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191-124
191-124 T38906 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:56:58 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7725'feet None feet true vertical 6705' feet 7410', 7425' feet Effective Depth measured 7522'feet 7075', 7377'feet true vertical 6534' feet 6152', 6410' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7399' MD 6430' TVD Packers and SSSV (type, measured and true vertical depth)7075' MD 7377' MD N/A 6152' TVD 6410' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 915 mcf Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Rtvbl Packer Packer: Camco HRDP-1-SP Retrvbl Packer SSSV: None Jill Simek jill.simek@conocophillips.com (907) 263-4131Staff Well Interventions Engineer 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) 154 BOPD Gas-Mcf MD 1235 Size 123' 515 BWPD 1265706 mcf 144 BOPD 169482 BWPD 154 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-124 50-029-22219-00-00 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: ADL0025512, ADL0373301 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3Q-04 Plugs Junk measured Length Production Liner 7700' Casing 6701'7716' 4475' 123'Conductor Surface Intermediate 16" 9-5/8" 82' 4518' 3955' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 7475-7495', 7498-7538' 6494-6511', 6514-6548' By Grace Christianson at 10:39 am, Mar 21, 2024 Jill Simek Digitally signed by Jill Simek Date: 2024.03.21 10:20:09 -08'00' DSR-3/21/24 RBDMS JSB 032824 DTTMSTART JOBTYP SUMMARYOPS 12/24/2023 REPAIR WELL DRIFT TUBING W/ 10' 2.5'' DRIFT, FOR 2- 1/8'' DUMMY GUN DRIFT TAG BTM 7522' RKB. READY FOR E-LINE OR FCO. 2/11/2024 MAINTAIN WELL FREEZE PROTECT TBG & FLOWLINE FROM MANIFOLD BUILDING WITH 20 BBLS DSL FOLLOWED BY 8 BBLS METH. WELL READY FOR E- LINE 2/17/2024 MAINTAIN WELL FREEZE PROTECT TBG & FLOWLINE FROM MANIFOLD BUILDING WITH 20 BBLS DSL FOLLOWED BY 8 BBLS METH. WELL READY FOR E- LINE 2/18/2024 REPAIR WELL RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WEIGHTS, 1-11/16" GR/CCL TAG BOTTOM @ 7514' PDC. RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WEIGHTS, 1-11/16" JARS, 2- 1/8" CCL, STRIP GUN (LOADED 10' W/ OWEN 13.9 GRAM, 2.125" STP CHARGES), PERFORATE FROM 7504'-7514', CCL-TS = 2.3', CCL STOP = 7501.7', CORRELATE TO SLB CEMENT EVAQL LOG DATED 1-FEB-1992. RD FOR DARK VISION LOG ON 3S-624. JOB IN PROGRESS. 2/24/2024 REPAIR WELL CONTINUE JOB FROM 2/18/24. PERFORATE 7498'-7504', CCL TO TOP-SHOT = 2.3', CCL STOP = 7495.7'. PERFORATE 7485'-7495', CCL TO TOP-SHOT = 2.6', CCL STOP = 7482.4'. CORRELATE TO SLB CEMENT EVAL LOG DATED 1-FEB-1992. WELL LEFT SHUT IN, FUSIBLE CAP REMOVED, JOB IN PROGRESS. 2/25/2024 REPAIR WELL CONTINUE JOB FROM 2/24/24. PERFORATE 7475'-7485', CCL TO TOP-SHOT = 2.6', CCL STOP = 7472.4'. CORRELATE TO SLB CEMENT EVAL LOG DATED 1-FEB-1992. WELL LEFT SHUT IN, FUSIBLE CAP REMOVED, JOB COMPLETE. 3Q-04 Perforations Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,522.0 3Q-04 12/24/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Re-Perf Intervals 3Q-04 2/25/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: LEFT SPRING TO GA-2 RUNNING TOOL IN WELL 10/20/2013 lehallf 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 41.0 123.0 123.0 62.50 H-40 SURFACE 9 5/8 8.83 42.2 4,517.7 3,955.1 36.00 J-55 BTC PRODUCTION 7 6.28 15.7 7,716.0 6,701.5 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.9 Set Depth … 6,425.7 Set Depth … 5,588.0 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.9 37.9 0.11 Hanger 6.930 McEvoy Gen IV Tubing Hanger Camero n Gen IV 2.950 558.3 558.2 2.39 Nipple - DS 4.470 3-1/2" x 2.875" DS-Nipple SN# D021910 SLB DS Nipple 2.875 2,780.0 2,517.5 33.58 Mandrel 5.695 3-1/2" x 1 1/2" MMG, EUE 8RD SN# 032AJ07 SLB Camco MMG 2.925 4,225.0 3,715.0 35.21 Mandrel 5.698 3-1/2" x 1 1/2" MMG, EUE 8RD SN# 036AJ07 SLB Camco MMG 2.925 5,545.0 4,819.8 30.16 Mandrel 5.698 3-1/2" x 1 1/2" MMG, EUE 8RD SN# 012AJ07 SLB Camco MMG 2.925 6,266.2 5,449.1 29.30 Mandrel 5.698 3-1/2" x 1 1/2" MMG, EUE 8RD SN# 033AJ07 SLB Camco MMG 2.925 6,327.0 5,502.0 29.43 Locator 4.510 80-40 Seal Locator 2.920 6,327.7 5,502.6 29.43 Seal Assembly 4.000 80-40 Seal Assembly (11.83' seal length. 1.88' from fully located) Baker 80-40 Seal Assembl y 2.990 6,329.6 5,504.3 29.43 PBR (Polished Bore Receptacle) 5.860 80-40 Polish Bore Reciprocal Baker 80-40 Seal Assembl y 4.000 6,419.0 5,582.2 29.55 Overshot 5.980 3.5" Non-Sealing Overshot (4.92' barrel. 1.43' from fully located) Baker Poorboy Oversho t 3.600 6,425.7 5,588.0 29.56 5.980 Top (ftKB) 6,422.2 Set Depth … 7,052.4 Set Depth … 6,131.8 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,990.0 6,078.0 30.40 GAS LIFT 5.968 CAMCO MMG GLM . SR# SBG- 8158 CAMCO MMG 2.925 7,045.2 6,125.6 30.45 LOCATOR 4.520 BAKER LOCATOR SUB 2.990 Top (ftKB) 7,052.4 Set Depth … 7,370.7 Set Depth … 6,405.2 String Max No… 3 1/2 Tubing Description STACKER PACKER Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,052.4 6,131.8 30.45 PBR 5.880 BAKER 80-40 PBR BAKER 80-40 4.000 7,075.5 6,151.7 30.46 PACKER 5.970 BAKER FHL RETRIEVABLE PACKER 47B2 SHEAR 60K BAKER FHL RETRIE VABLE 2.950 7,097.3 6,170.4 30.48 NIPPLE 3.500 CAMERON DS NIPPLE 2.812" CAMER ON 2.812 7,360.5 6,396.4 31.21 LOCATOR 5.500 BAKER NO GO LOCATOR SUB BAKER 2.992 7,361.3 6,397.1 31.21 SHOE 3.500 BAKER MULE SHOE BAKER 2.992 Top (ftKB) 7,363.4 Set Depth … 7,399.5 Set Depth … 6,429.8 String Max No… 5 5/8 Tubing Description TUBING - original Wt (lb/ft) Grade Top Connection ID (in) 2.94 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,363.4 6,398.9 31.21 PBR 5.625 CAMCO PBR, 10' stroke, 5.625" OD Bbl, 2.937" ID (30K# Shear) CAMCO 2.937 7,376.8 6,410.4 31.24 PACKER 5.937 CAMCO 'HRP-1-SP' Retr. Pkr, 60K# pull or rot. release, 5.937"OD, 2.867"ID CAMCO HRP-1- SP 2.867 7,391.2 6,422.7 31.26 NIPPLE 4.500 CAMCO 'D' Nipple w/ 2.75" packing bore. CAMCO D 2.750 7,398.8 6,429.2 31.27 SOS 3.500 CAMCO PE-500 Shearout Sub CAMCO 2.992 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) 6,422.2 5,584.9 29.56 CUT Welltec Mechanical Tbg Cut 12/8/2021 2.992 7,135.0 6,202.9 30.56 Tubing Punch Tubing Punch, 2' of 4 SPF 7/10/2019 2.990 7,410.0 6,438.8 31.27 FISH Spring to GA-2 Running Tool 10/20/2013 0.000 3Q-04, 3/18/2024 10:12:57 AM Vertical schematic (actual) PRODUCTION; 15.7-7,716.0 IPERF; 7,498.0-7,538.0 RPERF; 7,498.0-7,514.0 IPERF; 7,483.0-7,495.0 RPERF; 7,475.0-7,495.0 IPERF; 7,475.0-7,483.0 FISH; 7,425.0 FISH; 7,410.0 PACKER; 7,376.8 Tubing Punch; 7,135.0 Cement Squeeze; 7,082.9 ftKB NIPPLE; 7,097.2 PACKER; 7,075.5 CMT SQZ; 7,040.0-7,044.0 GAS LIFT; 6,990.0 Cement Squeeze; 6,810.0 ftKB CUT; 6,422.2 Packer (Tubing); 6,359.0 Mandrel; 6,266.2 Mandrel; 5,544.9 SURFACE; 42.2-4,517.7 Mandrel; 4,225.0 Mandrel; 2,780.0 Nipple - DS; 558.3 CONDUCTOR; 41.0-123.0 Hanger; 37.9 KUP PROD KB-Grd (ft) 40.99 RR Date 1/19/1992 Other Elev… 3Q-04 ... TD Act Btm (ftKB) 7,725.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292221900 Wellbore Status PROD Max Angle & MD Incl (°) 39.76 MD (ftKB) 2,300.00 WELLNAME WELLBORE3Q-04 Annotation Last WO: End Date 2/22/2022 H2S (ppm) 230 Date 2/1/2019 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,425.0 6,451.6 31.27 FISH 100% of Cups Left in Well Removed Tree Saver 4/26/1997 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,780.0 2,517.5 33.58 1 GLV RK 1 1/2 1,265.0 3/3/2022 Camco MMG 0.188 4,225.0 3,715.0 35.21 2 GLV RK 1 1/2 1,259.0 3/3/2022 Camco MMG 0.188 5,545.0 4,819.8 30.16 3 OV RK 1 1/2 0.0 3/3/2022 Camco MMG 0.250 6,266.2 5,449.1 29.30 4 DMY RK 1 1/2 0.0 3/4/2022 Camco MMG 0.000 6,990.0 6,078.0 30.40 5 DMY RK 1 1/2 4/17/2019 Camco MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,040.0 7,044.0 6,121.1 6,124.5 9/26/2019 4.0 CMT SQZ 1 9/16" Tubing Punch. 4SPF, 0 deg Phasing 7,475.0 7,483.0 6,494.3 6,501.2 C-1, A-2, 3Q-04 2/13/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing 7,475.0 7,495.0 6,494.3 6,511.4 C-1, 3Q-04 2/25/2024 6.0 RPERF 13.9 G, 6 SPF, 40 DEG PHASE, STRIP GUN 7,483.0 7,495.0 6,501.2 6,511.4 C-1, A-2, 3Q-04 2/13/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing 7,498.0 7,538.0 6,514.0 6,548.2 A-1, 3Q-04 2/13/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing 7,498.0 7,514.0 6,514.0 6,527.7 A-1, 3Q-04 2/24/2024 6.0 RPERF 13.9 G, 6 SPF, 40 DEG PHASE, STRIP GUN Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,810.0 7,075.0 5,922.3 6,151.2 Cement Squeeze 7/17/2019 7,082.9 7,139.0 6,158.1 6,206.4 Cement Squeeze 7/17/2019 3Q-04, 3/18/2024 10:12:57 AM Vertical schematic (actual) PRODUCTION; 15.7-7,716.0 IPERF; 7,498.0-7,538.0 RPERF; 7,498.0-7,514.0 IPERF; 7,483.0-7,495.0 RPERF; 7,475.0-7,495.0 IPERF; 7,475.0-7,483.0 FISH; 7,425.0 FISH; 7,410.0 PACKER; 7,376.8 Tubing Punch; 7,135.0 Cement Squeeze; 7,082.9 ftKB NIPPLE; 7,097.2 PACKER; 7,075.5 CMT SQZ; 7,040.0-7,044.0 GAS LIFT; 6,990.0 Cement Squeeze; 6,810.0 ftKB CUT; 6,422.2 Packer (Tubing); 6,359.0 Mandrel; 6,266.2 Mandrel; 5,544.9 SURFACE; 42.2-4,517.7 Mandrel; 4,225.0 Mandrel; 2,780.0 Nipple - DS; 558.3 CONDUCTOR; 41.0-123.0 Hanger; 37.9 KUP PROD 3Q-04 ... WELLNAME WELLBORE3Q-04 Originated: Delivered to:8-Apr-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-15 50-029-22932-00 907743115 Kuparuk River Multi Finger Caliper Field & Processed 16-Mar-22 0 12 1E-31 50-029-22791-00 907676477 Kuparuk River Packer Setting Record Field- Final 14-Feb-22 0 13 1L-29 50-029-22157-00 907706865 Kuparuk River Plug Setting Record Field- Final 25-Feb-22 0 14 1L-29 50-029-22157-00 n/a Kuparuk River Jet Cut Record Field- Final 14-Nov-21 0 15 2W-09 50-029-21235-00 907723402 Kuparuk River Multi Finger Caliper Field & Processed 1-Mar-22 0 16 2W-09 50-029-21235-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-22 0 17 3B-02 50-029-21319-00 907705186 Kuparuk River Injection Profile Field- Final 23-Feb-22 0 18 3M-05 50-029-21706-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 23-Jan-22 0 19 3Q-04 50-029-22219-00 n/a Kuparuk River Plug Setting Record Field- Final 20-Feb-22 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:191-124T3646293Q-0450-029-22219-00Meredith GuhlDigitally signed by Meredith Guhl Date: 2022.04.08 10:39:17 -08'00' ! 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,725 feet None feet true vertical 6,709 feet None feet Effective Depth measured 7,630 feet 7076, 7377 feet true vertical 6,627 feet 6152, 6410 feet Perforation depth: Tubing (size, grade, measured and true vertical depth)3.5 ''L-80 7,400' MD 6,430' TVD Packers and SSSV (type, measured and true vertical depth) 7,076' MD 6,152' TVD 7,377' MD 6,410' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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 GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name:Jill Simek Authorized Title: Staff Wells Engineer Contact Email:Jill.Simek@cop.com Contact Phone:(907) 263-4131 Authorized Name: Jill Simek Authorized Signature with date: Senior Engineer: Senior Res. Engineer: 7040-7044, 7475-7483, 7483-7495, 7498-7538 feet 6121-6124, 6494-6501, 6501-6511, 6514-6548 feet Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-408/319-268 øø ø 1291 1277 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure øø ø 2098 2150 IA CEMENT PACKER REPAIR - 6700' KB - 7135' KB 16 bbls of 15.8ppg CLASS "G " cement pumped, final T/I/O=950/1500/364psi Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: SSSV - NONE PACKER - BAKER FHL RETRIEVABLE PKR PACKER - CAMCO 'HRP-1-SP' RETR. PKR CONDUCTOR 82 feet 16 '' 123' MD 123' TVD PRODUCTION 7,700 feet 7 '' 7,716' MD 6701' TVD SURFACE 4,476 feet 9 5/8 ''4,518' MD 3955' TVD Packer measured true vertical Casing Length Size MD TVD NONE Kuparuk River Field / Kuparuk River Oil Pool Plugs measured Junk measured Burst Collapse 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-029-22219-00 8. Well Name and Number:KRU 3Q-04ADL 25512, ADL 373301 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 191-124 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:31 pm, Jun 09, 2020 Jill Simek Digitally signed by Jill Simek Date: 2020.06.09 13:28:06 -08'00' SFD 6/10/2020DSR-6/9/2020 RBDMS HEW 6/10/2020 VTL 7/27/20 SUNDRY NOTICE 10-404 ConocoPhillips Well 3Q-04 Sundry #319-408 June 8, 2020 On September 26, 2019, operations commenced for a cement packer repair attempt on 3Q-04. Tubing was punched at 7,040-7,044ft KB, per approved procedure; however, circulation could not be achieved for the cement repair. A cement bond log was run, which showed cement in the IA, left from the previous repair attempt (Sundry #319-268; work performed July 2019). Further review of the cement bond log determined top of cement in the IA to be approximately 6,450ft KB, above the planned cement circulation point. Based on the cement bond log, permission was granted from the AOGCC (email dated December 10, 2019) to attempt the cement repair at a shallower depth than originally planned, moving the cement circulation point from 7,044ft KB to 6,415ft KB. Permission was also granted to mill out the cement and cement retainer left in the tubing from the previous repair attempt, and pull the RBP at 7,160ft KB. On December 24, 2020 an IA pressure increase was noted and reported to the AOGCC. Once milling was completed, and RBP pulled, a new RBP was run to 7,391ft KB to secure the well. Two tubing and IA circ-outs have followed for IA pressure management: 200 bbls of 9.8 ppg brine / 40 bbls diesel circulated on March 1, 2020 and 163 bbls 12.7 ppg potassium formate / 54 bbls diesel circulated on April 29, 2020. Current wellhead pressures are T/I/O = 1277/1291/100 psi (June 4, 2020). Due to work scope change and increased repair complexity, ConocoPhillips has chosen to suspend further cement packer repair activities and evaluate the well for a rig workover. With this notification, please consider Sundry #319-408 closed. A new sundry application will be submitted for future repair. The field Well Service Report for activities performed is attached, along with current well schematic. Start Date Last 24hr Sum 4/29/2020 CIRC OUT PUMPED 5 BBLS MEOH DOWN TUBING PUMPED 163 BBLS 12.7 PPG K-FORMATE DOWN TUBING TAKING RETURNS FROM IA. PUMPED 5 BBLS MEOH DOWN TUBING PUMPED 54 BBLS DIESEL DOWN TUBING U-TUBE FOR 45 MINUTES JOB COMPLETE 4/29/2020 PULL DMY @ 6222' RKB. LEAVE POCKET OPEN. READY FOR CIRC OUT, IN PROGRESS. 3/30/2020 (AC EVAL) IA DDT (FAILED) MONITOR IA FOR BUR (IN PROGRESS) 3/6/2020 (PRE RWO) FT LDS/GN's (COMPLETE), T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), MIT-OA TO 1820 PSI (PASSED). 3/1/2020 MIT-TUBING TO 3000 PSI (PASSED) DDT-TUBING TO 1000 PSI (PASSED) MIT-IA TO 2500 PSI (PASSED) JOB COMPLETE 3/1/2020 LRS PERFORM CIRC-OUT 200 BBLS 9.8 BRINE DWN IA & UP THE TUBING FOLLOWED BY 40 BBLS DIESEL. PULLED BAITED CATCHER ASSEMBLY, EQ PRONG & 2.75" PLUG BODY @ 7391' RKB. PUMP 20 BBLS DIESEL DWN TBG. SET 2.81'' CSA-2 PLUG @ 7097' RKB. SET DMY @ 6222' RKB. LEAVE LRS TO PERFORM MIT-T & MIT-IA. 2/29/2020 CALIPER FROM 7517' RKB TO SURFACE @ 50 FPM. SET 2.75'' CA-2 PLUG @ 7391' RKB. SET 2.76'' x 8' CATCHER W/ GUTTED 2.5'' JD ON PLUG @ 7390' RKB. PULLED DMY @ 6222' RKB. READY TO LOAD WELL W/ 9.8 BRINE, IN PROGRESS. 2/28/2020 SET 3.5'' HOLEFINDER ON TOP OF PLUG @ 7391' RKB, MIT-T TO 3050 PSI FAILED. PULLED 2.75'' CA-2 PLUG @ 7391' RKB. TAG @ 7520' RKB (EST. 18' FILL / 63' OPEN PERFS). DRIFTED W/ 3.5'' DMY WHIPSTOCK DRIFT TO SAME TAG DEPTH. MEASURE BHP @ 7510' RKB (4917 PSI) IN PROGRESS. 2/25/2020 LRS ATTEMPT TO MITT TO 3300 PSI (TWO FAILS). IN PROGRESS. 2/15/2020 BAIL FILL & PULLED RBP @ 7160' RKB; ESTABLISH INJECTIVITY TEST OF 1.8 BPM @ 2975 PSI; SET 2.75" CA-2 PLUG @ 7391' RKB. OBTAIN GOOD TBG TEST ON PLUG TO 3000 PSI AND DRAW DOWN TO 1500 PSI. JOB COMPLETE & READY FOR ELINE. 2/11/2020 (WEATHER DELAYED DUE TO -36°F TEMPERATURE) BAILED FILL (1 GALLON) FROM RBP @ 7160' RKB. SUSPENDED WORK DUE TO -36° TEMPERATURE. IN PROGRESS. 2/10/2020 RAN 2.5" BAILER TO TOP OF RBP @ 7160' RKB & RECOVER 1' OF FILL. JOB SUSPENDED TO DUE AMBIENT TEMPERATURE IN EXCESS OF -35°F. IN PROGRESS. 2/9/2020 BRUSHED INSIDE OF RBP @ 7160' RKB AND ATTEMPT TO LATCH 2 SAME; RAN MULTIPLE SPEARS AND UNABLE TO LATCH RBP; RAN 2.72" & 2.79" IMPRESSION BLOCKS TO SAME (INCONCLUSIVE RESULTS); RAN BARBELL BRUSH ASSEMBLY W/ TT PINS & APPEAR TO GET 15" IN INSIDE RBP. IN PROGRESS. 2/1/2020 ATTEMPT TO PULL 3.5'' RBP @ 7160' RKB BUT UNABLE TO LATCH UP (LAY DWN DUE TO TEMPS). IN PROGRESS. 3Q-04 Well Service Reports 1/30/2020 RETRIEVED LOWER 6'' OF CEMENT RETAINER @ 7157' RKB.PULLED 3.5'' CATCHER @ 7158' RKB. EQUALIZED RBP @ 7160' RKB (CONFIRM BY PUMPING DWN TBG). IN PROGRESS. 1/20/2020 RAN MULTIPLE SPEAR ASSEMBLIES & ONLY ABLE TO OBTAIN FRICTION BITE @ 7160; RAN 2.5" HYDROSTATIC BAILER (YIELDED NOTHING); RAN 2.2O" BELL GUIDE W/ TATTLE TAIL PINS (DID NOT GET OVER FISH); RAN 2.69" MAGNET & RECOVERED METAL SHAVINGS; RAN 2.24" IMPRESSION BLOCK AND OBTAIN IMPRESSION (1.16: X 1.10")WHAT APPEARS TO BE PART OF CEMENT RETAINER (SEE ATTACHMENTS). 1/19/2020 OBTAIN IMPRESSION OF INNER MANDREL (1.1" ID) OF CMT RETAINER W/ 2.74" TAPERED IMPRESSION BLOCK @ 7160' RKB; RAN PRONG W/ TATTLE TAIL PINS AND ABLE TO GET 3/4" INSIDE FISH; RAN 2.5" HYDROSTATIC BAILER (YIELDED NOTHING) RAN BAR BELLED SPEAR ASSEMBLY AND ABLE TO GET FRICTION BITE ON FISH, HOWEVER IT APPEARED WE WENT 3" INSIDE FISH (CEMENT ON SPEAR). IN PROGRESS. 1/18/2020 RAN 2.74" IMPRESSION BLOCK TO FISH @ 7160' RKB (INCONCLUSIVE PICTURE). IN PROGRESS. 1/16/2020 RIH WITH WIRE LINE SPEAR TO RECOVER PART OF CEMENT RETAINER. SET DOWN AT 7150' CTMD, TRIED TO GET JAR HIT DOWN, COULD NOT GET JARS TO FIRE. SET 20K DOWN, POOH, OOH WITH NO FISH, MAKE UP RIH WITH BOWEN ITCO SPEAR TO TAG AT 7150', RUN INTO FISH MULTIPLE TIMES TRIED TO JAR DOWN, JARS STILL NOT FIRING DOWN. OOH NO FISH. RIG COIL DOWN TURN OVER TO SLICKLINE. JOB IN PROGRESS. ( PICS IN ATTACHMENTS). 1/15/2020 RIH WITH VENTURI BASKET, SET DOWN ON CATCHER @ 7150', PU COME ONLINE DOWN COIL PUMPING 1.5 BPM RECIP DOWN/UP ON CATCHER. OOH RECOVERED PIECES OF PACK OFF FROM INJECTOR. RIH WITH PULLING TOOL. STACK DOWN ON CATCHER AT 7150'. GET JAR HIT DOWN. OOH STILL NO CATCHER. RIH WITH TAPERED LIB. (PIC IN ATTACHMENTS). LOOKS LIKE PIECE OF FH CMT RETAINER ON CATCHER. JOB IN PROGRESS. 1/14/2020 RIH WITH 3" G-SPEAR TRY AND LATCH CATCHER AT 7150' RKB, HAD TWO MISS RUNS. MAKE UP VENTURI, STAND BACK FOR THE NIGHT. JOB IN PROGRESS., 12/31/2019 DID A CHAIN INSPECTION EVERY THING LOOKED GOOD. RBIH W/ 2.72" PDC MILL. MILL 7114' - 7144' TAG AT TOP OF CATCHER. RBIH W/ 2" DJN. WASH W/ 10 BBL GEL AND S. DIESEL TO 7148' CTMD TAG. INJECTIVITY TEST @ 1/4, 1/2, 3/4 & 1.BPM. RBIH W/ G-SPEAR TO TAG AT 7148'. OOH W/O CATCHER - MISSED RUN. RBIH W/ VENTURI TO 7149' TAG. POOH PUMPING 46 BBL SSW & 24 BBL FREEZE PROTECT DIESEL TO TUBING. VENTURI BASKET RETURNED TO SURFACE WITH 1/2 CUP OF CEMENT SHEATH PIECES (PHOTO SAVED TO ATTACHMENTS). RIG DOWN. JOB IN PROGRESS. 12/30/2019 PERFORM WEEKLY BOP TEST, RIH WITH MOTOR AND PIRANAH CONVEX MILL, TAG CEMENT AT 7064' CTMD, MILL DOWN TO RETAINER AT 7104' CTMD, MADE IT THROUGH RETAINER AT 7108' CTMD, MILL CEMENT DOWN TO SAND AT 7130' CTMD, RIH WITH 2.25" DJN, WASH DOWN TO THE RBP AT 7140' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS. FOUND DENTS IN PIPE ORDER MANLIFT AND CHECK OUT CHAINS FOUND NOTHING ABNORMAL. CHAINS ARE OUT OF TIME POOH. STACK DOWN AND DO A FULL CHAIN INSPECTION DID NOT FIND ANYTHING ABNORMAL CHAINS ARE BACK IN TIME STACK BACK UP. 12/29/2019 RIH WITH QUADCO BEAR CLAW MILL, TAG RETAINER AT 7060' CTMD, 14 STALLS, POOH AND CHANGE MILL TO 5 BLADED CONVEX, TAG RETAINER AT 7060' CTMD, UNABLE TO MAKE ANY FOOTAGE, POOH TO RUN A 2 5/8" VENTURI BASKET AND RECOVER BOWSPRING CENTRALIZER ARM THAT WAS LOST ON E-LINE 10/14/2019, RIH WITH VENTURI AGAIN TO VERIFY THAT THE HOLE IS CLEAN, AT SURFACE WITH SECOND VENTURI RUN GOT A CHUNK OF CEMENT. PREP FOR WEEKLY BOP TEST.CHANGE PACK OFF'S 12/20/2019 SET DV @ 6222' RKB & OBTAIN GOOD IA DDT. JOB COMPLETE & READY FOR CTU. 10/22/2019 MIT-IA TO 3000 (PASS). DRIFTED TBG W/ BLB, 2.66" MAGNET TO CMT RETAINER @ 7070' RKB; NO RECOVERY OF CENT ARM LOST 10/14/2019. PULLED DV @ 6222' RKB. PUMPED 3 BBLS @ 1/2 BPM DOWN TBG WHILE BLEEDING OFF IA. JOB COMPLETE. 10/16/2019 (AC EVAL) IA DDT (FAIL) REVERSE IA LLR (0.59 GAL / MIN) 10/14/2019 PULLED E-LINE TOOLSTRING STUCK IN GLM # 2 @ 4325' RKB **MIDDLE BOWSPRING CENT BROKE, LEFT 1/2 OF SPRING LEG IN WELL**. DRIFT TBG w/ 2.13" MAGNET TO CEMENT TAG @ 7026' SLM, NOTHING RECOVERED ON MAGNET. COMPLETE 10/11/2019 LOG SCMT TO DETERMINE TOP OF CEMENT IN IA. LOGGED 2 PASSES UP FROM CEMENT RETAINER AT 7070' TO 6000'. TOP OF GOOD CEMENT FOUND AT ~6810' TRANSITIONS TO CLEAN FREE PIPE AT ~6450'. TOOLSTRING STUCK IN MANDREL AT 4325', PULL OUT OF ROPE SOCKET LEAVING 1.1875" FN AT ~4300'. SCMT LOGGING COMPLETE. 9/26/2019 PUMP 3 BBLS DIESEL DOWN TBG. TBG PSI'D UP TO 3000 PSI, IA DID NOT TRACK PERFORM MIT-T TO 3000 PSI TBG GAINIED 10 PSI OVER 30 MIN, IA GAINED 260 PSI JOB COMPLETE 9/26/2019 SHOT TUBING PUNCH FROM 7040' - 7044'. 4 SPF, 0 DEG PHASING. CCL TO TOP SHOT: 6.7'. CCL STOP DEPTH: 7033.3'. LOG CORRELATED TO JEWELRY LOG DATED 07-AUGUST-2019. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,520.0 2/28/2020 3Q-04 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled DV 4/29/2020 3Q-04 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 123.0 Set Depth (TVD) … 123.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 42.2 Set Depth (ftKB) 4,517.7 Set Depth (TVD) … 3,955.1 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 15.7 Set Depth (ftKB) 7,716.0 Set Depth (TVD) … 6,701.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 38.0 Set Depth (ft… 7,052.4 Set Depth (TVD) (… 6,131.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 38.0 37.9 0.11 HANGER CAMERON GEN IV TUBING HANGER 2.992 514.6 514.6 1.31 NIPPLE CAMERON "DS" NIPPLE 3.5" X 2.875 2.875 7,045.2 6,125.6 30.45 LOCATOR BAKER LOCATOR SUB 2.990 Tubing Description STACKER PACKER String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,052.4 Set Depth (ft… 7,370.7 Set Depth (TVD) (… 6,405.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,052.4 6,131.8 30.45 PBR BAKER 80-40 PBR 4.000 7,075.5 6,151.7 30.46 PACKER BAKER FHL RETRIEVABLE PACKER 47B2 SHEAR 60K 2.950 7,097.3 6,170.4 30.48 NIPPLE CAMERON DS NIPPLE 2.812" 2.812 7,360.5 6,396.4 31.21 LOCATOR BAKER NO GO LOCATOR SUB 2.992 7,361.3 6,397.1 31.21 SHOE BAKER MULE SHOE 2.992 Tubing Description TUBING - original String Ma… 5 5/8 ID (in) 2.94 Top (ftKB) 7,363.4 Set Depth (ft… 7,399.5 Set Depth (TVD) (… 6,429.8 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,363.4 6,398.9 31.21 PBR CAMCO PBR, 10' stroke, 5.625" OD Bbl, 2.937" ID (30K# Shear) 2.937 7,376.8 6,410.4 31.24 PACKER CAMCO 'HRP-1-SP' Retr. Pkr, 60K# pull or rot. release, 5.937"OD, 2.867"ID 2.867 7,391.2 6,422.7 31.26 NIPPLE CAMCO 'D' Nipple w/ 2.75" packing bore. 2.750 7,398.8 6,429.2 31.27 SOS CAMCO PE-500 Shearout Sub 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,097.0 6,170.2 30.48 2.81" CA-2 PLUG Set 2.81" CA-2 PLUG (2' 6" OAL) 3/1/2020 0.000 7,135.0 6,202.9 30.56 Tubing Punch Tubing Punch, 2' of 4 SPF 7/10/2019 2.990 7,410.0 6,438.8 31.27 FISH Spring to GA-2 Running Tool 10/20/2013 0.000 7,425.0 6,451.6 31.27 FISH 100% of Cups Left in Well Removed Tree Saver 4/26/1997 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,040.0 7,044.0 6,121.1 6,124.5 9/26/2019 4.0 CMT SQZ 1 9/16" Tubing Punch. 4SPF, 0 deg Phasing 7,475.0 7,483.0 6,494.3 6,501.2 C-1, A-2, 3Q-04 2/13/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing 7,483.0 7,495.0 6,501.2 6,511.4 C-1, A-2, 3Q-04 2/13/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing 7,498.0 7,538.0 6,514.0 6,548.2 A-1, 3Q-04 2/13/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 6,810.0 7,075.0 5,922.3 6,151.2 Cement Squeeze 7/17/2019 TOP OF CEMENT VARIFIED W/ SLB SCMT LOG RUN 10/11/19 7,082.9 7,139.0 6,158.1 6,206.4 Cement Squeeze 7/17/2019 TOP OF CEMENT VARIFIED W/ SLB SCMT LOG RUN 10/11/19 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,887.9 2,607.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/27/2019 2 4,325.4 3,797.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/27/2019 3 5,395.4 4,690.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/27/2019 4 6,222.2 5,410.7 CAMCO MMG 1 1/2 GAS LIFT OPEN 0.000 0.0 4/29/2020 5 6,990.1 6,078.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/27/2019 Notes: General & Safety End Date Annotation 10/20/2013 NOTE: LEFT SPRING TO GA-2 RUNNING TOOL IN WELL 3Q-04, 6/9/2020 6:13:30 AM Vertical schematic (actual) PRODUCTION; 15.7-7,716.0 IPERF; 7,498.0-7,538.0 IPERF; 7,483.0-7,495.0 IPERF; 7,475.0-7,483.0 FISH; 7,425.0 FISH; 7,410.0 SOS; 7,398.8 NIPPLE; 7,391.2 PACKER; 7,376.8 PBR; 7,363.4 SHOE; 7,361.3 LOCATOR; 7,360.4 Tubing Punch; 7,135.0 Cement Squeeze; 7,082.9 ftKB 2.81" CA-2 PLUG; 7,097.0 NIPPLE; 7,097.2 PACKER; 7,075.5 PBR; 7,052.4 LOCATOR; 7,045.2 CMT SQZ; 7,040.0-7,044.0 GAS LIFT; 6,990.1 Cement Squeeze; 6,810.0 ftKB GAS LIFT; 6,222.2 GAS LIFT; 5,395.4 SURFACE; 42.2-4,517.7 GAS LIFT; 4,325.4 GAS LIFT; 2,887.9 NIPPLE; 514.6 CONDUCTOR; 41.0-123.0 HANGER; 37.9 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 1/19/1992 3Q-04 ... TD Act Btm (ftKB) 7,725.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292221900 Wellbore Status PROD Max Angle & MD Incl (°) 39.76 MD (ftKB) 2,300.00 WELLNAME WELLBORE3Q-04 Annotation Last WO: End Date 12/9/2013 H2S (ppm) 175 Date 12/23/2012 Comment SSSV: NIPPLE Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Thursday, April 23, 2020 4:16 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: 313-10 (PTD 191-124, AIO 26.067) Sustained IA Casing Pressure Attachments: 3B-10 90 -day TIO 4.23.20.pdf; 313-10.pdf Hi Chris, Kuparuk producer 313-10 (PTD 191-124, A10 26.067) was reported yesterday for suspect IA pressurization. The inner annulus reached a maximum of 2600 psi yesterday, 4/22/20. As of today, 4/23/20 the inner annulus pressure is presently at 2375 psi. The pressure has exceeded 45% of the 7" 26# J-55 production casing that has an internal yield rating of 4,980 psi (45% here is 2,241 psi). Our team performed initial diagnostics on the well today and it failed a diagnostic MIT -IA. The well remains shut in and freeze protected. CPAI plans to mobilize slickline as soon as operationally possible to secure the well with a down hole plug and bleed the IA pressure. Please let us know if you have any questions or disagree with this plan. Attached is a wellbore schematic and 90 -day TIO trend. Sincerely, Sarcv CowlW& (}f PAZ v) / Stepha vu l Pim Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com 191124 Well To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : READ Cased Hole, Inc. RECIED Attn: Diane Williams MAR �pZp 4141 B Street Suite 308 /t OGCC Anchorage, AK 99503 /'1V \.r Diane.Williamsna readcasedhole.com 1) Caliper Report 29 -Feb -20 3Q-04 1 Reort / CD 50-029-22219-00 2) 1 r r ��jJI j n Signed: I Date : V ✓! l l �I��N Print Name: P'uU % l r� READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL: READ-ANCHORAGEWREADCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM 32 13 .3 hnps://readcaaedhole-myshvepointcom/personal/diane_v piams_reMcasedhole com/Docvment.D DrivdAchives/Meste�'I'ample[eFilea/Cemplates/DisMbufioM'ransmitmlSheeta/ConowPhillips_hatumicdocz 19 1124 32 13 3 -- ICASED Memory Multi -Finger Caliper HOLE Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Description: Pipe Use: Pipe Description: ConocoPhillips Alaska, Inc. February 29, 2020 20113 1 3.5 inch 9.3 Ib. L-80 EUE Tubing 7 inch 26 Ib. J-55 BTC Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS: 3Q-04 Kuparuk Alaska 50-029-22219-00 Surface 7,399 Ft. (MD) 7,399 Ft. (MD) 7,513 Ft. (MD) This caliper data is tied into the SOS at 7,398.8 feet (Driller's Depth) per the attached wellbore schematic dated February 15, 2020. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage, particularly across the 7 inch casing to help with CTD evaluation. A 3-D log plot of the caliper recordings across the interval of casing logged is included in this report. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions outside of the tubing punches listed on the wellbore schematic. The caliper recordings indicate the 7 inch casing logged appears to be in fair condition with respect to internal corrosive and mechanical damage. Wall penetrations ranging from 23% to 31 % wall thickness are recorded outside of the perforation interval throughout the casing logged. Cross-sectional wall loss of 16% metal volume is recorded in an area of general corrosion in marker joint 2 (7,440 ft). Outside of the perforation interval, no other significant areas of cross-sectional wall loss are recorded throughout the casing logged. Recorded damage appears as a line of pits, line corrosion, and general corrosion. Although no significant I.D. restrictions were recorded, the caliper recorded slight oval deformation in the perforation interval at 7,503 feet, restricting the I.D. to 6.02 inches. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Outside of the tubing punches, no significant wall penetrations (> 18%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Outside of the tubing punches, no significant areas of cross-sectional wall loss (> 6%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmericaralreadcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Description PE rcont Wall Penotrato., Joint Depth Corrosion 31 2 7,453 Ft. (MD) Line of Pits 26 1 7,422 Ft. (MD) Line Corrosion 23 3 7,459 Ft. (MD) Outside of the perforation interval, no other significant wall penetrations are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Description Percent V.1all Loss ,. Depth Corrosion 16 2 7,440 Ft. (MD) Outside of the perforation interval, no significant areas of cross-sectional wall loss (> 9%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: Description Minimum Recorded Diameter Joint Denth Slight Oval Deformation 6.02 inches 4 7,503 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. M. Domec C. Waldrop S. Ferguson Field Enoineens) A-1 ... t1-1 Wit- e �s( ) t<eHu i,aseo Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmericana readcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ;� -- ,t:: Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (28.8'- 7,398.9') Well: 3Q-04 Pipe 2 7. in (7,398.9'- 7,512.6') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February29, 2020 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 r� J 7 ti - y l 33 ► i � J 25 783 1,552 75 2,319 GLM 1 3,119 E 125! 3,885 GLM 2 a 150 4,680 GLM 3 175 5,475 GLM 4 6,274 GLM 5 7,140 MM 7,399 7,474 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 4 ■ Perforations 1 r� J 7 ti - y l 1 � � ► i � J Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Damage Profile (% wall) =0 Penetration body MONN Metal loss body 0 50 100 GLM 1 (11:00) GLM 2 (10:00) GLM 3 (12:30) GLM 4 (10:30) GLM 5 (10:30) Bottom of Survey = 231.7 Perforations _ CASED HOLE Body Region Analysis Well: 3Q-04 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Survey Date: Tool Type: Tool Size: February 29, 2020 UW MFC 24 Ext. No. 211390 1.69 inches Country: Pie USA 3.5 in. 93 f L-80 EUE No. of Fingers: Analyst 24 Waldrop Pi ipe Nom.OD Weight Grade & Thread 3.5 in. 9.3 ppf L-80 EUE Nom.ID 2.992 in. Top Depth Bottom Depth 29 ft. 7,399 ft. Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Damage Profile (% wall) =0 Penetration body MONN Metal loss body 0 50 100 GLM 1 (11:00) GLM 2 (10:00) GLM 3 (12:30) GLM 4 (10:30) GLM 5 (10:30) Bottom of Survey = 231.7 Perforations - _-= Well: Field: Company: CASED HOLE 3Q-04 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: February 29, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID 2.992 in. Body Wall Top Depth Bottom Depth 0.254 in. 29 ft 7,3 99ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. 1. D. (in.) Damage Profile Comments (% wall) 0 50 100 0.1 29 0 0.02 8 2 2.90 Pu Lt. Deposits. 1 33 0 0.02 7 2 2.94 1.1 64 0 0.02 8 2 2.91 Pu Lt. De osits. 1.2 70 0 0.02 8 1 2.93 Pu Lt. Deposit; 2 80 0 0.02 9 2 2.94 3 111 0 0.02 6 2 2.94 4 140 0 0.02 7 2 2.95 5 171 0 0.01 5 2 2.94 6 202 0 0.02 7 2 2.95 7 233 0 0.01 4 2 2.93 8 L 264 0 0.02 9 2 2.95 9 1 295 0 0.02 7 2 2.94 70 325 0 0.02 7 2 2.94 11 356 0 0.01 6 1 2.92 1 Lt. Deposits. 12 387 0 0.02 7 2 2.94 13 418 0 0.02 7 2 2.93 Lt. Deposits, 14 448 0 0.02 9 2 2.95 15 479 0 0.02 7 2 2.94 15.1 507 0 0 0 0 2.85 3.5 Camco DS Nioole 16 509 0 0.02 8 2 2.93 Lt. Deposits. _ 17 539 0 0.02 7 2 2.94 18 570 0 0.02 6 2 2.95 19 600 0 0.02 8 2 2.94 20 630 0 0.02 9 2 2.95 21 660 0 0.02 9 2 2.94 22 691 0 0.03 11 2 2.95 23 722 0 0.03 10 3 2.95 24 753 0 0.03 73 2 2.96 25 783 0 0.02 7 2 2.95 26 814 0 0.02 7 2 2.94 27 844 0 0.02 9 2 2.94 28 875 0 0.02 7 2 2.95 29 906 0 0.03 11 5 2.95 30 937 0 0.02 9 3 2.96 31 967 0 0.03 10 3 2.94 32 998 0 0.02 9 2 2.95 33 1029 0 0.02 9 2 2.95 34 1059 0 0.02 9 3 2.95 35 1090 0 0.02 8 2 2.93 36 1121 0 0.02 9 4 2.95 371752 0 0.02 7 2 2.95 38 1182 1 0 0.02 7 2 2.94 39 1273 0 0.02 9 3 2.95 40 1244 1 0 0.02 8 2 2.94 41 1275 0 0.02 6 2 2.95 42 1306 0 0,02 7 2 2.95 43 1337 0 0.02 6 2 2.96 44 1367 0 0.02 9 2 2.95 45 1397 0 0.0 8 2 2.95 46 1428 0 0.02 7 2 2.95 Penetration Body Metal Loss Body Page 1 Well: Field: Company: CASED RV HOLE 3Q-04 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: February 29, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 29 ft 7,399 ft. Joint No. )t. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. 1. D. (in.) Damage Profile Comments (% wall) 0 50 100 47 1459 0 0.02 9 2 2.94 48 1490 0 0.02 7 2 2.95 49 1521 0 0.02 7 2 2.94 50 1552 0 0.01 6 2 2.95 51 1583 0 0.02 7 2 2.93 52 1613 0 0.02 9 3 2.95 53 1644 0 0.02 7 2 2.94 54 1675 0 0.02 8 3 2.94 55 1706 0 0.02 7 2 2.94 56 1737 0 0.02 9 2 2.94 57 1767 0 0.03 11 4 2.94 58 1798 0 0.02 8 3 2.93 Lt. Deposits. 59 1829 0 0.02 9 1 2.93 60 1860 0 0.02 7 2 2.93 61 1890 0 0.02 7 2 2.92 Lt. De osits. 62 1921 0 0.02 9 4 2.93 Lt. De osits. 63 1952 0 0.02 6 2 2.92 Lt. De osits. 64 1983 0 0.02 9 2 2.92 Lt. De osits. 65 2013 0 0.02 8 2 2.92 Lt. De osits. 66 2044 0 0.02 7 2 2.94 67 2075 0 0.02 9 2 2.93 Lt. Deposits. 68 2106 0 0.02 8 3 2.92 Lt. Deposits. 69 2136 0 0.03 11 2 2.90 Lt. Deposits. 70 2166 0 0.02 9 2 2.94 71 2197 0 0.02 7 2 2.93 72 2228 0 0.02 6 2 2.93 Lt. Deposits. 73 2258 0 0.02 9 2 2.93 Lt. De osits. 74 2289 0 0.03 10 3 2.94 75 2319 0 0.02 7 2 2.94 76 2350 0 0.04 14 4 2.94 77 2381 0 0.03 11 3 2.94 78 2412 0 0.02 8 2 2.95 79 2443 0 0.03 11 2 2.94 80 1 2474 0 0.02 9 2 2.94 81 1 2505 0 0.03 12 3 2.93 82 2536 0 0.02. 9 2 2.95 11 83 2567 1 0 0.02 7 2 2.94 84 2597 0 0.03 12 2 2.94 85 2628 0 0.02 7 2 2.92 1 Lt. Deposits. 86 2659 0 0.03 10 2 2.93 Lt. De osits. 87 2690 0 0.02 7 2 2.94 88 2720 0 0.02 7 2 2.94 89 2751 0 0.02 7 1 .94 90 2782 0 0.03 10 2 2.95 91 2813 0 0.02 8 2 2.93 92 2844 0 0.02 9 3 2.93 Lt. De osits. 92.1 2875 0 0.02 9 2 2.91 Pu Lt. De osits. 9 .2 2885 0 0 0 0 .90 GLM i Latch @ 11:00 92.3 2893 0 0.05 18 6 2.91 Pu Shallow Pittin . Lt De osits. 93 2904 0 0.02 9 2 2.93 Penetrafion Body Metal Loss Body Page 2 Well: Field: Company: HOLED 3Q-04 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: February 29, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 29 ft Bottom Depth 7,399 ft. Joint No. )t. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. 1. D. (in.) Comments Damage Profile (% wall) 0 50 100 94 2935 0 0.03 11 2 2.94 -1 95 2966 0 0.03 10 3 2.94 96 2996 1 0 0.02 8 3 2.93 Lt. Deposits. 97 3026 0 0.02 9 3 2.93 Lt. Deposits. 98 3057 0 0.02 9 2 2.92 Lt. Deposits. 99 3088 0 0.02 7 2 2.90 Lt. Deposits. 100 3119 0 0.02 7 3 2.93 Lt. Deposits. 101 3150 0 0.03 12 4 2.94 102 3181 0 0.02 9 3 2.93 103 3211 0 0.02 9 2 2.92 Lt. De osits. 104 3241 0 0.02 7 2 2.93 Lt. Deposits, 105 3272 0 0.02 7 2 2.92 Lt. De osits. 106 3303 0 0.03 13 2 2.93 107 3333 0 0.02 8 2 2.94 108 3364 0 0.02 8 2 2.92 Lt. Deposits. 109 3395 0 0.03 11 3 2.92 Lt. Deposits. 110 3425 0 0.03 12 2 2.92 Lt. De osits. 111 3456 0 0.03 11 1 2.93 Lt. Deposits. 112 3487 _ 0 0.04 14 2 2.94 113 3517 0 0.02 7 2 2.92 _ Lt. Deposits, 114 3547 0 0.02 9 2 2.92 Lt. De osits. 115 3578 0 0.03 12 4 2.93 Lt. Deposits. 116 3609 0 0.02 7 2 2.94 117 3639 0 0.02 9 2 2.92 Lt. Deposits, 118 367 0 0.02 8 2 2.92 Lt. Deposits. 119 3701 0 0.02 9 2 2.92 Lt. Deposits. 120 3732 0 0.03 10 2 2. 3 121 3763 0 0.03 13 4 2.23 122 3792 0 0.02 8 2 2.90 _ Lt. De osits. 123 3823 0 0.02 9 2 2.91 Lt. De sits. 124 3854 0 0.03 10 2 2.93 125 3885 0 0.02 9 2 2.94 126 3916 0 0.03 11 2 2.91 Lt. De osits. 127 3946 0 0.03 12 3 2.92 Lt. De osits. 128 3977 0 0.03 12 3 2.91 Lt. Deposits. 129 4008 0 0.03 11 3 2.93 130 4039 0 0.02 9 3 2.91 Lt. De osits. 131 4068 0 0.02 7 2 2.91 Lt. Deposits. 132 4099 0 0.02 9 2 2.91 Lt. Deposits. 133 4130 0 0.03 11 2 2.92 Lt. De osits. 134 4161 1 0 0.02 9 2 2.92 Lt. Deposits. 135 4192 1 0 0.02 9 3 2.93 136 4222 1 0 1 0.04 15 3 2.92 Shallow Line of Pits. Lt. Deposits, 137 4253 0 0.03 11 2 2.92 Lt. Deposits. 138 4284 0 0.02 9 2 2.93 138.1 4314 0 0.03 11 2 2.89 Pup Lt. Deposits, 138.2 4325 0 0 0 0 2.89 GLM 2 Latch ® 10:00 138.3 4336 0 0.03 11 2 2.94 Pu 139 4344 1 0 0.03 13 2 2.93 140 4375 0 0.03 13 3 2.93 Lt. Deposits. Penetrafion Body Metal Loss Body Page 3 Well: Field: Company: CASED HOLE 3Q-04 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: February 29, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 29 ft Bottom Depth 7,399 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. 1. D. (in.) Comments Damage Profile (% wall) 0 50 100 141 4405 0 0.04 14 4 2.91 Lt. Deposits. 142 4436 0 0.03 11 4 2.92 Lt. Deposits. 143 4467 0 0.02 9 2 2.93 Lt. Deposits. 144 4497 0 0.04 16 5 2.94 Shallow Line of Pits. 145 4527 0 0.03 12 2 2.95 146 4558 0 0.04 14 3 2.93 147 4589 0 0.02 9 3 2.91 Lt. De osits. 148 4620 0 0.02 7 2 2.92 Lt. Deposits. 149 4649. 0 0.02 9 3 2.94 150 4680 0 0.03 12 2 2.94 151 4711 0 0.04 15 4 2.94 Shallow Line of Pits. 152 4742 0 0.02 8 2 2.93 153 4773 1 0 0.02 9 2 2.91 Lt. Deposits. 154 4803 0 0.02 9 2 2.93 155 4834 0.04 0.03 13 3 2.93 156 4865 0 0.02 9 2 2.93 Lt. Deposits. 157 4896 0 0.02 9 2 2.92 Lt. Deposits. 158 4926 0 0.02 9 2 2.92 Lt. Deposits. 159 4956 0 0.02 9 2 2.95 160 4987 0 0.04 14 4 2.94 161 5018 0 0.03 10 3 2.91 Lt. Deposits. 162 5047 0 0.02 9 3 2.91 Lt. De osits. 163 5078 0 0.02 9 2 2.91 Lt. Deposits. 164 5109 0 0.02 7 2 2.95 165 5140 0 0.02 9 5 2.94 166 5170 0 0.03 13 2 2.92 LL De osits. 167 5201 0 0.03 10 2 2.92 Lt. Deposits. 168 5232 0 0.02 9 3 2.92 Lt_. De osits. 169 5263 0 0.02 9 2 2.93 170 5293 0 0.02 9 2 2.93 171 5324 0 0.02 8 2 2.94 1 172 5355 0 0.02 7 2 2.92 Lt. Deposits. 172.1 1 5386 1 0 0.03 13 3 2.91 Pup Lt. Deposits. 172.2 53 6 0 0 0 0 2.89 GLM 3 Latch ® 12:30 172.3 5405 0 0.04 15 3 2.93 Pup Shallow Line of Pits. Lt. De osits. 173 5415 0 0.03 11 4 2.94 174 5445 0 0.04 14 2 2.93 175 5475 0 0.03 12 3 2.93 Lt. Deposits. 176 5506 0 0.02 9 2 2.93 177 5537 0 0.02 9 3 2.93 178 55k61 0 0.03 11 2 2.95 179 5598 1 0 0.04 15 2 2.95 Shallow Line of Pits. 180 1629Q 0.03 12 2 2.94 181 5660 0 0.03 11 2 2.93 182 5691 1 0 0.03 10 2 2.92 Lt. Deposits. 1835721 0 0.03 11 2 2.94 184 5752 0 0.02 9 2 2.94 185 5783 0 0.03 12 4 2.94 186 5814 0 0.03 11 2 2.94 187 5845 0 0.02 8 2 2.94 'Penetrafion Body Metal Loss Body Page 4 HOLED Well: 3Q-04 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Joint Tabulation Sheet Survey Date: February 29, 2020 Analyst: Waldrop Nom. ID Body Wall Top Depth 2.992 in 0.254 in 29 ft Bottom Depth 7,399 ft Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 188 5876 0 0.03 13 3 2.95 189 5907 0 0.04 14 4 2.95 190 5937 0 0.03 12 2 2.95 191 5968 0 0.02 7 2 2.95 192 5999 0 0.03 12 2 2.94 193 6029 0 0.03 12 4 2.92 Lt. -Deposits 194 6060 0 0.03 11 2 2.95 195 6090 0 0.02 6 2 2.95 196 6121 0 0.03 12 2 2.96 197 6152 0 0.02 9 2 2.95 198 6183 0 0.03 11 4 2.95 198.1 6213 0 0.03 10 3 2.92 Pup Lt. Deposits. 198.2 6224 0 0 o 0 2.88 GLM 4 Latch @ 10:30 198.3 6233 0 0.03 10 2 2.92 Pup Lt. Deposits. 199 6243 00.03 10 2 2.94 200 6274 0 0.02 8 2 2.91 Lt. Deposits. 201 6305 1 0 0.02 9 3 2.94 202 6336 0 0.03 10 2 2.95 203 6366 0 _ 0.02 7 2 2.95 204 6397 0 0.02 9 2 2.96 _ 205 6428 0 0.02 7 2 2.95 206 6459 0 0.02 9 2 2.94 207 6490 0 0.02 9 3 2.93 Lt. Deposits. 208 6521 0 0.02 8 2 2.94 209 6552 0 0.03 10 2 2.95 210 6583 0 0.02 9 2 2.95 211 6614 0 0.01 6 2 2.95 212 6644 0 0.02 9 2 2.95 213 6675 1 0 0.03 11 4 2.95 214 6706 0 0.02 9 3 2.95 215 6737 0 0.02 7 2 2.94 216 6768 0 0.02 8 2 2.93 217 6798 0 0.02 7 2 2.95 218 6829 0 0.02 9 3 2.95 219 6860 0 0.02 8 3 2.95 220 6890 0 0.02 9 2 2.95 221 6921 0 0.03 11 3 2.95 222 6951 0 0.02 9 2 2.95 222.1 6983 0 0.03 10 2 2.91 Pug Lt. De osits. 222.2 6993 0 0 0 0 2.89 GLM 5 Latch d 10:30 222.3 7002 0 0.03 11 5 2.91 Pup Lt. De osits. 223 7012 0 _ 0.03 10 4 2.94 223.1_ 17042 223.2 7048 0__. 0 0.18. 0 71_ 6_ 0 0 2.92 _ 2.97 Perforations Lt Seal Assemb 223.3 1 7070 1 0 0 0 0 2.90 Baker FHL Retrievable Packer 223.4 7087 0 0.02 9 2 2.93 Pup Lt. Deposits. 223.5 7098 0 0 0 0 2.80 Camco DS Nipple 223_6 .__7099__1_ _224 _.�_ _7109_ 225 _7140 00.02 8 2 I0_ '_0.29 100 15 _ 10 T 0.03 70 4 2.91 2.9_4_ 2.90 Pu Lt. Deposits. Perforations_________ Lt. De osits. 'Penetration Perforations Metal Loss Perforations Page 5 Penetration Body Metal Loss Body Well: Field: Company: CASED HOLE 3Q-04 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: February 29, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing _ Nom, ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 29 ft 7,399 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min, I.D. (in.) Comments 0 Damage Profile (% wall) 50 100 226 7171 0 0.03 12 6 2.91 Lt. Deposits. 227 7202 00.03 11 2 2.95 228 7232 0 0.02 9 3 2.94 229 7264 0 0.02 9 2 2.92 Lt. Deposits. 230 7294 0 0.02 9 4 2.91 Lt. Deposits. 231 7324 0 0.02 9 4 2.94 231.1 7355 0 0.03 10 2 2.92 Pu Lt. De -sits. 231.2 7361 0 0 0 0 2.92 Seal Ass--b 231.3 7375 0 0 0 0 2.86 Camco HRP-1-SP Retrievable Packer 231.4 7384 0 0.01 5 1 2.92 Pu Lt. De---i- e -sits. 231.5 231.5 7390 0 0 0 0 2.40 Camco D "p-1- i le 231.6 231.6 7391 0 0.02 7 1 2.89 Pu Lt. De -sits. 2 7399 0 0 0 0 2.81 Camco PE-5005hearout Sub 'Penetration Body Metal Loss Body Page 6 __ CASED HOLE Body Region Analysis Well: Field: Company: Country: Pipe 3Q-04 Kuparuk ConocoPhillips Alaska, Inc. USA 7 in. 26 ppf 1-55 BTC Survey Date: February 29, 2020 Tool Type: UW MFC 24 Ext No. 211390 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf J-55 BTC 6.276 in. 7,399 ft. 7,513 ft. Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line. Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole. Number of joints dam dto = 3 0 1 2 0 0 Damage Profile (% wall) Penetration body s Metal loss body Bottom of Survey = 4 2 3 4 � Perforations Penetrafion Perforations Metal Loss Perforations Page 1 Penetrafion Body Metal Loss Body CASED HOLE Joint Tabulation Sheet Well: 3Q-04 Survey Date: February 29, 2020 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf J-55 BTC Casing 6.276 in. 0.362 in. 7,399 ft. 7,513 ft. Joint It. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (in.) (in.) % (in.) 0 50 100 1 7399 0.09 0.09 26 7 6.16 Line of Pits. Lt. De osits. 2 7435 0.07 0.11 31 16 6.27 Marker Joint. Corrosion. 3 7454 0.05 0.08 23 9 6. 0 Marker oint. Line Corrosion. 4 7474 0.07 0.43 100 22 1 6.02 Perforations. Slight Ovality. Lt. Deposits. Lj Penetrafion Perforations Metal Loss Perforations Page 1 Penetrafion Body Metal Loss Body _a CASED HOLE Cross-sectional Illustration Well: 3Q-04 Survey Date: February 29, 2020 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing:_ _ 7 in. 26 ppf 1-55 BTC Analvst: Wald,,,., Cross Section for Joint 2 at depth 7,452.990 ft. Tool speed = 53 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 86% Tool deviation = 25° Finger = 6 Penetration = 0.115 in. Corrosion 0.11 in. = 31% Wall Penetration HIGH SIDE = UP CASED Cross-sectional Illustration Survey Date: February 29, 2020 HOLE Well: 3Q-04 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: _ 7 in. 26 ppf J-55 BTC Cross-sectional Illustration Survey Date: February 29, 2020 Tool Type: UW MFC 24 Ext. No. 211390 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 1 at depth 7,421.600 ft. Tool speed = 54 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 98% Tool deviation = 21 ° Finger = 19 Penetration = 0.094 in. Line of Pits 0.09 in. = 26% Wall Penetration HIGH SIDE= UP CASED HOLE Well: 3Q-04 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 7 in. 26 onf 1-55 BTC Cross-sectional Illustration Survey Date: Tool Type: Tool Size: No. of Fingers: Cross Section for Joint 2 at depth 7,439.910 ft. Tool speed = 52 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 84% Tool deviation = 26° February 29, 2020 UW MFC 24 Ext, No. 211390 1.69 inches 24 Waldrop Finger = 20 Penetration = 0.097 in. Corrosion 16% Cross -Sectional Wall Loss HIGH SIDE = UP CASED HOLE Cross-sectional Illustration Well: 3Q-04 Survey Date: February 29, 2020 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf J-55 BTC Analyst: _ Waldrop Cross Section for Joint 4 at depth 7,503.200 Tool speed = 51 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = N/A Tool deviation = 26° Minimum I.D. = 6.018 in. Slight Oval Deformation Minimum I.D. = 6.02 inches HIGH SIDE = UP KUP PROD WELLNAME 30-04 WELLBORE 3Q-04 Corivcomillips lLLMbutBs M-Angle&MD TD Alaska, Inc. Fleltl Neme Wellbore gPVlIWI WMEo,e 3teWa cll°I MD(Me) qct Bbn lnKBf K P 92lD 9.76 2,300.0( ),725.0 Comment N28fppm) Date gnmtNlon End Oah KB-0rd (Xf Rlg Release Dab SSSV'. NIPPLE 175 12/23/2012 Last WO: 1&92013 411.99 1/19/1992 30pf, L1512Ma0:19:1a PM Last Tag Venlul etlamelkladueD .............................................................................................. ..............._. Mwhnon Depth HIRE) End Dap Wellpora LwI Mod By LAST TAG:]149'CTMD VENTURE BASKET 1x212019 30-04 seep Last Rev Reason .GER:3].0 Mnopnon End. Wellbore Leet Mod By Rev Reason B -H -d Santl/bate Carb, Pulled Cetcher, Pulletl RBP, 8 ser V152020 CA -2 Plug 30Dul xembael Casing Strings aaing Desu;pGanOD AnI ID pnl Tap (XNB) s.l U.0h(--) 8Y Dep"(]vDl YnM1en p. Bred. rop TM1reetl CONDUCTOR 18 15.08 41.0 123.0 123.0 62.50 HA Cii Dauninn OD (M) p(In) Tap VPuG SN De.....c ) Set O.0n, M... WIMn11... Gnda Top TM1r.ed SURFACE 9518 8.03 42.2 4,SiJ.J 3,955.1 36.00 755 BTC CONDGGTOR: 41.04 a0 Cesing Deactlptlan ODlln) ID nn) Top (nKB) Sn Deplb (ryKB) Set DapM fNOL.. O -n a- Grade Top TM1re.d PRODUCTION ] 6.28 iS.J 7716.0 6,]01.5 26.00 J-55 BTC Tubing Strings NWPLE: 51 <.8 TUdA,0pA 0dPG- SlilnS Ma... 1D (In) T1%1"6) $e1 DepIM1(R. Set De 1M1 p TL'Bf 1... WtllblX) Gratle Top Gonnecdon TUBING WO 31/2 2.99 38.0 ].052.4 fi.Y3t8L-80 EUE Completion Details Ons un;z,fiexebarnTOP (rw�, Tap Md cont Nam;ml TOP ("Kid (HKe) V) Du wild 38.0 37.9 0.11 HANGER CAMERON GEN IV TUBING HANGER 2,992 514.6 514.6 1.31 NIPPLE CAMERON 'DS"NIPPLE 3.5"X2,8]5 2.8]5 cns uFT; 4,as a 7.045.2 6,125.6 30,45 LOCATOR BAKER LOCATOR SUB 2,950 TuWng D&Ice age, Ma... ID gra) 7,0(2.41 9e[Oegn B1.. 8N DapIM1 (NDE L.. VA6Wn) Mtle EUOonnactlon STACKER PACKER 31/2 2.99 ],052.0 7,3]OJ 6,405.2 9.30 L-80 EUE Coupl4NloOPOsta is .._ - SNRFACE', 4R.3i,5P.] To EAB) mM xa(in) Top(nnR) (XKB) (°) Ipm D.. cont ID gra) 7,052.4 6,131.8 30.45 PER BAKER 8040 PER 4.000 ],0]5.5 6,151.7 30.48 PACKER BAKER FHL RETRIEVABLE PACKER 4782 SHEAR 60K 2.950 cASUFT:SSFE4 7,097.3 6,170A 30AS NIPPLE CAMERON DS NIPPLE 2.812• 2812 7,360.5 6,396.4 31.21 LOCATOR BAKER NO GOLOCATORSUB 2,992 7,361.3 6,39..1 31.21 SHOE BARER MV LE SHOE 2,992 GAS LIFT; 6,120.2 Taun...... 1pllon Shing Ma... 10 (in) Top lnKB) ..I Much (R. 3el Dep" ball 1... W111EM1 Gratle.-CanTop ,uctlon TUBING -original 55/8 2.94 ],363.4 ],399.5 6,429.8 Completion Detaft Cement sa..me, 6,810 o ane Top (ft.)TIRKBD) -P)nel Nomin•I Pl nem Da• C. ID (in) 1.3113.4 5,398.9 3111 POR CAMCO PER, 10'stroke, 5.625' OD BDL, 2937"ID(30Ke Shear) 2.93] GAS UFT: 6,Wd.1 ),376.8 6,410.4 J1.2A PACKER CAMCO 'HRP-i-SP'Retr.Pal. 60M pull Or AH. release, 5.937'OD, 2.86] 2.007"ID 7,391.2 6,422.7 31.26 NIPPLE CAM O D'Nigple W/2J5" packing bare. 2750 7,398.8 6,429.2 31.27 SOS CAMCO PE -Sig 50eamut Sub 2.992 FW sax', 7.w3w,a4q Other In Hole iWlreOne retrievable plugs, valves, pumps, fish, ei IDP(TVD) Tap Mtl m.0a, 7,0452 TOP(gKB) fW1B1 fl a• Can Bun Dt ],135.0 6,202.9 30.56 Tubing Punch Tubing Punch, 2' 014 SPF]/1020),391.0 7gEG4 6.422.5 31.28 2]5•Ch2 2.]5"CA-2PW0(T B"OAL) 14/29/2Men; PLUG91,41011 1.15.5 6,438.8 3L4> FISH Sptlng io GA•2 Running Tool 1020/2PACKER 3],425.0 6,451.6 31.2] FISH 100%Bf Cups Lett in WellRemoved Te Saver 4/26119 NIPPLE:1.001.2 I"Orf0ratlenb & Slob .-.e.`auP ?'AgS.B TuW9 Punch, 7135.0 TOPIBKD) BM IBKB) TOP N 1Dl (nKB) BImfTVO) (ft-) Linked Zona pep chat Oene lWaWX l Type G.m ),040.0 7,044.0 6,121.1 8,124.5 9/2&2019 4.O CMT SOZ 19/16'Tubing Punch. 4SEP, 0 tleg Phasing ],4]5.0 ),483.0 6,494.3 6,551.2 61, A-2.30,04 213/1992 4.0 IPERF 4112" CW Gun; 180 deg. LOOATGR', 7SRC4 Phas;ng 7,483.0 ),495.0 6,501.2 6,511-401,7,-$30-04 213x1992 4.0 TE -RF- 412"CsgGun; 180 tleg. SHOT1, W PiPER?aa3.4 2498.0 7538.0 8514.0 6,548.2 ,4-1,30M 211311992 1111PE131 41/271 Dun; LBO tleg. PACKER: ],]]B.a phasing Cement Squeezes NIPI-G 1,301.2 3 ]5'C42 PLVc; 1,N!A TOP IIVD) BM IND) Tap 01KBl Btm l%I®l (XKB) IXKB) px eWM1Daro Com 6,810.0 7.075.0 5,922.3 61151.2 Cement squeeze ./17/21119 TOP OF CEMENT VARIFI DW/SLBSCMT LOG PUN 10/11/19 ],082.9 7139.0 6,158.1 6,208.4 Cement Squeeze ]/1)/2019 11 VAMIEIEDWI SLB BCMT LOG e05p.se.e 1-1 PUN 10111/19 Mandrel inserts FISH:]A1oo .n FISH; ),4260 ToPDI VON. h Po,t31m TRORun N T ryl(B) (TVgIKBI Make Madel BD(in) Ben Type Tylepe Int (Ps6 Run Dap Com 1 2,88].9 2,607.4 CAMCO MM G 11/2 GASLIFT DMY RK 0.000 0.0 42712019 2 4,325.4 3,797.4 CAMCO MM G 11/2 GAS LIFT DMV RK 0.000 0.0 41272019 3 5,395.4 4,690.6 CAMCO MIA G 112 GAS LET )MY RK 0.000 0.0 42]2019 IPERF; 1,415.0-1,48a0'-- 4 8.222.2 5,410.7 CAMCO NIM G 1112 GAS LIFT OMY RK 0.000 0.0 1220/2019 IPERF: 1,481 5 6,990.1 6.078.0 CAMCO MMG 1 i/2 GAS LIFT OMY RK 0.000 0,0 4/x]/2019 Notes: General & Safety IPERF T490.0.1,fi3B.g� 10/20/2013 Entl Defe Mnohnen NOTE: LEFTSPRING TO GA4 RUNNING TOOL IN WELL PRODUCTION; 157-7,n60 P7 -L) /9/-/?-+ Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, February 27, 2020 3:47 PM To: Loepp, Victoria T (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3; Kozak, Devin Subject: RE: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Follow Up Flag: Follow up Flag Status: Flagged Victoria, As discussed, we have been unable to (re)establish injectivity for the planned water flow log on 3Q-04 and have therefore decided to forgo the WFL and CBL. In addition, an opportunity for coil tubing drilling has been identified and is being evaluated as alternative to the planned/approved cement packer repair. Per Sara Carlisle email dated 2/20/2020, T/1/0 = 2560/2305/355 psi Slickline is on location (currently weather standby) with intent to circulate 9.8ppg fluid for pressure management. I'll update you as soon as we are done evaluating repair/CTD options. Thanks, Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, January 07, 2020 2:45 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Thanx for the update. This plan forward is approved. I'm assuming this work will continue in the near term. Let me know the results of the CBL. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loeoofg�alaskagov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victorici.Loer)ip@alaska.gov From: Simek, Jill <Jill.SimekCalconocophillips.com> Sent: Tuesday, January 7, 2020 2:41 PM To: Loepp, Victoria T (CED) <victoria.loepp(&alaska.aov> Cc: Well Integrity Compliance Specialist WNS & CPF3 <n25491 conocophillips.com> Subject: RE: KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Victoria, Per our conversation, I would like to update you on 3Q-04 progress towards cement packer repair: On 12/31/2019, the cement and cement retainer were milled out to the top of the retrievable bridge plug at 7,148 CTMD. The next step in the procedure was to pull the plug and proceed with uphole cement packer repair. However, initial efforts to pull the plug have failed due to cement/debris from the first cement packer repair attempt. Coil tubing will reattempt to pull the plug this week. In the meantime, due to an elevated pressure in the IA of 2250psi (45% casing burst pressure=2241psi), 46 bbls seawater has been bullheaded down the tubing to reduce pressures. Currently, IA pressure is 1378psi. We will continue to monitor the well to ensure pressures remain within tolerance. Also of note, we performed an injectivity test between the packers, at the site of the original cement packer repair, and were able to inject approximately 23 bbls of diesel up to a rate of lbpm through the tubing punches. This indicates that a communication path still exists from tubing to annulus to formation AND/OR tubing to annulus and past one or more of the packers. Once the RBP has been pulled, we would like to set a deeper plug, then run CBL and/or waterflow log in an attempt to evaluate cement and possible channeling behind pipe. Should logging provide us with new information that warrants changes to the planned cement packer repair, we will inform the AOGCC and make the appropriate change of approved sundry request. If you have any questions on our path forward, please contact me Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loeppC�alaska.gov> Sent: Tuesday, December 10, 2019 8:29 AM To: Simek, Jill<Jill.Simek(Mconocophillivs.com> Subject: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Approval is granted for the changes to the approved sundry as outlined below. Please include this approval with your copy of the approved sundry and have this approval on the job site. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victona.LoeooCdalaska gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Victoda.Loepr)@alaska.gov From: Simek, Jill <1ill.Simek0conocoahillios.com> Sent: Monday, December 9, 2019 9:46 AM To: Loepp, Victoria T (CED) <victoria.loeppOalaska.lzov> Subject: 3Q-04 Cement Packer Repair (Sundry #319-408) Victoria, Per approved Sundry#319-408, ConocoPhilligs has Derformed the following activitv at 30-04- 10/22/2019 MIT -IA TO 3000 (PASS). DRIFTED TBG W/ BLB, 2.66" MAGNET TO CMT RETAINER @ 7070' RKB; NO RECOVERY OF CENT ARM LOST 10/14/2019. PULLED DV @ 6222' RKB. PUMPED 3 BBLS @ 1/2 BPM DOWN TBG WHILE BLEEDING OFF IA. JOB COMPLETE. 10/16/2019 (AC EVAL) IA DDT (FAIL) REVERSE IA LLR (0.59 GAL/ MIN) 10/14/2019 PULLED E -LINE TOOLSTRING STUCK IN GLM # 2 @ 4325' RKB "MIDDLE BOWSPRING CENT BROKE, LEFT 1/2 OF SPRING LEG IN WELL". DRIFT TBG w/ 2.13" MAGNETTO CEMENT TAG @ 7026' SIM, NOTHING RECOVERED ON MAGNET. COMPLETE 10/11/2019 LOG SCMT TO DETERMINE TOP OF CEMENT IN IA. LOGGED 2 PASSES UP FROM CEMENT RETAINER AT 7070' TO 6000'. TOP OF GOOD CEMENT FOUND AT -6830' TRANSITIONS TO CLEAN FREE PIPE AT -6450'. TOOLSTRING STUCK IN MANDREL AT 4325', PULL OUT OF ROPE SOCKET LEAVING 1.1875" FN AT "'4300'. SCMT LOGGING COMPLETE. 9/26/2019 PUMP 3 BBLS DIESEL DOWN TBG. TBG PSI'D UP TO 3000 PSI, IA DID NOT TRACK PERFORM MIT -T TO 3000 PSI TBG GAINIED 10 PSI OVER 30 MIN, IA GAINED 260 PSI JOB COMPLETE 9/26/2019 SHOT TUBING PUNCH FROM 7040'- 7044'. 4 SPF, 0 DEG PHASING. CCL TO TOP SHOT: 6.7'. CCL STOP DEPTH: 7033.3'. LOG CORRELATED TO JEWELRY LOG DATED 07 -AUGUST -2019. Because cement was encountered in the IA after perforating at 7,040ft-7,044ft KB, and circulation could not be achieved, ConocoPhillips requests to amend the remaining steps in the procedure as outlined below. Please let me know if AOGCC approves these changes. PROCEDURE: SL — Set DV 1. MIRU SL 2. Set DV in open GLM at 6,222ft KB. 3. RDMO CTU - Mill cement and retainer (from first cement packer repair attempt) 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and cement retainer, taking returns off tubing to tanks. Cement retainer expected at-7,070ft KB. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-7,160ft KB. 4. RDMO. Well ready for DSL. DSL - Pull and set plugs, set DV, punch tubing iniectivity test 4. MIRU DSL. 5. Pull catcher on RBP at 7,160ft KB. 6. Pull RBP at 7,160ft KB 7. Set RBP at 6,440ft KB. 8. Set catcher on RBP. 9. RIH with 2.5" dump bailer and dump 15ft of sand on top of RBP/catcher. 10. RIH with tubing punch (4' of 4SPF) and punch holes at 6,411ft - 6,415ft KB. 11. Pump 20 bbls of diesel down the tubing to confirm injectivity. 12. RDMO. Well ready for CTU. CTU - Set retainer, pump cement 5. MIRU CTU and Cementers. 6. MU and RIH with 3.5" Weatherford millable cement retainer. 7. Tag top of sand for depth correction. Top of sand should beat 6,425ft KB. 8. Set WFD cement retainer at 6,400ft KB. 9. Come online with diesel pumping 10 bbls diesel lead (assuming CT is fluid packed with diesel at this point). 10. Follow diesel with 5 bbls fresh water spacer. 11. Follow fresh water spacer with 16 bbls of 15.8 ppg Class "G" cement. 12. Follow cement with 5 bbls fresh water spacer. 13. Follow fresh water spacer with diesel. 14. Once all of cement is out of nozzle, unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 15. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi. Eline - Log SCMT 1. MIRU Eline. 2. RIH and tag cement retainer at 6,400ft KB. 3. Log SCMT from cement retainer to above IA TOC. 4. RDMO. CTU- Mill cement/retainers 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and retainer, taking returns off tubing to tanks. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-6,440ft KB. 4. POOH. RDMO. Well ready for SL. SL - GILD 1. MIRU SL. 2. Pull DMY valves from GLD. 3. Install GLD 4. PT tubing to ensure valves are holding or DD IA. 5. Pull catcher. 6. Pull RBP at 6,440ft KB. 7. RDMO. Turn well over to Ops to BOL. Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 1 Cell: 907-980-7503 PT -1) 16J/—/24 Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS &CPF3 <n2549@conocophillips.com> Sent: Thursday, February 20, 2020 5:51 PM To: Loepp, Victoria T (CED) Cc. CPA Wells Supt Subject: Update: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Attachments: 3Q-04.pdf Follow Up Flag: Follow up Flag Status: Flagged Dear Victoria, I want to update you regarding well work progression and further IA pressurization on 3Q-04 (PTD# 191-124). Coiled Tubing and Slickline attempted to pull the catcher and plug from 1/14/20 through 2/15/20 to prepare the well for the amended steps to the cement packer repair that Jill sent on 1/7/20. There was substantial amount of debris from the cement retainer that complicated fishing attempts and numerous inoperable days due to cold weather. Upon successfully retrieving the RBP on 2/15/20 a plug was set in the tubing tail at 7391' MD and pressure tested to 3000 psi in preparation for the waterflow log and CBL. Pressure testing the plug indicated that there is no longer injectivity between the packers, at the site of the original cement packer repair. Without injectivity, a waterflow log is unable to be performed. The tubing was drawn down to 1500 psi on 2/15/20 before Slickline left the well. The annulus pressures have risen to T/1/0= 2560/2305/355 psi. as of today. This indicates that there is one-way communication from the reservoir to the IA and tubing despite the deep set plug. Additionally, we believe the seawater that was bullheaded has swapped out with formation fluids resulting in the sustained casing pressure on the inner annulus. Jill Simek is planning to contact you with an updated path forward with plans likely to forgo logging and proceed to the cement packer repair. This well work continues to be at the top of our priority list. Sincerely, Scwct,,Cas'Ug&Cj{ebk%vv)/Stepha L PaCIV Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, Con ocoPhillips Alaska Office: 907-659-7126 I n2549 c_0P_com Cell: 907-331-7514 1 Sara e carlisle cop.com Jill, Thanx for the update. This plan forward is approved. I'm assuming this work will continue in the near term. Let me know the results of the CBL. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loeoo&ilalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo@olaska aov From: Simek, Jill <Jill Simek@conocophillips.com> Sent: Tuesday, January 7, 2020 2:41 PM To: Loepp, Victoria T (CED) <victoria IoeppPalaska.gov> Cc: Well Integrity Compliance Specialist WNS & CPF3 <n2549 conocophillips.com> Subject: RE: KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Victoria, Per our conversation, I would like to update you on 3Q-04 progress towards cement packer repair: On 12/31/2019, the cement and cement retainer were milled out to the top of the retrievable bridge plug at 7,148 CTMD. The next step in the procedure was to pull the plug and proceed with uphole cement packer repair. However, initial efforts to pull the plug have failed due to cement/debris from the first cement packer repair attempt. Coil tubing will reattempt to pull the plug this week. In the meantime, due to an elevated pressure in the IA of 2250psi (45% casing burst pressure=2241psi), 46 bbls seawater has been bullheaded down the tubing to reduce pressures. Currently, IA pressure is 1378psi. We will continue to monitor the well to ensure pressures remain within tolerance. Also of note, we performed an injectivity test between the packers, at the site of the original cement packer repair, and were able to inject approximately 23 bbls of diesel up to a rate of Sbpm through the tubing punches. This indicates that a communication path still exists from tubing to annulus to formation AND/OR tubing to annulus and past one or more of the packers. Once the RBP has been pulled, we would like to set a deeper plug, then run CBL and/or waterflow log in an attempt to evaluate cement and possible channeling behind pipe. Should logging provide us with new information that warrants changes to the planned cement packer repair, we will inform the AOGCC and make the appropriate change of approved sundry request. If you have any questions on our path forward, please contact me. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, December 26, 2019 9:34 AM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: Re: [EXTERNAL]Re: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Dusty, This needs to be addressed as soon as conditions permit. Thanx, Victoria Sent from my iPhone On Dec 24, 2019, at 1:49 PM, Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> wrote: Victoria - One option is to pull a dummy valve and circulate weighted fluid into the IA however, slick line units are actively laying down their cranes due to low temperature restraints. Based on the weather forecast of continued cold weather and then elevated winds, that may not be a timely option. Bleeding fluid off the IA will potentially exacerbate the issue as the well is loaded with corrosion inhibited seawater with a diesel freeze protect. Because we would be inflowing well bore fluids, we have the potential for both freezing off the well and replacing the heavier seawater with lighter crude oil causing our surface pressure to increase. I talked with the production engineer responsible for prioritization and he is going to move it to a very high priority. CTU will potentially be moving to 24 hour operations as soon as the cold/weather allows. At that point in time it will be a top priority to get the packer repair procedure back in motion. If this is not an acceptable approach, please let me know and we can further discuss ideas on how to address the elevated IA pressure. Thank you. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 <image001.png> From: Loepp, Victoria T (CED) <victoria.loepp@alaska.Rov> Sent: Tuesday, December 24, 2019 12:37 PM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: [EXTERNAL]Re: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure What other alternatives do you have? Sent from my iPhone On Dec 24, 2019, at 10:47 AM, Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocoohillips.com> wrote: Victoria - 3Q -04 was reported by operations with an IA pressure of 2250 psi which exceeds 45% of the casing burst pressure of 2241 psi. CPA[ previously applied and received an approved 10-403 (Sundry #319-268 and change of approval #319-408) for a cement packer repair. The cement packer repair prep work is in progress and the first step has been completed. At this point in time due to vendor equipment issues the progress is on hold until CTU repairs are completed. At that point in time the progress will resume with an elevation of priority within our normal prioritization process. Please let us know if you have any questions or disagree with the plan. Dusty Freebom/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 <i mage001. p ng> From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 10, 2019 8:29 AM To: Simek, Jill <1ill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Jill, Approval is granted for the changes to the approved sundry as outlined below. Please include this approval with your copy of the approved sundry and have this approval on the job site. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(coalaska.00V CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska 01 and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recip[ent(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-7247 or Victoria Loeoo@alaska qov From: Simek, Jill <JiII.Simek@conocon�ll�s.com> Sent: Monday, December 9, 2019 9:46 AM To: Loepp, Victoria T (CED) <victoria.loeppalaska gov> Subject: 3Q-04 Cement Packer Repair (Sundry #319-408) Victoria, Per approved Sundry#319-408, ConocoPhillips has performed the following activity at 3Q-04: 10/22/2019 MIT -IA TO 3000 (PASS). DRIFTED TBG W/ BLB, 2.66" MAGNET TO CMT RETAINER @ 7070' RKB; NO REC( CENT ARM LOST 10/14/2019. PULLED DV @ 6222' RKB. PUMPED 3 BBLS @ 1/2 BPM DOWN TBG WHILE BLEEDING OFF IA. JOB COMPLETE. 10/16/2019 (AC EVAL) IA DDT (FAIL) REVERSE IA LLR (0.59 GAL/ MIN) 10/14/2019 PULLED E -LINE TOOLSTRING STUCK IN GLM a 2 @ 4325' RKB "MIDDLE BOWSPRING CENT BROKE, LEFT SPRING LEG IN WELL". DRIFT TBG w/ 2.13" MAGNETTO CEMENTTAG @ 7026' SLM, NOTHING RECOVI MAGNET. COMPLETE 10/11/2019 LOG SCMT TO DETERMINE TOP OF CEMENT IN IA. LOGGED 2 PASSES UP FROM CEMENT RETAINER AT 7 6000'. TOP OF GOOD CEMENT FOUND AT ^'6810' TRANSITIONS TO CLEAN FREE PIPE AT -64501. TOOLS STUCK IN MANDREL AT 4325', PULL OUT OF ROPE SOCKET LEAVING 1.1875" FN AT "'4300'. SCMT LOGG COMPLETE. 9/26/2019 PUMP 3 BBLS DIESEL DOWN TBG. TBG PSI'D UP TO 3000 PSI, IA DID NOT TRACK PERFORM MIT -T TO 3000 PSI TBG GAINIED 10 PSI OVER 30 MIN, IA GAINED 260 PSI JOB COMPLETE 9/26/2019 SHOT TUBING PUNCH FROM 7040'- 7044'. 4 SPF, 0 DEG PHASING. CCLTO TOP SHOT: 6.7'. CCL STOP DE 7033.3'. LOG CORRELATED TO JEWELRY LOG DATED 07 -AUGUST -2019. Because cement was encountered in the IA after perforating at 7,040ft-7,044ft KB, and circulation could not be achieved, ConocoPhillips requests to amend the remaining steps in the procedure as outlined below. Please let me know if AOGCC approves these changes. PROCEDURE: SL - Set DV 1. MIRU SL 2. Set DV in open GLM at 6,222ft KB. 3. RDMO CTU - Mill cement and retainer (from first cement packer repair attempt 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and cement retainer, taking returns off tubing to tanks. Cement retainer expected at "'7,070ft KB. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-7,160ft KB. 4. RDMO. Well ready for DSL. DSL - Pull and set plugs, set DV, punch tubing, infectivity test 4. MIRU DSL. 5. Pull catcher on RBP at 7,160ft KB. 6. Pull RBP at 7,160ft KB 7. Set RBP at 6,440ft KB. 8. Set catcher on RBP. 9. RIH with 2.5" dump bailer and dump 15ft of sand on top of RBP/catcher. 10. RIH with tubing punch (4' of 4SPF) and punch holes at 6,411ft - 6,415ft KB. 11. Pump 20 bbls of diesel down the tubing to confirm injectivity. 12. RDMO. Well ready for CTU. CTU - Set retainer, pump cement 5. MIRU CTU and Cementers. 6. MU and RIH with 3.5" Weatherford millable cement retainer. 7. Tag top of sand for depth correction. Top of sand should beat 6,425ft KB. 8. Set WFD cement retainer at 6,400ft KB. 9. Come online with diesel pumping 10 bbis diesel lead (assuming CT is fluid packed with diesel at this point). 10. Follow diesel with 5 bbls fresh water spacer. 11. Follow fresh water spacer with 16 bbls of 15.8 ppg Class "G" cement. 12. Follow cement with 5 bbls fresh water spacer. 13. Follow fresh water spacer with diesel. 14. Once all of cement is out of nozzle, unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 15. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi. Eline - Log SCMT 1. MIRU Eline. 2. RIH and tag cement retainer at 6,400ft KB. 3. Log SCMT from cement retainer to above IA TOC. 4. RDMO. CTU- Mill cement/retainers 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and retainer, taking returns off tubing to tanks. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-6,440ft KB. 4. POOH. RDMO. Well ready for SL. SL -GLD 1. MIRU SL. 2. Pull DMY valves from GLD. 3. Install GLD 4. PT tubing to ensure valves are holding or DD IA. 5. Pull catcher. 6. Pull RBP at 6,440ft KB. 7. RDMO. Turn well over to Ops to BOL. 0 Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 Cell: 907-980-7503 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, July 28, 2019 9:02 AM To: 'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.Kov> Cc: CPA Wells Supt <n103Q�conocophillips.com_> Subject: RE: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Victoria, As previously reported 6.16.19 Kuparuk producer 3Q-04 (PTD 191-124) experienced SCP of the IA. The IA was loaded with fluid to reduce the IA pressure below the DNE where it remained until recent well work has caused the IAP to increase to "2100 psi. A work plan is in progress as per approved sundry # 319-268. CPA] intends to leave the pressure as is until the work has been completed. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 <image001.png> From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, lune 16, 2019 1:42 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Hi Victoria, Kuparuk producer 3Q-04 (PTD 191-124) is experiencing sustained casing pressure on the inner annulus after being shut-in on April 11th, 2019. The IA pressure recorded today was 2100 psi. The production casing is 7" 26# J-55 with an internal yield rating of 4,980 psi (45% here is 2,241 psi). CPAI will load the well with fluid to reduce the IA pressure below DNE while we progress a repair option for the well. Please let us know if you have any questions or disagree with this plan. Sincerely, Sara Ca -Ua& (HwAl vt.) / Ra.cM,K"tk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhi►lips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara e carlisle@cop.com <3Q-04.pdf> <3Q-04 APPROVED 10-403 Repair Well, Cement Pkr Sundry App.pdf> <3Q-04 APPROVED 10-403 Change of Approved Program Sundry Application.pdf> ,,� KUP PROD WELLNAME 3Q-04 WELLBORE 3Q-04 COIIOCUPh)llip$ At Well Attributes - -- _-_-- - M"AngleSMD 7D T Alaska. Inc. rein weuMeRPwVfl VRUM„8.en,a I In MDIIIKB) Bnn nlKBl KUPAR VE0. NIT 1900 PROD 9,76 2,300.00 ],]25.0 CommI Ip Iavii.. Con. SSSV NIPPLE 175lppml 12n 012 Lash WO: 12)912013 40.99 IF 1/19/1992 30M, b1:/dYd18:14.18PM Last Tag W,nsltlenutic(uvxub Sao momm IKKaI EMM. WMbore Imt MaE BY LAST TAG: 7147 CTMOVENTURI KET 12IJ12019 re p Last Raw Reason HANGER ,Ta 4nroMM EM D. 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LEFTSPRING TOGA-2RUNNING TOOLINWELL IPERF:74b.b1,S%0� PfgWCTK)N: 1151-771.11- P7—D 6R6— bZ¢ Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, January 7, 2020 2:41 PM To: Loepp, Victoria T (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3 Subject: RE: KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Follow Up Flag: Follow up Flag Status: Flagged Victoria, Per our conversation, I would like to update you on 3Q-04 progress towards cement packer repair: On 12/31/2019, the cement and cement retainer were milled out to the top of the retrievable bridge plug at 7,148 CTMD. The next step in the procedure was to pull the plug and proceed with uphole cement packer repair. However, initial efforts to pull the plug have failed due to cement/debris from the first cement packer repair attempt. Coil tubing will reattempt to pull the plug this week. In the meantime, due to an elevated pressure in the IA of 2250psi (45% casing burst pressure=2241psi), 46 bbls seawater has been bullheaded down the tubing to reduce pressures. Currently, IA pressure is 1378psi. We will continue to monitor the well to ensure pressures remain within tolerance. Also of note, we performed an injectivity test between the packers, at the site of the original cement packer repair, and were able to inject approximately 23 bbls of diesel up to a rate of lbpm through the tubing punches. This indicates that a communication path still exists from tubing to annulus to formation AND/OR tubing to annulus and past one or more of the packers. Once the RBP has been pulled, we would like to set a deeper plug, then run CBL and/or waterflow log in an attempt to evaluate cement and possible channeling behind pipe. Should logging provide us with new information that warrants changes to the planned cement packer repair, we will inform the AOGCC and make the appropriate change of approved sundry request. if you have any questions on our path forward, please contact me. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 10, 2019 8:29 AM To: Simek, Jill <Jiii.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Approval is granted for the changes to the approved sundry as outlined below. Please include this approval with your copy of the approved sundry and have this approval on the job site. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppaalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeao@alaska yov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, December 9, 2019 9:46 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Subject: 3Q-04 Cement Packer Repair (Sundry #319-408) Victoria, Per approved Sundry#319-408, ConocoPhillips has performed the following activity at 3Q-04: 10/22/2019 MIT -IA TO 3000 (PASS). DRIFTED TBG W/ BLB, 2.66" MAGNET TO CMT RETAINER @ 7070' RKB; NO RECOVERY OF CENT ARM LOST 10/14/2019. PULLED DV @ 6222' RKB, PUMPED 3 BBLS @ 1/2 BPM DOWN TBG WHILE BLEEDING OFF IA. JOB COMPLETE. 10/16/2019 (AC EVAL) IA DDT (FAIL) REVERSE IA LLR (0.59 GAL / MIN) 10/14/2019 PULLED E -LINE TOOLSTRING STUCK IN GLM # 2 @ 4325' RKB "MIDDLE BOWSPRING CENT BROKE, LEFT 1/2 OF SPRING LEG IN WELL". DRIFT TBG w/ 2.13" MAGNET TO CEMENT TAG @ 7026' SLM, NOTHING RECOVERED ON MAGNET. COMPLETE 10/11/2019 LOG SCMT TO DETERMINE TOP OF CEMENT IN IA. LOGGED 2 PASSES UP FROM CEMENT RETAINER AT 7070' TO 6000'. TOP OF GOOD CEMENT FOUND AT ^'6810' TRANSITIONS TO CLEAN FREE PIPE AT -6450'. TOOLSTRING STUCK IN MANDREL AT 4325', PULL OUT OF ROPE SOCKET LEAVING 1.1875" FN AT -4300'. SCMT LOGGING COMPLETE. 9/26/2019 PUMP 3 BBLS DIESEL DOWN TBG. TBG PSI'D UP TO 3000 PSI, IA DID NOT TRACK PERFORM MIT -T TO 3000 PSI TBG GAINIED 10 PSI OVER 30 MIN, IA GAINED 260 PSI JOB COMPLETE 9/26/2019 SHOT TUBING PUNCH FROM 7040'- 7044'.4 SPF, 0 DEG PHASING. CCL TO TOP SHOT: 6.7'. CCL STOP DEPTH: 7033.3'. LOG CORRELATED TO JEWELRY LOG DATED 07 -AUGUST -2019. Because cement was encountered in the IA after perforating at 7,040ft-7,044ft KB, and circulation could not be achieved, ConocoPhillips requests to amend the remaining steps in the procedure as outlined below. Please let me know if AOGCC approves these changes. PROCEDURE: SL — Set DV 1. MIRU SL 2. Set DV in open GLM at 6,222ft KB. 3. RDMO CTU - Mill cement and retainer (from first cement packer repair attempt) 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and cement retainer, taking returns off tubing to tanks. Cement retainer expected at-7,070ft KB. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-7,160ft KB. 4. RDMO. Well ready for DSL. DSL- Pull and set plugs set DV punch tubing infectivity test 4. MIRU DSL. S. Pull catcher on RBP at 7,160ft KB. 6. Pull RBP at 7,160ft KB 7. Set RBP at 6,440ft KB. 8. Set catcher on RBP. 9. RIH with 2.5" dump bailer and dump 15ft of sand on top of RBP/catcher. 10. RIH with tubing punch (4' of 4SPF) and punch holes at 6,411ft - 6,415ft KB. 11. Pump 20 bbis of diesel down the tubing to confirm injectivity. 12. RDMO. Well ready for CTU. CTU - Set retainer, pump cement 5. MIRU CTU and Cementers. 6. MU and RIH with 3.5" Weatherford millable cement retainer. 7. Tag top of sand for depth correction. Top of sand should be at 6,425ft KB. 8. Set W FD cement retainer at 6,400ft KB. 9. Come online with diesel pumping 10 bbis diesel lead (assuming CT is fluid packed with diesel at this point). 10. Follow diesel with 5 bbis fresh water spacer. 11. Follow fresh water spacer with 16 bbis of 15.8 ppg Class "G" cement. 12. Follow cement with 5 bbis fresh water spacer. 13. Follow fresh water spacer with diesel. 14. Once all of cement is out of nozzle, unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 15. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi. Eline - Loa SCMT 1. MIRU Eline. 2. RIH and tag cement retainer at 6,400ft KB. 3. Log SCMT from cement retainer to above IA TOC. 4. RDMO. CTU- Mill cement/retainers 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and retainer, taking returns off tubing to tanks. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-6,440ft KB, 4. POOH. RDMO. Well ready for SL. SL - GLD 1. MIRU SL. 2. Pull DMY valves from GLD. 3. Install GLD 4. PT tubing to ensure valves are holding or DD M. 5. Pull catcher. 6. Pull RBP at 6,440ft KB. 7. RDMO. Turn well over to Ops to BOL. Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 6 Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cella 907-980-7503 Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, December 29, 2019 12:59 PM To: Loepp, Victoria T (CED) Subject: Re: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I just wanted to follow up and let you know that coiled tubing was able to move onto 3Q-04 this morning and has begun the procedural steps for the cemented packer repair. They started milling out the original cement retainer today. Sincerely, SarcoCarW& (Xesk6w) /'R ache-( Ka4,Ltk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 Sara e carlisle@cop.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, December 26, 2019 9:34 AM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: Re: [EXTERNAL]Re: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Dusty, This needs to be addressed as soon as conditions permit. Thanx, Victoria Sent from my iPhone On Dec 24, 2019, at 1:49 PM, Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> wrote: Victoria - One option is to pull a dummy valve and circulate weighted fluid into the IA however, slick line units are actively laying down their cranes due to low temperature restraints. Based on the weather forecast of continued cold weather and then elevated winds, that may not be a timely option. Bleeding fluid off the IA will potentially exacerbate the issue as the well is loaded with corrosion inhibited seawater with a diesel freeze protect. Because we would be inflowing well bore fluids, we have the potential for both freezing off the well and replacing the heavier seawater with lighter crude oil causing our surface pressure to increase. I talked with the production engineer responsible for prioritization and he is going to move it to a very high priority. CTU will potentially be moving to 24 hour operations as soon as the cold/weather allows. At that point in time it will be a top priority to get the packer repair procedure back in motion. If this is not an acceptable approach, please let me know and we can further discuss ideas on how to address the elevated IA pressure. Thank you. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 <image001.png> From: Loepp, Victoria T (CED) <victoria loepp@alaska.eov> Sent: Tuesday, December 24, 2019 12:37 PM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophi11ips.com> Subject: [EXTERNAL]Re: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure What other alternatives do you have? Sent from my iPhone On Dec 24, 2019, at 10:47 AM, Well Integrity Compliance Specialist WNS & CPF3 <n2549 conocophillips.com>wrote: Victoria - 3Q -04 was reported by operations with an IA pressure of 2250 psi which exceeds 45% of the casing burst pressure of 2241 psi. CPAI previously applied and received an approved 10-403 (Sundry #319-268 and change of approval #319-408) for a cement packer repair. The cement packer repair prep work is in progress and the first step has been completed. At this point in time due to vendor equipment issues the progress is on hold until CTU repairs are completed. At that point in time the progress will resume with an elevation of priority within our normal prioritization process. Please let us know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 <image001.png> From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, July 28, 2019 9:02 AM To:'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.Qov> Cc: CPA Wells Supt <n1030 conocophillips.com> Subject: RE: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Victoria, As previously reported 6.16.19 Kuparuk producer 3Q-04 (PTD 191-124) experienced SCP of the IA. The IA was loaded with fluid to reduce the IA pressure below the DNE where it remained until recent well work has caused the IAP to increase to —2100 psi. A work plan is in progress as per approved sundry # 319-268. CPAI intends to leave the pressure as is until the work has been completed. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhiliips Alaska, Inc. Office phone: (907) 659-7224 <image001.png> From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, June 16, 2019 1:42 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Hi Victoria, Kuparuk producer 3Q-04 (PTD 191-124) is experiencing sustained casing pressure on the inner annulus after being shut-in on April 11", 2019. The IA pressure recorded today was 2100 psi. The production casing is 7" 26# 1-55 with an internal yield rating of 4,980 psi (45% here is 2,241 psi). CPAI will load the well with fluid to reduce the IA pressure below DNE while we progress a repair option for the well. Please let us know if you have any questions or disagree with this plan. Sincerely, S"WCcwUa& (U"4w) w) / 2aJtieV Kautk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 I n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com <3Q-04.pdf> <3Q-04 APPROVED 10-403 Repair Well, Cement Pkr Sundry App.pdf> <3Q-04 APPROVED 10-403 Change of Approved Program Sundry Application.pdf> KUP PROD WELLNAME 3Q-04 WELLBORE 3Q_04 ConocOPhill! -� Ala6ka, 1110. Well Attributes Ne11A gleaMD TD IR dHme Wellban AFinning WNlhore losing ntl (') M.pagal An1eMIfIKa) KUPARUK RIVER UNIT 5002922219110 PROD 916 2,300.00 ],]250 Canmenl HEe 1pPm1 Uel^ MnolnHo.a End Dain KB-Ging% Wg Rei -a SSSV. 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ID(in)4 6,131.8 30.45 PER BAKER 80-00 PER 4.005 6,151.] 30.46 PACKER BAKER FHL RETRIEVABLE PACKER 47132 SH BOK 2.960 7,097.3 4170.4 30.48 NIPPLE CAMERON DS NIPPLE 2AIr 2.812 7,360.5 6,39T.-4 31.21 -LOUT-OR BAKER NO GO LOCATOR SUB 2.992 7381.3 5,391.1 31.21 SHOE BAKER MULE S OE 2.992 Tupin00s¢dPHon BMnB Ya... 1011121 Top IHNB) 7.39. bb (a- Capin (TV%1 Wt1aM1 GnM Tap Cennec-on TUBING-otlgbnal 55/8 2.94 ],3834 ],3985 8,4298 Completion Details Top jNO) TOP lets R.. .1 TOP 61KBI (fIKB) (°I "R -x CM, IO Pan 7,363.4 3981 31.21 PER AMCO MR, 10- larblaa, 5.625° OD Bbl, 2.931° ID (30" Shear) 2931 7, M.B 6,4106 312A ACKE CAM Hfl-0AP'Retr Pp, 60K#pull or not release, 5.93] 00, 2.867 2.86]90 7,391.2 6,422.1 31.26 N LE AM V Nipple W275• Packing bore. 2.750 1,398. 64292 31 27 SOS CRAIM PE -500 Shenrout Sub 2.992 Other In Hob ipaline reirlevable, plugs, valvas, pumps, leh, etc.) Top flb,I Top mM T (NKR) MS) 1°I m Corn Run 41. 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PM81n TRORun Yap "S)MM) sales Medal OD IIn) sub, Typ Type On) get Ran. one 1 2,887.9 2,607A CAMCO MMG 1112 GAS LIFTO RK D.0 0.0 412]12019 2 4,325.4 3,79].4 CAMCO M 1112 GAS,,, DMY RK 0. 00 0.0 4427=1 5.395. 4,890.6 CAMCO RAW 111GAS LIFI JUMY IRK I U.OW 0.0 4 ]12019 4 6, 2.2 5,410.7 CA . MMG 1112 GAELHFL DMY IMM 1 0.000 0.0 412]20 9 5 6, 90. 6,078.0 5W -W MW 1112 GAS LI DMY RK 0.0 0 0 412 12019 Rog$: Gammill Bl Safety End DSM AnnMaKon 1 9 2812 0 0 9 NOTE: IEW SCH MATICW/Alaag; Schemara.0 10/2012013 NOTE: LE SPRUNG TO GA-2RUNNINGTOOL INWELL Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, December 24, 2019 10:46 AM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist WNS & CPF3 Subject: FW: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Attachments: 3Q-04.pdf; 3Q-04 APPROVED 10-403 Repair Well, Cement Pkr Sundry App.pdf; 3Q-04 APPROVED 10-403 Change of Approved Program Sundry Application.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria - 3Q -04 was reported by operations with an IA pressure of 2250 psi which exceeds 45% of the casing burst pressure of 2241 psi. CPAI previously applied and received an approved 10-403 (Sundry #319-268 and change of approval #319-408) for a cement packer repair. The cement packer repair prep work is in progress and the first step has been completed. At this point in time due to vendor equipment issues the progress is on hold until CTU repairs are completed. At that point in time the progress will resume with an elevation of priority within our normal prioritization process. Please let us know if you have any questions or disagree with the plan. Dusty Freebom/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Cono� From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, July 28, 2019 9:02 AM To: 'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Victoria, As previously reported 6.16.19 Kuparuk producer 3Q-04 (PTD 191-124) experienced SCP of the IA. The IA was loaded with fluid to reduce the IA pressure below the DNE where it remained until recent well work has caused the IAP to increase to —2100 psi. A work plan is in progress as per approved sundry # 319-268. CPAI intends to leave the pressure as is until the work has been completed. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM C.a�Ps From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, June 16, 2019 1:42 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Hi Victoria, Kuparuk producer 3Q-04 (PTD 191-124) is experiencing sustained casing pressure on the inner annulus after being shut- in on April 11th, 2019. The IA pressure recorded today was ^2100 psi. The production casing is 7" 26# J-55 with an internal yield rating of 4,980 psi (45% here is 2,241 psi). CPAI will load the well with fluid to reduce the IA pressure below DNE while we progress a repair option for the well. Please let us know if you have any questions or disagree with this plan. Sincerely, Sara.CarUs & (Ue4") /ZadwabKa &k Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com PTD l9/- 17- Loepp, 2 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, December 10, 2019 8:29 AM To: Simek, Jill Subject: KRU 3Q-04(PTD 191-124, Sundry 319-408) Cement Packer Repair Changes Approval Approval is granted for the changes to the approved sundry as outlined below. Please include this approval with your copy of the approved sundry and have this approval on the job site. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppOalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victo0a.Loeco@alaska yov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, December 9, 2019 9:46 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3Q-04 Cement Packer Repair (Sundry #319-408) Victoria, Per approved Sundry#319-408, ConocoPhillips has performed the following activity at 3Q-04: 10/22/2019 MIT -IA TO 3000 (PASS). DRIFTED TBG W/ BLB, 2.66" MAGNET TO CMT RETAINER @ 7070' RKB; NO RECOVERY OF CENT ARM LOST 10/14/2019. PULLED DV @ 6222' RKB. PUMPED 3 BBLS @ 1/2 BPM DOWN TBG WHILE BLEEDING OFF IA, JOB COMPLETE. 10/16/2019 (AC EVAL) IA DDT (FAIL) REVERSE IA LLR (0.59 GAL / MIN) 10/14/2019 PULLED E -LINE TOOLSTRING STUCK IN GLM # 2 @ 4325' RKB "MIDDLE BOWSPRING CENT BROKE, LEFT 1/2 OF SPRING LEG IN WELL". DRIFT TBG w/ 2.13" MAGNET TO CEMENT TAG @ 7026' SUM, NOTHING RECOVERED ON MAGNET. COMPLETE 10/11/2019 LOG SCMT TO DETERMINE TOP OF CEMENT IN IA. LOGGED 2 PASSES UP FROM CEMENT RETAINER AT 7070' TO 6000'. TOP OF GOOD CEMENT FOUND AT ^'6810' TRANSITIONS TO CLEAN FREE PIPE AT "'6450'. TOOLSTRING STUCK IN MANDREL AT 4325', PULL OUT OF ROPE SOCKET LEAVING 1.1875" FN AT -4300% SCMT LOGGING COMPLETE. 4P 3 BBLS DIESEL DOWN TBG. PSI'D UP TO 3000 PSI, IA DID NOTTRACK rORM MIT -T TO 3000 PSI GAINIED 10 PSI OVER 30 MIN, IA GAINED 260 PSI COMPLETE 9/26/2019 SHOT TUBING PUNCH FROM 7040'- 7044'. 4 SPF, 0 DEG PHASING. CCL TO TOP SHOT: 6.7'. CCL STOP DEPTH: 7033.3'. LOG CORRELATED TO JEWELRY LOG DATED 07 -AUGUST -2019. Because cement was encountered in the IA after perforating at 7,040ft-7,044ft KB, and circulation could not be achieved, ConocoPhillips requests to amend the remaining steps in the procedure as outlined below. Please let me know if AOGCC approves these changes. PROCEDURE: SL - Set DV 1. MIRU SL 2. Set DV in open GLM at 6,222ft KB. 3. RDMO CTU - Mill cement and retainer (from first cement packer repair attempt) 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and cement retainer, taking returns off tubing to tanks. Cement retainer expected at-7,070ft KB. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-7,160ft KB. 4. RDMO. Well ready for DSL. DSL- Pull and set plugs, set DV, punch tubing infectivity test 4. MIRU DSL. 5. Pull catcher on RBP at 7,160ft KB. 6. Pull RBP at 7,160ft KB 7. Set RBP at 6,440ft KB. 8. Set catcher on RBP. 9. RIH with 2.5" dump bailer and dump 15ft of sand on top of RBP/catcher. 10. RIH with tubing punch (4' of 4SPF) and punch holes at 6,411ft - 6,415ft KB. 11. Pump 20 bbls of diesel down the tubing to confirm injectivity. 12. RDMO. Well ready for CTU. CTU - Set retainer, pump cement 5. MIRU CTU and Cementers. 6. MU and RIH with 3.5" Weatherford millable cement retainer. 7. Tag top of sand for depth correction. Top of sand should beat 6,425ft KB. 8. Set WFD cement retainer at 6,400ft KB. 9. Come online with diesel pumping 10 bbis diesel lead (assuming CT is fluid packed with diesel at this point). 10. Follow diesel with 5 bbls fresh water spacer. 11. Follow fresh water spacer with 16 bbls of 15.8 ppg Class "G" cement. 12. Follow cement with 5 bbls fresh water spacer. 13. Follow fresh water spacer with diesel. 14. Once all of cement is out of nozzle, unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 15. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi. Eline — Loc SCMT 1. MIRU Eline. 2. RIH and tag cement retainer at 6,400ft KB. 3. Log SCMT from cement retainer to above IA TOC. 4. RDMO. CTU- Mill cement/retainers 1. MIRU CTU. 2. RIH with milling assembly and mill up cement and retainer, taking returns off tubing to tanks. 3. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at-6,440ft KB. 4. POOH. RDMO. Well ready for SL. SL - GLD 1. MIRU SL 2. Pull DMY Valves from GLD. 3. Install GLD 4. PT tubing to ensure valves are holding or DD IA. S. Pull catcher. 6. Pull RBP at 6,440ft KB. 7. RDMO. Turn well over to Ops to BOL. Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 Cell: 907-980-7503 3 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: N/ AOGCC �.. ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision Y" 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 1911.24 3 137 8 WELL NAME 1F-14 30.04 API # 50.029-21022-00 50-029-22219-00 SERVICE ORDER # DWUJ-11034 DWUJ-00133 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVERWWL SERVICE WL DELIVERABLE DESCRIPTION PPROMCALIPER DATA TYPE FINAL FIELD9 FINAL FIELDU21-00-19 -Color DATELOGGED Prints 9 CIA 1 1 1B-03 50.029-20588.00 DWUJ-00136 KUPARUK RIVERFINAL FIELD9 1 1D -04A 50-029-20416-01 DWUJ-00132 KUPARUK RIVERFINAL FIELD9 1 31-08 50-029-21550-00 DWUJ-00137 KUPARUK RIVERFINAL FIELD 1 1D -04A 50-029-20416-01 EDWI-00025 KUPARUK RIVERFINAL FIELD 1 2N-329 50-103-20257-00 DWUJ-00143 KUPARUK RIVERFINAL FIELD 9 1 7 ittal return via courier or sign/scan and email a copy to A Transmittal Receipt signature confirms that a package (box �! and CPAI. SLB Auditor - Schlumberger -Private envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. WELL LOG TRANSMITTAL #905827540 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch and Plug Setting Records: 3Q-04 Run Date: 7/9/2019 19 1124 3120 1 September 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 30-04 Digital Data in LAS format, Digital Log Image file 50-029-22219-00 Ike1 CD Rom SF �'bF 01-10 C rLEASE AUKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: THE STATE °fALAS- A GOVERNOR MIKE DUNLEAVY Jill Simek Staff Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-04 Permit to Drill Number: 191-124 Sundry Number: 319-408 Dear Ms. Simek: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J) J sie L. Chmielowski Commissioner DATED this I � day of September, 2019. RBDMS !E!' SEP 12 2019 RECEIVE® SEP 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Programp Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Con000Philli sAlaska Inc. Exploratory ❑ Development 21 • Stratigrephic ❑ Service ❑ 191-124 ' 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-22219-00 7. If perforating: 8. Well Name and Number: s..y,il What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3Q-04 Will planned perforations require a spacing exception? Yes 11No 10 9. Property Designation (Lease Number): 10. FieldlPool(s): 4 -46-5-1,x2_ ADL 373301 ' Kuparuk River Field/ Kuparuk River Oil Pool ' 11. 1! ^4 g q,/sj PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,725' 6,709' 7630 6627 3250 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 82' 16" 123' 123' Surface 4,476' 11" 4,518' 3,955' Production 7,700' 7" 7,716' 6,701' Perforation Depth MD (ft) 113eftration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7475-7483, 7483-7495, 6494-6501, 6501-6511, 3.500" J-55 7.399' 7498-7 6514-654 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER FHL RETRIEVABLE PACKER 47B2 SHEAR 60K MD= 7076 TVD= 6152 PACKER - CAMCO HRP -I -SP Reb. Pkr. MD= 7377 TVD= 6410 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: , Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 9/12/2019 15. Well Status after proposed work: Commencing Operations: OIL p WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ' R,t� GSTOR 13 SPLUG ❑ A: 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Wells Engineer Contact Email: lill.simek@cop.com Contact Phone: (907) 2634131 Authorized Signature: Date: Q 6 111 COMMISSION USE ONLY Conditions of approval: Notify mission so that a representative may witness Sundry Number: U Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. y Req'd? RBDMS �� SEP 12 2019 Post Initial Injection MIT Yes ❑ Not, Spacing Exception Required? Yes ❑ No L� Subsequent Form Required: 162-4,04 ' APPROVED BY 4 Approved by: , ` �� COMMISSIONER THE COMMISSION Date: ITL 9l/0I/9 rel �% 7;:rs A ORIGINAL ���p, Submit Form and Form 10 Revised 4/2017 !� A ` 4 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips 3Q-04 Request for Change of Approved Program Permit to Drill #: 191-124 Sundry #: 319-268 ConocoPhillips hereby applies for Change of Approved Program to Sundry #319-268 (3Q-04 cement packer repair). The new 3Q-04 cement packer repair procedure adds steps to place cement in the IA / above the top packer. These steps come after the failed cement packer repair attempt, performed July 2019, where IA cement was placed between the top and bottom packer. PROCEDURE: Eline - Punch tubing, infectivity test 1. MIRU Eline and associated support equipment. 2. RIH with tubing punch (4' of 4SPF) and punch holes at 7,047ft-7,051ft KB. 3. Pump 20 bbls of diesel down the tubing to confirm injectivity. i. Record rates and pressures while holding IA closed (attempt to inject down IA past packer). ii. Record rates and pressures while taking returns on IA. 4. RDMO. Well ready for CTU. CTU - Set retainer/pump/squeeze cement 1. MIRU CTU and Cementers. 2. MU and RIH with 3.5" Weatherford millable cement retainer. 3. Tag top of cement for depth correction. Cement top/retainer should be @ 7,070ft KB. 4. Set WFD cement retainer @ 7,035ft KB. 5. Come online with diesel pumping 10 bbls diesel lead (assuming CT is fluid packed with diesel at this point). 6. Follow diesel with 5 bbls fresh water spacer. 7. Follow fresh water spacer with 10 bbls of 15.8 ppg Class "G" cement. 8. Follow cement with 5 bbls fresh water spacer. 9. Follow fresh water spacer with diesel. 10. Monitor IA pressure during pumping. Bleed IA to maintain constant pressure at packer. 11. Once all of cement is out of nozzle, or "squeeze pressure" is seen ("'200psi above pump pressure), unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 12. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi. JS CTU- Mill cement/retainer 1. RIH with milling assembly and mill up cement and retainers, taking returns off tubing to tanks. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at 7,160ft KB. 3. POOH. RDMO. Well ready for SL. SL - GLD 1. MIRU SL and associated support equipment. 2. Pull DMY Valves from GLD. 3. Install GLD 4. PT tubing to ensure valves are holding or DO IA. 5. Pull catcher. 6. Pull RBP at 7,160ft KB. 7. RDMO. Turn well over to Ops to BOL. DHD- TIFL 1. Perform TIFL to ensure packer repair has worked. PREVIOUS STEPS PERFORMED: 8/12/2019 RIH WITH MOTOR AND 2.79" MILL, DRY TAG AT 7046' CTMD (7070' RKB), GET 4 HARD STALLS AND DETERMINE THAT WE ARE ON THE CEMENT RETAINER, DISCUSS PLAN FORWARD WITH TOWN ENGINEER, F/P TBG TO 4000' RKB, READY FOR E -LINE, JOB IN PROGRESS. 8/7/2019 TAGGED CEMENT @ 7070'. PERFORM JEWELRY LOG OVER INTERVAL 6100,- 7068'. UNABLE TO MAKE IT TO PUNCHER DEPTH. 7/24/2019 (AC EVAL) : MIT -T TO 3000 PSI (PASSED). DDT-TTO O PSI (PASSED). DDT -IA (FAILED). 7/22/2019 PERFORM PASSING MITIA TO 2500 PS, UNABLE TO GET A DRAWDOWN TOO PSI, DISCUSS FINDINGS WITH TOWN ENGINEER, RIH WITH WFT2.72" CONVEX MILL, TAG CEMENTAT 6526' CTMD MILLED DOWN TO CEMENT RETAINER AT 7125' RKB HAD FOUR STALLS PUMP A GEL SWEEP AND CHASE GEL TO SURFACE / PUMP 25 BBLS OF DIESEL FOR FREEZE PROTECT/ RDMO 7/17/2019 RIH TO TAG TOP OF SAFE-CARB AT 7139' RKB, PUH TO 7125' RKB AND SET 3.5" WFT CEMENT RETAINER, PUMP16 BBLS OF 15.8 PPG CLASS "G" CEMENT BELOW RETAINER, UN -STING FROM RETAINER AND PUMP SLICK DIESEL TO SURFACE, RETURN IN 72 HOURS TO MILL OUT RETAINER, JOB IN PROGRESS. 7/10/2019 TAG TOP OF SAFE CARB @ 7139' RKB, SHOOT 2' OF 4 SPF TBG PUNCH @ 7135' RKB, LRS PREFORMED INJECTIVITY TEST @ 1.25 BPM @ 2450 PSI FOR 20 BBLS READY FOR CTU. 7/9/2019 BRUSHED & FLUSHED TBG F/ 7103'- 7253' RKB. SET 2.725" RBP (P2P #CPP35212, EQ VLV #CPEQ35014) MID-ELEM @ 7160' RKB. DUMP 2 GAL'S OF SAFE CARB ON RBP, SET 2.77 x 59" CATCHER ON TOP OF RBP @ 7158' RKB, DUMP BAILED - 15' OF CARB SAFE ON TOP OF RBP/ CATCHER TOP OF SAND @'" 7143' RKB. IN PROGRESS. 7/4/2019 PULLED CATCHER & CA -2 PLUG @ 7097' RKB; TAG TO @ 7562' RKB (EST. 87' RAT HOLE) & MEASURED BHP @ 7500' RKB. SBHP OF 4,453 PSI MEASURED. JOB COMPLETE & READY FOR RELAY. IIA Current 3Q-04 Cement Packer Repair Proposed 16' 62.5# H-40 Conductor @ 123' KB � I I I I L Cameron IDS' Nipple @ 515' KB /8" 36# J-55 Surface Casing @ 4,518' KB rM W Upper Packer at 7,076' KB Leak (unknown depth, between packers) Tubing Punch @ 7135' KB Lower Packer at 7,377' KB Tubing Tail @ 7,400' KB 26# J-55 Production Casing @ 7,716' KS 314P4 ivO 1� "TOC in IA @ 6,700' KB Tu in Punch @ 7,047-7,051' KB 719.6 JS 9-4-2019 KUP PROD WELLNAME 3Q-04 WELLBORE 3Q-04 C/�/�/�/w r'� r anoeoPhflU(ps ida6Ka, III,. Well Attributes Max Angle &MCI 10 Field Name .11WreAPVUW Well ores lua 1-1 MDIflNaI /+ct9lminN81 KUPARUK RIVER UNIT 500292221900 PROD 9]6 2.3 K050I )]250 COmmenl Nl3ppm1 Oab Annahnon Ene Da@ NBGre lfll Rip ReNeae DaM SSS-711PPLE 175 12([32012 Last WO'. 12512013 40.99 71911992 yJM,B^ .a.IS PY I Last Tag gab+I rilsrnEc ladW) An"2 b DepM IXK01 Ene.. wellborn I Iaat MeeeY Lase Tag: RKB(ESL BT of Rat Hole) ],ah"D III4I2019 30-04 zembeej _........... ....... ..........__ ....... Last Rev Reason XPNGER; 3]e COND.CTON: 41 D1MO NIPPIs:51ae G43 LIR, 18979 GnbNR:l3xS+ SGRPACEQx1.177 Gas LIR; s.as+ Gna uR; S222 Gas uR:6.wm LOCKPOR'. 7.062 PIR:7.0 PACKER. 70155 NIPPLE:7.0 cemewsP.rw.; 7,lzsoas CmxnIRNY.aC T.1zxD Thig Pa 'jar.. sam:],13e.D CaMxr T.158.D P .wwariten.I.aam.D LourDR', T.3m.a SHOE:7.361.3 VBR:L3W4 PACKER TS76.8 NIPPLIS13913 sos?.nae FISH; 1410 n 11m.;7axs0 IPERS', nano;+e30- IPEgP: T+99.D753e.o----- Pq�ULTKIN: 1577>18p UA E e i Annobtlon End DNe WelRore Last MW By Rev ReasonSet RBD, Catcher and Dump Bail a Carb 711012019 30-04 Ithrerlin Casing Strings Lasing DeicnpVon DD (n1 ID lin) ToplXNal Set DeplM1 (XNaI :iet Oepin IND1.. WVLen 11... Grave Top ibreW CONDUCTOR 16 15.06 410 123.0 1230 6250 HAO Caamq Dea nuumn DD nnl l0(in) Tap Me) sN Drom MB) sd 0epnrlrvDl... 3600Iventraa...1 Grade Toprnroae SURFACE 9518 8.83 422 4,51]] 3955.1 J6.00 J-55 BTC Culnq Oescnplbn ODINI -an) Top IflKB) SN Depen temen tat- (IVDL.. WVLen p... Grave OpThread PRODUCTION ] 6.26 157 ],]160 6]01.5 26.00 J-55 SITE Tubing Strings Tubing Deacnm1h slrine Ma... ID lint rop lXNal IS. Dapm ltt.. set Delnn lrvDl l... wlpb'X) GrvJe Tap cnnrrxtion TUBING WO 3112 299 380 ],0524 6,1310 930 L-80 EUE Completion Details iop P -VD) Top Incl Nominal TOIFHHSN ;iatn (') Ilem Daa Com m(n) 3801 37.9 0.11 HANGER CAMERON GEN IV TUBING HANGER 2992 514.6 514.6 1]t NIPPLE CAMERON - DT NIPPLE 33A28]5 2.875 >,0452 61256 30.45 LOCATOR BAKERL ATOR SUB 2.990 Tublrp On[ripVOn $Mnq Ma... ID llm Top lkNm SN DepIh IX..Ser Demn (WD) I.. WIIIdM1I Grade TOp Lonnaceon STACKERPACKER 3112 2.99 ],052.4 )3]O.] 6.405.2 9.30 L-80 EUE Completion Details man(rv.) TOP enol Nominal TOPmKS) RK&) 1.1 II.. Des cam ID Iii) 7,0524 6,131.8 3045 PBR BAKER80 PBR 4000 ],0]5.5 6,1513 3046 PACKER BAKER FHL RETRIEVABLE PACKER 47B2 SHEAR 60K 2.950 ],09].3 6,1704 30.48 NIPPLE CAMERON DS NIPPLE 2. 12• 2812 7,360.5 6,396.4 31 21LOCATOR BAKER NO GO LOCATOR SUB 2.992 7,361.3 ,397.1 31.1 SHOE BAKER MULE SHOE .992 Tube, Deacnmian Sting Me...10 dr) TGIF (Po(B) &rt DepM (fl.. SH Demh nVD11... Wllldlq Grave TbPCwrrccOar, TUBING-onginal 55/8 2.94 ],3634 7,399.5 15,429 8 Completion Details TOP ITVDt Top Incl Hommel Top(ME) INKS) t•) 11em Des can ID (in) 7,383.4 6, 98.9 31.21 PBR CAMCO PBR, 1D'seoke, 5.62Y OD Bbl, 293T ID (30K# Shear) 2 937 ],3]6.8 6,d 0.4 3124 PACKER GAIATO'HRP-TTP Bar K#pull or rot release, 5. D, 287 2.86TID ],3912 642,7 3126 NIPPLE CAMCO 'U Nipple.1275- packing bore. 2750 ],3988 6.429.2 312] SO CAMCO PE -500 Shermue Sub 2992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top 0' Top Incl Tam(mal Iflrce PI Des Lon. Runeae m[n) ],125.0 6,1 .3 30.53 emem ]11]12019 0.000 RelBinet ],1350 6,202,91 30.56 Tubing Punch Tubing Punch. 2'o 4 SPF 7/10/209 29 ],139.0 6,2 0641 M57 Sand ' Df Sak-Carb ]192 19 0. 0 7,158.0 6.2 ] 30.61 Catcher N 59- Catcher On RB etween REP and 2 gal's 7192 19 0000 of Sade Carle) ],160.0 6. 4.5 306179S -e-71- 3-1 'RSP P2 #CVP352l2 ad ED VLV llCPE035014 ]5 12019 0.000 Bridge Plug TOMT ],4100 6,4 31.2] FISH Sprang to GA -2 Running Tool 0.000 ]4250 6451.6 J127 FISH 100 Id CDPS Left in Well Removed Tree Saver 41261199] OW0 Perforations & Slots Top(MB) 6Yn are) TopmD) dIKa1 91m (TND) IRKe) unkW zone Dm an., Den ISholate 1 Type cam 7,475.0 7483,0 6,49+.3 8,501.2 C-1, A-,30-04 2]1311992 4.0 1PERF 4112• sA un; 80 deg. phasing ],4830 7p 5.0 6,501.2 8,511.4 C-1, A-2,30-04 2]1311992 4.0 (DERE 41 sA ug18 deg. phasing 7,4980 7,538.0 6,5140 6,5462 A -1,30-D4 2/111992 4.0 (PERF 41 s9 me 1REd.9. phasing Cement Squeezes T0p25Bbn TapND) m(arell Das LOm ...;:j . 7,1250 7,1399 b.194.3 b,dm04jr,SNNrm Squeeze Mandrel Inserts an . N TopngD) VWa Lain POI. si:e rRgen TOP 00111 east IMke MWeI DD led &ery Typ Type I. IpslI Run Doh Com 2,887. 2,607.4 I CAMCO MMG DMV RK 0.000 00'"'A19 2 4,3254 3,]9]4 CAMCO MMG DMY RK 0.000 0.0 N2]IE 3 5,3 54 d,fi90. CAMCO MMG DMY RK 0.000 0.0 4IZIIX119 RDMY 4 6,222.2 5010.1 AMCO MM Y RK 0000 0. 412712019PERS:[a6361,asa0� 5 6990.1 6,078.0 CAMCO MMG DMY RK 0.000 0.0 4/2712019 Notes: General 8 Safety End Data I AnndalWn 111291209 ]NO TE VIEW SCHEMATIC wlAlaska S1hema0c9.0 102 013 NOTE LEFT 5PRINU I V Un, RUNNIN TOOL IN WELL Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, September 5, 2019 10:09 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]RE: KRU 3Q-04 (PTD 191-124, Sundry 319-268) Cement Packer Repair Attachments: 3Q-04 Cement Packer Repair 9-5-2019.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Attached is the requested schematic, showing proposed packer repair with planned IA TOC at—6,700ft KB. I will call to discuss steps to obtain "change of approved sundry". Thanks, Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, September 05, 2019 9:28 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3Q-04 (PTD 191-124, Sundry 319-268) Cement Packer Repair The scope of this sundry has changed enough(IA cement packer squeeze -above packer) that a change of approved sundry is required. Thanx, Victoria From: Loepp, Victoria T (CED) Sent: Tuesday, September 3, 2019 10:46 AM To: Simek, Jill <JiILSimek@conocophillips.com> Subject: KRU 3Q-04 (PTD 191-124, Sundry 319-268) Cement Packer Repair Please provide schematic showing tubing punch, leak locations and TOC planned in IA. What is the planned TOC of the cement packer in the IA? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loew(adalaska. qoy CONFIDENFIAUTY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria Loeoo a'alaska From: Simek, Jill <Jill.Simek conocophillips.com> Sent: Thursday, August 22, 2019 10:53 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Subject: RE: (EXTERNAL]Re: 3Q-04 Cement Packer Repair (Sundry #319-268) Victoria, Due to tagging cement high (7,070ft vs expected 7,125ft), we would like to amend the 3Q-04 cement packer repair procedure, to place cement in IA ABOVE the top packer, rather than between top and bottom packers, as previously planned. Steps are below. Please let me know if the AOGCC approves these changes. Eline - Punch tubing, injectivity test 1. MIRU Eline and associated support equipment. 2. RIH with tubing punch (4' of 45PF) and punch holes at 7,047ft-7,051ftKB. 3. Pump 20 bbls of diesel down the tubing to confirm injectivity. i. Record rates and pressures while holding IA closed (attempt to inject down IA past packer). ii. Record rates and pressures while taking returns on IA. 4. RDMO. Well ready for CTU. CTU - Set retainer/pump/squeeze cement 1. MIRU CTU and Cementers. 2. MU and RIH with 3.5" Weatherford millable cement retainer. 3. Tag top of cement for depth correction. Cement top/retainer should be @ 7,070ft KB. 4. Set WFD cement retainer @ 7,035ft KB. S. Come online with diesel pumping 10 bbls diesel lead (assuming CT is fluid packed with diesel at this point). 6. Follow diesel with 5 bbls fresh water spacer. 7. Follow fresh water spacer with 10 bbls of 15.8 ppg Class "G" cement. 8. Follow cement with 5 bbls fresh water spacer. 9. Follow fresh water spacer with diesel. 10. Monitor IA pressure during pumping. Bleed IA to maintain constant pressure at packer. 11. Once all of cement is out of nozzle, or "squeeze pressure" is seen (^200psi above pump pressure), unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 12. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi. CTU- Mill cement/retainer 1. RIH with milling assembly and mill up cement and retainers, taking returns off tubing to tanks. 2. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at 7,160ft KB. 3. POOH. RDMO. Well ready for SL. SL - GILD 1. MIRU SL and associated support equipment. 2. Pull DMY valves from GLD. 3. Install GLD 4. PT tubing to ensure valves are holding or DD IA. 5. Pull catcher. 6. Pull RBP at 7,160ft KB. 7. RDMO. Turn well over to Ops to BOL. DHD-TIFL 1. Perform TIFL to ensure packer repair has worked. Thanks, Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, July 29, 2019 9:36 AM To: Simek, Jill <JiILSimek@conocophillips.com> Subject: [EXTERNAL]Re: 3Q-04 Cement Packer Repair (Sundry #319-268) Approval is granted for the reattempt of the packer repair as outlined below. Thanx, Victoria Sent from my iPhone On Jul 29, 2019, at 9:20 AM, Simek, Jill <JiII.Simek@conocophillips.com> wrote: Victoria, Per approved Sundry procedure (attached), ConocoPhillips has recently attempted the cement packer repair on 3Q-04. The post -repair MIT -IA passed to 2500psi. However, the DDT -IA failed, indicating continued communication to the IA from below the production packer at 7,075.5ft KB. ConocoPhillips requests permission to reattempt the repair by reperforating the tubing below the packer and pumping up to 32 bbls additional Class "G" cement into the tubing x production casing annulus, per steps outlined below. Please advise if AOGCC approves these next steps. Eline - Punch tubing, infectivity test 1. MIRU Eline and associated support equipment. 2. RIH with tubing punch (2' of 4SPF) and punch holes at 7,115ft KB. 3. Pump 20 bbls of diesel down the tubing to confirm injectivity (+/- 1bpm @ 2,OOOpsi). LCM additive (CTU - Step #7) will be determined based on this result. 4. RDMO. Well ready for CTU. CTU - Set retainer/pump/squeeze cement 1. MIRU CTU and Halliburton Cementers. 2. MU and RIH with 3.5" Weatherford millable cement retainer. 3. Tag top of cement for depth correction. Cement top/retainer should be @ 7,125ft KB. 4. Set WFD cement retainer @ 7,104ft KB. 5. Come online with diesel pumping 30 bbls diesel lead (assuming CT is fluid packed with diesel at this point). 6. Follow diesel with 5 bbls fresh water spacer. 7. Follow fresh water spacer with 32 bbls of 15.8 ppg Class "G" cement. LCM additive to be determined based on injectivtiy/leak rate established (Eline - Step #3). 8. Follow cement with 5 bbls fresh water spacer. 9. Follow fresh water spacer with diesel. 10. Monitor IA pressure during pumping. Bleed IA to maintain constant pressure at packer. 11. Once all of cement is out of nozzle, or "squeeze pressure" is seen (^200psi above pump pressure), unsting from retainer. Pump any excess cement out of coil, contaminate and circulate out of hole. Ensure well is freeze protected. 12. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD-Pressure test 1. Perform a MITIA to 2,500 psi as well as a DDT to O psi on the IA to confirm that the cement repair is holding in both directions. CTU- Mill cement/retainer 1. RIH with milling assembly and mill up cement and retainers (7,104ft and 7,125ft KB), taking returns off tubing to tanks. 2. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at 7,160ft KB. 3. POOH. RDMO. Well ready for SL. SL - GLD 1. MIRU SL and associated support equipment. 2. Pull DMY valves from GLD. 3. Install following GLD Surf. Surf. TRO MD Valve Valve Port Open Close Press GLM (RKB) Size Name Size Press Press 60° F 1 2887 1.5" Camco_R-20 3/16" 1350 1331 1281 2 4325 1.5" Camco_R-20 3/16" 1325 1311 1274 3 5395 1.5" Camco_R-20 3/16" 1302 1291 1265 4 6222 1.5" Camco_R-20 3/16" 1282 1271 1256 5 6990 1.5" Camco RDO-20 1/4" ------ Orifice ------ 4. PT tubing to ensure valves are holding or DD IA. 5. Pull catcher. 6. Pull RBP at 7,160ft KB. 7. RDMO. Turn well over to Ops to BOL. DHD- TIFL 1. Perform TIFL to ensure packer repair has worked. Summary of recent work: 7/24/2019 (AC EVAL) : MIT -T TO 3000 PSI (PASSED). DDT-TTO 0 PSI (PASSED). DDT -IA (FAILED). 7/22/2019 PERFORM PASSING MITIA TO 2500 PS, UNABLE TO GET A DRAWDOWN TO 0 PSI, DISCUSS FINDINGS WITH TOWN ENGINEER RIH WITH WFT 2.72" CONVEX MILL, TAG CEMENT AT 6526' CTMD MILLED 4 Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 <3Q-04 APPROVED 10-403 Repair Well, Cement Pkr Sundry App.pdf> <3Q-04.pdf> DOWN TO CEMENT RETAINER AT 7125' RKB HAD FOUR STALLS PUMP A GEL SWEEP AND CHASE GEL TO SURFACE / PUMP 25 BBLS OF DIESEL FOR FREEZE PROTECT / RDMO 7/17/2019 RIH TO TAG TOP OF SAFE-CARB AT 7139' RKB, PUH TO 7125' RKB AND SET 3.5" WFT CEMENT RETAINER, PUMP16 BBLS OF 15.8 PPG CLASS "G" CEMENT BELOW RETAINER, UN -STING FROM RETAINER AND PUMP SLICK DIESEL TO SURFACE, RETURN IN 72 HOURS TO MILL OUT RETAINER, JOB I PROGRESS. 7/10/2019 TAG TOP OF SAFE CARB @ 7139' RKB, SHOOT 2' OF 4 SPF TBG PUNCH @ 7135' RKB, LRS PREFORMED INJECTIVITY TEST @ 1.25 BPM @ 2450 PSI FOR 20 BBLS READY FOR CTU. 7/9/2019 BRUSHED & FLUSHED TBG F/ 7103'- 7253' RKB. SET 2.725" RBP (13213 #CPP35212, EQ VLV #CPEQ35014) MID-ELEM @ 7160' RKB. DUMP 2 GAL'S OF SAFE CARB ON RBP, SET 2.77 x 59" CATCHEF ON TOP OF RBP @ 7158' RKB, DUMP BAILED'" 15' OF CARB SAFE ON TOP OF RBP/ CATCHER TOP OF SAND @'"7143' RKB. IN PROGRESS. 7/4/2019 PULLED CATCHER & CA -2 PLUG @ 7097' RKB; TAG TD @ 7562' RKB (EST. 87' RAT HOLE) & MEASURED BHP @ 7500' RKB. SBHP OF 4,453 PSI MEASURED. JOB COMPLETE & READY FOR RELAY. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 <3Q-04 APPROVED 10-403 Repair Well, Cement Pkr Sundry App.pdf> <3Q-04.pdf> PTD !9< -417- -t Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, July 28, 2019 9:02 AM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt Subject: RE: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Attachments: 3Q-04.pdf, 3Q-04 APPROVED 10-403 Repair Well, Cement Pkr Sundry App.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, As previously reported 6.16.19 Kuparuk producer 3Q-04 (PTD 191-124) experienced SCP of the IA. The IA was loaded with fluid to reduce the IA pressure below the DNE where it remained until recent well work has caused the IAP to increase to ^2100 psi. A work plan is in progress as per approved sundry # 319-268. CPAI intends to leave the pressure as is until the work has been completed. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, June 16, 2019 1:42 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure Hi Victoria, Kuparuk producer 3Q-04 (PTD 191-124) is experiencing sustained casing pressure on the inner annulus after being shut- in on April 11t", 2019. The IA pressure recorded today was ^2100 psi. The production casing is 7 26#J-55 with an internal yield rating of 4,980 psi (45% here is 2,241 psi). CPAI will load the well with fluid to reduce the IA pressure below DNE while we progress a repair option for the well. Please let us know if you have any questions or disagree with this plan. Sincerely, SaraCarle. (}feskt4v) /2ache,LKau.tk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com u¢IIuAOC nasi WELLBORE 30-04 Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Hi Victoria, PTD /,ql — / z 4 NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sunday, June 16, 2019 1:42 PM Loepp, Victoria T (CED) CPA Wells Supt KRU Producer 3Q-04 (PTD 191-124) Report of IA Sustained Casing Pressure 3Q-04.pdf Follow up Flagged Kuparuk producer 3Q-04 (PTD 191-124) is experiencing sustained casing pressure on the inner annulus after being shut- in on April 11th, 2019. The IA pressure recorded today was ^2100 psi. The production casing is T' 26#J-55 with an internal yield rating of 4,980 psi (45% here is 2,241 psi). CPAI will load the well with fluid to reduce the IA pressure below DNE while we progress a repair option for the well. Please let us know if you have any questions or disagree with this plan. Sincerely, Saea, CarUg& (-Heaci+v) / X aJieb Kaatk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F•218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549(@cop.com Cell: 907-331-7514 ) sara.e.carlisleCOcop.com THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Jill Simek Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-04 Permit to Drill Number: 191-124 Sundry Number: 319-268 Dear Ms. Simek: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.2767542 www. a ogc c. o laska. g ov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Siincerely, 2y 'l'.C C OC - Jessie L. hmielowski Commissioner DATED this -LL day of June, 2019. gBDMSL�^' JUN 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAC 9S 9Rn 4e%mow' e LED — MAY 2 4 2019 /ns c // ¢(15 1. Type of Request. Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well t7 Operations shutdowrP Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Progran❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑L�' j �� S Other 2. Operator Name. 4. Current Well Class: , 5. Permit to Dnll Number: ConocoPhllll sAlaska Inc. Exploratory ❑ Development o 191-124 r 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 500292221900— d d TO perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 5/t4'I Will planned perforations require a spacing exception? Yes ❑ No E3KRU 3Q-04 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 373301 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD. Effective Depth ND: MPSP (psi): Plugs (MD) Junk (MD) 7,725' 6,709' 3250 7097 7410 Casing Length size MD ND Burst Collapse Structural Conductor 82' 16" 123' 123' Surface 4,476' 11" 4,518' 3,955' Intermediate Production 7,700' 7" 7,716' 6,702' Liner Perforation Depth MD (ft): Perforation Depth ND (ft) ITubing Size: Tubing Grade: Tubing MD (ft): 7475-7483; 7483-7495', 7498- 6494.3-6501.2; 6501.2-6511.4; 3.500" J-55 7,399' 7538 6514-65482 Packers and SSSV Type: Packers antl SSSV MD (ft) and ND (ft): PACKER - BAKER FHL RETRIEVABLE PACKER 4782 SHEAR 60K MD= 7076 ND= 6152 12. Attachments: Proposal Summary Wellbore schematic O 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: 6/15/2019 OIL 2 • WINJ ❑ WDSPL ❑ElSuspendetl GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Jill Simek Contact Name: Authorized Title: Staff Wells Engineer Contact Email: lillsimek@cop.com Contact Phone: (907) 263-4131 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval. N tity C mission so that a representative may witness Sundry Number n/ 'I 01 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSI.�JUN 18 2019 Post Initial Injection MIT Redd? Yes ❑ No ram Spacing Exception Required? Yes 11/ No Q' Subsequent Form Required l�—ga�y Approved by: APPROVED BY lq COMMISSIONER THE COMMISSION Date: vn ��11 /1 , 1 A 1 �� Form 1 3 Revised 4/2017 Approved applic ti nfSy�iA fdr �2 H�dttr�frL the date of approval. Submit Form and R' v'„'j PP Attachments in Duplicate 45-�8sh(/n ConocoPhillips 3Q-04 Permit to Drill #: 191-124 3Q-04 has a (upper) packer leak and production casing leak. This procedure outlines steps to squeeze cement into/across the casing leak, filling the annulus between packers, to repair both upper packer leak and production casing leak. Procedure: Slickline - Pull CA2 plug SBHP 1. MIRU SL and associated equipment. 2. Pull catcher on CA2 plug at 7,097ft KB. 3. Pull CA2 plug at 7,097ft KB. 4. RIH with GR; drift and tag. S. RIH with dual guages to obtain 30 minute SBHP above tag depth. Perform 15 min gradient check 100ft TVD uphole. 6. RDMO. Well ready for Eline. Rine - Set RBP, punch tubing, infectivity test 1. MIRU EL and associated support equipment. 2. RIH and set RBP at 7,160ft KB. 3. RIH and set catcher on RBP. 4. RIH with 2.5" dump bailer and dump 15ft of sand on top of RBP/catcher. 5. RIH with tubing punch (2' of 4SPF) and punch holes at 7,135ft KB. 6. Pump 20 bbls of diesel down the tubing to confirm injectivity (+/- 2bpm @ 2,000psi). 7. RDMO. Well ready for CTU. CTU - Pump/squeeze cement 1. MIRU CTU and associated equipment. 2. MU and RIH with 3.5" Weatherford millable cement retainer. 3. Tag top of sand for depth correction. See previous WSR. Sand top should be @ 7,145ft KB. 4. Set WFD cement retainer @ 7,125ft KB. 5. Come online with diesel pumping 10 bbls diesel lead (assuming CT is fluid packed with diesel at this point). 6. Follow diesel with 5 bbls fresh water spacer. 7. Follow fresh water spacer with 16 bbls of 15.8 ppg Class "G" cement with 1 pound per barrel LCM additive. LCM additive to be determined based on injectivtiy/leak rate established. 8. Follow cement with 5 bbls fresh water spacer. 9. Follow fresh water spacer with diesel. 10. Once all of cement is out of nozzle, unsting from retainer. Ensure well is freeze protected. • If squeeze pressure is seen before all cement is out of nozzle, unsting from retainer. Pump remaining cement out of coil, contaminate and circulate out excess cement. 11. POOH. RDMO. Allow cement 72 hours to cure before milling out. JS DHD-Pressure test I. Performa MITIA to 2,500 psi as well as a DDTto 0 psi on the IA to confirm that the cement repair is holding in both directions. CTU- Mill cement/retainer 1. RIH with milling assembly and mill up cement, taking returns off tubing to tanks. Mill through cement retainer at 7,125ft KB. 2. Clean out sand as deep as possible to safe distance above the catcher/RBP plug at 7,160ft KB. 3. POOH. RDMO. Well ready for SL. SL - GLD 1. MIRU SL and associated support equipment. 2. Pull DMY valves from GLD. 3. Install following GLD: Surf. Surf. TRO MD Valve Valve Port Open Close Press GLM (RKB) Size Name Size Press Press 60° F 1 2887 1.5" Camco_R-20 3/16" 1350 1331 1281 2 4325 1.5" Camco_R-20 3/16" 1325 1311 1274 3 5395 1.5" Camco_R-20 3/16" 1302 1291 1265 4 6222 1.5" Camco_R-20 3/16" 1282 1271 1256 5 6990 1.5" Camco_RDO-201/4" ------ Orifice ------ 4. PT tubing to ensure valves are holding or DD IA. 5. Pull catcher. 6. Pull RBP at 7,160ft KB. 7. RDMO. Turn well over to Ops to BOL. DHD- TIFL 1. Perform TIFL to ensure packer repair has worked. JS Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, June 12, 2019 8:29 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-268) Cement Sqz for Packer/PC Leak Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Sorry for delayed response, I was on vacation until yesterday. Well history is below. Last CMIT was 4/27/2019, which failed. MIT -T (4/27) passed to 2500psi. Leak diagnostic method was WaterFlow Log performed 5/13/2019. Fluid movement was seen past all stations, indicating packer leak. Let me know if you need more information. Thanks! Jill 5/13/2019 WATERFLOW LDL. PERFORM BASELINE TEMPERATURE PASS FROM SURFACE TO TOP OF PLUG @ 7097'. PUMP DIESEL DOWN IA AT 0.5 BPM. PERFORMED STATION SURVEYS @ 6000', 6500', 6800', 7000', 7050', 7080'. FLUID MOVING THROUGH ALL STATIONS, INDICATING PACKER @ 7075' IS LEAKING. 4/27/2019 ATTEMPT C -MIT. FAILED. PERFORM PASSING MIT -T TO 2500PSI w/ EZ TEST DMY SET IN STN# 5 @ 6990'RKB. SET DMY @ SAME. PULL GLV's & SET DMY's @ 6222', 5395', 4325'& 2888' RKB. TEST TBG TO 2500PSI. ESTABLISH IA LLR OF .72 BPM @ 2500PSI. JOB SUSPENDED FOR PLAN FORWARD. IN PROGRESS. 4/26/2019 PUMPED 10OBBL5 INHIBITED SW AND 145BBLS DSL DOWN TBG OUT IA, RETURNS TO 3Q-03 FLOW LINE UTUBE 1 HOUR FOR FREEZE PROTECT CMIT TO 2500PSI/FAIL TBG AND IA PRESSURED UP TO 1550PSI AND STALLED OUT, COULD NOT GAIN MORE THAN 1750PSI AT .36BPM SHUT DOWN, ISLOATED FROM TRUCK AND TBG/IA FELL FROM 175OPSI TO 1375PSI RAPIDLY. JOB COMPLETE 4/26/2019 PULL CAT SV @ 7097'RKB. SET 2.81" CA -2 PLUG & CATCHER @ SAME. PULL OV @ 6990'RKB. READY FOR CIRC OUT. IN PROGRESS. 4/14/2019 (AC EVAL) SI TIFL (FAILED DUE TO INFLOW AND PRESSURE INCREASE). 4/11/2019 SET 2.81" DS CSV @ 7097' RKB; MITT TO 2500 PSI (PASS); JOB SUSPENDED DUE TO HIGH WINDS & PHASE CONDITIONS; LEFT CSV IN HOLE (INFO TAG ON TREE) FOR DHD TO PERFORM SI-TIFL. 4/1/2019 (AC EVAL) PROACTIVE RE-TIFL (FAIL DUE TO PRESSURE AND FLUID LEVEL INCREASE) 3/27/2019 PULL 1.5" OV FROM 6990', REPLACE WITH 1.5" OV IN KIND @ 6990' RKB. JOB COMPLETE. 3/19/2019 (AC EVAL) PROACTIVE TIFL (FAIL) From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, May 30, 2019 9:44 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-268) Cement Sqz for Packer/PC Leak Please provide recent well history including most recent MITs and any leak diagnostic work that has been performed. Thank, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeooaalaska.00v, CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria Loenocs'alaska.gavv Loepp, Victoria T (CED) From: Simek, Jill <1ill.Simek@conocophillips.com> Sent: Wednesday, June 12, 2019 8:29 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-268) Cement Sqz for Packer/PC Leak Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Sorry for delayed response, I was on vacation until yesterday. Well history is below. Last CMIT was 4/27/2019, which failed. MIT -T (4/27) passed to 2500psi. Leak diagnostic method was WaterFlow Log performed 5/13/2019. Fluid movement was seen past all stations, indicating packer leak. Let me know if you need more information. Thanks! Jill 5/13/2019 WATERFLOW LDL. PERFORM BASELINE TEMPERATURE PASS FROM SURFACE TO TOP OF PLUG @ 7097'. PUMP DIESEL DOWN IA AT 0.5 BPM. PERFORMED STATION SURVEYS @ 6000', 6500', 6800', 7000', 7050', 7080'. FLUID MOVING THROUGH ALL STATIONS, INDICATING PACKER @ 7075' IS LEAKING. 4/27/2019 ATTEMPT C -MIT. FAILED. PERFORM PASSING MIT -T TO 2500PSI w/ EZ TEST DMY SET IN STN# 5 @ 6990'RKB. SET DMY @ SAME. PULL GLV's & SET DMY's @ 6222', 5395', 4325'& 2888' RKB. TEST TBG TO 2500PSI. ESTABLISH IA LLR OF .72 BPM @ 2500PSI. JOB SUSPENDED FOR PLAN FORWARD. IN PROGRESS. 4/26/2019 PUMPED 100BBLS INHIBITED SW AND 1458BLS DSL DOWN TBG OUT IA, RETURNS TO 3Q-03 FLOW LINE UTUBE 1 HOUR FOR FREEZE PROTECT CM IT TO 2500PSI/FAI L TBG AND IA PRESSURED UP TO 1550PSI AND STALLED OUT, COULD NOT GAIN MORE THAN 1750PSI AT .36BPM SHUT DOWN, ISLOATED FROM TRUCK AND TBG/IA FELL FROM 1750PSI TO 1375PSI RAPIDLY. JOB COMPLETE 4/26/2019 PULL CAT SV @ 7097'RKB. SET 2.81" CA -2 PLUG & CATCHER @ SAME. PULL OV @ 6990'RKB. READY FOR CIRC OUT. IN PROGRESS. 4/14/2019 (AC EVAL) SI TIFL (FAILED DUE TO INFLOW AND PRESSURE INCREASE). 4/11/2019 SET 2.81" DS CSV @ 7097' RKB; MITT TO 2500 PSI (PASS); JOB SUSPENDED DUE TO HIGH WINDS & PHASE CONDITIONS; LEFT CSV IN HOLE (INFO TAG ON TREE) FOR DHD TO PERFORM SI -TI FL. 4/1/2019 (AC EVAL) PROACTIVE RE-TIFL (FAIL DUE TO PRESSURE AND FLUID LEVEL INCREASE) 3/27/2019 PULL 1.5" OV FROM 6990', REPLACE WITH 1.5" OV IN KIND @ 6990' RKB. JOB COMPLETE. 3/19/2019 (AC EVAL) PROACTIVE TIFL (FAIL) From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, May 30, 2019 9:44 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3Q-04(PTD 191-124, Sundry 319-268) Cement Sqz for Packer/PC Leak Please provide recent well history including most recent MITs and any leak diagnostic work that has been performed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loeoo onalaska goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loeoo�alaska_aov Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: �Y AOGCC ATTN: Natural Resources Technician II \ Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 —j&j Anchorage, AK 99501 TRANSMITTALDATE TRANSMITTAL# 11124 30 85 8 Schlumberger -Private Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~/yF File Number of We il History File PAGES TO DELETE Complete RESCAN Color items - Pages: GrayScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .~' Logs-of various kinds Other COMMENTS: Scanned by: Beverly Diann~than Lowell Date:~/¢ a TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ALA— A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '"'`' 14 `,. at', 1.Operations Performed: Abandon r Repair w ell P Rug Perforations r Perforate r Other qtDGCC Alter Casing r Pull Tubing J Stimulate-Frac r Waiver r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;r Exploratory r . 191-124 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r I% 50-029-22219-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 373301 4 * 3Q-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):a none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured t 7725 feet Plugs(measured) None true vertical 6709 feet Junk(measured) None Effective Depth measured 4 7630 feet Packer(measured) 7076,7377 true vertical 6627 feet (true vertical) 6152,6410 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 123 123 SURFACE 4476 9.625 4518 3955 PRODUCTION 7700 7 7716 6701 Perforation depth: Measured depth: 7475 7495, 7498-7538 JUL 6 1� �L 1 • tlj True Vertical Depth: 6495-6513,6515-6549 SCANN Tubing(size,grade,MD,and TVD) 3.5, L-80, 7400 MD,6429 TVD RBDMS____MAY 16 2014 Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER 47B2 SHEAR 60K @ 7076 MD and 6152 TVD PACKER-CAMCO'HRP-I-SP' RETR. PKR @ 7377 MD and 6410 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development [✓"` Service r Stratigraphic r 16.Well Status after work: OilrF Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Theresa Lee(a)263-4837 Email Theresa.M.LeeCa�conocophillips.com Printed Name Theresa L Title Wells Engineer Signature Phone:263-4837 Date \ / 13 I ' 1 1/1-F 5/23/ 14-- Form 10-404 Revised 10/2012 '�/ �N/ Submit Original Only m- Li KUP PROD 3Q-04 ConocoPhdhps S Well Attributes Max Angle&MD TD A dsk�t IncWellbore API/UWField Name Wellbore Status ncl("I MD(ftKB) Act 8tm(ftKB) LarKry+wepc 500292221900 KUPARUK RIVER UNIT PROD39.76 2,300.00 7,725.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-04,1/14/20148.06.58 AM SSSV:NIPPLE 175 12/23/2012 Last WO: 12/9/2013 4099 1/19/1992 - Vertical schematic(actual) -Annotation Depth MB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,473.0 6/5/2012 Rev Reason:WORKOVER,GLV C/O,PULL haggea 1/14/2014 BALL&ROD/PLUG HANGER,37.9 -Mir Casing Strings ■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(L..Grade Top Thread .,, I CONDUCTOR 16 15.062 41.0 123.0 123.0 62.50 H-40 Casing Description OD lin) ID tel Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I.Grade Top Thread SURFACE 9 5/8 8.835 42.2 4,517.7 3,955.1 36.00 J-55 BTC I ' Casing Description PRODUCTION OD lin) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 7 6.276 15.7 7,716.0 6,701.5 26.00 J-55 BTC ,Tubing Strings Is Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib#t) Grade Top Connection 1111 TUBING WO 31/2 2.992 38.0 7,052.4 6,131.8 9.30 L-80 CUE Completion Details Nominal ID CONDUCTOR;41.0-123.0 . Top(ftKB) Top(ND)(ftKB) Top Incl(`) Item Des Com (in) 38.0 i 37.9 0.11 HANGER CAMERON GEN IV TUBING HANGER 2.992 NIPPLE;514.6 514,6'• 514.6 1.31 NIPPLE CAMERON"DS"NIPPLE 3.5"X 2.875 2.875 7,045.2- 6,125.6 30.45 LOCATOR BAKER LOCATOR SUB 2.990 Tubing Description -- String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;2,887.9 10.-... STACKER PACKER 3112 2.992 7,052.4 7,370.7 6,405.2 9.30 L-80 EUE Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(-) Item Des Com (in) 7,052.4 6,131.8 30.45 PBR BAKER 80-40 PBR 4.000 7,075.5 6,151.7 30.46 PACKER BAKER FHL RETRIEVABLE PACKER 4782 SHEAR 60K 2950 GAS LIFT;•325.4 <_ 7,097.3 6,170.4 30.48 NIPPLE CAMERON DS NIPPLE 2.812" 2.812 7,360.5 ' 6,396.4 31.21 LOCATOR BAKER NO GO LOCATOR SUB 2.992 7,3613 6,397.1 31.21 SHOE BAKER MULE SHOE 2.992 Tubing Description String Ma...ID(in) /Top(ttKB) [Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection l TUBING-original 55/8 29371 7,36341 7,399.5 6,429.8 SURFACE;42.2-4,517.7 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inei 13 Item Des Com (in) GAS LIFT,5395 4-.f' c.- 7,363.4 6,398.9 3121 PBR CAMCO PBR,10'stroke,5.625"OD Bbl,2.937"ID(30K# 2.937 Shear) 7,376.8 6,410.4 31.24 PACKER CAMCO'HRP-1-SP'Retr.Pkr,60K#pull or rot.release, 2.867 5.937"0D,2.8671D 7,391.2 6,422.7 31.26 NIPPLE CAMCO'D'Nipple w/2.75"packing bore. 2.750 GAS LIFT.6.222.2 - 7,398.8 6,429.2' 31.27 SOS CAMCO PE-500 Shearout Sub 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top led/ Top(ftKB) (ftKB) C) _ Des Com Run Date - ID(in) 7,410.0 6,438.8 31.27 FISH Spring to GA-2 Running Tool 10/20/2013 0.000 GAO LIFT;0,990.1 ..8. 7,425.0 6,451.6 31.27 FISH 100%of Cups Left in Well Removed Tree Saver 4/26/1997 0.000 - - Perforations&Slots Shot Dens Top(ND) Bier(ND) (shots# LOCATOR;7,00.5.2 L. Top(ftKB) Btm(ftKB) OMB) (ftKB) Zone Date t) Type Corn 7,475.0 7,483.0 6,494.3 6,501.2 C-1,A-2,3Q- 2/13/1992 4.0 IPERF 4 1/2"Csg Gun;180 04 deg.phasing PBR:7.052.4 • _ • 7,483.0 7,495.0 6,501.2 6,511.4 C-1,A-2,30- 2/13/1992 4.0 IPERF 4 12"Csg Gun;180 PACKER;7,075.5 04 deg,phasing 7,498.0 7,538,0 6,514.0 6,5482 A-1,30-04 "2/13/1992 4.0 IPERF 4 12"Csg Gun;180 deg.phasing NIPPLE.,7,0972 Mandrel Inserts St ati C On Top(N _ NnD) Valve Latch Port Size TRO Run Top(MB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 2,887.9 2,607.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,277.0 12/23/2013 LOCATOR;7,360.4 1. 2 4,325.4 3,797.4 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,274.0 12/23/2013 3 5,395.4 4,690.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,267.0 12/23/2013 SHOE;7,3613 - 4 6,2222 5,410.7 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,259.0 12/23/2013 FOR;7,363.4 5 6,990.1 6,078.0 CAMCO MMG 1 1/2 GAS LIFT OV RK 0250 0.0 12/23/2013 MP Notes:General&Safety PACKER;7,376.8 _ ' End Date Annotation 11/29/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 NIPPLE;7,391.2 ." 10/20/2013 NOTE:LEFT SPRING TO GA-2 RUNNING TOOL IN WELL A SOS;7,398.8 L. FISH;7,410.0 0 FISH;7,425.0 Y (PERF;7,475.0-7,483.0 --• IPERF;7.4030-7,460.0- IPERF,7.498.0-7,538.0 PRODUCTION;15.7-7,7160 • 3n-04 PRE AND POST RIG WELL WORK PRE RIG WELL WORK ' DATE SUMMARY 7/7/2013 BRUSH n' FLUSH TBG AND TAGGED TD @ 7539'SLM; GAUGE TBG W/2.77"GAUGE RING DOWN TO D-NIPPLE @ 7391' RKB; SET 2.75" CA-2 PLUG @ 7391' RKB; LEAK DETECT W/ HOLE FINDER W/INCONCLUSIVE RESULTS. IN PROGRESS. 7/8/2013 LEAK DETECT W/HOLE FINDER AND DETERMINE LEAK IS @ OV @ 6986' RKB; SET CATCHER ON CA-2 PLUG @ 7391' RKB. PULLED OV @ 6986' RKB (SEVERE EROSION @ NOSE CONE); ATTEMPT TO SET NEW OV. IN PROGRESS. 7/9/2013 SET NEW OV @ 6986' RKB. TBG/IA COMMUNICATING. PULLED OV @ 6986' RKB, REPLACED WITH EXT PKG DV. COMMUNICATION REMAINS. IN PROGRESS. 7/19/2013 (AC EVAL): T-LLRT-ESTABLISHED T-LLRT OF >6.2 GPM @ 230 PSI. 8/10/2013 PUMP DOWN TBG @ 1 BPM TAKING RETURNS OFF IA TO FLOWLINE, RAN LEAK DETECT LOG, FOUND HOLE IN TUBING @ 7182' RKB, IN PROGRESS. 8/11/2013 RAN LEAK DETECT LOG, FOUND NO INDICATIONS OF ANY LEAKS OTHER THAN THE LEAK FOUND @ 7182' RKB, LRS PERFORMED PASSING CMIT-TxIA @ 2000psi, PULLED AVA CATCHER FROM 7343' SLM, IN PROGRESS 8/12/2013 RAN 2.50" LIB TO CA-2 PLUG @ 7391' RKB (IMPRESSION OF FILL), BAILED-3 CUPS OF SCALE OFF CA-2 PLUG @ 7391' RKB, PULLED CA-2 PLUG @ PRONG FROM 7391' RKB, BRUSH & FLUSHED TUBING FROM SURFACE TO 7450'SLM W/70bbls DIESEL 9/25/2013 (PRE-RWO) FT LDS ALL FUNCTIONED. T-POT PASSED. T-PPPOT PASSED. IC-POT PASSED. IC-PPPOT PASSED. MIT-OA PASSED TO 1800 PSI. 10/18/2013 MEASURED BHP (3866 psi)@ 7502' RKB. IN PROGRESS. 10/19/2013 SET 2.75" CA-2 PLUG @ 7391' RKB; SET CATCHER ON CA-2 PLUG @ 7386' RKB; PULLED GLV'S @ 6604', 6069', &4973' RKB; SET DV @ 6604' RKB. IN PROGRESS. 10/20/2013 PULLED GLV @ 3001' RKB; SET DV'S @ 6069', 4973', &3001' RKB; PULLED CATCHER& RECOVERED SCREW FROM GA-2 RUNNING (MISSING SPRING); DEPLOY CATCHER& PULLED DV @ 7312' RKB (LEFT OPEN), CMIT TXIA FAILED. WILL SET UP TO CIRC OUT. IN PROGRESS. 10/24/2013 Loaded well with 290 bbls inhibited Seawater and 78 bbls diesel, pumping down the Tubing taking returns off the IA, U-Tube'd freeze protect. Attempted CMIT to 3000 psi- Failed. Estimate liquid leak rate of 1.8 gpm @ 3000 psi. - In Progress 10/29/2013 (PRE-RWO) : RE-CMIT-T x IA(FAILED)TO 3000 PSI, ESTABLISHED LLR OF 2.5 GPM. 10/30/2013 (PRE RWO)TEST WV TO SSV TO 3000 PSI (PASSED). 11/6/2013 SAT DOWN @ 2230' SLM WITH GR PULLING TOOL AND LOST SPANG ACTION. BRUSHED/ GAUGED TBG TO 2.80"TO 7338'SLM. BAILED SCALE OFF CATCHER @ 7386' RKB. PULLED CATCHER @ SAME. IN PROGRESS. 11/8/2013 BAILED SCALE OFF CA-2 PLUG @ 7391' RKB. ATTEMPTED EQUALIZE. IN PROGRESS. 11/9/2013 PULLED CA-2 PLUG. BRUSHED & FLUSHED NIPPLE, SET NEW 2.75" CA-2 PLUG @ 7391' RKB. ATTEMPTED CMIT: FAILED. PULLED CA-2 PLUG. READY FOR WRP. 11/12/2013 LOG CORRELATED TO TUBING TALLY RECORD DATED 14-FEB-1992. WRP MID-ELEMENT SET DEPTH: 7386', CCL TO WRP MID-ELEMENT OFF SET: 11', CCL STOP DEPTH: 7375'. READY FOR LRS TO CMIT. LRS PERFORMED FAILING CMIT. SEE ATTACHED REPORT. 11/15/2013 (PRE RWO) : CMIT TXIA FAILED TO 2500 PSI. 11/21/2013 DUMP BAILED 13'OF CaCO3 ON TOP OF WRP @ 7385' RKB. SET 2.72"x 10.25'JUNK CATCHER @ 7362' RKB. IN PROGRESS. 11/23/2013 Pulled Catcher @ 7362 RKB; Bail Appx- 3' of CaCO3. Job Complete (Ready for BPV). ConocoF iIIips Time Log & Summary We!Mew Web Reporting Report Well Name: 3Q-04 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/10/2013 3:00:00 AM Rig Release: 12/15/2013 3:25:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/09/2013 24 hr summary Rig Released from 3R pad @ 19:30 hrs. Rig Move. 19:30 00:00 4.50 MIRU MOVE MOB P Move rig from 3R pad to 3Q pad. Welding repairs on pits, auger system during move. 12/10/2013 Moved rig to 3Q pad, clear snow from around cellar area. Spot rig over well and accept at 03:00hrs 12/10/2013. Rig up to kill well, pull BPV,bleed well down. Circulate 273 bbls of 11.8#around. Switch back to the pits and circulate until good 11.8#in and out. Monitor well-Good. Set BPV. N/D tree and inspect hanger threads. Set test dart and N/U BOP's. 00:00 03:00 3.00 MIRU MOVE MOB P Rig excempt time 23:00 hrs to 02:00 for loading tree in cellar, removing snow from around wellhead, leveling area. Spot rig from 02:00 hrs to 03:00 hrs 03:00 06:00 3.00 MIRU MOVE RURD P ***Rig accept 03:00 hrs***. Rig up support equipment,spot cutting tank and containment, build up snow around cellar wind walls. RU cellar pump lines to Tree and IA. Test hard line with air-Trouble shoot ice plug,found flex hoses to have ice plug,treat with steam, reconnect. 06:00 07:30 1.50 MIRU WHDBO MPSP P Rig up lubricator, PT @ 2,000 psi and pull BPV. lay down and offload lubricator. 07:30 11:00 3.50 MIRU WELCTL OTHR P PT Kill line @ 250/3,000 psi-good test. Weight up pit system to11.8 ppg NaBr/NaCI brine 11:00 17:30 6.50 MIRU WELCTL KLWL P PJSM, Notify proper authorities for venting gas. Open up well SITP= 1,320 psi, SICP= 1,080 psi w/OA Pressure @ 250 psi. Attempt to Bleed off gas cap, Manual choke failed again-tip issue. Re build and test-Good Test. Continue to bleed to 580 SITP and 240 SICP. Reverse circulate @2bpm 1870psi ICP 273BBLS. FCP 570psi. Fluid out 11.4ppg 20psi on tubing 30psi on IA. Reverse circulate back to the pits through the Poor Boy at 3BPM 243bbls. FCP 400psi 17:30 18:30 1.00 MIRU WELCTL OWFF P Blow down lines and open up well at tree to check for flow-Good. 18:30 19:00 0.50 MIRU WHDBO PLUG P Set Cameron"H"style BPV. Page 1 of 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:30 2.50 MIRU WHDBO NUND P PJSM,Verify voids bled off. Nipple down tree. Inspect hanger threads and screw in pup count 9 turns to tighten. Function LDS 2.5"out-clear 2.75" out-Full out. Install test dart in top of BPV. 21:30 23:30 2.00 MIRU WHDBO NUND P PJSM, Set DSA and hammer up bottom flange. Set stack and make up Choke&Kill Gray lock flanged.Torque up 11"5k flange on stack. 23:30 00:00 0.50 MIRU WHDBO BOPE P Rig up to test BOPE with 3 1/2"test joint. 12/11/2013 Tested BOP's to 250/3000psi, Pulled test dart/BPV. Pulled hanger free and pulled out of PBR. Circulated the hole clean and flow checked. POOH L/D tubing and SSSV control line. Load new completion into the pipe shed. Pick up new completion and begin to run in hole. 00:00 03:30 3.50 MIRU WHDBO BOPE P PJSM test BOPE 250/3000 PSI (1)Blinds, Stand pipe kill,choke 4,11,12, 3.5 IF dart,TD Hydraulic UKV. Passed (2)BR, Kill HCR,Lower TD, 3.5 IF FOSV,Choke 3,7,9,10 Passed (3)BR, Man Kill,3.5 FOSV 8rd, Choke 2,5,8. Passed (4)LPR W/3 1/2"TJ Passed (5)Annular 3 1/2""TJ, Manual Kill, choke valves 2,5,6. Passed (6)Upper variable pipe rams 3 1/2"" TJ, Choke HCR Passed (7)Manual choke Passed (8)Choke valve#1 Passed Accumulator test. Initial-3000psi Actuate all BOP(function upper pipe rams 2x's for blinds) 1950psi First 200psi-16sec Final 3000psi-86sec Rig down test equipment. Time to close annular:14sec Upper pipe rams:4sec Lower pipe rams:4sec 03:30 04:00 0.50 MIRU WHDBO BOPE P Conduct AAR on N/U and testing of BOPE. *Identify lifting plate needs to be re-engineered/replaced to allow stack to be turned to help align bolt holes to stab onto well head* 1 hr in time attempting to stab stack on well head. 04:00 05:00 1.00 MIRU WHDBO PLUG P Suck out stack. Engage test dart verify no pressure below BPV, pull BPV Page 2 of 7 Time Logs • Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 05:00 I 06:00 1.00 COMPZ RPCOM RTWH I P Make up landing joint to top drive. BOLDS and confirm minimum of 2.5" of Lock Down retracted. Check IA for pressure-Good. Pick up and unseat hanger at 70k with 35k blocks work pipe up to 145k and pull seals free at 52k over original string weight. 06:00 08:00 2.00 COMPZ RPCOM CIRC P Circulate 300bbIs at 4bpm 440psi No gains or losses 08:00 08:30 0.50 COMPZ RPCOM OWFF P Flow check well-Good 08:30 16:00 7.50 COMPZ RPCOM PULL P POOH laying down tubing with SSSV control line. All bands recoverd. 32 total. Corrosion on collars from 4980'to 7,363', holes in tubing joint 227-7180'. Heavy corrosion/light scale from 7,117'to 7,321'. 16:00 22:00 6.00 COMPZ RPCOM OTHR P Load remainder of completion into shed.Verify lengths of jewelry and running order. Drift tubing to 2.867" top 500'to 2.91" 22:00 00:00 2.00 COMPZ RPCOM RCST P PJSM, Pick up completion as per well plan. Monitor displacement to the trip tank.Torque 3 1/2"8rd eue modified to 2240psi. Run pipe in hole at 90 fUmin. 12/12/2013 Continue to run 3 1/2"completion. Locate top of PBR @7362'. Reverse circulate 197bbls of CI 11.8ppg down hole. Space out No-Go 1'above PBR. Drop ball and rod and set packer. PT IA to 1000psi-Good. Shear out PBR,space out and land hanger. PT tubing to 3000psi-good, attempt to test IA to 2500psi-fail.Appears to be a leak in the casing. Circulate CI 11.8ppg brine out of the hole. Flow check. POOH with 3 1/2"completion racking back tubing. 00:00 09:00 9.00 COMPZ RPCOM RCST P Continue to run 3 1/2"completion string from 1,500 to 7,334-ft 95k up wt, 85 do wt. Monitoring displacement to the pits. Locate PBR @ 7,362-ft and NoGo @ 7,371-ft. 09:00 11:00 2.00 COMPZ RPCOM CIRC P Reverse Circ 197 bbls of CI 11.8 ppg Brine @ 3 bpm @ 280 ICP and displace w/56 bbls of clean brine w/ 260 FCP 11:00 12:00 1.00 COMPZ RPCOM PACK P Drop ball and Rod,space out 1-ft of No-Go. Pressure up to 1,650 psi, seen screws shear, increased pressure to 2,000 psi,slacked 10k to assist in packing off element and increased preesure to 3,000 psi. Tested IA @ 1,000 psi-good test- bled off. Bleed TBG pressure back to 2,000 psi and puilled 20k osw and sheared PBR. Dump pressure and continue to pull seals from PBR. Page 3 of 7 ... . .. ......._.__ ....... Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 ¶COMPZ WHDBO THGR P Space out-laid 3 jts and inserted 16.33-ft of pups(6.20-ft+ 10.13-ft), PU 3rd jt and RIH. MU landing jt to Hanger and MU hanger to string. Move fluid with charge pump and locate PBR w/Seals. Drain stack and land hanger. RILDS. 14:00 16:00 2.00 COMPZ RPCOM PRTS P RU and Pressure test TBG @ 3,000 psi for 30 minutes-Good Test, lost 90 psi in first 15 minutes and 10 psi in second 15 minutes. Bleed tubing down to 1500psi, pressure test IA to 2500psi bled down to 1000psi attempt again and same loss rate. Isolate floor equipment and attempt to test again. Same loss rate. Bleed off IA and tubing.Appears to be a casing leak. 16:00 19:00 3.00 COMPZ RPCOM CIRC T Line pits up to circulate out corrosion inhibitor taking returns out of the pits straight to a truck. Circulate 255bbls of 11.8 CI brine out of well. 19:00 19:30 0.50 COMPZ RPCOM OWFF T Check well for flow-Good 19:30 19:45 0.25 COMPZ RPCOM PRTS T Attempt to pressure test well bore to 2000psi against the pipe rams. Same leak rate as established before. Bleed off. 19:45 20:00 0.25 COMPZ RPCOM CIRC T Circulate tubing volume to balance out well. 5bpm 539psi 20:00 20:30 0.50 COMPZ RPCOM OWFF T Check well for flow-Good PJSM for pulling out of the hole with completion standing back tubing in the derrick. 20:30 00:00 3.50 COMPZ RPCOM TRIP T Trip out of the hole with 3 1/2" completion racking back tubing in the derrick. Monitor displacement on the trip tank. 12/13/2013 Continue to POOH with 3 1/2"completion. RIH with test packer test at 4,000'-Good,7,208'-Fail, 7,178'Good. POOH with test packer. Make up packer retrieving assembly with circulating sub.Trip in hole with retrieving assembly on 3 1/2"tubing from the derrick SLM in the hole. 00:00 02:30 2.50 COMPZ RPCOM TRIP T Continue to trip out of the hole with 3 1/2"Completion assembly. Monitor displacement on the trip tank. Calculated Displacement:24.5bbls Actual Displacement:24.5bbls Page 4 of 7 Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 02:30 11:00 8.50 COMPZ RPCOM TRIP T Pick up Baker test packer. Trip in the hole with Baker test packer to 4000', set packer and test IA @ 2,500 psi- Good test. test down TBG @ 2,500 psi- Failed test. Continue to RIH to 7,208-ft and Set packer, PT IA @ 2,500 psi-failed. PU to 7,178-ft, PT @ 2,500 psi- Good Test, RIH to 7,194-ft and PT @ 2,500 psi-Failed test, PU to 7,186-ft -PT @ 2,500 psi-Failed test. Pressure up down TBG against RHC plug and FHL Packer @ 2,500 psi- Good Test. Hole between 7,188-ft and 7,196-ft. 11:00 16:00 5.00 COMPZ RPCOM TRIP T Release Packer and POOH, lay down test packer. Monitor displacement to the trip tank. Calculated displacement:24.3bbls Actual displacement:23.4bbls Hole static 16:00 19:30 3.50 COMPZ RPCOM OTHR T Wait for packer retrieving tool to arrive, MU BHA and prepare to RIH. Reviewed task, ran circ point and decided to RIH w/Circ sub(w/o insert)installed in BHA. Call out for Circ sub. 19:30 00:00 4.50 COMPZ RPCOM TRIP T Make up retrieving tool, LBS, circulating sub,xo, ljnt of tubing. Trip in hole with 75 tubing stands from derrick monitoring displacement to trip tank. Calculated displacement:24.3bbls Actual displacement:24bbls 12/14/2013 Trip in hole to top of PBR. Engage PBR and release packer with 58k over pull. Circulate bottoms up. Flow check well-Good. POOH with Packer/PBR assembly and lay down. Cut and slip 84'of drill line. Pick up completion as per new run order. Locate out on PBR @ 7371'pick up to 7370'. Circulate 240bbls of 1%CI brine. Drop ball&rod,set packer. Test back side 1000psi. Shear out of PBR. Space out and land hanger. Pressure test tubing to 3000psi for 30min-Good. 00:00 00:30 0.50 7,267 7,370 COMPZ RPCOM TRIP T Pick up 11 singles oft 3 1/2"tubing and tag top of PBR @7,267'. Engage top of PBR with retrieving tool pumping 2bpm @100psi. Up wt 92k down wt 83k. Set 10k down pick up 33k over and confirm latch.Work weight up release packer at 58k over. Allow elements to relax and pick up to confirm packer released. New up wt 95k 3k over.g 00:30 02:00 1.50 7,370 7,370 COMPZ RPCOM CIRC T Circulate hole volume at 5 bpm 520 psi. No gains or losses during circulation. 02:00 02:30 0.50 7,370 7,370 COMPZ RPCOM OWFF T Flow check well-Good Page 5 of 7 Time Logs ' . .,. ..,,. r Date From To Dur S. Depth E.Death Phase Code Subcode'' T Comment 02:30 10:30 8.00 7,370 0 COMPZ RPCOM TRIP T Trip out of hole with PBR/Packer assembly. Monitor displacement to the trip tank. Calculated displacement:24bbls Actual displacement:24bbls 10:30 12:30 2.00 0 0 COMPZ RPCOM SLPC T Slip and Cut 84-ft 12:30 18:00 5.50 0 7,371 COMPZ RPCOM RCST T PJSM, PU and RIH w/3-1/2 Gas Lift completion as per run order. 18:00 18:30 0.50 7,371 7,370 COMPZ RPCOM RCST T Locate out on PBR with no go at 7,371'. Pick up 1'put Mule shoe at 7,370'. 18:30 20:00 1.50 7,370 7,370 COMPZ RPCOM CIRC T Circulate 240bbls of 1%Conqor 303A Corrosion Inhibitor. 20:00 21:00 1.00 7,370 7,370 COMPZ RPCOM PACK T Drop 1 5/16"Ball&Rod allow to fall for 14min. Pressure up on tubing to 2000psi, indications at 1850 that packer was setting. Hold pressure for 5min. Slack off and set 10k down. Pressure up to 3000psi and hold for 15min-Good. Bleed off pressure.Test back side to 1000psi-Good. Bleed off. Up wt-92k Dn wt-85k Top of packer at 7,075' Packer elements at 7,070' Top of PBR at 7,052' 21:00 23:00 2.00 7,370 7,370 COMPZ RPCOM HOSO T Pressure tubing up to 2000psi. Pick up and shear out PBR @105k-12k over. Bleed off pressure. Pick up out of PBR. Come back down no go out. Lay down 3 joints space out with 2 pups 6.20&10.13. Pick back up jnt 231 and land hanger.Verify stabing into seals with no circulation. RILDS. 23:00 00:00 1.00 7,370 7,370 COMPZ RPCOM PRTS T PJSM. Rig up to pressure test. Pressure test Tubing for 30minutes. Initial pressure 3050psi drop down to 3000psi in 10minutes flat line at 3000psi for remainder of test. Bleed tubing down to 1500psi. 12/15/2013 Pressure test IA to 2500psi-Good. Shear SOV. Set BPV. Pressure test to 1000psi. N/D BOPE. N/U Tree. Pressure test to 250/5000psi. Freeze protect. Set BPV. Secure cellar and release rig @15:30hrs 12/15/2013 00:00 01:30 1.50 7,370 7,370 COMPZ RPCOM PRTS P Pressure test IA to 2,500psi for 30minutes-Good. Bleed IA down and then tubing. Pressure IA up to 1900psi and shear SOV. Rig down testing equipment and blow down. 01:30 02:30 1.00 7,370 7,370 COMPZ RPCOM PLUG P Set BPV and test from below to 1000psi for 10min-Good. 02:30 06:00 3.50 7,370 7,370 COMPZ RPCOM NUND P PJSM, Nipple down BOPE 06:00 08:00 2.00 7,370 7,370 COMPZ RPCOM NUND P N/U tree, install Test Plug,test tree to 250/5000psi. Page 6 of 7 Time Logs Date From To Dur S.Depth E. Depth Phase Code - Subcode T Comment 08:00 09:00 1.00 7,370 7,370 COMPZ RPCOM PLUG P Pull test plug/BPV 09:00 12:00 3.00 7,370 7,370 COMPZ RPCOM FRZP P Rig up LRS. PT lines to 250/3000psi. Reverse circulate 75bbls of diesel down IA taking returns to the kill tank from the tubing.Allow to u-tube. 12:00 13:00 1.00 7,370 7,370 COMPZ RPCOM PLUG P Install BPV. 13:00 15:30 2.50 7,370 7,370 COMPZ RPCOM RURD P Secure cellar and finish cleaning pits. Release rig @15:30hrs 12/15/2013 Page 7 of 7 POST RIG WELL WORK 12/23/2913 PULLED BALL& ROD @ 7069' SLM; REPLACED SOV w/OV @ 6991' RKB; PULLED DV'S &SET GLV'S @ 6223', 5396', 4326', &2889' RKB. IN PROGRESS. 12/25/2013 PULLED RHC @ 7097' RKB. BAILED CaCO3 FROM 7339'-7347' SLM. IN PROGRESS. 12/26/2013 BAILED CaCO3 TO WRP @ 7385' RKB. UNABLE TO EQUALIZE OR LATCH. 2.65" LIB SHOWS CLEAN WRP SHEAR STUD. IN PROGRESS. 12/28/2013 RAN BAILER TO WRP @ 7385' RKB. ATTEMPTED PULL WRP, UNABLE TO LATCH. IN PROGRESSS. 12/29/2013 EQUALIZED WRP @ 7385' RKB w/EQ SLEEVE. BAILED TO REMOVE DEBRIS F/WRP FN. LATCHED/RELEASED WRP @ 7385' RKB; WORKED UP HOLE TO PKR @ 7376' RKB. IN PROGRESS. 12/30/2013 ATTEMPTED PULL WRP F/PKR @ 7376' RKB; NO APPARENT MOVEMENT. IN PROGRESS. 12/31/2013 PULL WRP @ 7376' RKB, COMPLETE. i M Conoc / ' ' oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder ~ ~ `~"~ Alaska Oil & Gas Commission (~ ~ 333 West 7~' Avenue, Suite 100 ~ ~~~ Anchorage, AK 99501 3~ ,~ ,~~. ~, :se t i~ ~ r` . .. ~ k' .~' .. . ... . c.. > > .,.< .. Dear Mr. Maunder: - Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30th 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and l Oth 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, v~~~°( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. SurFace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~~ ~~ ~~ o ~., ~_~ Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitoN sealant date bbls a~ 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" Na 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" Na 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30l2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF Na 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/S/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8l2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E E C:LORIXMFILM.~ PL E W M A T E R IA L U N D ER TH IS M A R K ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown ~ Stimulate X Alter casing Repair well 5. Type of Well: I Development X I Exploratory _ I Stratigraphic 99510 I Service Plugging 4. Location of well at surface 2217' FNL, 2304' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 1089' FSL, 1364' FEL, Sec. 8, T13N, R9E, UM At effective depth 1089' FSL, 1364' FEL, Sec. 8 , T13N, R9E, UM At total depth 1213' FSL, 1335' FEL, Sec. 8, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7720' feet Plugs (measured) 6705' feet Perforate Other 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-04 9. Permit number/approval number 91-124 10. APl number 50-029-22219 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7630' feet Junk (measured) true vertical 6627' feet Casing Length Size Cemented Conductor 1 22' 1 6" 1875 Sx Pole Set Surface 4518' 9 5/8" 1065 Sx PF E & 430 Sx Class G Measured depth 122' 4518' True vertical depth 122' 3954' Production 77 1 6' 7" 250 Sx Class G & 7716' 6701' Perforation depth: measured 7475'-7495', 7498'-7538' true vertical 6495'-651 3', 6515'-6549' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55, EUE 8 RD, ABMOD, Tail @ 7400' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-4A MOD, 1842', Packer: 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 4/26/97 Intervals treated (measured) 7475'-7495', 7498'-7538' Treatment description including volumes used and final pressure Camco HRP-I-SP, 7377' ,' i ~"~';" "A" Sand fracture completed thru flush. Injected 197166 lbs of Prop in formation w/14# PPA of #12/18 @ PERFs. Freeze protected TBG down to 3400' RKB w/30 bbls of diesel. Maximum pressure 5000 3si & F.G. @ (.76) 14. Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 463 177 0 300 160 Subsequent to operation 2183 815 2 200 140 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ X 16. Status of well classification as: Water Injector Oil X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢~A f¢~ Form ,10-4(~4 Re 09',¢~~ Title Wells Superintendent ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT ~ K1(3Q-04(W4-6)) WELL JOB SCOPE JOB NUMBER 3Q-04 FRAC, FRAC SUPPORT 0422971818.5 DATE DAILY WORK UNIT NUMBER 04/26/97 "A" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O No ,I (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC# CCff DAILY COST ACCUMCOST Si~'ne~l.~' ESTIMATE KD1818 230DS36QL $132,568 $141,209 /~./'~?. .~----~.~ ..' Initial Tbcl Press Final Tbq Press Initial Inner Ann Final Inner Ann, Initial Outer Ann , Final Outer~n 1000 PSI 1500 PSI 700 PSI 500 PSII I ,./'00 PSI PSI DALLY SUMMARY I FREEZE PROTECTED TBG DOWN TO 3400' RKB W/30 BBLS OF DIESEL. MAXIMUM PRESSURE 5000 PSI & F.G. @ (.76). "A" SAND FRAC COMPLETED THRU FLUSH. INJECTED 197166 LBS OF PROP IN FORMATION W/144f PPA OF #12/18 @ PERF'S. TIME 07:00 09:45 10:05 11:20 12:20 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL TRK. HELD SAFETY MEETING (14 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS NEEDED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9400 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 15 BPM. VOLUME PUMPED 360 BBLS. USED 6225 LBS OF #20/40 PROP FOR CONDITIONING. MAXIMUM PRESSURE 4750 PSI AND ENDING PRESSURE 3200 PSI. S/D AND OBTAINED ISIP OF 2074 PSI W/F.G. @ (.76/. MONITORED WHTP AND PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 189 BBLS. MAXIMUM PRESSURE 4100 PSI AND ENDING PRESSURE 3300 PSI. S/D AND OBTAINED ISIP OF 2216 PSI W/F.G @ (.78). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH . S/D AND MONITORED WHTP FOR 5 MINS. VOLUME PUMPED 1421 BBLS. MAXIMUM PRESSURE 5000 PSI AND ENDING PRESSURE 4300 PSI. TOTAL PUMPED 198257 LBS PROP ( 17415 LBS OF #20/40 AND 180842 LBS OF #12/18 ) INJECTED 197166 LBS OF PROP IN FORMATION W/14# PPA OF #12/18 @ PERF'S. LEFT 1091 LBS OF PROP IN THE WELLBORE. ESTIMATE TOP OF FILL TO BE @ 7550' RKB. FREEZE PROTECTED TBG DOWN TO 3400' RKB W/30 BBLS OF DIESEL. 14:50 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 15:30 16:00 REMOVED TREESAVER (100% OF CUPS LEFT IN WELL) CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION . WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $882.00 APC $5,700.00 $5,700.00 DIESEL $475.00 $475.00 DOWELL $122,323.00 $122,323.00 HALLIBURTON $0.00 $4,019.00 _ LITTLE RED $4,070.00 $7,810.00 , TOTAL FIELD ESTIMATE $132,568,00 $141,209,00 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' 1 Date' 01/18/94 SCALE DATE_RECVD 91-124 CBT 91 - 124 CDN 91-124 CDR 91-124 CET 91-124 407 91-124 91-124 91-124 DAILY WELL OP ~S DI.~ CTI~L 91-124 5210 L 6690-7610 L 4517-7720, LWD L 4517-7720, LWD L 6690-7628 R COMP DATE: 02/14/92 R 01/08/92-02/15/92 R 0-7720 R 0-7720 T 4398-7724,OH-CDR/CDN 2&5 2&5 Are dry ditch samples required? yes ~/gnd received? Was the well cored? yes//~nalysis & description received? Well is in compliance Initial 02/14/92 02/11/92 02/11/92 02/14/92 04/01/92 04/01/92 04/01/92 03/31/92 03/24/92 yes Comments ~'"' ~ STATE OF ALASKA ALR,.,,,,A OIL AND GAS CONSERVATION COMMIb,.~ON ORIGINAL REPORT OF SUNDRY WELL OPERATIONS Stimulate X Plugging Repair well Perforate Other 1. Operations Performed: Operation Shutdown__ Pull tubing . Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address 5. Type of Well: Development Exploratory Stratigraphic Service P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2217' FNL, 2304' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 1089' FSL, 1364' FEL, Sec. 8, T13N, R9E, UM At effective depth 1089' FSL, 1364' FEL, Sec. 8 , T13N, R9E, UM At total depth 1213' FSL, 1335' FEL, Sec. 8, T13N, R9E, UM Present well condition summary Total Depth: measured true vertical 7720' feet Plugs (measured) 6705' feet 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-04 9. Permit number/approval number 91-1~4 10. APl number ~(~-02~-2221cj 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7630' feet Junk (measured) true vertical 6627' feet Casing Length Size Cemented Conductor 1 2 2' 1 6" 1875 Sx Pole Set Surface 451 8' 9 5/8" 1065 Sx PF E & 430 Sx Class G Measured depth True vertical depth 122' 122' 4518' 3954' Production 771 6' 7" 250 Sx Class G & 12. 7716' Ri~=(~IVEi) JUN 1 0 1392 Alaska 0il & Gas Cons. Com~tss~ot~ Anchorage Camco HRP-1-SP, 7377' Perforation depth: measured 7475'-7495', 7498'-7538' true vertical 6495'-6513', 6515'-6549' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55, EUE 8 RD, ABMOD, Tail @ 7400' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-4A MOD, 1842', Packer: 13. Stimulation or cement squeeze, summary Intervals treated (measured) Perforated interval. Treatment description including volumes used and final pressure Refractured A Sand w/106 M LBS proppant & 870 BBL gelled sea water. Final pressure 7900 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water~Bbl Casing Pressure Tubing Pressure 463 177 0 300 160 Prior to well operation 2183 815 2 200 140 Subsequent to operation 16. Status of well classification as' Water Injector__ Oil X Gas Suspended Service 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Operations Engineer Date ~/0¢/? ~-- SUBMIT IN' DU'PLICATE Form 10-404 Rev 09/12/90 Procedure Date: 3///f/~,f, ..... Service Co: _- J~,.~ .-- Annulus Press: Begin Frac: Zone: ~, Az, A! . Test L J nes To: ..~.~ ~ .... --- i i i i i _ i .... · -- .- ,,~. _STAGE VOL FLUID P;;OP . _ -- , _-- _~ - ---- n i ! , 3 RATE PRESSURE __ 70 ~ _ t, ~~ ,..__ . ___ " .- ~~__ -.~/~o_ _ ISlP: 1l Mtn: ~ -- Fluid to Recover: ///~,d'~',~ ~_ Sand In Zone: mm m Il_ · ,. Sand In Csg: Job Complete: T~/mJk/31OO/Z04 Z/27/87 --- Alaska, Oki & Gas C,o~s. ...... ~ m ~mm m Rlg~uperVis~r - -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [] GAS r"-I SUSPENDED ["'-I ABANDONED I'--I SERVICE r--1 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-124 3 Address 8 APl Number P.O. Box 100360, Anchora~Ie, AK 99510-0360~, 50-029-22219 4 Location of well at surface ? i~i'~':-'.;".: ........... 9 Unit or Lease Name 2217' FNL, 2304' FEL, SEC 17, T13N, RDE, UM ~..~.__,..: ~. ~~ JV~j~:ii~D KUPARUK RIVER At Top Prorfucing Interval ~ "'~'../~.~ ~,~:~,.:.~.~,.~~ 10 Well Number 1089'FSL, 1364'FEL, SECB, T13N, R9E, UM .[. ' ...... ;'- ~ ~ i gt"~/3'~ ~ 3Q-04 12i3' FSL, i335' FEL, SEC 8, T13N, RDE, UM KUPARUK RIVER FIELD 5 ElevaIion in teet (indicate KB, DF, elc.)16Lease Designalion and Serial No. KUPARUK RIVER OIL POOL RKB 63', PAD 22' GLI ADL 373301, ALK 4162 12 Dale Spudded 13 Date T.D. Reached 14 Date Comp., Suop. or Aband. 115 Waler Deplh, if offshore 16 No. of Cornplelions 01/08/92. 01/17/92. 02/14/92.I NA feel MSL 1 17 Tolal Deplh (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Deplh where SSSV sel 21 Thickness of permafrosl 7720' MD ,6705' TVD 7630' M D, 6627' TVD YES [~ NO ~1 1636' feet MD 1700' APPROX 22 Type Electric or Other Logs Run CDR/C DN/GR/CET/C BT/GCT 23 CASING, LINER AND CEMENTING RECORD I SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 122' 24" 1875 SX POLE S ET{foam ~pe) 1986 conductor 9-5/8" 36# J-55 SURF 4518' 12-1/4" 1065 sx PF E, 430 SX CLASS G 7" 26# J-55 SURF 7716' 8" 250 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7475'-7495' W/ 4-1/2 "CSG GUN @ 4 SPF MD 6495-'6513' TVD 3-1/2" 9.3# 7400' 7377' -- 7498'-7538' W/ 4-1/2" CSG GUN @ 4 SPF MD 6515'-6549' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,1~ 28 CORE DATAP I" I V P U Brief description of Iitholo~¥, porosity, fractures, apparent dip~ and presence of oil, gas or water. Submit core chips. -.- ^laska Oil &flas Cons. Commia~i0n ; neh0rag, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NNVlE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NA KUPARUK C TOP 7470' 6490' KUPARUK C BOTTOM 7483' 6501' KUPARUK A TOP 7483' 6501' KUPARUK A BOTTOM 7562' 6569' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ...... ~_-Y, _~_~ .......... Title AREA DRILLING ENGINEER Date ~__~_ _~_~_~'~-- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO KLASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT PPROVAL: 3Q-04 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 373301 ALK 4162 50-029-22219 91-124 ACCEPT: 01/07/92 SPUD: 01/08/92 RELEASE: 01/19/92 OPERATION: DRILLING RIG: PARKER 245 AFE: AK6225 WI: 55.252072 01/08/92 (1) TD: 122'( 122) SUPV:CD 01/09/92 ( 2) TD: 1260'( 1138) SUPV:CD 01/10/92 (3) TD: 4209'(2949) SUPV:CD 01/11/92 ( 5) TD: 4538'( 329) SUPV:CD 01/12/92 ( 6) TD: 4538'( SUPV:CD o) 01/13/92 (7) TD: 5690'(1152) SUPV:CD 01/14/92 (8) TD: 6652'( 962) SUPV:CD 01/15/92 (9) TD: 7350'( 698) SUPV:SMS 01/16/92 (10) TD: 7627'( 277) SUPV:SMS RIG UP/MIX MUD MW: 0.0 VIS: 0 MOVE RIG FROM 3Q-01 TO 3Q-04. NU DIVERTER AND MIX SPUD MUD. DAILY:S35,945 CUM:$35,945 ETD:SO EFC:$1,325,945 DRILLING MW: 8.8 VIS: 58 CONTINUE MIXING MUD. SLIP AND CUT DRLG LINE AND SERVICE TOP DRIVE. DRILL ICE FROM CONDUCTER AND NEW HOLE TO 271'. POOH TO CHANGE BHA. RIH AND DRILL FROM 271' TO 1260' DAILY:S70,917 CUM:$106,862 ETD:SO EFC:$1,396,862 DRILLING AT 4209' MW: 9.0 VIS: 50 DRILL FROM 1260' TO 1771'. POOH TO SERVICE TOP DRIVE. RIH AND DRILL FROM 1771' TO 4209' DAILY:S66,111 CUM:$172,973 ETD:SO EFC:$1,462,973 RU TO RUN SURF CSG MW: 9.1 VIS: 51 DRILL TO CSG PT (4538'). POOH TO REPAIR MOYNO PUMPS. RIH FOR WIPER TRIP. CBU AND POOH. RIG UP TO RUN CSG. DAILY:S60,069 CUM:$233,042 ETD:SO EFC:$1,523,042 NU AND TEST BOPE 9-5/8"~ 4517' MW: 9.4 VIS: 38 RUN 9-5/8" CSG TO 4518'. CMT WITH 1065 SX LEAD AND 430 SX TAIL. BUMP PLUG. GOT 100 BBLS OF CMT RETURNS. DID NOT RECIP CSG. ND DIVERTER AND NU BOPE. DAILY:S219,989 CUM:$453,031 ETD:SO EFC:$1,743,031 DRILLING AT 5690' 9-5/8"~ 4517' MW: 8.8 VIS: 36 NU AND TEST BOPE. RIH AND DRILL FLOAT EQPT AND 10' NEW HOLE. PERFORM LOT. FORMATION BRK DOWN AT 13.6 PPG EMW. DRILL TO 5690'. DAILY $63,553 CUM:$516,584 ETD:SO EFC:$1,806,584 DRLG AT 6652' 9-5/8"~ 4517' MW:ll.0 VIS: 42 DRLD TO 6015'. TRIP FOR MWD TOOL FAILURE. DRLD TO 6652' DAILY:S74,762 CUM:$591,346 ETD:SO EFC:$1,881,346 RIH WITH LOCKED UP BHA 9-5/8'~ 4517' MW:12.0 VIS: 48 DRLD 6657'-7350'. CIRC. POH. LD MWD, LWD & TURBINE. RIH W/ ROTARY ASSEMBLY. DAILY:S55,192 CUM:$646,538 ETD:SO EFC:$1,936,538 POH FOR LWD & NEW BIT 9-5/8"~ 4517' MW:12.0 VIS: 38 RIH. DRLD 7350'-7627'. NO PIT GAIN OR LOSS IN DRLG BREAK 7480'-7530'. CIRC. POH TO PU LWD, MWD AND BIT. DAILY:S125,141 CUM:$771,679 ETD:SO EFC:$2,061,679 APR - 1 1992 Alaska Oil & Gas Cons. Commission Anchorage WELL: 3Q-04 OPERATION: DRILLING RIG: PARKER 245 PAGE: 2 01/17/92 (11) TD: 7671'( 44) SUPV:SMS CHANGED OUT SAVER SUB 9-5/8"~ 4517' MW:12.0 VIS: 42 POH. CHANGE BIT & PU LWD, MWD TOOLS. RIH. REAMED STICKY HOLE 7067'-7627'. DRLD 7627'-7671'. POH TO SHOE TO CHANGE OUT SAVER SUB (WASHOUT). DAILY:S62,501 CUM:$834,180 ETD:SO EFC:$2,124,180 01/18/92 (12) TD: 7720' ( 49) SUPV:SMS RNG 7' CSG 9-5/8"~ 4517' MW:12.0 VIS: 44 RIH W/ BIT. DRLD 7671'-7720'TD. CIRC. POH. RAN 7" CASING. DAILY:S63,161 CUM:$897,341 ETD:SO EFC:$2,187,341 01/19/92 (13) TD: 7720'( SUPV:SMS o) RIG RLSD 9-5/8"~ 4517' MW: 0.0 VIS: 0 RAN 7" CSG. CMTD W/ 250 SX CL G W/ ADDITIVES. SET SLIPS. ND BOP. NU TBG HEAD. RLSD RIG. 0300 1/19/92 DAILY:S355,936 CUM:$1,253,277 ETD:SO EFC:$2,543,279 SIGNATURE: ~ ~ DRILLING SUP~INTENDEN~~ DATE: ~RCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 3Q-04 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 373301 ALK 4162 50-029-22219 91-124 ACCEPT: 02/13/92 SPUD: RELEASE: 02/14/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK6225 WI: 55.252072 02/14/92 (14) TD: 7720 PB: 7630 SUPV:GB/SB RUNNING 3-1/2" SINGLE COMP 9-5/8"~ 4517' MW:12.0 NaC1/Br MOVE RIG F/3J-03 TO 3Q-04,ACCEPT RIG AT 13:30 HRS 13-FEB-92 NU BOPE, SET TEST PLUG, BUILD BERM FOR TIGER TANKS,LOAD PITS W/150 BBLS 12.0 PPG BRINE,TEST BOPE TO 3000 PSI,OK, PULL TEST PLUG, RU SWS,PERFORATE F/7475-7495' & 7498-7538' AT 4 SPF, 180 DEG PHASING, RD SWS,LOAD PIPE SHED W/TBG AND JEWELRY,STRAP TALLY,DRIFT SAME, INSTALL SEAL RINGS,RU FLOOR TO RUN COMP,RIH W/3-1/2" SINGLE COMP AS PER PROCEDURE,CURRENTLY PREPPING TEMPORARY CAMP AT 3Q PAD, NORDIC CAMP AT DOYON 14 DAILY:S96,503 CUM:$1,349,780 ETD:SO EFC:$2,639,78 02/15/92 (15) TD: 7720 PB: 7630 SUPV:GB/SB RELEASE RIG 9-5/8"~ 4517' MW:12.0 NaCl/Br SERVICE RIG, CONT RIH W/3-1/2" SINGLE COMP AS PER PROCEDURE MU SSSV AND C-LINE, TEST C-LINE TO 5K,OK,CONT RIH,MU HGR AND C-LINE,TEST SAME TO 5K,OK,LAND TBG, RILDS,DROP BALL, SET PKR W/2500 PSI ON TBG, PRESS ANN TO 1000 PSI TO CHECK SEALS OK BLEED OFF PRESS,BOLDS,PRESS TBG TO 1100 PSI,PU AND SHEAR PBR RELAND TBG, RILDS,PRESS TEST SSSV W/500 PSI DIFF,OK,TEST ANN TO 2500 PSI F/15 MIN, OK, PRESS TBG TO 4300 PSI AND SHEAR SOS RD CIRC EQUIP,LD LANDING JT, SET BPV, ND BOPE,NU TREE,TEST TREE TO 250/5000 ~PSI,OK, RU CIRC EQUIP,DISPLACE ANN W/12 BBLS DIESEL, BULLHEAD TBG W/4 BBLS DIESEL,RD CIRC EQUIP,SECURE WELL,SITP=1000 PSI,SICP=0 RELEASE RIG,MOVE TO 3Q-03 DAILY:S156,617 CUM:$1,506,397 ETD:SO EFC:$2,796,397 SIGNATURE: ~ ~ DRILLING S~R~NTENDEN~ DATE: -~/Z ?/~ -~ SUB - S URFA CE DIRECTIONAL SURVEY [-~l UIDANCE l'~'i ONTINUOUS r~ OOL Company ARCO ALASKA~ INC. Well Name 3Q-4(2217'FNL,2304'FEL,SEC 17,T13N,R9E) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92113 Loqcjed By: T. WEST i~ECEIVED Date 1-FEB-1992 APR - Computed By: Alaska Oil & Gas Cons. Commission Anchorage R. KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 1-FEB-1992 ENGINEER: T. WEST METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. Averaged oeviation anO azimuth PROJECTED ONTO A TARGET AZIMUTH OF NORTH 16 DEG 47 MIN EAST COMPUTATION DATE: 22-MAR-92 PAGE 1 ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 1-FEB-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 200 3OO 4O0 50O 600 700 800 900 0.00 -63.00 0 0 N 0 0 E O0 100 O0 37.00 0 17 N 75 59 E O0 200 O0 137.00 0 22 N 10 39 W O0 299 99 236.99 0 15 N 39 22 W O0 399 99 336.99 0 10 N 20 7 W O0 499 99 436.99 0 57 N 3 8 E O0 599 90 536.90 3 26 N 12 27 E O0 699 46 636.46 6 49 N 15 59 E O0 798 44 '735.44 9 24 N 19 10 E O0 896.99 833.99 10 13 N 19 57 E 0.00 0 13 0 59 0 98 1 17 1 76 = 83 15 02 29 i7 46 15 0 O0 015 0 47 0 O0 0 O7 2 85 2 8O 2 66 1 O2 I 56 0.00 N 0 O0 E 0.03 5 0 54 E 0 0.38 N 0 79 E 0 0.86 N 0 54 E 1 1.12 N 0 34 E 1 1 .74 N 0 31 E 1 5.78 N 1 02 E 5 14,67 N 3.38 E 15 28. 17 N 7.61 E 29 44.18 N 13.34 E 46 0 O0 N 0 0 E 54 S 87 17 E 88 N 64 43 E 01 N 32 19 E · 17 N 16 50 E 77 N 10 11E 87 N 9 59 E 05 N 12 58 E lB N 15 7 E 15 N 16 48 E 1000.00 995.05 932.05 12 53 N 19 42 E 65.64 1100.00 1091.45 1028.45 17 41 N 18 43 E 92.07 1200,00 1185.94 1122.94 20 17 N 19 32 E 124,77 1300.00 1279.38 1216.38 21 15 N 20 48 E 160.31 1400.00 1372.39 1309.39 21 59 N 21 37 E 196.93 1500.00 1464.52 1401.52 23 58 N 21 41 E 235.66 1600.00 1555.14 1492.14 25 42 N 22 22 E 277.76 1700.00 1644.76 1581,76 27 12 N 21 44 E 321.93 1800.00 1732.67 1669.67 30 14 N 20 56 E 369.41 1900.00 1816.82 1753.82 35 1 N 19 5 E 423.27 4.62 4.30 t .67 0.56 1 .27 2.59 O. 69 1 .61 5.02 4.80 62.52 N 20.02 E 65.65 N 17 46 E 87.53 N 28.64 E 92.10 N 18 7 E 118.48 N 39.27 E 124.82 N 18 20 E 151.89 N 51.56 E 160.40 N 18 45 E 186.12 N 64,88 E 197.10 N 19 13 E 222.25 N 79.23 E 235.95 N 19 37 E 261.43 N 95.13 E 278.20 N 20 0 E 302.51 N 111.85 E 322.53 N 20 17 E 346.87 N 129.20 E 370.15 N 20 26 E 397,57 N 147.65 E 424.10 N 20 22 E 2000.00 1897 2B 1834,28 37 9 N 17 50 E 482.62 2100.00 1976 63 1913.63 37 55 N 18 29 E 543.46 2200 O0 2054 86 1991.86 39 8 N 16 34 E 605.73 2300 O0 2132 O0 2069.00 39 46 N 16 33 E 669.36 2400 O0 2209 50 2146.50 38 35 N 15 34 E 732.55 2500 O0 2288 08 2225.08 37'33 N 15 25 E 794.39 2600 O0 2368 52 2305.52 35 27 N 14 6 E 853.75 2700 O0 2450.76 2387.76 34 6 N 13 13 E 910.54 2800.00 2533.81 2470.81 33 27 N 14 14 E 966.15 2900.00 2617.30 2554.30 33 34 N 14 51 E 1021,15 0.50 1 ,04 I .49 0.22 0.63 2.18 2.21 1 .04 1 .65 0.72 453.97 N 166.18 E 483.43 N 20 6 E 511.78 N 185.21 E 544.26 N 19 54 E 571.12 N 204.12 E 606 50 N 19 40 E 632.16 N 222.08 E 670 04 N 19 21 E 692.86 N 239.64 E 733 13 N 19 5 E 752.49 N 256.10 E 794 87 N 18 48 E 809.88 N 271.39 E 854 14 N 18 32 E 865.21 N 284.59 E 910 82 N 18 12 E 919.32 N 297.78 E 966 34 N 17 57 E 972.56 N 311.73 E 1021 30 N 17 46 E 3000.00 2700.34 2637.34 34 2 N 15 11 E 1076.84 3100.00 2783.32 2720.32 33 46 N 16 31 E 1132.63 3200.00 2866.42 2803.42 33 44 N 17 29 E 1188.26 3300.00 2949.64 2886.64 33 45 N 18 24 E 1243.69 3400,00 3032.95 2969,95 33 9 N 17 56 E 1299.00 3500.00 3117.27 3054.27 32 18 N 19 28 E 1352.72 3600.00 3201.84 3138.84 32 13 N 21 55 E 1405.94 3700.00 3285.67 3222.67 34 1 N 19 16 E 1460.32 3800.00 3367.86 3304.86 35 27 N 15 41 E 1517.25 3900.00 3449.16 3386.16 35 39 N 11 4 E 1575.32 0.42 1026 38 N 326.15 E 1076.96 N 17 38 E 0 84 1080 0 87 1133 0 26 1186 1 55 1238 1 4O 1289 0 94 1339 2 07 1390 3 88 1444 0 55 1501 08 N 341.33 E 1132.73 N 17 32 E 28 N 357.57 E 1188.35 N 17 31 E 01 N 374.72 E 1243.80 N 17 32 E 54 N 392 07 E 1299.11 N 17 34 E 51 N 409 11 E 1352.86 N 17 36 E 37 N 428 10 E 1406.13 N 17 44 E 31 N 447 54 E 1460.56 N 17 51 E 52 N 464 96 E 1517.50 N 17 51 E 26 N 477 92 E 1575.50 N 17 40 E COMPUTATZON DATE: 22-MAR-92 PAGE 2 ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 1-FEB-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION .SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3530 50 3467.50 35 5 N 11 17 E 1633.20 4100 O0 3612 60 3549.60 34 58 N 11 12 E 1690.02 4200 O0 3694 28 3631.28 35 25 N 11 0 E 1747.43 4300 O0 3776 29 3713.29 34 36 N 12 51 E 1804.43 4400 O0 3858 53 3795.53 34 49 N 13 39 E 1861.22 4500 O0 3940 44 3877.44 35 7 N 13 30 E 1918.50 4600.00 4022 14 3959.14 35 25 N 12 45 E 1976.0~ 4700.00 4103.92 4040.92 34 34 N 13 28 E 2033.46 4800.00 4186.50 4123.50 34 ? N 14 23 E 2089.78 4900.00 4269.55 4206.55 33 46 N 15 51 E 2145.47 2.37 0.55 0.31 0.89 0.48 0.50 0.32 1 .63 1.13 0.25 1558.36 N 489 08 E 1633.30 N 17 25 E 1614 33 N 500 1670 97 N 511 1726 95 N 523 1782 3O N 536 1838 05 N 549 1894 23 N 562 1950 33 N 575 2005 05 N 589 28 E 1690.07 N 17 13 E 29 E 1747.44 N 17 1 E 09 E 1804.43 N 16 51 E 22 E 1861.22 N 16 45 E 78 E 1918.51 N 16 39 E 76 E 1976.06 N 16 33 E 60 E 2033.50 N 16 27 E 2t E 2089.83 N 16 23 E 2058.80 N 603.88 E 2145.53 N 16 21 E 5000.00 4352.83 4289 83 33 7 5100.00 4437.20 4374 5200.00 4522.57 4459 5300.00 4608.48 4545 5400.00 4694.36 4631 5500.00 4780.77 4717 5600.00 4867.21 4804 5700.00 4953.67 4890 5800.00 5041.14 4978 5900.00 5128.69 5065 20 31 59 57 30 53 48 30 50 36 30 41 77 30 2 21 30 19 67 29 35 14 28 53 69 29 3 N 16 28 E 2200 82 N 18 4 E 2254 N 19 31 E 23O6 N 19 46 E 2357 N 19 24 E 2408 N 19 7 E 2459 N 19 7 E 2509 N 18 2 E 2559 N 16 15 E 2608 N 16 5 E 2656 48 52 63 81 10 33 5~, 01 33 2.76 1 .70 0 77 0 25 1 32 0 28 0 27 3 01 0 23 1 76 2112.00 N 619 18 E 2200.89 N 16 20 E 2163.21N 635 2212.47 N 652 2260.65 N 669 2308.91N 686 2356.45 N 703 2403.94 N 719 2451.50 N 735 2497.89 N 749 2544.30 N 763 19 E 2254.54 N 16 22 E 10 E 2306.57 N 16 25 E 35 E 2357.66 N 16 30 E 59 E 2408.83 N 16 34 E 12 E 2459.11 N 16 37 E 61 E 2509.33 N 16 40 E 81 E 2559.54 N 16 42 E 85 E 2608.01 N 16 43 E 29 E 2656.33 N 16 42 E 6000.00 5216.27 5153.27 28 50 6100.00 5303.89 5240.89 28 54 6200.00 5391.34 5328.34 29 8 6300.00 5478 57 5415 57 29 23 6400.00 5565 65 5502 65 29 31 6500.00 5652 57 5589 57 29 41 6600.00 5739 51 5676 51 29 24 6700.00 5826 65 5763 65 29 28 6800.00 5913 67 5850 67 29 41 6900.00 6000.31 5937 31 30 12 N 15 41 E 2704.59 N 15 2 E 2752.77 N 14 45 E 2801.24 N 14 42 E 2850.11 N 14 30 E 2899.23 N 13 59 E 2948.63 N 12 49 E 2997.96 N 12 14 E 3046.86 N 11 46 E 3095.96 N 11 41 E 3145.71 0.35 0.42 0.35 0 20 0 39 0 34 I 01 0 46 0 51 0 45 2590.72 N 776.53 E 2704.59 N 16 41 E 2637.20 N 789.27 E 2752.77 N 16 40 E 2684.09 N 801.69 E 2801.26 N 16 38 E 2731.37 N 814.13 E 2850.12 N 16 36 E 2778.94 N 826.53 E 2899.25 N 16 34 E 2826.87 N 838.70 E 2948.67 N 16 32 E 2874.92 N 850.24 E 2998.01 N 16 29 E 2922.81 N 860.78 E 3046.93 N 16 25 E 2971.02 N 871.00 E 3096.06 N 16 20 E 3019.91 N 881.17 E 3145.84 N 16 16 E 7000.00 6086.66 6023.66 30 25 7100.00 6172.79 6109.79 30 29 7200.00 6258.92 6195.92 30 42 7300.00 6344.70 6281.70 31 7 7400.00 6430.11 6367.11 31 17 7500.00 6515.56 6452.56 31 t6 7600.00 6601.47 6538.47 30 29 7700.00 6687.65 6624.65 30 29 7720.00 6704.89 6641.89 30 29 N 11 22 E 3195.93 N 11 6 E 3246.49 N 11 8 E 3297.05 N 11 35 E 3348.22 N 12 25 E 3400.05 N 13 19 E 3451.87 N 13 22 E 3502.93 N 13 22 E 3553.56 N 13 22 E 3563.69 0 55 0 18 0 76 0 94 1 0 0 0 0 3069.34 N 891.21 E 3196.10 N 16 11 E 3119.17 N 901.07 E 3246.72 N 16 7 E 3169.04 N 910.82 E 3297.33 N 16 2 E 3219.44 N 920.96 E 3348.57 N 15 58 E 05 3270.33 N 931.68 E 3400.46 N 15 54 E 16 3320.95 N 943.33 E 3452.33 N 15 51 E O0 3370.73 N 955.10 E 3503.43 N 15 49 E O0 3420.08 N 966.83 E 3554.11 N 15 47 E 00' 3429.94 N 969.17 E 3564.24 N 15 47 E COMPUTATION DATE: 22-MAR-92 PAGE 3 ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 1-FEB-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N FEET DEG/100 FEET FEET FEET DEG 0.00 ' 0.00 -63.00 0 0 N 0 0 E 0.00 1000.00 995.05 932.05 12 53 N 19 42 E 65.64 2000.00 1897.28 1834.28 37 9 N 17 50 E 482.62 3000.00 2700.34 2637 34 34 2 N 15 11 E 1076.84 4000.00 3530.50 3467 50 35 5 N 11 17 E 1633.20 5000.00 4352.83 4289 83 33 7 N 16 28 E 2200.82 6000.00 5216;27 5153 27 28 50 N 15 41 E 2704.59 7000.00 6086.66 6023 66 30 25 N 11 22 E 3195.93 7720.00 6704.89 6641 89 30 29 N 13 22 E 3563.69 0.00 0.00 N 0.00 E 0.00 N 0 0 E 4.62 62.52 N 20.02 E 65.65 N 17 46 E 0.50 453.97 N 166.18 E 483.43 N 20 6 E 0 42 1026.38 N 326.15 E 1076,96 N 17 38 E 2 37 1558,36 N 489.08 E 1633.30 N 17 25 E 2 76 2112.00 N 619.18 E 2200.89 N 16 20 E 0 35 2590.72 N 776.53 E 2704.59 N 16 41E 0 55 3069.34 N 891.21 E 3196.10 N 16 11 E 0 O0 3429.94 N 969;17 E 3564.24 N 15 47 E ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 22-MAR-92 PAGE 4 DATE OF SURVEY: 1-FEB-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0,00 63,00 163.00 163,00 100 263.00 263.00 200 363.0~ 363,00 300 463.01 463,00 400 563,05 563,00 500 663,31 663,00 600 764.11 763.00 700 865.49 863.00 800 0,00 -63,00 0 0 N 0 0 E 63,00 0 O0 0 15 S 86 12 E O0 0 20 N 23 37 E O0 0 18 N 32 48 W O0 0 11 N 43 24 W O0 0 21 N 2 11W O0 2 46 N 10 42 E O0 5 51 N 15 22 E O0 8 32 N 17 41 E 00 9 52 N 19 48 E 0 O0 0 07 0 37 0 87 1 11 1 39 3,86 10,96 23,54 40.16, 0 O0 001 0 53 0 14 017 0 77 I 65 3 16, 2 85 0 23 0,00 N 0.04 S 0,15 N 0,72 N 1,04 N 1,36 N 3,85 N 10,76 N 22,83 N 0.00 E 0.00 N 0 0 E 0.36 E 0.37 S 83 49 E 0.77 E 0.78 N 78 43 E 0.65 E 0.97 N 42 0 E 0.39 E 1.11 N 20 48 E 0.31 E 1.40 N 12 46 E 0.62 E 3.90 N 9 7 E 2,28 E 11,00 N 11 58 E 5,82 E 23,56 N 14 18 E 38,54 N 1t,30 E 40.16 N 16 21 E 967,20 963,00 900,00 11 39 N 20 0 E 58,70 1070,22 1063,00 1000,00 16 21 N 18 46 E 83,30 1175,59 1163,00 1100,00 19 47 N 19 9 E 116,44 1282.43 1263,00 1200,00 21 10 N 20 35 E 153,97 1389,87 1363,00 1300,00 21 51 N 21 34 E 193,15 1498,34 1463,00 1400,00 23 56 N 21 41 E 235,00 1608,73 1563,00 1500,00 25 46 N 22 22 E 281,54 1720,55 1663,00 1600,00 27 33 N 21 35 E 331,35 1835,43 1763,00 1700,00 31 59 N 20 17 E 387,67 1957,09 1863,00 1800,00 36 47 N 17 56 E 456,82 3 58 4 85 2 32 0 75 1 01 2 56 0 75 1 88 5 07 1 55 55,98 N 17.66 E 58.70 N 17 31 E 79,22 N 25,82 E 8.3,32 N 18 3 E 110,61 N 36,52 E 116.48 N 18 16 E 145,95 N 49,32 E 154,06 N 18 40 E 182,59 N 63,48 E 193.31 N 19 10 E 221.63 N 78.98~E 235.28 N 19 37 E 264.94 N 96.57 E 281.99 N 20 2 E 311.30 N 115.34 E 331.98 N 20 20 E 364.01 N 135.64 E 388.46 N 20 26 E 429.40 N 158.27 E 457.64 N 20 14 E 2082,75 1963 O0 1900 O0 37 45 N 18 28 E 532~88 2210.49 2063 2340,22 2163 2468.25 2263 2593,22 2363 2714,77 2463 2834,94 2563 2954,97 2663 3075,54 2763 3195,88 2863 O0 2000 O0 39 14 N 16 24 E 612 35 O0 2100 O0 39 22 N 16 19 E 695 O0 O0 2200 O0 38 7 N 15 23 E 774 92 O0 2300 O0 35 34 N 14 13 E 849 81 O0 2400 O0 34 2 N 13 22 E 918 79 O0 2500 O0 33 18 N 14 41 E 985 34 O0 2600 O0 33 55 N 15 1 E 1051 68 O0 2700,00 33 49 N 16 9 E 1119 03 O0 2800,00 33 45 N 17 26 E 1185,97 1 03 501,74 N 181.86 E 533,68 N 19 55 E 1 09 577,46 N 206,01 E 613,11 N 19 38 E 2 29 656,74 N 229.35 E 695,64 N 19 15 E ! 36 733,71 N 250,93 E 775.43 N 18 53 E 2 05 806,06 N 270.42 E 850.21 N 18 33 E 0 71 B73,26 N 286,50 E 919.06 N 18 10 E 0 66 937,92 N 302,58 E 985,52 N 17 53 E 0 47 1002,08 N 319,60 E 1051,B1 N 17 41 E 1 11 1067,02 N 337,50 E 1119,13 N 17 33 E 0,84 1131,10 N 356,89 E 1186,07 N 17 31 E 3316,06 2963,00 2900,00 33 46 N 18 26 E 1252,61 3435,78 3063,00 3000,00 32 32 N 18 8 E 1318,41 3554,10 3163,00 3100,00 32 13 N 21 3 E 1381,57 3672,73 3263.00 3200,00 33 31 N 20 14 E 1445,18 3794,03 3363,00 3300,00 35 23 N 16 5 E 1513,78 3917,04 3463,00 3400,00 35 41 N 10 57 E 1585,20 4039.59 3563,00 3500,00 34 40 N 11 23 E 1655.71 4161,63 3663,00 3600,00 35 21 N 10 54 E 1725,33 4283,85 3763,00 3700.00 34 37 N 12 35 E 1795,28 4405,44 3863,00 3800.00 34 51 N 13 40 E 1864,32 0.07 1194.48 N 377.54 E 1252.72 N 17 32 E 2.34 1257.01 N 398.07 E 1318.54 N 17 34 E 2.11 1316.63 N 419.11 E 1381.73 N 17 39 E 3.41 1376.04 N 442.43 E 1445.41 N 17 49 E 3.80 1441.17 N 464.06 E 1514.04 N 17 51 E 0.28 1511.01 N 479.83 E 1585.37 N 17 37 E 0.65 1580.52 N 493.53 E 1655.79 N 17 20 E 0.50 1649.15 N 507.07 E 1725.35 N 17 5 E 1,05 1718,00 N 521.06 E 1795,28 N 16 52 E 0,47 1785,32 N 536,95 E 1864,32 N 16 44 E ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 22-MAR-92 PAGE 5 DATE OF SURVEY= 1-FEB-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4527.58 3963 O0 3900 O0 35 6 4650.11 4063 O0 4000.00 35 16 4771.59 4163 O0 4100.00 34 17 4892.13 4263 O0 4200 O0 33 45 5012.12 4363 O0 4300 O0 32 54 5130.34 4463 O0 4400 O0 31 34 5247.06 4563 O0 4500 O0 30 44 5363.50 4663 O0 4600 O0 30 53 5479.48 4763.00 4700 O0 30 0 5595.12 4863.00 4800 O0 30 18 5710.71 4963.00 4900 O0 29 22 5824.97 5063.00 5000 O0 28 54 5939,20 5163.00 5100 O0 28 49 6053.32 5263,00 5200 O0 28 46 6167.57 5363.00 5300 O0 29 3 6282.14 5463.00 5400 O0 29 21 6396.95 5563.00 5500 O0 29 31 6512.01 5663.00 5600.00 29 42 6626.96 5763.00 5700.00 29 19 6741.75 5863.00 5800.00 29 29 6856.87 5963.00 5900.00 30 1 6972 58 6063.00 6000.00 30 17 7088 63 6163 O0 6100.00 30 31 7204 74 6263 O0 6200.00 30 44 7321 40 6363 O0 6300,00 31 16 7438 50 6463 O0 6400.00 31 19 7555 35 6563 O0 6500.00 30 39 7671 40 6663 O0 6600,00 30 29 7720.00 6704 89 6641.89 30 29 DEG MIN FEET VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEG/IO0 FEET FEET FEET DEG N 13 12 E 1934.34 N 12 45 E 2004.97 N 14 6 E 2073.83 N 15 50 E 2141.09 N 16 44 E 2207.40 N 18 44 E 2270.46 N 19 43 E 2330,58 N 19 40 E 2390.15 N 19 5 E 2448.64 N 19 7 E 2506.87 N 17 41 E 2564.80 N 16 12 E 2620.08 N 15 58 E 2675.27 N 15 17 E 2730.26 N 14 46 E 2785.49 N 14 43 E 2841.35 N 14 31 E 2897.72 N 13 54 E 2954.57 N 12 28 E 3011.15 N 11 59 E 3067.34 N 11 46 E 3124.15 N 11 24 E 3182 13 N 11 6 E 3240 74 N 11 9 E 3299 46 N 11 41 E 3359 27 N 12 54 E 3419 99 N 13 13 E 3480 33 N 13 22 E 3539 08 N 13 22 E 3563.69 0.87 1 .27 0.54 0.31 2.42 i .81 0.23 0.21 0.01 0.27 1853.49 N 553.44 E 1934 35 N 16 38 E 1922.53 N 569.14 E 2005 O0 N 16 29 E 1989,58 N 585.28 E 2073 88 N 16 24 E 2054.58 N 602.69 E 2141 16 N 16 21 E 2118.30 N 621.08 E 2207 47 N 16 20 E 2178.38 N 640.23 E 2270 51 N 16 23 E 2235.16 N 660.19 E 2330 62 N 16 27 E 2291-.30 N 680.34 E 2390 18 N 16 32 E 2346.74 N 699.76 E 2448.85 N 16 36 E 2401.61 N 718.81 E 2506.87 N 16 40 E 2.85 0.20 0.18 0.36 0.13 0.19 0.38 0.41 0.48 0.51 2456.50 N 737.41 E 2564.80 N 16 43 E 2509.48 N 753.22 E 2620.08 N 16 42 E 2562.51 N 768.52 E 2675.27 N 16 42 E 2615.47 N 783.39 E 2730.27 N 16 40 E 2668.84 N 797.68 E 2785.50 N 16 38 E 2722.90 N 811.90 E 2841.37 N 16 36 E 2777.48 N 826,15 E 2897.75 N 16 34 E 2832.64 N 840.14 E 2954.61 N 16 31 E 2887.82 N 853.13 E 3011.20 N 16 28 E 2942.90 N 865.09 E 3067.42 N 16 23 E 0.54 0.57 0.27 0.73 1.14 0.54 1.12 0.00 0.00 2998 72 N 876.77 E 3124.27 N 16 18 E 3055 75 N 888.47 E 3182.29 N 16 13 E 3113 50 N 899.96 E 3240.96 N 16 7 E 3171 42 N 911.29 E 3299.75 N 16 2 E 3230 30 N 923.19 E 3359.63 N 15 57 E 3289 84 N 936.07 E 3420.42 N 15 53 E 3348 68 N 949.92 E 3480.81 N 15 50 E 3405 96 N 963.47 E 3539.61 N 15 46 E 3429.94 N 969.17 E 3564.24 N 15 47 E COMPUTATION DATE: 22-MAR-92 PAGE 6 ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY= 1-FEB-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2217' FNL & 2304' FEL, SEC17 T13N R9E UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4518 O0 7470 O0 7483 O0 7483 O0 7562 O0 7571 9~ 7630.00 7716.00 7720.00 3955.16 3892.16 6489.92 6426.92 6501.03 6438.03 6501.03 6438.03 6568.73 6505.73 6577.29 6514.29 6627.32 6564.32 670!.44 6638.44 6704.89 664~.89 1848 12 N 3305 79 N 3312 36 N 3312 36 N 3351 98 N 3356 90 N 3385 53 N 3427 97 N 3429 94 N 552.18 E 939.76 E 941.30 E 941.30 E 950.69 E 951.85 E 958.62 E 968.70 E 969.17 E ARCO ALASKA, INC. 3Q - 4 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD COMPUTATION DATE: 22-MAR-92 PAGE 7 DATE OF SURVEY: 3-FEB-1992 KELLY BUSHING ELEVATION: 63,00 FT ENGINEER: T. WEST ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2217' FNL & 2304' FEL, SEC17 T13N RgE U~ MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 4518.00 3955.16 3892.16 1848.12 N 552.18 E 7470.00 6489.92 6426.92 3305.79 N 939.76 E 7483.00 6501.03 6438.03 3312.36 N 941,30 E 7483,00 6501.03 6438.03 3312.36 N 941.30 E 7562.00 6568,73 6505.73 3351.98 N 950,69 E 7571.94 6577.29 6514.29 3356.90 N 951.85 E 7630.00 6627.32 6564.32 3385.53 N 958.62 E 7716.00 6701.44 6638.4~ 3427.97 ~ 968.70 E 7720.00 6704.89 6641.89 3429.94 N 969.17 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7720.00 6704.89 6641.89 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3564.24 N 15 47 E klELL- 3Q-4 (2217' FNL,2304' FEL,SEC 17,T13N,RgE) HORIZONTAL PROJECTION IOO0 'T'F'r":-I"i"??i"'"i"i"i"i ..... i-i"i"'i'",'i"i"i-"i ...... .:--+--.:.-+-.p-i-.-:-+-.~ ...... ~.+-+-+..-:---,:--+-~ ....... ~-.P4---i-...d,.+-.~..-~...i-..i....'....P..~ ..... ,.+-~-+-.t-.~-:..i-.:..~ .. ;. :-'.: :...~-. .:...~.~. ~ L ~. 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"'i'"!'"rl ...... !'"ri"'i .... ~'"~'"~'"~ ...... ~..~ : ! L..L..:'...i...L.: ..+.-~-+-~-. "~"T !'"~ ...!.~i...i--i ...... ~.-".--.~.--': ...... i...i...~...h. -+-i.-.i-.-i ...... i--.i.--i-..i ....... r.?.?i ...... ~-..~---?-.~ ...... !~.~ ...... r~-.-?-~ ..... ?~t--i--~ ..... i?-.?--~ ..... i'"!':'i"'! ...... i"'!'"i"'i .... !'"!'"!'"i ...... !---!'..i-..i ..... ?...~ ...... ~,,, ._i...L.i.:.i ....... i...[...!...i ...... !...i.4...i ..... ~...i...~...~....:.L.~...i:..i.. ..~...~...~._~.....44...i...i ..... i...i...!...i ...... i...~._i...i ..... i...!...i...i ...... .4...~...i..4 ...... F.i.--F.i---~..-i--.i--.F.!--. · 'i-'!'+'i" .-:i--.i-.-!.'-! ...... ??...'.-'"-"?-'r?-~ ...... i'"!"?i ..... !-+-!--.i ..... ?..!...?! ..........??'"?"~ .......,,.?'?"r~ ......,,,~?"?'?'~ ..... ?"!'"i ...... i'"!'"} ......... ,~j...?..~...~... ,. : : AOGCC GEOLOGICAL MATFFIIAL~ {NVENIOH¥ LIS[ COMPL£TION DATE g ~ !~""~ ~ ?-"L"O. CONTACT & NO. ! form .... received received date comments 4117~ no completion report 403 yes no ' ' su"ndqf' application :: 404 yes no report of sundry application -bPcn-"'eqUi,ed ~-e-~ived CagciJ- ,eq'~i;e,J .... ;ece'~-d' ~r~'~i{~.. ,Cq.l,c~ ,ecelved' hole 10y hole Io9, ,, I°~ .. , _ DI~SFL CNL. / PHOD BHCISL ....... CET ~ ~ SPINNER ' Bii~d E~ o[tiER "LgS PFRF S.~cy ~ HEC ~~ Data , FoC- CNI_ l'e~l~ FDC 'nWD' ,cqui,c~" ,cccivcd SAMPLES ';cqui,C~ ~CcCivcd MWD ~' ' ~ /d'w diich ' " , , CyBER ~ ~ core LOOK ~ ~ ~Analysis , , , , , ,,, , , .... ....... ......... ,, , , ~ , , , ~ ~ _~ ARCO Alaska, Inc. Date: March 27, 1992 Transmittal #: 8392 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~//'"! ¥/ 2M-03 ?/"/>'("'30-01 ~ [~/~'~,~ 3Q-04 ,~/~/'..,~ O/3Q-03 JSub-Surface Directional ,,,,/' Survey Sub-Surface Directional ,.//- Survey Sub-Surface Directional r~ Survey Sub-Surface Directional Survey Receipt Acknowledged: D&M 1 -27-92 1 '-31 -92 2-1 -92 1 -31 -92 Date- 92101 92112 92113 92114 RECEIVED State of Alaska (2 copies) Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: March 20, 1992 Transmittal #: 8383 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 3Q-04 ~,~/' 3 R-12,~,/ 3 R-20 3R-18 3R-10 LIS Tape and Listing LIS Tape and Listing LIS Tape and Listing LIS Tape and Usting LIS Tape and Listing Receipt Acknowledged- DISTRIBUTION: Please acknowledge receipt and return 1 -1 6-92 92078 2-9-92 92141 3- 1 0-92 921 83 2-27-92 92161 3-14-92 92184 -/--~ Date' R.E...C..E..LVED MAR 2 4 1992 Alaska 011 & Gas Cons. Commission Anchorage Lynn Goettinger State of Alaska _. ARCO Alaska, Inc. Date- February 13, 1992 Transmittal #: 8361 RETURN TO: ARCO Alaska, lnc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmitt~ ~,/~ / > ~"130-01 30-01 ~/"'/>' ~'; 1330'040-04 ql...I>'g Q-03 ,,,,-' Cement Bond Log / Cement Evaluation Log Cement Evaluationog .-.-" Cement Bond Log L...;,~ Cement Bond Log J Cement Evaluation Log Please acknowledge receipt and 1 -31 -92 2-01 -92 2-01 -92 1 -31 -92 1 -31 -92 6395-7905 1-31-92 6690-7628 6690-7610 8585-9592 8585-9512 Receipt Drilling Acknowledge- State (~f" AiaSka(+sepia) Date' NSK 6395 RECEIVED FEB 1 4 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return o. ne signed copy of this transmittal. 2M-10 2M-10 I3Q-04 3Q-04 Litho-Density & Casing Neutron Porosity Data Litho-Density & Casing Neutron Raw Data CCN ~/ 1-12-16-92 CDR ,~ 1-12-16-92 Please acknowledge receipt 11-29-91 & 12-29-91 11-29-91 & 12-29-91 7000-7756,~ ~ 7000-7669 7000-7756 7000-7669 4517.7-7720 4517.7-7720 i3Q-03 CCN ~ 1-24-27-92 5090-9640 3Q-03 CDR %} 1-24-27-92 5090-9640 THE FOLLOWING LOGS ARE HAS BEEN REQUES~'ED~] PREVIOUS (UNCORRECT) COPY OF THIS LOG. ~ CORRECTED COPIES. IT THAT YOU THROW OUT THE ~HANK YOU. - ~ ~ 5-9-13-9~ ' ; ~237-10476 1 L- 26 d~-~~ 6-3-6-91 5225-10065 2M-19~ ~ 11,17-'91 3835-9250 '2 M- 21~ ~ 11-1 1-91 3914-10599 1R-17~ ~ 9-15-19-91 5698-10345 6-19-23-91 - 5390-9841 : 1R-21~ ~ 10-6-11-91 5070-10180 ~[~.~1R-22 ~ ~ 9--24-29-91 6001-10813 1R-23~/ ~ ~ 10-22-91 6330-12188 1R-24~ ~ ~ 7-30/8-5-91 6753-12972 ~,q~l R-26 '/ ~ 7- 1 8-21 -91 5591-10218 ~'~;~1R-27~ ~ / 8-31 -91' 6547-9250 8-14-91 8~ 1L-24 ~' ~ J 5-19-22-91 5081-9241 1L-25 ~ ~ ~ 5-26-29-91 4978-9352 RECEIVED FEB 1 1 1992 Alaska 0il & Gas Cons. G~mrnission Anchorage TO: THRU: FROM: MEMORANOUM Stale of Alaska ALASF~ Oil AN~ GAS CONS]~I~¥a~ION COt~ISSION Commissioner · DATE: FILE NO: TELEPHONE NO: Jan. 14, 1992 DA.114.1 Blair Wondzell~~-;/z~ Sr. Petroleum Engineer SUBJECT: Diverter Test AAI KRU 3Q-4 Permit No. --. -. Kuparuk Ry. Field Doug Amos~ Petroleum Inspector Tuesday .Jan 7,: 1992;, I traveled this date from my residence to Prudhoe Bay to stand by for the diverter test at AAI's KRU 3Q-4 well on Parker Rig No. 245. Wedngsday_Jan 8_, !~92;: As the attached AOGCC Rig/BOPE Inspection Report indicates the diverter was in compliance with all applicable AOGCC regulations. In summary, I conducted the diverter inspection at AAI's KRU 3Q-4 well on Parker Rig No 245. Attachment. 02-00lA (Rev. 6/89) 20/llfMEMO1.PM3 OPERATION: Drlg ~ Compl~ Wkvr UIC~ Operator ~/r~ Permit # Location: Sec /-7 T /~/~ R ~5 M Location (gen'l) ~/ Well sign I N COMPL I ANCE; ~es n~ n/a A. DIVERTER 1. (~/ ( ) ( ) line sz & length 2. (~ ( ) ( ) line conn& anchored 3. (~ ( ) ( ) bifurcated & dwn wind 4. (~ ( ) ( ) 90° targeted turns 5. (~ ( ) ( ) vlvs: auto & simultaneous 6. (~ ( ) ( ) annular pack-off 7. (~ ( ) ( ) condition B. BOP STACK 8. ( ) ( ) (~wellhead flg wkg press 9. ( ) ( ) (~stack wkg press 10. ( ) ( ) (~annular preventer 11. ( ) ( ) (~pipe rams 12. ( ) ( ) (~blind rams 13. ( ) ( ) (~stack anchored 44. ( ) 14. ( ) ( ) ( ~ chke/kill line sz 45. ( ) 15. ( ) ( ) (~-90° turns targeted (chke & kill ln) 46. ( ) 16. ( ) ( ) (~HCR vlvs (chke & kill) 47. ( ) 17. ( ) ( ) (~manual vlvs (chke & kill) 18. ( ) ( ) (~connections (flgd, whd, clmpd) 19. (') ( ) (~drl spool 20. ( ) ( ) (~flow nipple 21. ( ) ( ) (~low monitor 22. ( ) ( ) (~ control lines fire protected C. CLOSING UNITS 23. (:,)~ ( ) ( ) wkg press 24. (~)~ ( ) ( ) fluid level 25. (i~)~ ( ) ( ) oprtg press 26. (~ ( ) ( ) press gauges 27. (~J~ ( ) ( ) sufficient vlvs 28. (y~)-~ ( ) ( ) regulator bypass 29. (~ ( ) ( ) 4-way vlvs (actuators) 30. ( ~ ( ) ( ) blind handle cover 31. (~ ( ) ( ) driller control panel 32. (~ ( ) ( ) remote control panel REMARKS: 577'i STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report DATE: Representative Representative 34. (~" ( ) ~5. (~r~ ( ) IN COMPLIANCE: ~es no n/@ ( ) firewall ( ) nitrogen power source (back-up) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM ( ~pit level floats installed ( ~flow rate sensors ((J'~mud gas separator (b)~degasser (~Separator bypass (~gas sensor (~chke In corm (~trip tank E. RIG FLOOR ( ) (~r~kelly cocks (upper,lower, IBOP) ( ) ( ~floor vlvs (dart vlv, ball vlv) ( ) (~J'~'kelly & floor vlv wrenches ( ) (b)~driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) ('~)'~kill sheet up-to-date (~)~gas ~etection monitors (H-S & methane) (~ .... hydr chke panel (~chke manifold F. MISC EQUIPMENT (~ flare/vent line (~'~90 ° turns targeted (dwn strm choke Ins) ( ~reserve pit tankage (~)~Personnel protective equip avail (~J~all drl site suprvs trained for procedures (~}.~H2S probes ('~-ig housekeeping ~6.() () 37. ( ) ( ) ~8.() () 39. ( ) ( ) 40. ( ) ( ) 41.() () q2.() () 43.() () 48.() () 49. ( ) ( ) 5o.() () 51.() () 52.() () 53.() () s4.() () · ss.() () 56.() () 57.() () 58.() () RECORDS: Date of last BOP inspection: /-///~ Resul ting non-compliance: /~y/~ Non-compliances not corrected & why: Date corrections will be oomp, eted, BOP test & results properly entered on daily record? Inspector C.0013 (rev 07/08/91 ) ALASKA OIL AND GAS / CONSERVATION COMMISSION October 23, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3Q-04 ARCO Alaska, Inc. Permit No.91-124 Sur. Loc. 2217'FNL, 2304'FEL, Sec. 17, T13N, R9E, UM Btmhole Loc. ll81'FSL, 1279'FEL, Sec. 8, T13N, R9E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits, required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. · c. man Alaska Oi~x~~~as Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AI_/~,.~A OIL AND C-.-.-~S CONSERVATION COMMI~51ON PERMIT TO DRILL 2O AAC 25.0O5 la. Type of Work Drill X Redrill ~ I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone Z~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKI~ 63'. Pad Elev.: 22' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 373301 ALK 4162 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2217' FNL, 2304' FEL, Sec. 17, T13N, RgE, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 995' FSL, 1335' FEL, Sec. 8, T13N, RgE, UM 3Q-04 #U63061 0 At total depth 9. Approximate spud date Amount 1181' FSL, 1279' FEL, Sec 8, T13N, RgE, UM 08-Nov-91 $200,000 ,, 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3Q-05 7723' MD 1181'@ TD feet 23' at 660' MD feet 677 6735' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500' feet Maximum hole an,le 32° Maximum surface 2340 psi~ At total depth (TVD) 3500psig @ 6735 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin, Wei,ht Grade Couplin, Len,th IV~ 'FVD IVD TVD linclude sta, e dataI 24 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25 9.625 36.0# J-55 BTC 4403 41' 41' 4444 3953' 1160Sx. PFE& HF-ERW 430 Sx. Class G 8.5 7" 26.0# J-55 BTC 7682 41' 41' 7723' 6735' 170SxClassG H F-ERW TI~ ~OJ~ i~b(iv~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~, £ t~ E I V I' IJ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet OCT ], z~ Effective depth: measured feet Junk (measured) true vertical feet ~r~¢~ 0JJ & Gas Cons. C0mmissi0~ Casing Length Size Cemented Measured depth True Vertical ~;ilt0ra~ Structural Conductor , Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~X Diverter Sketch ~X Drilling program X Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25,050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si,ned ~,~, ~~ Title Area Drilling En, ineer Date /sAoPI_ n~_.,~m~e~I o. I ' Commission US;pp~al date_ Permit Number See cover letter for ?//- ¢/.~ Z-f .. 2'_ 2- ~-. I ? // '- r.~3~- ~/'~//' other recluirement, Conditions of apProval Samples required ~Yes ~ N o Mud log required~ Yes ,~. N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ~.Yes ~ N o Required working pressure for BOPE 2M; ~3M; ~ 5M' ~ 10M' ~ 15M Other: ~ by order of Approved b Commissioner the commission Date ~ ! Form 10-401 Rev. 7-2 triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 23, 1991 Mr. L. C. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Isolation of Significant Hydrocarbon Zones Kuparuk River Field Revisions to Permits to Drill for 3Q-1,3Q-3, 3Q-4, 2M-21 This letter is to clarify the Permits to Drill for Kuparuk River Unit Wells 3Q-1, 3Q-3, 3Q-4 and 2M-21. The previously submitted General Procedures for the above referenced wells did not include any mention of the possibility of encountering significant hydrocarbon zones at shallower depths than the Kuparuk. If such zones are encountered, a sufficient volume of cement will be used to provide annular fill- up to a minimum of 500' above all significant hydrocarbon zones in accordance with Rule 20 AAC 25.030. Subsequent applications for Permits to Drill will include a statement in the General Procedure referencing the isolation of any significant hydrocarbon zones above the Kuparuk. Thank you for your consideration on this matter. If ARCO can furnish any further information, contact me at 265-6575° Sincerely, T.A. Senior Drilling Engineer TAB/mac A. W. MCBrid~~,e-¢¢/.,-,- S. D. Bradley E. D. Fitzpatrick 3Q Pad General Wellfile RECEIVED OCT 2 1991 Alaska 0il & Gas Cons. Commission ;Anchorage DRILLING FLUID PROGRAb, WELL 3Q-04 Spud to 9-5/8" Drill out to surface casino weioht UD -- -- Density 9.0-10.0 9.0-9.3 PV 15-35 5-1 5 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-1 5 2- 4 10 Minute Gel 15-40 4-8 APl Filtrate 1 0-1 2 8-1 0 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up 10.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12 Drilling Fluid System: - Tandem Brandt Shale Shakers - Triple Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaner, Centrifuges, Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid-Flow Sensor - Fluid Agitators RECEIVED Alaska Oil & Gas Cons. Commissio~ ~Anchora.qe Notes' Drilling fluid practices will be in accordance with the appropriate regulations stated ir 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2340 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3Q-04 will be 3Q-05. As designed, the minimum distance between the two wells would be 23' at 660' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well Or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hrs) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. Spud mud shoUld be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. ARCO ALASHA Structure · Pad 3Q Well · 4 Field · Kuparuk River Unit Location · North Slope, Alaska Created by : jones For: T BILLINGSLEY Date plotted : 17-Sep-91 Plot Reference is 4 Version J%. Coordinates are in feet reference slot #4. True Vertical Depths are reference wellhead. ~J]J~ EASTMAN I/_/Z//IIIC H R I ST E N S E N A B~ker Hughee ~mpany TD LOCATION: I 1181' FSL, 1279' FEL SEC. 8. T13N, R9E ........ East 0 20D 400 RECEIVED OCT 1 ,~'~ 19SI Oil & Gas Cons. Commission A~chorage --> 600 600 1000 12D0 · . 400 4 - ~ 800 - ~ 1200- _ 1600- - ~--2000- - ~1 2400- _ ~ 2800- L 3200- (D - 3600- (D - ~ 4000- _ ~'~ 4400- I - 4800- I V5200- 5600- 6000- 6400 - 6800- N 16.79 DEG E 3355' (TO TARGET) JTARGET LOCATION: 1 995' FSL, 1335' FELJ SEC. 8, T13N, RgE J TARGET WD=6423 TMD=7355 0EP-3355 NORTH 5212 EAST 969 RKB ELEVATION: 63' KOP TVD=500 TMD:500 DEP=O 6.00 12.00 BUILD 3 DE(; / 100' 1 8.00 24-.00 30.00 EOC W0=1511 TMD=1566 DEP=290 B/ PERMAFROST TVD=1593 TMD=1662 DEP=341 T/ UGNU SNDSTVD=2613 TMD=2864 DEP=977 T/ W SAK SNDS 'WD=3313 TMD=3690 DEP=1414 B/ W SAK SNDS WD=3753 TMD=4208 DEP=1689 K-lO ]WD=3888 TMD=4367 DEP=1775 9 5/8"CSG PT ~WD=5953 TMD=4444 DEP=1814 SURFACE LOCATION: 2217' FNL, 2304' FEL SEC. 17, T13N, R9E AVERAGE ANGLE 51.97 DEG TARGET ~D=6423 TMD=7355 OEP=5355 ~ZONE A ~D=6492 TMD=7437 DEP=3398 ~ KUP SNDS ~D=6565 TMD=7523 DEP=5444 TD /LOOGINGPT ~D=6735TMD=7723DEP=3549 I1111111111111111111 0 400 8~ 1200 1600 2~0 2400 2800 3200 3600 Scalel:200.O0VedlcolSectionon16.TgazlmufhwilhreferenceO.OON, O.00E~romslof~4 - 2800 -2200 ~ -2000 _ -1800 ~1600 - -1400 _ -1200 10 O0 800 600 400 200 0 A I I Struc', : Pad 5Q ~ -4 Fl'eld · Kuparuk River Unit Location : North Slope, AlaskaJ West Scale 1 150.00 2550 2500 I I I 1500 2450" I I 2400 2350 2300 2250 2200 2150 I I I I I I I I I I 4100 1700 2100 L1750 1800 1850 1500 1300 1100 1300 500 3700 19OO 1950 2OOO ~300 1100 900 900 1100 2050 2100 2150 i V 500 300 ..~ 300 700 1300 700 300 5O0 22OO 225O 2300 GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD Well 3Q-04 · . . . · · · · . 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker 245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4444') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole logging while drilling to total depth (7723') according to directional plan. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED OCT 1 1991 Alas~ .0il & Gas Cons. Commission ~chora~ 7 5 4 I I 13 5/8" 5000 F..,I BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)0 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'I-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 ~.jPARUK RIVER UNI'~ 20" DIVERTER SCHEMATIC HCR j 6 4 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) RE( EIVED 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOLWITH TWO 10" OUTLETS. 5. O~Z[ 1 ~ 1991 Alas~ 0il & Gas Cons. commissio~ Anchoraffa . 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20"- 2000 PSI ANNULAR PREVENTER SRE 2/6/90 -' CHECK LIST FOR NEW WELL PERMITS ** · · ITEM APPROVE DATE [.§ thru ' ' [10 & 13] · .... (4) Casg ~.~4/~/' [14 thru 22] (5) BOPE /~.~" /~ - lq - <::2 / [23 thru 283 (6) Other (6) Addl e 3. 4. 5. 6. 7. 8. · 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company YES Is permit fee attached ................................... ~ well to be located in a defined po01 ............................... F Is Is well located proper distance from property line ................... ~ Is. well located proper distance from other wells ..................... ~ Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... ~ Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Lease & Well NO Does operator have a bond in force .... ~ ............................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & n~rnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Add it ional requirements ............................................. / REMARKS geol ogy' eng i neer i LCS- ~ MTM//,~ INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE rev 03/29/91 jo/6.011 O --t 'l-Z ~O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically · organize this category of information. .o ALASKA COMPUTING CENTER FIELD NAME ~ KUPRRUK R~VER BOROUGH STATE ~ ALASK~ APE NUMBER REFERENCE NO ~ 9~078 INC, RECEIVED MAR 2. 4 1992 ,IS TaPe Verification Listing ;cblUmberger ~las~a Computing Center 6-MAR-1992 08:44 **** REEL HEADER **** SERVICE NAME : EDIT DATE = 92/0]/ 6 ORIGIN : 'FLIC REEL ~A~E : 92078 CONTINUATION # ~ PREVIOUS REEL ~ COMMENT : ARCO ALASKA INC., 3Q-04, KUPARUK RIVER, 50-029-222~9-00 *$** TAPE HEADER SERVICE NAME : ~DIT DAT~ : 921031 6 O~IgIN : FLIC TAPF ~A~E : 92078 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., 3Q-04, KUPARUK RIVER, 50-029-22~19-00 **** FILE ~{EADER **** FIL~ NAME : EDIT .001 SERVICE : FLIC VERSION : O01A06 DATE : 92/0]/ 6 MAX REC SIZE ~ 1024 FIbF TYPE ~ LO L~ST FILE ****************************************************************************** FILE - EDIT.O01 ARCO ALASKA INC. KUPARUK Ri~VER 30-04 50-029-22219 MAIN PASS LWD LOG DATA THE DENSITY DAT~ PRESENTED ON THIS LIBRARY TAPE IS FROM 'RHOB MAX' DATA SAMPLED EVERY -.5000 FEET DATA INCb~!DMD - TOOL EXTENSION TOOL TYPE USED NAME RGS .L~1. NOS ,bWl LOGGI~tG wglbE DRILLING RESISTIVITY/GR 4517' TO 7700' LOGGING WHILE DRILLING NEUTRON/DENSITY 4517' TO 76]7' IS Tame verlficatio~ tisting cblumbergerA!asKa Computing Center 6-MAR-1992 08:44 TABLE TYPE ~ CONS TUNI YAbU DEFI TYPE CN ARCO ALASKA INC. Company Name FN KUPARUK RIVER Fle~d Name WN 30-04 Well Name APlN 50-029-22219 AP1 Serial Number FL 2217' FNL & 2304' FEL Field Location SECT 17 Section TOWN 13N Township RAN~ 9E Range COUN NORTH SLOPE COunts NAT! USA Nat ion LAT! Latitude LONG Longitude WITN Wit6ess' Name SON 599389 Service Order Number PDAT MSL Permanent datum EPD FT 0, Elevation of Perm. Da LMF RKB Log Measured From APO FT 63. ABOVE PERMANENT DATU~ EKB FT 63. Elevation o~ Kelly Bu EOF FT 63. Elevation of Derrtc~ ELL FT 2~ El~vation of Ground 5 TDD FT 77~0, Total Depth - Driller TDL FT 77~0, Total OePth - Logger BL! FT 7720, Bottom Log Interval TLI FT 4517 7 Top Log Interval DFT LSND' Drilling Fluid T¥~e. DFPH Drlllln~ Fluid Ph ZONE DFV CP 43, Drilling Fluid Vis¢os DFL F] Drilling Fluid Loss ZONE R~S OH~M 3.2! Resistivity of ~ud Sa ~ST DEGF 64 Mud.Sample Temperatur R~F$ OHM~ 2~6 Resistivity of mud fi ~FST DEGF 64, ~ud~Filtrate SamPle T RMCS OHMS ResiStivity Of MUd Ca ZONE MCST DEGF Mud Ca~e Sample Tempe ZONE STE~ DEGF -999,25 Surface Temperature BHT DEGF 140, Bottom Hole Temoeratu ,IS Tape verification Listing ;ChlUmberger AlasKa Computing Center \ 6-MAR-1992 08:44 TABLE TYPE : ZONE TUNI BDEP TDEP DFPH DFL RMCS MCST ..... ,: ! FT 0, 0. O, 0, O, 0, ..... TAOLE TYPE : CURV RMOB PEF DCA[, DPH! DPOR TNPH ATR PSR DER ROPE DEFI DEPT De~th Channel Name $$2 RHO Density - LDT Bulk Density Photoelectric Fa tot Differential Caliper Density Porosity Density Porosity Output from an ApPlication Program Thermal Neutron Porosity Gamma Ray ** DATA FORMAT SPECIFICATI~]N RECORD ** SET TYPE TYPE REPR CODE ~ALUE 1 66 0 2 66 0 3 73 52 4 66 5 66 6 73 7 65 9 11 66 19 12 68 1:~ 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 IS Tape Verification !misting chlumberger Alaska Computing Center 6-MAR-1992 08:44 ** SET TYP NAM~ SERV UNIT SER ID ORD DEPT FT 599389 00 000 ROS2 LWl G/C3 599389 O0 000 RHOB LW~ G/C3 599389 O0 000 PEF bWl 599389 00 000 DCAL bW! IN 599389 O0 000 DPHI LWI PU 599389 00 000 DPO~ LWI PU §99389 00 000 TNPH LW1 PU 599389 O0 000 ATR LW1 OHMM 599389 O0 000 PSR bWt OHM~ 599389 O0 000 D~R LW! OHMM 599389 O0 000 ROP~ LWI F/HR 599389 O0 000 GR LW~ GAPI 599389 O0 000 E - CHAN *~ VICE API API API API FILE ~UMB NUMB SIZE REPR PROCESS ER # LOG TYPE CLASS MOD NUmB SAMP ~5EM CODE (HEX) O0 0 I ! I 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 I ! 1 4 68 0000000000 O0 0 ~ 1 ! 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 ! 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 ! 1 I 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 ~ 1 4 68 0000000000 O0 0 I I I 4 68 0000000000 O0 0 I 1 I 4 68 0000000000 DEPT 7724 500 ROS2,bWI DCAL'LW! -999~250 DPHI,LW1 AT~'LW~ -999,~50 PSR'LW1 G~:LW~ -999,250 DEPT, !700,000 ROS2.LW1 DCAL,LWl 999,250 DPHI,LW1 AT~.LWl 999,250 PSR.LW~ G~.LW! -999.~50 DEPT 7600.000 R052. LW! DCAL:LW1 0.366 DPHI:LW! ATR,LW! ~ 707 PSR.LW1 G~,LW! 73:751 DEPT 7500.000 ROS2.LW! DCAt~LW! 0.108 DPHI ATR.LW~ I0,9tl PSR:LW! GR.LWI 44,196 DEPT 7400,000 ROS~ DCAL:LW1 0,775 ATR LW! 3.169 PSR.LW! G~LW! 95,384 DEPT. 73o0,000 RO$2.bWl DCAt..LW~ 0,857 DPHI LW1 AT~,LWi 1,548 PSR~LW1 GR,LW1 65,465 -999,250 DPOR,LW1 .999,-250 TNPH.,LW1 -999o250 DER,bW! -999,250 ROPEeLW1 -999 ~50 RHOB.,LW! -999,250 PEF,LWI -999i~50 DPOR,bW1 -999 ~50 TNPH,LW1 -999 50 DER,LW1 -999:2~0 · 2 43o ..os..uw! PEF 2,583 DER,LWl 2,626 ROPE,LW! ~6,029 DER:bWI 15. 6 ROPE,LW{ 2 ~8 RHOB.bW1 2 ~ PEF.bWI o: 3 DPOR.bw! O: TNPH.bWl 3,006 DER,LW1 3,060 ROP£,LW1 2 521 RHOB,LW1 2.511 PEF,LW! O:OB4 DPOR,LW1 0 084 TNPH,LW1 !,40q DER,LW! i:459 ROP~,LW1 24')81 -999, $o '999,2~0 27,355 222,858 5 8 90,~ ~0 47'~01 ~chlumberger A!asi<a Computlno Center DEPT. 7200.000 RO$2,LWI DCAL,LWI 0,652 DPHI,LWl ATR.bW1 2,350 PSR.LWl GR.LW1 78,832 DEPT, 7100 000 ROS2.LWl DCAL.LWl 0~558 DPHI.LWI ATR,LWI 2.906 PSR,LWl G~.LWI 123.716 DEPT 7000.000 ROS2.LWl DCAL:LW1 0.485 DPHI.LW1 ATR.bWI. 3,047 PSR,bWl GR,LW1 148.574 DEPT. 6800,000 ROS2,LW1 DCAL,SW1 0,589 DPHI,LWl ~T~,LW~ 3,020 PSR,LW~ G~.LW1 87.3~1 6-MAR-1992 08:44 2.273 RHOB.bN1 0.~29 DPOR,5Wl 2,165 DER~SW! 2.~2g RHOB,LWI 0, 55 DPOR.LW1 ~,623 DER,bW1 2,427 RHOB,bW1 0,135 DPOR.LWl 2.617 DER,.tWi I DPOR'bWI 2'873 D'ER,LW1 2.282 2o-u2 DEPT 6700.000 ROS2 LW! 2.544 DCAL;LW1 0.528 DPHI~LWI 0.064 ATR LWI 4 411 PSR.LWi 4,773 DEPT. 6600.000 ROS2.LWl DCAL LW1 0 448 DPHI.LW1 ATR:LW1 3;607 PSR,LW1 G~,LW1 81,190 DEPT 6500 000 RO$2.LWl DCAL;LW1 0;326 DPHI,LW1 AT".LW! I 781 PSR.LWl GI~.LWl 91:066 DEPT. 6400.000 ROS2.bW1 DCAL LW1 0,322 DPHI LW1 ATlm:bW~ 2.507 PSR:bW1 GR,bWl 106.421 DEPT 6200.000 ROS2.LWi DCAL:LW1 0.398 DPHI bWl ~T~.LWI 2,316 PSR~LW1 G~.LWl 84.081 RHOB,LW1 DPOR,SW1. DER,SW1 RHOB,LW1 DPOR,SWl DER,LWI 2.253 0.240 3.480 RHOB.LWt DPOR,bWI DER,bW1 2 2 1.642 RHOB.LW1 DPOR,LW1 DER,LW1 RHOB,LW1 DPOR,bW1 DER,LW1 2,377 0.165 2.128 o:l 1.868 RHOB,hW! DPOR,bW1 DER,LW1 2.286 0,220 2.165 RHOB,LW1 DPOR,LW1 DER,LW1 2,273 0.22 9 21228 O. 5 2.'712 2,427 O. 135 2,743 ,270 .231 2,989 .282 0,064 4.645 2 253 0!.240 3 522 2.402 0,150 1.692 2*377 243 2.373 0,168 1.924 2 286 0i220 2 218 PAGEI PEF,LW1 TNPH,LW! ROPE.LW1 98, 90 55, O0 325,638 PEF,LW1 TNPH.LWl ROPE.LW1 100,000 387' PEF, LW 1 TNPH,bW1 ROPEibW1 5~4.5' 8 0'5 0 456,609 PEF,bWI TNPH,LWI ROPE,bW1 319 t975 PEF,bWi TNPH,LWI ROPE,bWl PEF*bWI TNPH.LWI ROPE,bW1 OO4 00 23 586 34'400 348,882 PEF,LW1 TNPH..LW1 ROPE*bW1 100,000 oo PEF.LW1 TNPH.bW1 ROPE.bW1 PEF.LW1 TNPH,bW1 ROPE.bWl 9,888 43,100 412.852 15'980 46,?00 319.62t PEF.bW! TNPH.bWI ROPE.LW1 282",456 PEF.LW! TNPH.LW1 ROPE.LW1 46 , 339 5,7 0 333,$~0 Tape Verification Listing chlumberger AlasKa Computing Center 6-MAR-1992 08:44 ¸. DEPT 6100.000 ROS2.LWl DCAL~LWI 0,381 DPHI,LW~ ATR,LW 1 2,445 PSR,LW1 . g 2.4 G~. LWl DEPT. 5800,000 DCA[. 5Wl 0,112 ATR:LWl 2,643 G~,LWl 73.875 DEPT, 5700,000 DCAL.LWl 0. 160 AT~ LWl 2,729 G{~ ~I..W ! 85 * 962 DEpT 5600.00o DCALiLW! 0,250 ~T~ LW1 2.744 G~.LW1. 64.781 DEPT, 5500,000 DCAL,LW! 0,085 ~T{~,LW1 2 928 G{~.LW1 67:630 DEPT, 5400,000 DCAL.LW1 0,521 AT~,LW! 3,059 GR.LWl 77,486 DEPT 5300.000 DCAL~LWl 0'1!5 {~TR LW1 2,473 G~.:LWI 66,558 D~PT. 5200.000 DCAL.LWl 0.040 ~T~.LW1 2,~36 G~.LWl 73, 95 D~PT. 5100.000 DCAL,L~ 0.064 ~T~ LW1 2 989 ROS~.LW1 DPH ,bW1 PSR.LW{ ROS2.LW1 DPHI,LW1 PSR.LW1 ROS2,bWl DPHI,LW1 PSR.LW! ROS2. bWl PSR.LW1 ROS LWl DPH~:LW1 PSR,bWl ~O82 bw 1 DPHI:LW1 PSR.LWI ROS2'LW1 DPHI,LW1 PSR,LW1 ROS2.LW1 DPHI bWl PSR:LWl ROS2.LWl DPHI.LWl PSR.LW1 2,284 RHOB,LW1 0,222 DPOR,bW1 2.191 DER.bWl 2,340 RHOB,LW1 0,188 DPOR,bW1 2.473 DER,bW1 2 393 RHOB,bW1 0:156 DPOR,LWl 2,741 DER,LWl 2.380 RHOB,bW1 0,~3 DPOR.SWl 2, 4 DER,LW1 2.398 RHOB~LW1 0,153 DPOR,LWI 2.552 DER'LW1 2,403 RHOB.DW1 0,150 DPOR,LW! 2' 05 DPOR,LW1 ,756 DER,LW1 2.503 RHOB'LW1 0 089 DPOR,LW1 ~917 DER,LW1 2.329 RHOB,LW1 0.194 DPOR,LWl 2'457 DER,LWl 2.348 RHOB,LW1 0 183 DPOR,LW1 2:349 DER,LW1 2.349 RHOB,bW1 0,183 DPOR,LWl 2,767 DER.LWl 2 284 PEF.*LW{ 0:222 TNPH,bW1 2.274 ROPE'bWI 2.340 P~r.bwl 0,188 TNPH,bW1 2.529 ROPE~bW1 2,393 PEF*bWI 0.i56 TNPH,bWl 2.792 ROPE,LW1 2'380 PEF,LWl 0,~63 TNPH.LWl 2. 52 ROPE,5~I ,153 TNP 2,611 ROP£,LW1 2 403 PEF'LWI 0:..1~0 TNPH,bW1 2,620 ROP~,LW1 O, TNPH bW! 2.813 ROPE 2.503 PEr.b~! 0.089 2,965 ROPE.b~! 2'329 PEF.bW! 463 ROPE.LW! 2.348 PEF.LW! 0.183 TNPH,LWl 2.412 ROPE,LW1 2.349 PEF.bWl 0.183 TNPH.LWl 2.839 ROPE.LW1 2 2 2 2 47'500 346,,058 . I ,040 4~:,4~7,6 0 233, 5,9 282.,~!66 2,929 1 34,~0 291.'4{2 436,888 336,062 304 900 3.3 7 35,2~0 265.090 IS Tare Yerlficatlon LiSting cblumberger Alaska Computing Center DEPT 5000 000 ROS2 DCA[,' ' ,tWl 0.!71 DPHI:LWl ATR,LW1 1,711 G.,LWt 77,232 DEPT 4900.000 ROS2,LWl DCALiLW1 0,000 DPHI..LWl AT~ LWi 0,650 PSR,LWl GR,LW! 73,526 EPT~ 4800,000 ROS2 AT~,LW1 2,393 PSR.LW1 G~.LW! 77,297 DEPT 4700,000 ROS2,LW1 DCALiLW1 0.267 DPHI.bWi ATR'LW! 2,924 PSR.LW1 G",LW! 66.698 DEPT 460~:000 ROS~.LWI DCAb:LW! 387 DPH ATR LW!, ] 707 PSR,LW~ DEPT 4500,000 ROS2,LW! DCAL~LW1 0,281 DPHI ~T~.LW! 0.080 PSR: LW! G~,LW! 37.883 DEDT 4400,000 DCAL~LW[ -999.250 DPHi:LW~ D~PT. 4398,500 ROS~.LW1 DCAL.LWl -999.250 DPHI.LWl AT~.LW{ -999.250 PSR,LW! GP.LW1 -999,250 ** END OF DATA **** FILE TRAILER **** FILM NAME : EDIT .001 SERVICE : FL!C VERSION : 001A06 DATE : 92/0]/ ~X AEC SIZE : 1024 FILF TYPE : LO LAST FILE : 6-MAR-1992 08:44 2,356 RHOB,LWl 0,178 DPOR.,bW1 4.172 DER,bW1 2,~6 RHOO.bWI O.. 3 DPOR., 2.256 RMOB,bWI 0,23g DPOR,LW1 2.388 ~DER.LWl 2.325 RHOB.LWI 2.830 DER 2 4~ RHOB,LW1 6,0~0 DER,LWI 2,470 RMOB,LWl 0.109 DPOR,LW1 25.161 DER,5Wl 9 50' DPOR,LWl -999 250 DER.bW! ~i99.i50 RHOB.LW1 99. ,~0 DPOR.bW1 99. 0 DER, GW ! TNPH,bWl 2.275 ROPE.LWl 2.266 PEF 0.,,2 ] 3 TNPH 0.828 ROPE ., 2,325 PEF.LWl 0.197 TNPH,LWI 2.862 ROPE.bWl 2.4~ 'PEF 5;< 69 RO E.hWl 2.470 PEF.LW! ooo. ooo -99 250 TNPH.LWl -999,250 ROPE.LWl -999 250 PEF:~W! -999i250 TNPH Wl -999 250 ROPE.LW! PAGE~ 3~ '964 ,800 287,194 2,904 40'400 492'77.3 215,995' 266~09! lO0'O00 . 44,~00 999'250 .999, i5o '999,~$0 '999,250 20 '999'2~0 -999, -999,250 IS Tape Verif~,.cation Listing cblumberger Alas.Ka Computing Center **** FILE HEADER **** FILE NAME ~ EDXT ,002 SERVICE ~ FbIC VERSION ~ 00lA06 DATE : 92/03/ 6 MAX REC SIZE : t024 FILE TYPE : LO L~ST FILE : 08:44 ****************************************************************************** FILE - EDIT,O02 ARCO ALASKA INC, KUPARUK RIVER 30-04 50-029-22~19 MAIN PASS bWD LOG DATA FROM BIT RUN TWO ***** PART OF THE DATA FROM BIT RUN TWO WAS UNRECOVERABLE, ***** THE DENSITY DATA PRESENTED ON THIS LIBRARY TAPE IS FRON 'RHOB MAX' DATA SAMPLED EVERY -,5000 FEET DATA INCLUDED ToOL EXTEW$ION TOOL TYPE USED NAmE ,LW2 bOGGING WHILE DRILLING RESISTIVITY/GR 5917' TO 7284' bOGGING WHILE DRILLING NEUTRON/DENSITY 5845' TO ****************************************************************************** TABLE TYPE : CONS TUNI VADU DEFI TYPE FN APIN FL SECT TOWN RANG COUN ARCO ALASKA. INC, Company Name KUPARUK RIVER Fleld Name 30-04 Well Name 50-029-22219 API Serial Number 2217' FNL & 2304' FEb Field Location 17 Section 13N Township 9E ~ange NORTH SLOPE County A~so~od uo~neN Iem~eqt e~eN leuueqj ql--O ~d~O *0 '0 °0 '0 *0 '0 £~ 3NOZ 3NOZ 3NOg 3NOg e~n%e~adme& aoe~zn~ S~'666- XD3Q eD pnw ~o ~I ~stse~ '~9 ~93Q soos]A pint ~u$ JO 'f~ dj A~O ~SUeQ.P]nt~ ~u~]I]~ QN~q ED/9 QJQ · TeA:a~uI oo~ dO~ L'L~S~ ~3 leAve,u! Ooq mop,oB 'O:LL ~J Iqa .~ebeoq - q~deO Te~o~ .0:4 &A qpunqa~ ;o UoT3eAel3 ~O!~aO ~o uoI~eAel~ *E9 &~ mo:A pe~nseew bOq ~0' epn3T3eq uoT~N Vgfl 2dX~ i~20 flqVA INll~ Nq'...l.qd 666- 3M'I't~OH8 0§3'666- ~Mq ~[3H 000 [83/.. 0000000000 89 9 T ] ~ 0 O0 000 O0 68£66g NNHO ~q 0000000000 89 9 T I g 0 O0 000 O0 68[66~ Ad gN"! 0000000000 89 ~ ~ I ~ 0 O0 000 O0 68E66~ NI ~q 0000000000 89 ~ ] ~ ~ 0 O0 000 O0 bSE66~ ~Mq 0000000000 89 ~ I ~ ~ 0 O0 000 O0 68E66~ £0/9 ~q aOHa 0000000000 89 9 ] ~ ~ 0 O0 000 O0 68E66~ Eb/D ~M~ 0000000000 89 9 g I ~ 0 O0 000 O0 6BE66~ £J T 99 0 t 99 9~ 89 99 ~I 89 g~ J S9 6 ~0 89 8 g9 ~ Ef 9 99 g ~ 99 ~ ~E E~ E 0 gg ~ 0 99 i ~fiqVA 3GOD 8d3~ ** QSOO3a NOI£~DiJlD3dS iVNSO~ ~&~ 01 ~9:80 g66I-SVN-9 buT~STq UOT~eOl~T~eA eae£ gl; ,IS TaPe Verification Listing ,chlumberger Alaska Computing Center 6-MAR-J992 0B:44 PAGE~ DEPT 7200.000 DCAL:LW2 0.233 DEPT 7100.000 DCAL~hW2 0,08t D~PT, 7000,000 DCALoLW2 0,164 DEPT. 6900.000 DCAL.LW2 0,244 .oo ooo DEPT. 6700.000 DCAL,tW2 -0.291 DEPT. 6600,000 DCAL.LW2 0,281 DEPT. 6500.000 DCAL.LW2 0.20! DEPT 6400 000 DCAL:L DEPT. 6300,000 DCAL.LW2 0,268 DEPT 6200.000 DCAt.~LW2 0,158 DEPT. 6100.000 DCAI..LN2 0,249 D~PT. 6000.000 DCAL.LW2 0,940 DEPT 5900.000 DCAI,~LW2 0,247 D~PT ~845.500 DCAL:LW2 999.250 RO$2.LW2 2,520 TNPH.LW2 ROS2,LW2 2.387 TNPH.LW2 40.600 ROS2 bW2 2.4!8 TNPH:LW2 42,700 ROS2.bW2 ~ 47~ TNPH,LW2 3 RO$2.LW2 ~,527 TNPH.LW2 ~ ,900 TNPH,.LW2 ,300 RO$2,LW2 ~,504 TNPH.LW2 3 ,200 .. ROS2 LW2 ~.414 TNPH~LW2 3 .900 TNP [,W2 4 . 0 473 o ROS2 LW2 2 7 RO$2.LW2 2.439 TNPH.LW2 39.600 560 RO$2.LW2 2 402 TNPH.LW2 -999~250 ROS2.LW2 -999 250 TNPH.SW2 -999:~50 RHOB,LW2 DER.bW2 RHOB,bW2 DER,~W2 RHOB.bW2 DER,bW2 DER,SW2 ~HOB,bW2 DER,LW2 RHDB.bW~ DER,bW2 RHOB,bW2 DER,~W2 RHOB,LW2 DFR.GW2 RHOB,bW2 DER,LW2 RHOB,LW2 DER,LW2 EHOB.LW2 DER.bW2 RHOB,LW2 DER.LW2 RHOB.bW2 DER.bW2 RHOO.LW2 DER,LW2 RHOB.bW2 DER.LW2 2 520 739 2~418 2.51~ 2, 2.670 4°362 2,414 1,841 2 2 473 2 2.439 2.303 2 560 2 402 -999:250 -999,250 -999,250 PEF.bW2 GR,bW2 PEF.LW2 GR..LW2 PEF,LW2 GR'LW2 PEF,~W2 GR. W2 PE~.~W2 GR.LW2 PEF'LW2 GR,LW2 P~F.LW2 GR,LW2 PEF,LW2 GR.LW2 PEF W2 PEF.LW2 G~.~W2 PEF,hW2 GR.hW2 PEF,LW2 GR.bW2 PEF.LW2 GR,bW2 ,, 101. 9 4,260 151,728 ., ., 4,792 ~09,212 X06'790 9,042 78,0~7 ? 3,316 95,965 5,007 250 ENO OF DATA IS Tape VerlficatloD Listing cblumberger AlasKa ComPuting Center 6-MAR-1992 08:44 **** FILE TRAILER FILE NA~E : EDIT .002 SERVICE ~ FbIC VERSION ~ O01A06 DATE : 92/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME ~ EDIT DATE ~ 921031 6 ORIGIN ~ FLIC TAPE NAME : 92078 CONTINUATION # : 1 PREVIOUS TAPE ~ COMMENT ~ ARCO ALASKA INC., 3Q-04, KUPARUK RIVER, 50-029-22219-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE ! 921031 6 ORIGIN : FbIC R~E[, NAME ~ 92075 CONTINUATION # : PREVIOUS REEL ~ COMMENT ~ ARCO ALASKA INC., 30-04, KUPARUK RIVER, 50-029-~19-00
