Grd (ft) 46.51 Rig Release Data 12/15/1998 1C-15, 2/4/2022 6:16:42 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Dale Wellbore Last Mod By HANGER; 36.E CONDUCTOR; 47.0-121.0 SAFETY VLV; 2,019.3 GAS LIFT; 3,324.9 GAS LIFT; 5,349.2 SURFACE; 40.4-6,249.3- GAS LIFT; 6,592.1 GAS LIFT; 7,553.E GAS LIFT; 8,330.E1 NIPPLE; 8,876.2 PACKER; 8,919.3 NIPPLE; 8,964.5 SOS; 8,975.E APERF; 9,096.0-9,106.0 IPERF; 9,106.0-9,126.0 FRAC; 9:096.0 APERF; 9,126.0-9,141.0 Kickoff Plug; 9,141.0 ftKB LINER; 8,845.3-11,111.0 4" WINDOW u; 9,142.0-9,147.0 PRODUCTION; 38.5-9,392.7 Last Tag: SLIM 9,320.0 12/7/2011 1C-15 Ininam Last Rev Reason Annotation End Date Wellbore Last Moday Rev Reason: DRILL DATES/DEPTHS 3/12/2013 1C-15 bwolthil Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) Set Depth (ftKB) 41.0 121.0 Set Depth (TVD)... 121.0 WVLen (I... Grade 62.58 H-40 Top Thread WELDED Casing Description SURFACE OD (in) 95/8 ID (in) 8.83 Top IRKS) Set Depth (ftKB) 40.4 6,249.3 Set Depth (TVD)... 4,488.5 WtlLen (I... Grade 40.00 L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) Set Depth (ftKB) 38.5 9,392.7 Set Depth (TVD)... WtlLen (I... Grade 26.00 L-80 Top Thread ABM-BTC Casing Description WINDOW L1 OD (in) 7 ID (in) 6.00 Top IRKS) Set Depth (ftKB) 9,142.0 9,147.0 Set Depth (TVD)... 6,621.5 WtlLen (I... Grade 26.00 L-80 Top Thread Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wl (lb/ft) Grade Top Connection TUBING 31/2 2.99 36.6 8,976.5 6,468.1 9.30 L-80 ABM-EUE Completion Details Top IRKS) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model Corn 36.6 36.6 0.00 HANGER 3.500 8.000 FMC HANGER GEN IV TUBING 2,019.3 1,796.2 49.18 SAFETY VLV 2.812 5.250 CAMCO SAFETY OUT 7/16/2004) TRDP-4E VALVE (LOCKED 3,324.9 2,602.4 51.58 GAS LIFT 2.920 5.500 CAMCO KBMM 5,349.2 3,907.5 50.32 GAS LIFT 2.920 5.500 CAMCO KBMM 6,592.1 4,709.3 49.76 GAS LIFT 2.920 5.500 CAMCO KBMM 7,553.6 5,339.8 48.22 GAS LIFT 2.920 5.500 CAMCO KBMM 8,330.6 5,905.9 35.35 GAS LIFT 2.920 5.500 CAMCO KBMM 8,826.5 6,333.3 26.13 GAS LIFT 2.371 5.500 CAMCO MMM 8,876.2 6,377.9 26.07 NIPPLE 2.812 4.540 CAMCO W NIPPLE 8,919.3 6,416.7 26.08 PACKER 3.875 5.968 BAKER PACKER S-3 PERMANENT 8,964.5 6,457.3 25.98 NIPPLE 2.800 4.470 CAMCO ID - MILLED ID 2/5/2003 D NIPPLE 2.75" OUT TO 2.80" 8,975.6 6,467.3 25.94 SOS 3.000 4.520 BAKER SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (ND) Top (ftKB) Incl V) Des Corn Run Date ID (in) SN El PATCH SURF CSG PATCH install from bottom of starter head to top of pup collar 1' 11.5", used 9 5/8" 40 #, .395 pipe for patch material 4/10/2009 Mandrel Inserts at at! on N Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (In) Sam Valve Type Latch Port Type Sin (in) TRO Run (psi) Run Date Com 1 3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 2 5,349.2 3,907.5 50.32 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 3 6,592.1 4,709.3 49.76 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 4 7,553.6 5,339.8 48.22 1 GAS LIFT DMY BK 0.000 0.0 7/16/2004 5 8,330.E 5,905.9 35.35 1 GAS LIFT DMY BK-5 0.000 0.0 2/12/2003 6 8,826.5 6,333.3 26.13 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/16/2004 Perforations & Slots Top (ftKB) Bt. (ftKB) Top (ND) (ftKB) Sim (ND) (ftKB) Linked Zone Date Shot Dens (shots/ft ) Type Com 9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD phase PJ Chgs, 60 deg 9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IERF 2.5" HC DP 9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD phase PJ Chgs, 60 deg Stimulation Intervals Interva I Numbs r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed lb) Proppanl Vol Total lb) Total Clean (bbl) Vol Slurry Total (bb0 1 FRAC 1/11/1999 1 9,096.0 9,142.0 0.0 0.00 0.00 Cement Squeezes Top (kKB) St. (ftKB) Top (ND) Btm (ftKB) (TVD) (ftK B) Des Com Pump Start Date 9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141 rkb 3/28/2003 Notes: General & Safety End Date Annotation 11/17/2010 NOTE: View Schematic w/Alaska Schematic9.0 4/15/2003 NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-151-1 KUP INJ WELLNAME 1C-15 WELLBORE 1C-15L1 ConocoPhillips Alaska, InC. Well Attributes Max Angle & MD TD Field Name Wellbore API/UWI Wellbore Status KUPARUK RIVER UNIT 500292293260 INJ I cl (°) 04.79 MD (ftKB) 10,640"9 Act 07. (ftKB) 11,207.0 Comment H2S (ppm) Date Annotation End Data KB-Grd (ft) Rig Release Data SSSV: LOCKED OUT Last WO: 4/13/2003 46.51 12/15/1998 1 C-15L1, 2/4/2022 6:17:00 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Dale Wellbore Last Mod By Last Tag: SLM 9,348.0 6/28/2019 iC-15L1 hazenmc Last Rev Reason HANGER; 36 6 Annotation End Date Wellbore Lest Motl By Rev Reason: CUT LINER 2/4/2022 1C-15L1 bworthi1 Casing Strings Casing Description OD (in) ID (in) TOP (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread LINER 2.38 1.92 8,845.3 11,111.0 6,638.0 4.43 L-80 STL I Liner Details CONDUCTOR; 41.0-121.0 Top (ftKB) Top (TVD) (ftKB) Top Intl (°) Item Des Co. Nominal ID (in) 8, 45.31 6,350.2 26.05 DEPLOY I BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 11,072.7 6,640.6 93.39 1 O-RING I BAKER O-RING SUB 1.000 SAFETY VLV; 2,019.3 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (Top TVD) Top Intl I Q11 (ftKB) (ftKB) (°) Des Co. Run Data S 9,150.0 6,624.3 23.04 CUT CUT LINER WITH CHEMICAL CUTTER 2/4/2022 1.920 GAS LIFT; 3,324.9 Perforations & Slots Shot Den Top (TVD) Btm (TVD) (shots/ft GAS LIFT; 5,349.2 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com 10,344.0 11,075.0 6,675.0 6,640.5 C-3, C-4, C-3, 4/12/2003 4.0 SLOTS SLOTTED LINER 'IC-15L1 Notes: General & Safety End Date Annotation 4/15/2003 NOTE: (Multi-Lat) 1C-151-1 DRILLED 411512003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE 1C-15 CMT PLUG SURFACE; 40.4-6,249.3- 4/15/2003 NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS GAS LIFT; 6,592.1 GAS LIFT; 7,553.E GAS LIFT; 8,330.E NIPPLE; 8,876.2 PACKER; 8,919.3 NIPPLE; 8,964.5 SOS; 8,975.E APERF; 9,096.0-9,106.0 IPERF; 9,106.0-9,126.0 FRAC; 9,096.0 APERF; 9,126.0-9,141.0 Kickoff Plug; 9,141.0 ftKB PRODUCTION; 38.5-9,392.7 CUT; 9,150.0 SLOTS; 10,344.0-11,075.0 LINER; 8,845.3-11,111.0 1 C-15L2 Proposed CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 6249' MD KOP@9125'MD via 7" HEW C-sand perfs 9096' - 9141' MD ITOC @ 9142' MD 7" 26# L-80 shoe @ 9393' MD 3-1/2" Camco TRDP-4E SSSV @ 2019' MD (locked out) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrel at 3325', 5349', 6592', 7554', 8331', 8827' MD Camco 3-1/2" W-Nipple @ 8876' MD Baker S-3 packer at 8919' MD (3.875" ID) D-nipple at 8965' MD (2.80" min ID, milled out 2003) Baker SOS @ 8976' MD 1 C-15L2 wp01 TD @ 13,200' MD Top of Liner —8950' MD 1 C-15L1 TD @ 11,206' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: KRU 1 C-15L2 PTD: 222-029 Development —X Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Kuparuk River POOL: Kuparuk River Oil Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit X LATERAL No. 198-229 , API No. 50-029-22932-00-00 (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both Pilot Hole well name ( PH) and API number (50- ) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of Exception a conservation order approving a spacing exception. ( ) as Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non- well ( ) until after ( ) Conventional has designed and implemented a water well testing program to provide Well baseline data on water quality and quantity. ( ) must contact the AOGCC to obtain advance approval of such water well testing program. 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 X by ( ) in the attached application, the following well logs are also required for this well: Well Logging Requirements 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 X within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1C-15L2 Program SER Well bore seg ❑d PTD#: 2220290 Company ConocoPhillips Alaska, Inc. Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate - - - - Yes 3 Unique well -name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes 4 Well locatedina_definedpool--------------------------------------- Yes--------------------------------------------------------------------------- 5 Well located proper distance_from_drilling unit boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 Well located proper distance_ from other wells_ Yes 7 Sufficient acreage available in drilling unit - - - - - Yes 8 If_deviated,is_wellbo_replat-included ----------------------------- Yes 9 Operator only affected party----------------------------------------Yes --------------------------------------------------------------------------- 10 Operator has appropriate -bond in force- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit can be issued without conservation order --------------------------------------------------------------------------------------------------------------------------------------- Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day_wait _ - - - Yes DLB 3/10/2022 14 Well located within area and strata authorized by_Iniection Order # (put_IO# in comments)_(For_ Yes _ _ _ _ _ _ _ Area Injection Order No._2C_- Kuparuk River Unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells within 1/4_mile area of review identified (For_service well only_) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre -produced injector; duration of pre -production less-than-3- months_(For service well_only) _ _ Yes _ _ _ _ _ _ _ KRU 1C-151-2 well will -not bepre-produced_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) - - - - - - - - - - - - - - - - NA_ 18 Conductor string_provided-----------------------------------------NA --------------------------------------------------------------------------- Engineering 19 Surface casing protects all known_ USDWs NA_ 20 CMT_vol adequate to circulate on conductor & surf csg - - - - - NA_ 21 CMT_vol_adequate_to tie-in long string to surf_ csg_ - - NA_ 22 C_M_T_will_ cover all known productive horizons - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - - - - - - - Prod uctiv_e interval will be completed with uncemented sl_otted_liner_ - - - - - - - - - - - - - - - - - - - - - - - 23 Casing designs adequate for C, T, B & permafrost Yes- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage or reserve pit Yes _ _ _ _ _ _ _ Rig has steel tanks; all waste to approved disposal wells_ _ _ _ _ 25 If -a -re -drill, has a 10-403 for abandonment been approved NA_ 26 Adequate wellbore separation proposed - - - - - Yes Anti collision_ analysis complete, no major risk failures 27 If diverter required, does it _meet regulations NA_ Appr Date 28 Drilling.fluid_program schematic A- equip list adequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Max formation_pressure is_3943 psig(14,8 ppg EMW); will drill_w/ 8.6_ppg and maintain overbal w/ MPD VTL 3/11 /2022 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BOPE_- press - rating appropriate; test to (put prig in comments)_ Yes MPSP is 3283_psg; will test BOPE to 4000_psig_ - - - - 31 Choke -manifold complies w/API_RP-53 (May 84)_ Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 112S gas- probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ 1 C-14, 1 C-22,_1 C-23, 1 C-25 in AOR_ _ _ _ _ _ _ _ _ 35 Permit can be issued w/o_hydrogen_sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Wells -on 1C=Pad are_H2S-bearing. 112S. measures required. Geology 36 Data -presented on potential overpressure zones - - Yes ------------------ Appr Date 37 Seismic analysis_of shallow gas zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - DLB 3/10/2022 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ 39 Contact name/phone for weekly_progress reports_[explOratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geologic Engineering Public Commissioner: Date: Commissioner: Date Cora iQn r Date JLC 3/11/2022 J S/�1/22