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Home My WebLink About181-137MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-07 KUPARUK RIV UNIT 1A-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-07 50-029-20658-00-00 181-137-0 W SPT 5832 1811370 1500 2608 2602 2606 2588 20 20 20 20 4YRTST P Adam Earl 7/12/2023 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-07 Inspection Date: Tubing OA Packer Depth 560 1810 1740 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714090529 BBL Pumped:1.2 BBL Returned:1.2 Friday, September 1, 2023 Page 1 of 1           Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-20 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 1811370 E-Set: 34407 Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-01 50-029-20590-00 906681181 Kuparuk River Production Profile Field & Processed 26-Sep-20 0 1 2 1A-07 50-029-20658-00 906722930 Kuparuk River Leak Detect Log Field- Final 27-Sep-20 0 1 3 1A-07 50-029-20658-00 n/a Kuparuk River Leak Detect Log Field- Final 12-Sep-20 0 1 4 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 11-Sep-20 0 1 5 1A-24 50-029-22984-00 906701351 Kuparuk River Multi Finger Caliper Field & Processed 10-Sep-20 0 1 6 1D-118 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 13-Sep-20 0 1 7 1D-118 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 14-Sep-20 0 1 8 1D-141A 50-029-22967-01 906685052 West Sak Packer Setting Record Field- Final 30-Sep-20 0 1 9 1H-116 50-029-23594-00 9067722868 Kuparuk River Injection Profile Field & Processed 21-Sep-20 0 1 10 1H-113 50-029-23588-00 906714570 Kuparuk River Injection Profile Field & Processed 19-Sep-20 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1811370 E-Set: 34323 12/07/2020 Abby Bell Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-01 50-029-20590-00 906681181 Kuparuk River Production Profile Field & Processed 26-Sep-20 0 1 2 1A-07 50-029-20658-00 906722930 Kuparuk River Leak Detect Log Field- Final 27-Sep-20 0 1 3 1A-07 50-029-20658-00 n/a Kuparuk River Leak Detect Log Field- Final 12-Sep-20 0 1 4 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 11-Sep-20 0 1 5 1A-24 50-029-22984-00 906701351 Kuparuk River Multi Finger Caliper Field & Processed 10-Sep-20 0 1 6 1D-118 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 13-Sep-20 0 1 7 1D-118 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 14-Sep-20 0 1 8 1D-141A 50-029-22967-01 906685052 West Sak Packer Setting Record Field- Final 30-Sep-20 0 1 9 1H-116 50-029-23594-00 9067722868 Kuparuk River Injection Profile Field & Processed 21-Sep-20 0 1 10 1H-113 50-029-23588-00 906714570 Kuparuk River Injection Profile Field & Processed 19-Sep-20 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1811370 E-Set: 34322 12/07/2020 Abby Bell Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-01 50-029-20590-00 906681181 Kuparuk River Production Profile Field & Processed 26-Sep-20 0 1 2 1A-07 50-029-20658-00 906722930 Kuparuk River Leak Detect Log Field- Final 27-Sep-20 0 1 3 1A-07 50-029-20658-00 n/a Kuparuk River Leak Detect Log Field- Final 12-Sep-20 0 1 4 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 11-Sep-20 0 1 5 1A-24 50-029-22984-00 906701351 Kuparuk River Multi Finger Caliper Field & Processed 10-Sep-20 0 1 6 1D-118 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 13-Sep-20 0 1 7 1D-118 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 14-Sep-20 0 1 8 1D-141A 50-029-22967-01 906685052 West Sak Packer Setting Record Field- Final 30-Sep-20 0 1 9 1H-116 50-029-23594-00 9067722868 Kuparuk River Injection Profile Field & Processed 21-Sep-20 0 1 10 1H-113 50-029-23588-00 906714570 Kuparuk River Injection Profile Field & Processed 19-Sep-20 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1811370 E-Set: 34321 12/04/2020 Abby Bell ! 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ast Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (~52' OF RATHOLE, ALL PERFS OPEN) 8,518.0 9/10/2020 1A-07 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: UPDATE PATCH INFORMATION 11/11/2020 1A-07 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 31.6 Set Depth (ftKB) 88.0 Set Depth (TVD) … 88.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.5 Set Depth (ftKB) 2,469.5 Set Depth (TVD) … 2,212.6 Wt/Len (l… 45.50 Grade K-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 2,104.0 Set Depth (ftKB) 8,656.0 Set Depth (TVD) … 6,403.7 Wt/Len (l… 26.00 Grade K-55 Top Thread Casing Description PROD Tie-Back w/Patch OD (in) 7 ID (in) 6.15 Top (ftKB) 29.1 Set Depth (ftKB) 2,108.7 Set Depth (TVD) … 1,998.4 Wt/Len (l… 26.00 Grade L-80 Top Thread TCII Tubing Strings Tubing Description TUBING WO 2013 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.4 Set Depth (ft… 8,322.8 Set Depth (TVD) (… 6,131.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.4 25.4 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 515.7 515.7 1.26 NIPPLE CAMCO DS NIPPLE 2.875 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 8,078.0 5,932.3 35.13 Sliding Sleeve - Closed BAKER CMU SLIDING SLEEVE 2.812 8,316.1 6,126.2 35.70 LOCATOR BAKER LOCATOR 9Spaced out 1') 2.980 8,317.0 6,126.9 35.70 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 Tubing Description TUBING WO 1985 String Ma… 6 5/32 ID (in) 4.00 Top (ftKB) 8,317.2 Set Depth (ft… 8,340.3 Set Depth (TVD) (… 6,145.8 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,317.2 6,127.0 35.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" TUBING 4.000 8,332.2 6,139.2 35.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB.-ELMD TTL @8322' ON Iprof 8/22/07* 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,938.5 5,818.0 34.82 LEAK - TUBING Tubing LEAK, 1-WAY AT PBR 10/27/2013 2.992 8,183.0 6,017.9 35.44 P2P-PATCH- UPR 2.72 P2P (4' OAL) ATTACHED TO SPACER PIPE. 10/27/2020 1.600 SPP35269 8,187.0 6,021.2 35.44 SPACER PIPE & ANCHOR LATCH 2-1/16" P110 SPACER PIPE, ANCHOR LATCH (2400# SHEAR), 35.2' OAL 10/27/2020 1.590 CPAL35152 8,205.0 6,035.9 35.49 LEAK - TUBING Leak @3050 BWPD, HAL IPROF/LDL 9/26/2015 2.992 8,214.5 6,043.6 35.51 SPACER PIPE, ANCHOR LATCH 2-1/16" P110 SPACER PIPE, ANCHOR LATCH (4800# SHEAR), 36' OAL 10/26/2020 1.590 CPAL35020 8,214.5 6,043.6 35.51 PBR 2.70" PBR 10/26/2020 2.070 CPPBR35013 8,215.0 6,044.0 35.52 LEAK - TUBING Leak @3050 BWPD, HAL IPROF/LDL 9/26/2015 2.992 8,244.0 6,067.6 35.60 LEAK - TUBING Leak @3050 BWPD, HAL IPROF/LDL 9/26/2015 2.992 8,247.0 6,070.0 35.61 Fish 6 centralizer arms, 3 rings, and 1 spring from chem cutter centralizer. 11/20/2019 0.500 8,250.6 6,072.9 35.62 SPACER PIPE, ANCHOR LATCH 2-1/16" P110 SPACER PIPE, ANCHOR LATCH (7200# SHEAR), 31.65' OAL 10/26/2020 1.590 CPAL35154 8,250.6 6,073.0 35.62 PBR 2.70" PBR 10/26/2020 2.070 CPPBR35038 8,254.0 6,075.7 35.63 FIsh 1" long piece of grapple. Picture of broken grapple in attachments. 11/12/2019 0.000 8,282.2 6,098.6 35.72 PBR 2.70" PBR 10/26/2020 2.070 CPP35219 8,282.2 6,098.6 35.72 SPACER PIPE, ANCHOR LATCH 2-1/16" P110 SPACER PIPE, ANCHOR LATCH (9600# SHEAR), 31.8' OAL 10/26/2020 1.590 CPAL35151 8,285.0 6,100.9 35.73 LEAK - TUBING TUBING LEAK @ 1000 BWPD, 1800 PSI INJECTION, SLB IPROF/LDL 3/17/2019 2.992 8,300.0 6,113.1 35.77 LEAK - TUBING Ran LDL found a leak at 8300 RKB not on WSR 9/27/2020 2.992 8,314.0 6,124.4 35.71 P2P-PATCH- LWR 2.72" P2P LOWER PACKER (4800# SHEAR), 4.01' OAL 10/26/2020 1.600 CPP35219 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled & pushed to rathole during workover 12/9/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,126.0 8,220.0 5,971.5 6,048.1 C-4, C-3, C-2, 1A-07 2/10/1982 4.0 IPERF Enerjet 8,232.0 8,249.0 6,057.8 6,071.7 C-1, 1A-07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A-5, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing 1A-07, 11/11/2020 2:50:43 PM Vertical schematic (actual) PRODUCTION; 2,104.0-8,656.0 FISH; 8,537.0 IPERF; 8,445.0-8,466.0 IPERF; 8,422.0-8,443.0 IPERF; 8,404.0-8,413.0 PACKER; 8,317.2 P2P-PATCH-LWR; 8,314.0 LEAK - TUBING; 8,300.0 SPACER PIPE, ANCHOR LATCH; 8,282.2 LEAK - TUBING; 8,285.0 SPACER PIPE, ANCHOR LATCH; 8,250.5 FIsh; 8,254.0 Fish; 8,247.0 LEAK - TUBING; 8,244.0 IPERF; 8,232.0-8,249.0 SPACER PIPE, ANCHOR LATCH; 8,214.5 LEAK - TUBING; 8,215.0 LEAK - TUBING; 8,205.0 SPACER PIPE & ANCHOR LATCH; 8,187.0 P2P-PATCH-UPR; 8,183.0 IPERF; 8,126.0-8,220.0 Sliding Sleeve - Closed; 8,078.0 GAS LIFT; 8,017.5 PACKER; 7,965.6 LEAK - TUBING; 7,938.5 PLUG; 7,890.0 ftKB GAS LIFT; 7,881.0 SURFACE; 30.5-2,469.5 PROD Tie-Back w/Patch; 29.1- 2,108.7 CSG CMT; 34.0 ftKB NIPPLE; 515.7 CONDUCTOR; 31.6-88.0 Top Job; 28.8 ftKB HANGER; 25.4 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 10/17/1981 1A-07 ... TD Act Btm (ftKB) 8,704.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065800 Wellbore Status INJ Max Angle & MD Incl (°) 63.55 MD (ftKB) 4,150.00 WELLNAME WELLBORE1A-07 Annotation Last WO: End Date 9/3/2013 H2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,422.0 8,443.0 6,212.4 6,229.5 A-4, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,445.0 8,466.0 6,231.2 6,248.3 A-4, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 7,890.0 7,965.6 5,778.1 5,840.2 PLUG PLACED 2.1 bbls OF RESIN INTO IA FROM 7965' TO 7890' RKB OVER LEAK AT PBR 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 7,881.0 5,770.7 Camco MMG 1 1/2 GAS LIFT DV RK 0.000 0.0 7/27/2014 2 8,017.5 5,882.6 Camco MMG-W 1 1/2 INJ DMY RK 0.000 0.0 9/12/2013 1A-07, 11/11/2020 2:50:44 PM Vertical schematic (actual) PRODUCTION; 2,104.0-8,656.0 FISH; 8,537.0 IPERF; 8,445.0-8,466.0 IPERF; 8,422.0-8,443.0 IPERF; 8,404.0-8,413.0 PACKER; 8,317.2 P2P-PATCH-LWR; 8,314.0 LEAK - TUBING; 8,300.0 SPACER PIPE, ANCHOR LATCH; 8,282.2 LEAK - TUBING; 8,285.0 SPACER PIPE, ANCHOR LATCH; 8,250.5 FIsh; 8,254.0 Fish; 8,247.0 LEAK - TUBING; 8,244.0 IPERF; 8,232.0-8,249.0 SPACER PIPE, ANCHOR LATCH; 8,214.5 LEAK - TUBING; 8,215.0 LEAK - TUBING; 8,205.0 SPACER PIPE & ANCHOR LATCH; 8,187.0 P2P-PATCH-UPR; 8,183.0 IPERF; 8,126.0-8,220.0 Sliding Sleeve - Closed; 8,078.0 GAS LIFT; 8,017.5 PACKER; 7,965.6 LEAK - TUBING; 7,938.5 PLUG; 7,890.0 ftKB GAS LIFT; 7,881.0 SURFACE; 30.5-2,469.5 PROD Tie-Back w/Patch; 29.1- 2,108.7 CSG CMT; 34.0 ftKB NIPPLE; 515.7 CONDUCTOR; 31.6-88.0 Top Job; 28.8 ftKB HANGER; 25.4 KUP INJ 1A-07 ... WELLNAME WELLBORE1A-07 MEMORANDUM TO: Jim Regg P.I. Supervisor f FROM: Brian Bixby Petroleum Inspector I Well Name KUPARUK RIV UNIT 1A-07 Insp Num• mitBDB200924044650 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, September 24, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A-07 KUPARUK RIV UNIT 1 A-07 Src: Inspector Reviewed By P.I. Supry 1Y5A--1-- Comm API Well Number 50-029-20658-00-00 Inspector Name: Brian Bixby Permit Number: 181-137-0 Inspection Date: 9/23/2020 Well lA-o7 PTD 181 1370 BBL Interval Packer T Type Inj W 'TVD 'Type Test SPT -,Test psi 4vRTSTP P/F Depth - 5832 -1Tubing 1500 „✓ Pretest Initial 15 Min 30 Min 45 Min 60 Min IA 2450 a 1050 L-2-5 —-._ 24502450 -' 1790 - 1750 i _--- zs— 25 zaso T 1750 - 25 - Notes: Thursday, September 24, 2020 Page 1 of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ohn W. Peirce Digitally signed by John W. Peirce Date: 2020.04.09 10:19:15 -08'00' By Samantha Carlisle at 12:07 pm, Apr 09, 2020 320-160 X VTL 4/10/20 10-404 DSR-4/9/2020SFD 4/10/2020 12 $ " 4/10/2020 dts 4/10/2020 JLC 4/10/2020 1 Proposed 1A-07 Injector Tubing Patch Installation Procedure 1A-07 Kuparuk C & A Sand injector was drilled & completed in 1981. A 9/26/15 IPROF found 3 leaks in C Sd selective at 8205, 8215, and 8245’ RKB that took 97% PWI at 2080 BWPD. A ~60’ OAL patch was set 12/19/15 that isolated all C Sd leaks to convert 1A-07 to A Sd only injection. A 3/17/19 LDL shows the patch leaking, and a new leak was at 8285’ below the patch. Thus, the tubing patch of 12/19/15 at 8194 - 8253’ RKB was pulled in 2019 and early 2020. Complications while pulling the patch delayed removal of all the patch equipment until 3/28/20, so the Application Sundry approval of 4/3/19 to install a new tubing patch will expire before the new patch that was approved by the Sundry can be installed. Thus, we are applying for reapproval (via new 10-403) to install the new tubing patch. Per this procedure, a new patch that lengthened to ~90’ OAL will isolate at least 4 C Sd leaks to restore ‘A sand only’ injection. Procedure: DSL: 1. Brush & Flush 3.5” tubing at 8170 - 8310’ RKB in preparation for 90’ OAL patch install. Dummy Patch drift work is not requested and should not be needed if the patch run assemblies pulled during SL steps 1 - 3 (above) drifted OOH with no difficulty. All new patch equipment will have very similar equipment specs to drift to similar set depths. 2. RIH with 2.72” OD Retrievable Straddle Packer and set it at ~8293’ MD (element) in full joint. POOH for run #2 assembly of tubing patch. 3. RIH with ~30’ OAL run #2 assembly of tubing patch, and latch run #2 Anchor Latch Seal assembly into Straddle Packer set at ~8293’ MD. POOH for run #3 assembly of tubing patch. 4. RIH with ~30’ OAL run #3 assembly of tubing patch, and latch run #3 Anchor Latch Seal assembly into PBR at ~8263’ MD. POOH for run #4 assembly of tubing patch. 5. RIH with ~30’ OAL run #4 assembly of tubing patch, and latch run #4 seal assembly into PBR at ~8233’ RKB and then set the upper Straddle Packer of tubing patch at ~8202’ RKB. POOH. PIH with test plug and set it in the Straddle Packer at ~8202’ RKB. MIT-T to 2500 psi to verify upper Straddle Packer set integrity. Pull test plug. 6. RIH with 1-3/8” OD LDL to verify good integrity of patch at 8202 - 8293’ MD. Adjust injection rate as needed to drift LDL BHA safely through patch 1.61” min ID of the tubing patch. If LDL finds a leak exists in patch, pull patch as needed and redress equipment as needed and then reset patch for a new MITT and LDL. When LDL verifies patch has good integrity, RD DSL. Return 1A-07 to ‘A sand only’ injection. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: RKB 8,497.0 6/3/2017 1A-07 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: RECOVERED REMAINING PATCH SECTIONS & LOW PACKER 3/28/2020 1A-07 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 31.6 Set Depth (ftKB) 88.0 Set Depth (TVD)… 88.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.5 Set Depth (ftKB) 2,469.5 Set Depth (TVD)… 2,212.6 Wt/Len (l… 45.50 Grade K-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 2,104.0 Set Depth (ftKB) 8,656.0 Set Depth (TVD)… 6,403.7 Wt/Len (l… 26.00 Grade K-55 Top Thread Casing Description PRODUCTION Tie-Back w/Patch OD (in) 7 ID (in) 6.15 Top (ftKB) 29.1 Set Depth (ftKB) 2,108.7 Set Depth (TVD)… 1,998.4 Wt/Len (l… 26.00 Grade L-80 Top Thread TCII Tubing Strings Tubing Description TUBING WO 2013 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.4 Set Depth (ft… 8,322.8 Set Depth (TVD) (… 6,131.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 25.4 25.4 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 515.7 515.7 1.26 NIPPLE CAMCO DS NIPPLE 2.875 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 8,078.0 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 8,316.16,126.235.70 LOCATOR BAKER LOCATOR 9Spaced out 1')2.980 8,317.06,126.935.70SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 Tubing Description TUBING WO 1985 String Ma… 6 5/32 ID (in) 4.00 Top (ftKB) 8,317.2 Set Depth (ft… 8,340.3 Set Depth (TVD) (… 6,145.8 Wt (lb/ft)Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,317.26,127.035.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" TUBING 4.000 8,332.26,139.235.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB. **ELMD TTL @ 8322' ON IPROF 8/22/2007** 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 8,247.0 6,070.0 35.61 Fish 6 centralizer arms, 3 rings, and 1 spring from chem cutter centralizer. 11/20/201 9 0.500 8,254.0 6,075.7 35.63 FIsh 1" long piece of grapple. Picture of broken grapple in attachments. 11/12/201 9 0.000 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled & pushed to rathole during workover 12/9/1985 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,126.0 8,220.0 5,971.5 6,048.1 C-4, C-3, C-2, 1A-07 2/10/1982 4.0 IPERF Enerjet 8,232.0 8,249.0 6,057.8 6,071.7 C-1, 1A-07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A-5, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,422.08,443.06,212.4 6,229.5 A-4, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,445.08,466.06,231.26,248.3 A-4, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 7,890.0 7,965.6 5,778.1 5,840.2 Cement Plug 7/24/2014 Placed 2.1 bbls of Resin into IA from 7965' to 7890' RKB over leak at PBR. Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 7,881.0 5,770.7 Camco MMG1 1/2GAS LIFT DV RK 0.000 0.0 7/27/2014 2 8,017.5 5,882.6Camco MMG-W 1 1/2 INJ DMY RK 0.000 0.09/12/2013 Notes: General & Safety End Date Annotation 7/24/2014 NOTE: PLACED 2.1 bbls OF RESIN INTO IA FROM 7965' TO 7890' RKB OVER LEAK AT PBR 11/27/2005 NOTE: LEAK @ 8283' 1A-07, 4/8/2020 5:30:03 PM Vertical schematic (actual) PRODUCTION; 2,104.0-8,656.0 FISH; 8,537.0 IPERF; 8,445.0-8,466.0 IPERF; 8,422.0-8,443.0 IPERF; 8,404.0-8,413.0 PACKER; 8,317.2 FIsh; 8,254.0 Fish; 8,247.0 IPERF; 8,232.0-8,249.0 IPERF; 8,126.0-8,220.0 GAS LIFT; 8,017.5 PACKER; 7,965.6 PLUG; 7,890.0 ftKB GAS LIFT; 7,881.0 SURFACE; 30.5-2,469.5 PRODUCTION Tie-Back w/Patch; 29.1-2,108.7 CSG CMT; 34.0 ftKB NIPPLE; 515.7 CONDUCTOR; 31.6-88.0 Top Job; 28.8 ftKB HANGER; 25.4 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 10/17/1981 1A-07 ... TD Act Btm (ftKB) 8,704.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065800 Wellbore Status INJ Max Angle & MD Incl (°) 63.55 MD (ftKB) 4,150.00 WELLNAME WELLBORE Annotation Last WO: End Date 9/3/2013 H2S (ppm)DateComment SSSV: NIPPLE ! " # " $ %& ' ()! * '$ +, !- ."!! /, +, 01021*-1 3+ - " ' $ .*14 !3 (445 % $ .*14 */((6.5* (445 2.416(0* 7 8 + 966 -5#30: ,#.1 .541;7$ (4(;8$ < 8+ '6 -*/((;7$ 2.41;8$ .5*;7$ (0*;8$ 0 =9 ' ) + - !3 5 = 2" < $ ' " %& ' $ , ' (" < > "$, % $ > >)!?@,@> '!!3 %& 9! ! 9 % % % //.; ..; 005; (414;*: *: .(2(; 01/; 9 !"#$%$&'"( 2(; 045/; (220; 01.1; *)' ' '< 5/#( ?< !3 (: 1#534: %,A ,A),!$>!% 8)!77))! ! .#5* 21#10/#01(2.#11#11 2 $ ! A< 3A< 0 ! ! 5 4" B"< "#! $ ' )C $ $,02(4* #B < B&115(1 6A//21 A @#1* 4 += 01021*16021*6D020.5- "#! > #7 " #B $ ..; 04*1; <6) ) *+ ? +/1*-0(2#(4* ?" E " % ? ")!?"> 1#414 530101 " 51' John W. Peirce Digitally signed by John W. Peirce Date: 2020.04.09 10:24:56 -08'00' By Samantha Carlisle at 12:13 pm, Apr 09, 2020 VTL 4/10/20 DSR-4/9/2020 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: RKB 8,497.0 6/3/2017 1A-07 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: RECOVERED REMAINING PATCH SECTIONS & LOW PACKER 3/28/2020 1A-07 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 31.6 Set Depth (ftKB) 88.0 Set Depth (TVD)… 88.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.5 Set Depth (ftKB) 2,469.5 Set Depth (TVD)… 2,212.6 Wt/Len (l… 45.50 Grade K-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 2,104.0 Set Depth (ftKB) 8,656.0 Set Depth (TVD)… 6,403.7 Wt/Len (l… 26.00 Grade K-55 Top Thread Casing Description PRODUCTION Tie-Back w/Patch OD (in) 7 ID (in) 6.15 Top (ftKB) 29.1 Set Depth (ftKB) 2,108.7 Set Depth (TVD)… 1,998.4 Wt/Len (l… 26.00 Grade L-80 Top Thread TCII Tubing Strings Tubing Description TUBING WO 2013 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.4 Set Depth (ft… 8,322.8 Set Depth (TVD) (… 6,131.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 25.4 25.4 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 515.7 515.7 1.26 NIPPLE CAMCO DS NIPPLE 2.875 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 8,078.0 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 8,316.16,126.235.70 LOCATOR BAKER LOCATOR 9Spaced out 1')2.980 8,317.06,126.935.70SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 Tubing Description TUBING WO 1985 String Ma… 6 5/32 ID (in) 4.00 Top (ftKB) 8,317.2 Set Depth (ft… 8,340.3 Set Depth (TVD) (… 6,145.8 Wt (lb/ft)Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,317.26,127.035.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" TUBING 4.000 8,332.26,139.235.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB. **ELMD TTL @ 8322' ON IPROF 8/22/2007** 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 8,247.0 6,070.0 35.61 Fish 6 centralizer arms, 3 rings, and 1 spring from chem cutter centralizer. 11/20/201 9 0.500 8,254.0 6,075.7 35.63 FIsh 1" long piece of grapple. Picture of broken grapple in attachments. 11/12/201 9 0.000 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled & pushed to rathole during workover 12/9/1985 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,126.0 8,220.0 5,971.5 6,048.1 C-4, C-3, C-2, 1A-07 2/10/1982 4.0 IPERF Enerjet 8,232.0 8,249.0 6,057.8 6,071.7 C-1, 1A-07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A-5, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,422.08,443.06,212.4 6,229.5 A-4, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,445.08,466.06,231.26,248.3 A-4, 1A-07 2/11/1982 12.0 IPERF Thru-Tubing Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 7,890.0 7,965.6 5,778.1 5,840.2 Cement Plug 7/24/2014 Placed 2.1 bbls of Resin into IA from 7965' to 7890' RKB over leak at PBR. Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 7,881.0 5,770.7 Camco MMG1 1/2GAS LIFT DV RK 0.000 0.0 7/27/2014 2 8,017.5 5,882.6Camco MMG-W 1 1/2 INJ DMY RK 0.000 0.09/12/2013 Notes: General & Safety End Date Annotation 7/24/2014 NOTE: PLACED 2.1 bbls OF RESIN INTO IA FROM 7965' TO 7890' RKB OVER LEAK AT PBR 11/27/2005 NOTE: LEAK @ 8283' 1A-07, 4/8/2020 5:30:03 PM Vertical schematic (actual) PRODUCTION; 2,104.0-8,656.0 FISH; 8,537.0 IPERF; 8,445.0-8,466.0 IPERF; 8,422.0-8,443.0 IPERF; 8,404.0-8,413.0 PACKER; 8,317.2 FIsh; 8,254.0 Fish; 8,247.0 IPERF; 8,232.0-8,249.0 IPERF; 8,126.0-8,220.0 GAS LIFT; 8,017.5 PACKER; 7,965.6 PLUG; 7,890.0 ftKB GAS LIFT; 7,881.0 SURFACE; 30.5-2,469.5 PRODUCTION Tie-Back w/Patch; 29.1-2,108.7 CSG CMT; 34.0 ftKB NIPPLE; 515.7 CONDUCTOR; 31.6-88.0 Top Job; 28.8 ftKB HANGER; 25.4 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 10/17/1981 1A-07 ... TD Act Btm (ftKB) 8,704.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065800 Wellbore Status INJ Max Angle & MD Incl (°) 63.55 MD (ftKB) 4,150.00 WELLNAME WELLBORE Annotation Last WO: End Date 9/3/2013 H2S (ppm)DateComment SSSV: NIPPLE !"# ! "$%!% ! "!!"!!"&!!"% '& ( ' !"& ) '! ("& * ( ! ("'+' , ( ( +("", ! ("& $' +$ ,' ( +("", ! ("& ' +$ ,' )'* ! ("& ) ""+ -, ! ("& +"", . '''- ' -#' '' ' ' ( . ''' '%''' %'" &' ''/ %''%''' ''&' %' ''%''/ ''' !" '' . '' &# ''0 &' ' 0 &'*'' '' ' ''%" '& / '1 '' . ''' '%'!%' % '%&$'%(- % %'%&' '%''!% '' '&% ' %' . ''' '%''!"% ' ''%' &'%' % ' ! . ''- ''!"& ' "-*$!- % - "''''' # ! . '" '! "'# !-' ## ! . *'' !"& )! &) - %' !!"& %'%'') '*!"& )' ' .'!"& %' ' ''+$2, . '!"& )' ' , -/!" '+!-'&* -'& , * . '%''! "%'%'/ '% ''' & ( . ''' '%'! "% ' / "'% %'"%'%''' !"% &%&%'%& & '' # 34567895678:;< . & %''' '%''! "% (&% %'"% ''' '%' ! "%'% &' ' &' '% ' . -/!" '+!- '&* -'& , . "" /#!"& "" !"& +"", ("" !"& % ' = &' . . ' + , . '!$("+" ''' >$"'>! (" &' .'' & ( .% %' ' . ' !("& "' ' '!$"& & $ . '#!$"& % ?(-'?.&- % . ''&' '%''!("'% ' '" $ . '' '+-,%''!(" '%' '" '' '+(-,%''!("% !& % ( . &&'# '& & &' . '!( " '% $%'' '+-,%'!($" '/ %'& ' '% ''&'(--% '%''- '' '" %&'& ' %'' % ! . "% '+-,'/ ' &'' . ''- ''! !" '' '&' '(-' ( . ''( '& '' ' '''' ' ' (- '' . ''(- ' '/ '' '' '''!"' !'/' ''' !"'' ! . ''(-' &'& &/'&' ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 3 1137 TRANSMITTAL DATE: 9 TRANSMITTAL#: 082720191 FIELD BP North Slope 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. RECE 1. 11 E DT11 0 1 0 Attn: NSK-69 AUG 2 9 2019 700 G Street gOGCC Anchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Print Name \ " Signa' Please return via e-mail a copy to both Alaska E -Line Services and Phillips Alaska: qj THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-07 Permit to Drill Number: 181-137 Sundry Number: 319-161 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.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, Daniel T. Seamount, Jr. Commissioner I 1"d DATED this _ day of April, 2019. RBDMS —04V APR 9 41019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DECEIVED APR 0 2 2019 AOGCC 1. Type of Request Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Inj Tubing Patch InstalEl 2. Operator Name: 4. Current Well Class: 5. Permit to DdII Number: ConocolohillisAlaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service D . 181-137 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20658-00 -fY'i 7. If perforating: 8. Well Name and Number: y Z,( What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1A-07 Will planned perforations require a spacing exception? Yes ❑ No 121 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25647 ' Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,704' 6,443' • 8704 6443 2800psi NONE 8537 Casing Length Size MD TVD Burst Collapse Conductor 56' 16" 88' 88' Surface 2,439' 103/4 2,470' 2,213' Production 6,552' 7" 8,656' 6,404' Production Tie -back 2,080' 7" 2,109' 1,995' Perforation Depth MD (ft): IPerforation Depth TVD (ft): ITubing Size: Tubing Grade: Tubing MD (ft): 8126-8220, 8232-8249, 8404- 5971-6048, 6057-6072, 6198- 3.500" L-80 8,340' 8413, 8422-8443, 8445-8466 16205, 6212-6229, 6231-6248 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER PREMIER PRODUCTION PACKER MD= 7966 TVD= 5840 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service El .. 14. Estimated Date for 4/19/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG [D GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown p 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: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 Authorized Signature:Date: BNz ,G 1. 1 COMMISSION USE ONLY Conditions of approval: Notify Commissi n so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes Nom RBDMSL-' APR 0 41019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ( (/ 0Q& q1,31 Form 10403 Revised 4/2017 Y / I- -t1.0117 pp pp G UAL \I A Submit Form and Approved a li n i vIr f 2 m the date of approval. Attachments in Duplicate ConocoPhillips Alaska. Inc. KUP INJ RIVER UNIT NIPPLE WELLNAME to -07 WELLBORE 1A-07 tAN.92%At9939'.45 PM Last Tag Al xMmO[o.) Aar. ionCeptl,(M(B) End Gate Wa1100,e LatMW BY Lest Tag: RKB $49)0 613201] 1A-0] ppraven HANGER. par Last Rev Reason Annotation End Gak WeI1Ge tastMM By ,? Rev Reason TAG 6161201) IPPDwep Casing Strings Casino De..apimn 100 TO g10n1 topSdipasth MIKE) BN Depth PVDT-WULen g... Grade Toprnro+d CONDUCTOR 16 15.06 31.6 88.0 88.0 65.00 H40 WELDED rawob. DilrL a Cesingo Deanipren OO(m) IGpnl Top nll(ED S.IXXB) SH C¢01,Tad.. Wtllen L - GMs Top Trade SURFACE 10314 9.95 30.5 2,469.5 2,212.6 45.50 K-55 BUTT Cesing Description Go (Is) IOgn) Top IXl(91 Set Dl (Man Bat DOMP m'01... WlM1en g... Grade Tap Thread PRODUCTION 7 628 2,104.0 6,656.0 6,403) 26.00 K-55 pring Description 00 DO IO Par T.,(XKD Bat DeplM1 (nKB) se 0agn pv0)... wln.en Il Grade TOP Thered PRODUCTION Tie -Back 7 6.15 29.1 2.108] 1,9984 26.00 L -BD LED w1Pa1Ch COHDUOTOR: BI easy Tubing Strings Tubing Cede Top Connecgon TUGing Description Sting Ma... to (in) Tial"I) SN Depth to 5M 0epM(1VIED I - NIPPLE: 51sT TUBING W02013 312 299 25.4 8322.8 6,131.6 9.30 L-80 EUE-moo Completion Details CBGCaptp rtuc TOP 1TV)1 Top incl Nnminel Top Issup (rids) I.1 Xem Ox Com ID (n 254 254 0.00 HANGER FMC GEN IV TUBING HANGER 2992 5157 5157 1.266 NIPPLE CAMCO OS NIPPLE 2.875 7.9377 5,817.3 Mal LOCAT R BAKER LOCATOR Length above PER 2.990 7,945.5 5,8237 34.89 PER BAKER 8040 PBR 2.990 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PA KIR IIII Pnoouenorvrceeex 8,0]80 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2812 wpmKx91-21.1 8,316.1 6,126.2 35.70 LOCATOR BAKER LOCATOR 9SXCed.1 l') 2.980 8,3170 6,126.9 3570 SEALASSY BAKER GBH -22 BONDED SEAL ASV 2980 TubBy Geacripibn Ma... lDol Tap(XI(in set Deptn ln.. sal isi (NOI I...W1(IM Gnde Top Connc4ion suapACE; so.s2aess- here TUBING WO 1985 65132 400 8.3172 8,340.3 6,145.8 Completion Details GAS 11FTB810 ; J, Top INDI Top N[I Nominal ropgY(6) (X1(6) 'toIden des Corn 1o(IM PLUG: T,WDOX 8,317.25"U! .1 J 35665.69 PACKER BAKER FB -1 PACKER wri CROSSOVER TO 1 78' TUBING 4.000 8,332.2 ,139.2 33 NIPPLE CAMCO D NIPPLE NO GO 2.250 LOCATOR: Tel 63396 6,1452 I 35.60 SOS CAMCD SHEAROU LMO f I LSod1i ON It E61 I22/200T• ps"p7upr.e Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top m0) rnp incl PACKER: 7.M.6 Top (I (XKB) I•) Des Com Run Dab Man) 8,194.0 60268 35466 PATCH 272'SOS PARAGONII WI . =0I 1 1590 SPACER PIPE 8 SNAP LATCH@ 8194' RKB. (SNAP 5 LATCH SN CPAL35028. UPPPER PIP SN CPP35039) GASLIFT:8.g1]5 se ,1 ,02 .0 3506 PATCH Paragonalower pa BRw 11/191201 1.59 77 er tc 2n', 27Jgon 82t, 1nd 5 11 paragon II upper packer w 22.55 spacer pipe and snap uppipeand cker w 55 attract, pipesnap latch at 8196.66' SLEEVE: sinal g, 6.0497 35.54 PATCH 29.86'MIODLE STARODUE PATCH EXTENSION 1590 8222' RKB. (LOWER SNAP LATCH SN CPAL351 5 PBR SN CPPBP35006) 8,5370 6,3064 35.12 FISH ser PK Assembly ilea pushed to rallole drong 1 1 85 IPEflF; B.1R09,L0.0� wOrkaVQ! Perforations & Slots soli PATCH; SINN Dens Tap ITVO) 6bnmml Isnokm TopgIKB) B.Mm IXKeI yous) "need znne Om 1 Type Cam PATCH;B.15,8 8,126.0 8=. 5.71 .5 6,048.1 77, -3,1-2, 71d7i 40 BEEF Enedet 1A-07 PATCH: am.o 8,232.0 ,4. 60578 Ell C-1, to -07 2/1011982 OO PERE Entitled, PERPa'M2 Nsolezl 8,404.0 ,4130 6.1977 6205.1 AS, IA -07 2/11/1982 120 IPERF Thro-Tubing 8,422.0,443.0 6.2124 61.5 A-0, 1A-07 2/1111902 120 BEEF Thru-Tubing 8,445. 8,465.0 6,2312 6,248.3 T4 IA -07 1111982 120 IPERF Thou -Tubing Cement Squeezes 10CATORSS.1 EN Top iftsi Sur MKBI To( 801 She (TVD) pos) ) Oes Rbrt Oeb Com SEALArel lLd PACKER:asn.x 7,890.0 7,9656 5,7761 58402 Cement Plug 7242014 Pace bblso esin,.WIA m79TF178 RKB over leak at PBR, Mandrel Inserts st all 0=2 aX Bdb; 8.3'0.8 did n T - ma) TIXKI6 d1 Make Model 00 In gery ( ) Vetere YM L,edch YPa Port She TRO Run sts IPall Run Gate Cdn 7,881.0 5)707 amCO MMG 112 GAS LIFT DV RK 0000 00 71272014 2 8,0175 5,882.6 CamcO 112 INJ DMV RK 0.0 0 00 91122013 W PERE BAD4.daill { NCtBS' General Br Safety End Date AnnoUllon 12/971985 NOTE: WORKOVER 111212005 NOTE. LEAK @ 82V IPERF:e4a.0aa4aa- 71302010 NOTE: View Schematic vel Alaska Scbemal0 IPERF:eaas.0e.4os0_ 51142011 NOTE: Erratic"Kht Swings from 8071'-0600'81900-1509 72412014 NOTE: PLACED 2.1 bbl, OF RESIN INTO IA FROM 7965TO 7890' RKB OVER LEAK AT PER FISH:,,9id prprouc IDN:2,10p.,@BO Proposed 1A-07 Injector Tubing Patch Installation Procedure 1A-07 Kuparuk C & A Sand injector was drilled & completed in 1981. A 9/26/15 IPROF found 3 leaks in C Sd selective at 8205, 8215, and 8245' RKB that took 97% PWI at 2080 BWPD. A -60' OAL patch was set 12/19/15 that isolated all C Sd leaks to convert 1A-07 to A Sd only injection. A 3/17/19 LDL now shows the patch leaking, and anew leak at 8285' below the patch. Per this procedure, the leaky patch at 8194 - 8253' RKB will be pulled to perform a CT FCO to uncover the A Sd perf intervals before installing a new patch that will be lengthened to -90' OAL to isolate at least 4 C Sd leaks to restore 'A sand only' injection. Procedure SL: 1. Pull upper Straddle Packer of Patch and Straddle Patch Extension (-30' OAL) at 8194' RKB. 2. Pull lower Straddle Patch Extension (-32' OAL) that is set in the lower Straddle Packer. 3. RIH & pull lower Straddle Packer at 8253' RKB. RD SL. Coil Tubing: 4. Perform fill cleanout to as deep as possible to uncover A4 perf intervals and to leave some rathole before reinstalling anew tubing patch. RD CTU. DSL: 5. Brush & Flush 3.5" tubing at 8170 - 8310' RKB in preparation for 90' OAL patch install Dummy Patch drift work is not requested and should not be needed if the patch run assemblies pulled during SL steps 1 - 3 (above) drifted OOH with no difficulty. All new patch equipment will have very similar equipment specs to drift to similar set depths. 6. RIH with 2.72" OD Retrievable Straddle Packer and set it at 8293' MD (element) in full joint. POOH for run #2 assembly of tubing patch. 7. RIH with -30' OAL run #2 assembly of tubing patch, and latch run #2 Anchor Latch Seal assembly into Straddle Packer set at -8293' MD. POOH for run #3 assembly of tubing patch. 8. RIH with -30' OAL run #3 assembly of tubing patch, and latch run #3 Anchor Latch Seal assembly into PBR at 8263' MD. POOH for run #4 assembly of tubing patch. 9. RIH with -30' OAL run #4 assembly of tubing patch, and latch run #4 seal assembly into PBR at -8233' RKB and then set the upper Straddle Packer of tubing patch at -8202' RKB. POOH. PIH with test plug and set it in the Straddle Packer at 8202' RKB. MIT -T to 2500 psi to verify upper Straddle Packer set integrity. Pull test plug. 10. RIH with 1-3/8" OD LDL to verify good integrity of patch at 8202 - 8293' MD. Adjust injection rate as needed to drift LDL BHA safely through patch 1.61" min ID of the tubing patch. If LDL finds a leak exists in patch, pull patch as needed and redress equipment as needed and then reset patch for a new MITT and LDL. When LDL verifies patch has good integrity, RD DSL. Return 1A-07 to 'A sand only' injection. Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: ry j AOGCC ATTN: Natural Resources Technician It Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 --91&i Anchorage, AK 99501 161137 MM' 0 0 TRANSMITTAL DATE �-r -- TRANSMITTALN L' WELL NAME tE•104 API # 50-029-23234.00 ORDERSERVICE EA77-00006 FIELD KUPARUK RIVER DESCRIPTIONNAMEColor WL DELIVERABLEDESCRIPTION IPROF DATA TYPE FINAL FIELD DATELOGGED Prints 20 -Feb -19 r 1 1A-05 1A-07 1H-118 2A-17 2V-04 1H-114 3C -15A 50-029-20627-00 50-029-20658-00 50.029-23578.00 50-103-20193.00 50-029-21041-00 50-029.23584-00 50-029-21426-01 E0SH-00028 EOSH-00029 EOSH•00030 EA77-00009 EA77-00010 EOSH-00031 EA77-00011 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL1 WL WL WL IPROF (PROF IPROF Caliper (PROF (PROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 16 -Mar -19 17 -Mar -19 18-Mar•19 18 -Mar -19 19 -Mar -19 19 -Mar -19 20 -Mar -19 1 1 1 1 1 1 8 nsmittal A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X C' package have been verified to match the media noted above. The Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this via courier or sign/scan and email a copy chlumberger and CPAI. point. Schlumberger -Private co g • • .., by - ,, H > � -I "I0z a, m ic 3 0v m a�Y ° c a Velt ° v >of o ,o o v o0 U °• a O O �, r0 °+-' m .LU@ o Q o .0 u Q Q p 0 n n r r r r r r r r r r r r N 0 0 " m a O C C C C C 7 7 7 7 a o n J 7 7 7 7 7 7 M M 7 7 M M M 7 w C _C @ N C (" to r co th o ,n CO' 0) o c� <t u') p m y t N L• �' Q N N N N CO U -0 0 y, Vi Z Z J > O c v H '' ,r6 a) -6 N U CI CI CI CI CI O Cl CI D D CI 0 0 0v cn L W J J J J J J J J J J J J J J C 0 4= O yay W W W W W W W W W W W W W W , v 'C U "- ,—, F LL LL LL LL LL LL LL LL LL LL LL LL LL LL ., (1) 0) N "0 C) < J J J J J .J J J J J J J J J n' > .0 CU (C) F.. 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January 8, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 995014 4ZK! i2 K. BENDER RE: Injection Profile : 1A-07 Run Date: 09/26/2015 and 12/04/2015 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 1A-07 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20658-00 Injection Profile Log SCOW1 Color Log- each 50-029-20658-00 PLEASE ACKNOWLEDGE 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Si ne 6.-eiteezt E OF ALASKA KRU 1A-07 ALA KA OIL AND GAS CONSERVATION COMMIOON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon F', Plug Perforations Fracture Stimulate rPull Tubing FT Operations Shutdown FT Performed: Suspend F Perforate 1 Other StimulateAlter Casing FT Change Approved Program F' Plug for Redrill Perforate New Pool FT Repair Well Re-enter Susp Well FT Other:Tubing Retrievable Patch F 2.Operator Name: 4.Well Class Before WOrk: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development FT Exploratory F' 181-137 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20658-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 KRU 1A-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8704 feet Plugs(measured) None true vertical 6443 feet Junk(measured) 8537 Effective Depth measured 0 feet Packer(measured) 7966,8317 true vertical 0 feet (true vertical) 5840,6127 Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 88 88 0 0 SURFACE 2440 10 3/4 2470 2213 0 0 PRODUCTION 6552 7 8656 6404 0 0 PRODUCTION Tie- Back w/Patch 2080 21094, rJ r rv. h , 11911 0 0 Perforation depth: Measured depth: 8126-8220,8232-8249,8404-8413,8422-8443,8445-8466 RECEIVED True Vertical Depth: 5971-6048,6057,-6072,6198-6205,6212-6229,6231-6248 JAN 0 8 2016 Tubing(size,grade,MD,and TVD) 3 1/2, L-80,8323,6132 A0cC0 Packers&SSSV(type,MD,and TVD) PACKER-BAKER Premier Production Packer @ 7966 MD and 5840 ND, BAKER FB-1 Packer @ 8317 MD and 6127 ND SSSV: No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a 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 n/a n/a 3152 - 1849 Subsequent to operation 1670 2565 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory FT Development Service F Stratigraphic FT Copies of Logs and Surveys Run 16.Well Status after work: Oil FT Gas r WDSPL Printed and Electronic Fracture Stimulation Data FGSTOR F' WINJ F WAG FT GINJ SUSP FT SPLUG 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: 315-683 Contact John Peirce(a).265-6471 Email John.W.Peirce(c�cop.com Printed Name John Peirce Title Sr.Wells Engineer Signature �. Phone:265-6471 Date •q/I// tc� /::..q.A._ t t� //! �1' 3�RBDMJAN 2016 Form 10-404 Revised 5/2015 + - Submit Original Only A ` (/Vl'6 ..� Z , KUP Ie IA-07 te Conoco-Phillips Well Attributes Max Angle TD Alaska inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • LomcoPhiaip9 ° 500292065800 KUPARUK RIVER UNIT INJ 63.55 4,150.00 8,704.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-07, /6/2016133:27 PM SSSV:NIPPLE Last WO. 9/3/2013 39.01 10/17/1981 ,......Vence'schsmalic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date " Last Tag:SLM 8,409.0 5/25/2013 Rev Reason:SET PATCH pproven 12/21/2015 HANGER;25.4 ?Ir Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len p...Grade Top Thread ^4r i CONDUCTOR 16 15.060 31.6 88.0 88.0 65.00 H-40 _WELDED ,�7 4 's;�!,,...... : Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread `� SURFACE 10 3/4 9.950 30.5 2,469.5 2,212 6 45 50 K-55 BUTT z 1 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .,n,,,,,,•,,,,,,,,,,,,,,,,,,,,,,,,,,,,u.,,,u °• PRODUCTION 7 6.276 2,104.0 8,656.0 6,403 7 26 00 K-55 Casing DescriptionOD(in) ID(in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...GratleTopThreadrwPRODUCTIONTie-Back 7 6.151 29.1 2,108.7 1,998.4 26.00 L-80 TCII w/Patch Tubing Strings - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/r) Grade Top Connection �_A_ CONDUCTOR;31.8-88.0' ze TUBING WO 2013 1 31/21 2.9921 25.41 8,322.81 6,131.61 9.301 L-80 'Top Completion Details Nominal ID NIPPLE,515.7 ' Top)ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 11 � 25.4 25.4 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 4 515.7 515.7 126 NIPPLE CAMCO DS NIPPLE 2.875 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 I i t 1 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 7,965.6 5,840.1 3525 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 8,078.0 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 PRODUCTION Tie-Back , 8,316.1 6,126.2 35.70 LOCATOR BAKER LOCATOR 9Spaced out 1') 2.980 «/Patch;29.1-2.108.7 8,317.0 6,126.9 35.70 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb(lb/ft) Grade Top Connection TUBING WO 1985 1String 6.1561 4.0001 8,317.2 8,340.31 6,145.81 1 1 • Completion Details SURFACE;30 5-2,469.5-• l Nominal ID Top(11KB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 8,317.2 6,127.0 35.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" 4.000 TUBING GAS LIFT;7,881.0 r lir 8,332.2 6,139.2 35.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB.•'ELMD TTL @ 8322'ON 2.441 it • IPROF 8/22/2007" Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCATOR;7,937.7 vige Top(TVD) Top Incl Top(ftKB) (ftKB) I°) Des Com Run Date ID(in) PBR,7,945.5 %- 8.194.0 6,026.9 35.46 PATCH 2.72"SOS PARAGON II UPPER PACKER W/24.56' 12/20/2015 1.590 SPACER PIPE 8 SNAP LATCH @ 8194'RKB. (SNAP LATCH SN CPAL35028,UPPPER PIIP SN PACKER;7,885.8 he•'g' CPP35039) �'a tuft 8,196.6 6,029.0 35.46 PATCH SOS Paragon II lower packer at 8253',set 2.70"PBR 11/19/2015 1.590 w 27.78 spacer pipe and snaplatch @ 8222',set 2.72 SOS paragon II upper packer w 22.55 spacer pipe and snap latch at 8196.6' GAS LIFT,8,017.5 8,222.0 6,049.7 35.54 PATCH 29.86'MIDDLE STARDDLE PATCH EXTENSION @ 12/20/2015 1.590 ( ''`. 8222'RKB.(LOWER SNAP LATCH SN CPAL35023, PBR SN CPPBP35006) 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled 8 pushed to rathole 12/9/1985 0.000 during workover SLEEVE,8,078.0 - .51 Perforations&Slots It Shot 1 11 Dens Top(ND) Btm(TVD) (shots) Top)ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Cont (PERF;8,126.08,220.0 8,126.0 8,220.0 5,971.5 6,048.1 C-4,C-3,C-2, 2/10/1982 4.0 IPERF Enerjet 1A-07 PATCH;8,194.0 ! _ 8,232.0 8,249.0 6,057.8 6,071.7 C-1,1A-07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A-5,1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,422.0 8,443.0 6,212.4 6,229.5 A-4,1A-07 2/11/1982 12.0 IPERF Thru-Tubing PATCH,8,1868 PATCH;8,222.0-, 8,445I .0 8,466.0 6,231.2 6,248.3 A-4,1A-07 2/11/1982 12.0 IPERF Thru-Tubing IPERF;8,232089.0,24 Cement Squeezes Top)TVD) Btm(ND) f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com Ai 7,890.0 7,965.6 5,778.1 5,840.2 Cement Plug 7/24/2014 Placed 2.1 leak bbls aoin PBR. nto IA from 7965'to 7890' RKB over Mandrel Inserts LOCATOR;8,318.1 ■ St ati SEAL ASSY;8317.0 �I"f[YN Top(ND) Valve Latch Port Size TRO Run PACKER;8,317.2 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ,..®.,ri 1 7,881.0 5,770.7 Camco MMG 11/2 GAS LIFT DV RK 0.000 0.0 7/27/2014 2 8,017.5 5,882.6 Camco MMG- 1 1/2 (NJ DMY RK 0.000 0.0 9/12/2013 W NIPPLE;8,332.2 Notes:General&Safety End Date Annotation SOS;8,339.6 12/9/1985 NOTE.WORKOVER 11/27/2005 NOTE:LEAK @ 8283' IPERF,8,404.08,4130-1. I 7/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 I 5/14/2011 NOTE:Erratic weight swings from 8071'-4600'8 1900'-1500' 1 I 7/24/2014 NOTE:PLACED 2.1 bbls OF RESIN INTO IA FROM 7965'TO 7890'RKB OVER LEAK AT PBR IPERF;8,422.08,443.0 I IPERF;8,445.08,4880- FISH;8,536.0 PRODUCTION;2,104.08,656.0 WELL NAME • 1A-07 • JOBTYF SUMMARYOPS 9/25/15 IPROF BEGAN RIH, ENCOUNTERED SOME TELEMETRY ISSUES AT 5500'. POOH AND SWAPPED SOME TOOLS AROUND, BUT STILL HAVING THE SAME PROBLEM. TECH CAME OUT TO DIAGNOSE PROBLEM AND IS TAKING TELEMETRY TOOLS TO REBUILD THEM. JOB IN PROGRESS. 9/26/15 IPROF INJECTION PROFILE RESULTS AS FOLLOWS: 3050 BWPD: 87% TO C SANDS AND 13% TO A SANDS. 2060 BWPD: 97% TO C SANDS AND 3% TO A SANDS. ESTIMATED LEAKS AT 8205'AND 8245'. CROSSFLOW WAS OBSERVED FROM A SANDS TO C SANDS WHILE WELL WAS SHUT IN. THE IN LINE SPINNER WAS USED TO DETERMINE THE A-C SAND SPLITS. TAGGED TD AT 8448'. LOG CORRELATED TO SLB CBL LOG DATED 13-OCT-1981. JOB COMPLETE. 11/16/15 TUBING PERFORMED FILL CLEANOUT FROM 8438' CTMD TO HARD TAG AT 8534' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 1.4 BPM (EST. 70' OF RATHOLE) MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT, MODERATE SAND CONCENTRATIONS OBSERVED, EST TOTAL SOLIDS VOLUME AT 2.5 BBLS, F/P TBG TO 8534' CTMD, READY FOR E-LINE, JOB IN PROGRESS. 11/18/15 TUBING DRIFTED W/ 2.80" CENT,3.5" BLB W/2.63" GAUGE RING.TAGGED SBE CROSSOVER © 8270' SLM.B&F FROM 8075' SLM TO 8270' SLM. DRIFTED DOWN TO 8315' RKB W/2.74" X 34.6' DUMMY PATCH.SAW NO RESTRICTIONS. SET 2.72" SOS PARAGON II LOWER PACKER (ser#cpp35042) @ 8253' RKB. IN PROGRESS. 11/19/15 TUBING SET 2.7" PBR W/27.78' SPACER PIPE & SNAP LATCH INTO LOWER PACKER @ 8253' RKB. SET 2.72" SOS UPPER PARAGON II PACKER (ser#cpp35043) W/22.55' SPACER PIPE & SNAP LATCH @ 8196.6' RKB. SET TEST TOOL© 8196' RKB.LRS PERFORMED MIT-T TO 2500 PSI,PASSED. WELL READY TO PUT ON INJECTION. JOB COMPLETE. 12/4/15 (PROF PERFORM STATION FRICTION STOP © 100'. DUE TO LACK OF 1" SPINNER RESPONSE IN 7" CASING, DYNAMIC PASS INTERVAL CHANGED TO 7920' - 8360' LOGGED DYNAMIC PASSES AT 30/60/90/120/150/180, MULTIPLE SPEEDS LOGGED TO INSURE CONSISTENT SPINNER DATA. IPROF RESULTS @ 1000 BWPD: C-SANDS = 100%,A-SANDS = 0% (PROF RESULTS @ 1000 BWPD: C-SANDS = 96%,A-SANDS =4% UNABLE TO LOG 4500 BWPD DUE TO DIFFERENT STICKING. TOOK STOP COUNTS @ 7950' AND 8250', LEAK IDENTIFIED AT 8220'. NEAR SNAP LATCH IN MIDDLE OF 56' PATCH SHUT IN FOR 30 MINUTES AND WELL DID NOT STABILIZE. CROSS FLOW FROM A SANDS TO C SANDS OBSERVED ON THE UP DOWN PASSES. 12/6/15 PUMPIls FREEZE PROTECT, PUMP 6 BBLS METHANOL FLOWLINE, PUMP 21 BBLS DIESEL TUBING, JOB COMPLETE. 12/18/15 TUBING PULLED 2.72" UPPER SOS PARAGON II PACKER W/SPACER PIPE &SNAP LATCH FROM 8196' RKB. JOB IN PROGRESS... 12/19/15 TUBING RAN 2.74" CENT W/3.5" BLB &2.75" GAUGE RING.B&F FROM 8180' SLM TO 8140' SLM. PULLED 27.78' MIDDLE STRADDLE PATCH FROM 8222' RKB. RAN 2.74" CENT W/3.5" BLB & 2.5" BLB.BRUSHED INNER LOWER PACKER FROM 8222' RKB. SET 29.86' MIDDLE STARDDLE PATCH EXTENSION @ 8222' RKB. (LOWER SNAP LATCH SN CPAL35023, PBR SN CPPBP35006) SET 2.72" SOS PARAGON II UPPER PACKER W/24.56' SPACER PIPE & SNAP LATCH @ 8194' RKB. (SNAP LATCH SN CPAL35028, UPPPER PIIP SN CPP35039) JOB IN PROGRESS.. 12/20/15 TUBING RAN TTS TEST TOOL TO TOP OF PACKER @ 8195' RKB. LRS PERFORMED MIT-T TO 2500 PSI,PASSED. RAN SLB MEMORY LDL TO VERIFY PATCH HOLDING.NO LEAKS DETECTED. WELL READY TO PUT ON INJECTION.. JOB COMPLETE. • ®F T�� • • T THE STATE Alaska Oil and Gas ofConservation Commission As KA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov 3r7 John Peirce Sr. Wells Engineer o I ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-07 5A,��Ml J 21 Sundry Number: 315-683 Dear Mr. Peirce: Enclosed is the approved application for 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, P Cathy P. oerster �� Chair DATED this ieray of November, 2015 Encl. Rees STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMIS ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon d Plug Perforations r, Fracture Stimulate [ Pull Tubing fl Operations Shutdown E Suspend rPerforate E Other Stimulate 1— Alter Casing f Change Approved Program 9 Plug for Redrill 1 Perforate New Pool Repair Well .Re-enter Susp Well[ Other: retrievablg, tubing patch I� 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory - Development E 181-137 • 3.Address: 6.API Number: Stratigraphic I- Service P.O.Box 100360,Anchorage,Alaska 99510 50-029-20658-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes — No I KRU 1A-07 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25647 • Kuparuk River Field/Kuparuk River Oil Pool .. 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8704 6443 , 8566' 6316' , none 8537' - Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 88' 88' SURFACE 6552 10 3/4 2470' 2213' IL" PRODUCTION 2080 7 8656' 6404' /A/rt OV O A 2v 2. 5 GCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8126'-8220,8232'-8249,8404'-8413', 5971'-6048',6057'-6071',6197'-6205', 8422'-8443,8445'-8466' i 6212'-6229',6231'-6248' 3.5 L-80 8323 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PRODUCTION PACKER MD=7966 TVD=5840 . PACKER-BAKER FB-1 PACKER W/SBE CROSSOVER TO 2 7/8"T MD=8317 TVD=6127 - NIPPLE MD=516 TVD=516 12.Attachments: Description Summary of Proposal I✓ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic P Development l— Service F 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/13/2015 OIL P WINJ WDSPL r Suspended E 16.Verbal Approval: Date: GAS WAG p GSTOR f SPLUG r-1 Commission Representative: GINJ P Op Shutdown E Abandoned E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophilliops.com Printed Name John W. Peirce Title: Sr.Wells Engineer Signature y t :' Phone:265-6471 Date j 1--33.. j 5' Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 5 (e'2 Plug Integrity ._.. BOP Test 1- Mechanical Integrity Test Location Clearance — V \'I03 Other: M54* Spacing Exception Required? Yes IDNo i Subsequent Form Required: k-p. 41 VP APPROVED BY // `_ Approved by: 7 COMMISSIONER THE COMMISSION Date:/f `( Q �1 �Rvftiifthid for 12 months r m date of apprval. Submit Form and V H Ply Il�99l � �r�s Form 10-403 Revised 5/2015 i Attachments in Duplicate • • Proposed 1A-07 Retrievable Tubing Patch Installation An IPROF on 9/26/15 ran in 1A-07 injector found 3 tubing leaks in the C Sd selective at 8205', 8215', and 8245' RKB in two full joints of 3.5" tubing. At PWI = 3050 BWPD, the IPROF saw 87% entering the C Sd leaks and 13% to A Sd. At 2060 BWPD, the IPROF saw 97% of PWI entering the C Sd leaks and 3% to the A Sd. SI crossflow also was observed from A to C sand. It is proposed that the C Sd leaks be isolated using a 60' OAL retrievable tubing patch to improve PWI support to the offset to A Sd producers. A successful tubing patch would improve net oil benefits by converting 1A-07 to an A Sd only injector. ✓ Procedure: Coil Tubing { 1. Perform a fill cleanout to as deep as possible prior to setting a tubing patch. The last tag of 9/26/15 shows that top of fill at 8449' RKB is partially covering the lowest A4 perforation interval. Slickline 2. Brush & Flush 3.5" tubing at 8170 - 8270' RKB in preparation for tubing patch installation. 3. RIH with a Dummy Tubing Patch Drift assembly that mimics run #3 of the proposed tubing patch installation. The drift will consist of a 2.72" OD x 4' OAL (top section) made up to 2.06" x 25' OAL spacer pipe (bottom section). Run the top of the drift to 8250' RKB. POOH. RD. Digital Slickline or Eline: 4. RIH & set a 2.72" OD retrievable straddle packer at -82�RKB (seal) in a full joint. POOH. Digital Slickline or Slickline: 5. RIH with -28' OAL run #2 assembly consisting from bottom to top of a snap latch seal stinger tyr assembly, spacer pipe, and a snap latch/PBR receptacle at -8225' RKB (top). Sting into the 2 lower straddle packer at -8255' RKB to set run #2. Shear off run #2 & POOH. 6. RIH with -28' OAL run #3 assembly consisting from bottom to top of a snap latch stinger, oo spacer pipe, and an upper retrievable straddle packer at top. Sting & latch into PBR receptacle dry. at -8225' RKB and then set the straddle packer at -8195' RKB. This completes a tubing patch at 8195 - 8255' RKB. 7. RIH with test plug and set it in the upper patch packer at 8195' RKB. MIT-T to 2500 psi to verify good integrity of upper packer and tubing above the patch. POOH with test plug. RD. Return 1A-07 to A Sand only PWI service and obtain a valid injection rate. JWP 10/27/2015 4 , �y KUP INJ • 1A-07 ConocoPhiflips •.. $ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act etc(ftKB) _csxx;fTanpc ;, 500292065800 KUPARUK RIVER UNIT INJ 63.55 4,150.00 8,704.0 - ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-07,B114/20141031:58 AM SSSV:NIPPLE Last WO: 9/3/2013 39.01 10/17/1981 .w....sRal aahemaba(gclual).. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,409.0 5/25/2013 Rev Reason:ADD RESIN haggea 8/14/2014 HANGER;25.4 yli l' Casing Strings Casing Description OD(in) ID(in) Top(MKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread 44,1 ,tti; CONDUCTOR 16 15.060 31.6 88.0 88.0 65.00 H-40 WELDED rAtI5 5:,F - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread '.k 3; SURFACE 103/4 9.950 30.5 2,469.5 2,212.6 45.50 K-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)... Wt/Len(I...Grade Top Thread �! '., II PRODUCTION 7 6.276 2,104.0 8,656.0 6,403.7 26.00 K-55 " •"''';'. ,roPo Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION Tie-Back 7 6.151 29.1 2,108.7 1,998.4 26.00 L-80 TCI! w/Patch Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2013 31/2 2.992 25.4 8,322.8 6,131.6 9.30 L-80 EUE-mod .r..AA CONDUCTOR;31.6-86.0 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(1 Item Des Com (in) 25.4 254 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 NIPPLE;515.7 I lit 515.7 515.7 1.26 NIPPLE CAMCO DS NIPPLE 2.875 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 olip 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 E 8,078.0 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 • 8,316.1 6,126.2 35.70 LOCATOR BAKER LOCATOR 9Spaced out 1') 2.980 8,317.0 6,126.9 35.70 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 PRODUCTION Tie-Badr Tubing Description !String Ma...I ID(In) -Top(ftKB) !Set Depth(It. Set Depth(TVD)I...IWt(Ib/ft) 'Grade !Top Connection w/Patch;29.1-2,108.7 TUBING WO 1985 6.156 4.000 8,3172 8,340.3 6,1458 1 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 8,317.2 6,127.0 35.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" 4.000 SURFACE;30.5.2,469.5- TUBING 8,332.2 6,1392 35.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 11 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB.**ELMD TTL @ 8322'ON 2.441 GAS LIFT,7,881.0 !PROF 8/22/2007' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 4 I. 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled 5 pushed to rathole 12/9/1985 0.000 during workover LOCATOR;7,937.7 4 Perforations&Slots Shot PBR;7,945.5 . Dens 5, Top(TVD) Min(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com p-.a; 8,126.0 8,220.0 5,971.5 6,048.1 C-4,C-3,C-2, 2/10/1982 4.0 IPERF Enerjet PACKER;7,965.6 I1A-07 8,232.0 8,249.0 6,057.8 6,071.7 C-1,1A-07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A-5,1A-07 2/11/1982 120 IPERF Thru-Tubing 8,422.0 8,443.0 6,212.4 6,229.5 A-4,1A-07 2/11/1982 120 IPERF Thru-Tubing GAS LIFT;8,017.5 I "` ': 8,445.0 8,466.0 6,231.2 6,248.3 A-4,1A-07 2/11/1982 12.0 IPERF Thru-Tubing 4 Cement Squeezes ITop(ND) Btm(ND) Top(ftKB)I Btm((KB) (RKB) (ftKB) Des Start Date Corn 7,890.041 7,965.6 5,778.1 5,8402 Cement Plug 7/24/2014 Placed 2.1 bbls of Resin into IA from 7965'to 7890' SLEEVE;8,078.0 '.: 5RKB over leak at PBR. c aQ Mandrel Inserts CBt ab on •(PERF;8,126.0-8,220.0- N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,881.0 5,770.7 Camco MMG 1 1/2 GAS LIFT DV RK 0.000 0.0 7/27/2014 2 8,017.5 5,882.6 Camco MMG-W 11/2 INJ DMY RK 0.000 0.0 9/12/2013 IPERF;8,232 0-8,249.0- Notes:General&Safety � 1t4;or" it i, End Date Annotation 9/1985 NOTE:WORKOVER 'LOCATOR;8,316.1 �'k-1 11/27/2005 NOTE:LEAK @ 8283' SEAL Asst,6,317.0 1 I 7/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER,6.3172 I 5/14/2011 NOTE:Erratic weight swings from 8071'-4600'&1900'-1500' ` 7/24/2014 NOTE: PLACED 2.1 bbls OF RESIN INTO IA FROM 7965'TO 7890'RKB OVER LEAK AT PBR f NIPPLE,6.332.2 11 Lo SOS,8,339.6 A� .p IPERF;8,404.0-8,413.0 • IPERF;8,422.0-8,443.0- IPERF;8,445.0-8,466.0 FISH,8,537.0 PRODUCTION;2,104.0.8,656.0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,July 20,2015 TO: Jim Regg 131/Z11 P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-07 FROM: Bob Noble KUPARUK RIV UNIT 1A-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-07 API Well Number 50-029-20658-00-00 Inspector Name: Bob Noble Permit Number: 181-137-0 Inspection Date: 7/17/2015 Insp Num: mitRCN150719133536 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WelllA-0 7 Type In'� w TVD 5832 Tubing- 2250 - 2250 -I 2250 2250 - 2200 - PTD 1811370 Type Test SPT Test psi 1500 - IA 950 1750 1720 - 1700 - 1700 - Interval 4YRTST P/F P OA 20 - 20 20 - 20 20 Notes: SCANNED a Monday,July 20,2015 Page 1 of 1 Ima ect Well History File Cover le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Y 2 /- _/~ Z Well History File Identifier Organizing RE$CAN [] color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Project Proofing BY: OBINVINCENT SHERYL MARIA WINDY Scanning Preparation j~ x 30 = C/;' 0 * ~ = TOTAL PAGES ///o~'' Production Scanning Stage lPAGE COUNT FROM SCANNED FILE: '// ~, yV~Es PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISC REPANCIES WERE FOUND: __ YES NO (SCANNING IS COMPLETE AT THiS POINT UNLESS SPECIAL ATrENTION IS REQUIRED ON AN INDIVIDUAl, PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) ReScanned (individual page [~pecial a~entiet~] ~canr~ing completed) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked (do.e) 12110102Rev3NOTScanned.wpd „�\��%%%�a� ' 'HE SATEr I acI_ `_ '�a _ - 333 West Seve,Ith Avenue (;ovsRNOR SEAN P ARNELL Ancnorage, Alaska 99501 3572 N\ain y07.279.1 433 John Peirce SCANNED MAY 1 6 ?D14 Wells Engineer f t 3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-07 Sundry Number: 314-044 Dear Mr. Peirce: Enclosed is the approved application for 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 P Cathy :. Foerster Chair DATED this ti day of January, 2014. Encl. • STATE OF ALASKA �1`i q�`k AL A OIL AND GAS CONSERVATION COMM' DN • APPLICATION FOR SUNDRY APPROVALS D7 ' i1.111 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Apnrinvmparrn r Suspend r Rug Perforations r Pelf orate r Pull Tubing r r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Pump Resin Packer J 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 181-137 - 3.Address: 6.API Number: Stratigraphic r Service p,. P.O. Box 100360,Anchorage,Alaska 99510 50-029-20658-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F., 1A-07• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25647 ' Kuparuk River Field/Kuparuk River Oil Pool J 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8704 • 6443 8566' 6316' none 8537' Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 88' 88' SURFACE 2439 10.75 2470' 2213' PRODUCTION 6552 7 8656' 6403' Perforation Depth MD(18126'-8220', Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8232-8249,8404-8413,8422-8443,8445-8466• 5972-6048,6058-6072,6198-6205,6212-6230,6231-6248 3.5 L-80 8323 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PRODUCTION PACKER o MD=7966 TVD=5840 PACKER-BAKER FB-1 PACKER W/SBE CROSSOVER TO 2 7/8"TI MD=8317 TVD=6127 ' NIPPLE-CAMCO DS NIPPLE @ MD=516 TVD=516 • 12.Attachments: Description Surrrnary of Proposal Fi 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17 • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r , Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce(a)_conocoohillips.com Printed Name John Peirce Title: Wells Engineer Signature / Phone:265-6471 Date �,/�5/J 4 Commission Use Only Sundry Number:3)4- 7 �/ Conditions of approval: Notify Commission",o that a representative may witness "7 Plug Integrity r BOP Test Mechanical Integrity Test ocation Clearance r RBDMS' MAY 09 2014 Other: E cc. GV/ rco) Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: l6 —404 �) APPROVED BY / Approved by: ( / COMMISSIONER THE COMMISSION Date: l —LJf'—/ A proved application Is valid for 12 months from the date of approval. Form 10-403(Revised 10/2012) ORIGINAL ''M IN ii? Submit Form and Attachments in Duplicate VL r— 1 / / i i •4 4ei✓4e w KUP INJ 1A-07 • COI1000pt1��p5 $ Well Attributes Max Angle&MD TD Alaska In, Wellbore API/UWI held Name Wellbore Status eel(") MD(ftKB) Act Btm(ftKB) Lerlottil�WYpt 500292065800 KUPARUK ROVER UNI I INJ 635`', 4,150 00 8,704.0 °°° Comment 7(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-07,1/2310138:3193 AM SSSV:NIPPLE Last WO: 9/3/2013 39.01 10/17/1981 Vpkul.tchemakp laclW) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __............._......_.._................_.........._..._............_. Last Tag:SLM 8,409.0 525/2013 Rev Reason WORKOVER haggea 9/20/2013 HANGER;25.4 1.:1i$ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I.,.Grade Top Thread h$9js7"IY CONDUCTOR 16 15.060 31.6 88.0 88.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD),..Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 30.6 2,469.5 2212.6 45.50 K-55 BUTT ',';:'::'.::.'.:1.*:': . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WVLen(L..Grade Top Thread e; PRODUCTION 7 6.276 2,104.0 8,656.0 6,403.7 26.00 K-55 � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 4,*PRODUCTION Tie-Back 7 6.151 29.1 2,108.7 1,998,4 26.00 L-80 TCII Top Job;28.8 y w/Patch P r Tubing Strings '''s '''''Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(8.Set Depth(TVD)(...Wt(INft) Grade Top Connection ? TUBING WO 2013 I 31/21 2.9921 25.41 8,322.81 6,131.61 9.301L-80 IEUE-mod 4 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) .A,A CONDUCTOR;31.608.0- 2&4 25.4 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 515.7 515.7 1.26 NIPPLE CAMCO DS NIPPLE 2.920 NIPPLE:515.7 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 f 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 ii i 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 8,078.0 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 • Auto cement plug:2.054.0 8,316.1 6,126.2 35.70 LOCATOR BAKER LOCATOR 9Spaced out 1') 2.980 CSG CMT;34.0 • 8,317.0 6,126.9 35.70 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 i Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND))...WI(INR) Grade Top Connection TUBING WO 1985 6.156 4.000 8,317.2( 8,340.3 6,145.8 Completion Details • • Nominal ID •• Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 8,317.2 6,127.0 35.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" 4.000 PRODUCTION Tie-Back • TUBING w/Patch;25.1-2,108.7 8,332.2 6,139.2 35.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 I 1 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB.-ELME/TTL @ 8322'ON 2.441 (PROF 8/22/2007" SURFACE;306-2.469.5-- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl i Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8.537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled&pushed to rathole 12/9/1985 0.000 GAS LIFT;7,881.0 It during workover I■ Perforations&Slots • Shot Dens Top(ND) Btm(ND) (shots/f LOCATOR;7,9377 IIIIIIII Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn I 8,126.0 8,220.0 5,971.5 6,048.1 C-4,C-3,C-2, 2/10/1982 4A IPERF Enerjet 1A-07 PBR;7,945.6 8,232.0 8,249.0 6,057.8 6,071.7 C-1,1A-07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A-5,1A-07 2/11/1982 12.0 IPERF Thru-Tubing PACKER;7,965.6 '� , 8422.0 8,443.0 6,212.4 6,229.5 A-4,1A-07 2/11/1982 12.0 IPERF Thru-Tubing 8,445.0 8,466.0 6,231.2 6,248.3 A-4,1A-07 2/11/1982 12.0 IPERF Thru-Tubing • • • Mandrel Details St GAS LIFT,6 017 5 ati C • I on Top(TVD) Valve Latch Port Size TRO Run m0 on_ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date 1 7,881.0 5,770.7 Cameo MMG 1 1/2 GAS LIFT SOV RKP 0.000 2,000.0 9/12/2013 RI DCR-1 SLEEVE;8,0760 Y � 2 8,017.5 5,882.6 Cameo MMG-W 11/2 INJ DMY RK 0.000 0.0 9/12/2013 I Notes:General&Safety End Date Annotation 12/9/1985 EWKER IPERF;8,126.0-8,220.0- 11/27/2005 NOTE:NOT :LEK @ 8283' 7/30/2010 NOTE:ViewORASchematic w/Alaska Schematic9.0 IPERF;62320.8,2490- 5/14/2011 NOTE:Erratic weight swings from 8071'-4600'&1900'-1500' I LOCATOR;8,316.1 II SEAL ASSY;8,317.0I = It PACKER;8,317.2 S. 1'', IT I NIPPLE;8,332.2 _. I SOS;8.339.6 IPERF;8,404.0.8,413.0-- I PERF:8,422.0-8,443.0- IPERF;8,445.0-8,466.0-- FISH;8.5370 s PRODUCTION;2,104.040656.0 1A-07 Resin Repair Leaky PBR 1A-07 is a Kuparuk C and A sand injector that was drilled and completed in 1981. Due to problems related to subsidence, 1A-07 has been Shut-in since 2008. A RWO in August 2013 installed new 3.5", L-80 tubing and a post-RWO MIT-T & CMIT passed. However, the MIT-IA failed. A 10-27-13 LDL found a 1-way' leak from the IA to tubing at 7940'RKB near the top of the PBR. The MIT-IA to 3000 psi dropped to 2800 psi in 12 minutes with —0.53 gpm leak rate. It is proposed to pump 2 bbls of Resin into the IA to seal off the '1-way' PBR leak. A similar Resin job was recently pumped in 2T-202 to successfully isolate a packer leak. Procedure Slickline: 1) Pull XX Plug set in Sliding Sleeve at 8078' RKB. Digital Slickline: 2) Set a millable Composite Plug at 7910' RKB. Slickline: 3) Set Catcher Sub on Plug at 7910' RKB. Pull DV from GLM#1 at 7881' RKB. Set fully open large orifice CV in GLM #1 at 7881' RKB. Pull Catcher Sub. Coil Tubing: 4) Spot 400 bbl upright tank on location and load with —250 bbls of heated (120 - 140°F) corrosion inhibited Seawater. Warm fluids are to be used to warm the wellbore to help keep Resin safely within its working temperature range while Resin is pumped into the well. MIRU CTU. Stab CT on well. If CT isn't already fully loaded with Diesel FP, load CT with Diesel to tanks, then open swab valve & RIH with large port nozzle with the IA open to tanks. Tag the Plug at 7910' RKB and flag pipe, then PU 29' to park nozzle at the CV at 7881' RKB. Pump 64 bbls warm Diesel at 1 bpm down CT to ensure IA is liquid packed & FP. SI IA. Open Tbg x CT annulus. Swap to circulating 23 bbls warm Diesel at 1.5 bpm, followed by 5 bbls of warm 8.6# corrosion inhibited Seawater Spacer, followed by 2 bbls of activated 10.5 ppg Resin, followed by 10 bbls of warm 8.6# corrosion inhibited Seawater Spacer, followed by the 10 bbls warm Diesel Spacer, followed by 10 bbls of warm 50/50 mix of Freshwater& Resin Solvent down CT at 1.5 bpm to the nozzle, followed by warm Diesel to fill up the remaining CT volume. As Resin approaches nozzle, SI Tbg x CT annulus and open IA to tanks. Drop rate to 0.5 bpm as Resin exits nozzle to IA through CV at 7881' RKB. After the 2 bbls of Resin is displaced to IA, SI IA. Open Tbg x CT annulus, then pump 1 more barrel warm Diesel down CT to ensure all Resin exits CT. PU to 7381' RKB replacing voidage with Diesel, followed by SD for 30 minutes to let 10.5 ppg Resin swap down IA to isolate leaky PBR and settle on Plug in the tubing. With 2 bbls of Resin out of nozzle, final resin top should be +/-7890' RKB. This intentionally leaves a Resin top just below GLM #1, which should enable preserving future functionality of the GLM following Resin placement. After 30 minutes waiting on Resin swap, verify Tbg x CT annulus is open to take returns to tanks, then resume pumping warm Diesel down CT at 1.5 bpm while RIH to park the nozzle at the GLM at 7881' RKB as 50/50 Solvent mix begins to exit the nozzle. Reciprocate nozzle across CV, then RIH to jet down to Plug at 7910' RKB to contaminate the resin in the tubing then PU to jet the remaining solvent over CV to clear the pocket area of Resin. The solvent mix contaminates and prevents Resin curing in the tubing and it clears Resin from CT. With nozzle parked at 7881' RKB, continue pumping warm Diesel at 1.5 bpm while taking returns from the Tbg x CT annulus to displace all contaminated Resin and solvent mix from tubing until clean Diesel is seen at surface, which should require < 80 bbls of Diesel pumping. With clean Diesel returns seen at surface to tanks, SI the Tbg x CT annulus and open the IA to tanks. Continue pumping another 71 bbls of warm Diesel down CT at 1.5 bpm through the CV to the IA, then SD pumping and close the IA. This last Diesel pump stage flushes the CV clear of contaminated Resin and verifies good circulation remains through the CV. POOH with CT. Place tubing & IA in communication at surface and allow U-tubing to equalize tubing & IA. RD CTU. Slickline: 5) On the morning after CT Resin pumping, RU SL & pump 10 bbls Diesel down tubing at 1 bpm while taking returns from IA to verify good circulation exists through the CV. By design, the Resin 'set time' will be such that it will not yet have had enough set time to have cured. Make SL run #1 to brush the GLM pocket at 7881' RKB to remove any remaining Resin around the CV. Make run #2 to set Catcher Sub on plug at 7910' RKB. Make run #3 to pull the CV from the GLM pocket at 7881' RKB. Make run #4 with to set DV in the GLM at 7881' RKB. Following a successful set of the DV, do not perform any MIT's. MIT work must wait to prevent micro-annulus creation through the IA Resin Plug placement before the Resin has had enough time to fully cure. Make run #5 to pull Cather Sub. RD SL. Note: If repeated attempts to pull the CV fail, another work procedure will be prepared to pump another Resin job to cover the CV to provide mechanical integrity needed to return 1A-07 to injection service. On 2T-202 Resin job of 9/22/13 the CV did pull OK, and the DV also set OK. DHD: 6) If the DV was set (step 5) and the Resin has had 7 days to fully cure, perform an MIT-T to 2500 psi, MITIA to 2500 psi, and an IA-DDT. Depending on MIT results, a leak detect log and second Resin job may be needed, or if testing passes proceed to step 7. Coil Tubing: 7) RIH with CT milling BHA and mill through the Composite Plug set at 7910' RKB. POOH with milling BHA. PU & RIH with nozzle to perform a post milling fill cleanout to as deep as possible. POOH with BHA. RD CTU. Return 1A-07 to injection service. 2 Ferguson, Victoria L (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Monday, January 27, 2014 2:43 PM To: Ferguson, Victoria L(DOA) Subject: RE:Well 1A-07 (PTD 181-137, Sundry 313-276, Sundry 314-044) Victoria, I went back to the last day of the 1A-07 Rig Workover notes (attached below). You can see all the pressure testing that was done. 9/13/2013 00:00 03:30 3.50 4908 8281 COMPZN WELLPR RCST Continue running 3.5" 9.3 lb/ft L- 80 EUE TBG F/ 4908' T/ 8281' MD as per program. Ran 259 joints to 8281' MD. 03:30 05:00 1.50 8281 8323 COMPZN WELLPR OTHR Change out to long bails for well control continency, M/U TIW on jt # 260 and make up to tbg string, Went down did not see press increase, M/U TIW to jt # 261 and saw prssure increase © 8318' MDTop of PBR, No Go @ 8323.83' MD, Difference in dp tally &TBG tally= 7.83' 05:00 06:00 1 8323 8318 COMPZN WELLPR CIRC P/U to 8318' MD and Pump 10 bbl inhibited 8.9 ppg and spot outside of tbg with 78 bbls 6 bbls chasing pill. 4 bpm 320 psi, brk off jt and drop Ball & rod. 06:00 07:00 1 COMPZN WELLPR PACK Sting back into PBR 1' off no go, Pressure up to 2700 psi & hold for 5 min, Slack off 15K, Pressure up to 3500 psi & hold for 5 min, Pressure up to 4000 psi & hold for 10 min, Bleed off pressure to1500 psi, Pulled 20K over (120K)and shear PBR from Premier Packer Top Premier packer © 7965' MD. 07:00 09:00 2 COMPZN WELLPR PUTB Space out completion, L/D jt # 261, # 260 & # 259, M/U 5' pup and P/U jt # 259 and M/U TBG hanger on top of jt 259, P/U jt # 260 as landing jt. 09:00 10:30 1.50 COMPZN WELLPR CIRC Pump 210 bbls of 8.9 inhibited brine with 5 bpm 530 psi chase with 140 bbls brine 5 bpm 550 psi. 10:30 11:30 1 COMPZN WELLPR PUTB Land TBG hanger as per-FMC and RILDS 11:30 12:00 0.50 COMPZN WELLPR PRTS Pressure test 3.5" TBG to 3500 psi 30 min (Good) 12:00 13:00 1 COMPZN WELLPR PRTS ,Pressure test csg/packer to 3500 1 • psi 30 min (Good) Bleed down TBG pressure and SOV. 13:00 13:30 0.50 COMPZN WELLPR PULD L/D landing joint and blow down kill and cement lines. 13:30 14:00 0.50 COMPZN WELLPR OTHR 'Install BPV as per-FMC 14:00 14:30 0.50 COMPZN WELLPR PRTS Pressure test in direction of flow to 1000 psi for 30 min (Good) 14:30 17:30 3 COMPZN WELLPR NUND N/D BOP's and stand back, N/D adapter spool. 17:30 20:30 3 COMPZN WELLPR NUND NH/U adapter spool and tree. FMC tested adapter void, 250 psi -5 min, 5000 psi -5min. (Lee Martin witnessed test). 20:30 21:30 1 COMPZN WELLPR OTHR I Pulled BPV and install TWC valve. 21:30 22:30 1 COMPZN WELLPR PRTSR/U and pressure test tree 250 psi '/ 5000 psi and chart same, R/D. 22:30 23:30 1 COMPZN WELLPR FRZP R/U LRS and pressure test lines 1500 psi, pump 75 bbls diesel down OA ICP= 500 psi, FCP= 700 psi, Let well U-tube. 23:30 00:00 0.50 COMPZN WELLPR SEQP Install BPV, Finish cleaning pits, Rig released from 1A-07 @ 23:59 9/13/2013, begin MOB for 1A-25. Please let me know if you need anything else. John Peirce Sr Wells Engineer CPAI Drilling&Wells (907)-265-6471 office From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Thursday, January 23, 2014 9:43 AM To: Peirce, John W Subject: [EXTERNAL]Well 1A-07 (PTD 181-137, Sundry 313-276, Sundry 314-044) John, During the workover,what was the result of the PT of the tubing and the IA? Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonalaska.gov 2 CE STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMI ION )C1 O 3 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell !_ Plug Perforations r Perforate r Other Alter Casing Fi Rill Tubing IW Stimulate-Frac fl Waiver 1 Time Extension r Change Approved R-ogram Operat. Shutdow n I— 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 fl Exploratory r 181-137 . 3.Address: 6.API Number: Stratigraphic r Service p. P. O. Box 100360,Anchorage,Alaska 99510 50-029-20658-00• 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 . 1A-07, 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CCL,CAST-M Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8704 feet Plugs(measured) none true vertical 6443 feet Junk(measured) 8537 Effective Depth measured 8566 feet Packer(measured) 7966, 8317 true vertical 6316 feet (true vertical) 5840,6127 Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 88 88 SURFACE 2439 10.75 2470 2213 PRODUCTION 8624 7 8656 6404 SCANNED NOV 1 4 2011 Perforation depth: Measured depth: 8126-8220, 8232-8249,8404-8413, 8422-8443, 8445-8466 True Vertical Depth: 5972-6048,6058-6072,6198-6205,6212-6230,6231-6248 Tubing(size,grade,MD,and TVD) 3.5, L-80,8323 MD,6132 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 7966 MD and 5840 ND PACKER-BAKER FB-1 PACKER @ 8317 MD and 6127 ND NIPPLE-CAMCO DS NIPPLE @ 516 MD and 516 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze 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 fl Service P' Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations XXX GSTOR WIND r WAG r, GINJ r SUSP r SPLUG 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: 313-276 Contact Jonathan Coberly C ,265-1013 Email Jonathan.Coberly(p cop.com Printed Name Jonathan Coberly Title Wells Engineer Signature 3 ,c _ Phone:265-1013 Date 01*1,3 ` - Vi-/-------/o//57/-2 .0 RBDMS OCT 11 f Sal Form 10-404 Revised 10/2012 Submit Original Only KUP INJ • 1A-07 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. T Wellbore API/UWI I Field Name Wellbore Status Inc!(°) I MD(ftKB) Act Btm(ftKB) t vanwu,„, 500292065800 KUPARUK RIVER UNIT INJ I 63.55 4,150.00 8,704.0 ••• Comment Annotation End Date KB-Grd(ft) Rig Release Date 1A-07,9/20/20138:31:03 AM SSSV:NIPPLE 1 H2S(ppm) 1 Date Last WO: 9/3/2013 39.01 10/17/1981 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _... .__ __.. .._ Last Tag:SLM 8,409.0 15/25/2013 Rev Reason:WORKOVER I haggea I 9/20/2013 HANGER 25.404 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread r t CONDUCTOR 16 15.060 31.6 88.0 88.0 65.00 I-I-40 WELDED o a k 4 e s ti' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt./Len(I...Grade Top Thread Sr �`�t4yj: SURFACE 103/4 9.950 30.6 2,469.5 2,2126 45.50 K-55 BUTT • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 &, . lir PRODUCTION 7 6.276 2,104.0 8,656.0 6,403.7 26.00 K-55 s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)..Wt/Len(I...Grade Top Thread PRODUCTION Tie-Back 7 6.151 29.1 2,108.7 1,998.4 26.00 L-80 TCII Top Job,28.8 b r w/Patch Tubing Strings t y i um"Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lbkt) Grade Top Connection -� TUBING WO 2013 31/2 2.9921 2541 8,322.81 6,131.61 9.30 L-80 EUE-mod Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) •AAA CONDUCTOR 31.6-86.0• 25.4 25.4 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 515.7 515.7 1.26 NIPPLE CAMCO DS NIPPLE 2.920 NIPPLE;515.7 {t 7,937.7 5,817.3 34.81 LOCATOR BAKER LOCATOR Length above PBR 2.990 k 1 7,945.5 5,823.7 34.89 PBR BAKER 80-40 PBR 2.990 ' 7,965.6 5,840.1 35.25 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 i 8,078.0 5,932.3 35.13 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 Auto cement plug;2,054.0 8,316.1 6,1262 35.70 LOCATOR BAKER LOCATOR 9Spaced out 1') 2.980 CSG CMT;34.0 •* 8,317.0 6,126.9 35.70 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSY 2.980 { Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft Set Depth(ND)(...Wt pn/ft) Grade Top Connection I t{I TUBING WO 1985 1 6.156 4.0001 8,317.2 f 8,340 31 6,145.81 1 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc](°)_ Item Des Com (in) 8,317.2 6,127.0 35.69 PACKER BAKER FB-1 PACKER w/SBE CROSSOVER TO 2 7/8" 4.000 PRODUCTION Tie-Back TUBING w/Patch;29.1-2,108.7 8,332.2 6,139.2 35.63 NIPPLE CAMCO D NIPPLE NO GO 2.250 9 I 8,339.6 6,145.2 35.60 SOS CAMCO SHEAR OUT SUB.°°ELMD TTL @ 8322'ON 2.441 /PROF 8/22/2007°° SURFACE:30.6-2,469.5 • Other In.Hole iiireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc!' Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled&pushed to rathole 1219/1985 0.000 GAS LIFT,7,881.0 1. during workover 1 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/r LOCATOR 7,937.7 @ C�I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t( Type Com l■ 8,126.0 8,220.0 5,971.5 6,048.1 C-4,C-3,C-2, 2/10/1982 4.0 IPERF Enerjet 1A-07 PBR;7,945.5 8,2320 8,249.0 6,057.8 6,071.7 C-1,1A-07 2/10/1982 4.0 IPERF Enerjet 1 8,404.0 8,413.0 6,197.7 6,205.1 A-5,1A-07 2/11/1982 12.0 IPERF Thru-Tubing PACKER;7,965.6 11 1 8,422.0 8,443.0 6,212.4 6,229.5 A-4,1A-07 2/11/1982 12.0 IPERF Thru-Tubing I 8,4450 8,466.0 6,231.2 6,248.3 A-4,1A-07 2/11/1982 12.0 IPERF ThruTubing Mandrel Details St GAS LIFT;8,017.5 ati C Na 1on Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date m 1 7,881.0 5,770.7 Camco MMG 1 1/2 GAS LIFT SOV RKP 0.000 2,000.0 9/12/2013 DCR-1 2.1 2 8,017.5 5,882.6 Camco MMG-W 11/2 INJ DMY RK 0.000 0.0 9/12/2013 SLEEVE;8,078.0 Notes:General&Safety End Date Annotation 12/9/1985 NOTE:WORKOVER IPERF,8,126 0-8,220. _ .- 11/27/2005 NOTE:LEAK @8283' 760/2010 NOTE:View Schematic wl Alaska Schematic9.0 IPERF;8,232.0.8,249.0 5/14/2011 NOTE:Erratic weight swings from 8071'-4600'&1900'-1500' 1 LOCATOR 8,316.1 NM SEAL ASSY,8,317.01 I1 = r i PACKER,8,317.2 L 11 11 NIPPLE;8,332.2 I SOS;8339.6 IPERF;8,404.0-8,413.0 IPERF;8.4220-8.4430- IPERF,8,445.0-8,466.0 FISH,8,5370 PRODUCTION,2,104.0-8,656.0 • 1A-07 Pre-Rig Well Work Summary • DATE SUMMARY 5/24/2013 BRUSHED SSSV @ 1781' RKB. MIT T x IA 2500 PSI, PASSED. SET CATCHER SUB ON WRP @ 8071' RKB. PULLED SWELL PACKER DV @ 7978' RKB. PULLED CATCHER. BAILED FINE SCALE OFF WRP. IN PROGRESS. 5/25/2013 BAILED SCALE OFF WRP @ 8070' RKB; PULLED WRP. TAGGED @ 8409' SLM, EST. 53' FILL. IN PROGRESS. 5/28/2013 PULLED 1" DMY VLV @ 8075' RKB; MEASURE SBHP @ 8200' RKB (2640 psi ). READY FOR PUMPING. 6/9/2013 Bullheaded 165 bbls 9.9#brine followed by 55 diesel down IA @ 3 bpm. Re-rigged and bullheaded 85 9.9# brine(mt'd truck)followed by 18 bbls diesel down Tbg @ 3 bpm. 6/21/2013 RIH WITH STRING SHOT. CCL TO MIDDLE OF STRING SHOT: 5'. CCL STOP DEPTH @ 8091'. FIRED STRING SHOT @ 8096'.TENSION SWINGS OF 200#FROM BOTTOM TO 4000'. RIH WITH RADICAL CUTTING TORCH. CCL TO CUTTER: 9.5'. CCL STOP DEPTH @ 8087'. CUT PIPE @ 8096'. TENSION SWINGS OF 200#FROM BOTTOM TO 4000'. WILL RETURN TOMORROW FOR ANOTHER STRING SHOT AND CUT 6/23/2013 RUN 1: FIRE 160 GR/FT STRING SHOT FROM 79971-8002'. RUN 2: CUT TUBING USING RCT 2500-200 AT 8002'. TOOLSTRING BECAME STUCK IMMEDIATELY AFTER FIRING RCT. WORKED TOOLSTRING UNTIL EJARS ACTIVATED AND TOOLSTRING BECAME FREE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 09 DEC 1985. JOB COMPLETE, READY FOR BPV. • • ConocohiIIips Time Log & Summary Wel/view Web Reporting Report Well Name: 1A-07 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 8/4/2013 11:59:00 PM Rig Release: 9/13/2013 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/03/2013 24 hr Summary Release from 1A-08. LD derrick and prepare for move. Perform some rig maintenance while waiting on dirt work around well and pad for rig. 12:00 00:00 12.00 MIRU MOVE MOB P Lay down derrick, inspect and warm up moving system. Check moving system operations. 38/04/2013 Moved rig over 1A-07, prepare area with herculite and matting, move in pit module and hook up. Raise derrick and RU rigfloor equipment. Take on Brine to the pits and cut back weight to 8.9 PPG. Rig up to IA and Tubing: IP Tubing=200 psi, IP IA=0 psi, OA= 190 psi. Rig accepted as 2359 hrs 8/4/2013. 00:00 02:00 2.00 MIRU MOVE MOB P Wait as site preparation is completed over well. Leveling pad by adding gravel and building up in cellar area w/gravel. 02:00 06:00 4.00 MIRU MOVE MOB P Move rig over and spot over 1A-07. Set herculite, berming, and matting boards. Spot sub over well and set pit module. RU interconnect and pits. 06:00 12:00 6.00 MIRU MOVE MOB P Spot cuttings tank and berm the tank. Spot stairs, landings and continue with interconnect hook up. 12:00 18:00 6.00 MIRU MOVE MOB P Take 9.6 ppg Brine into the pits and cut back to 8.9 PPG. Raise derrick and rig up derrick equipment and raise cattle chute and MU kelly hose, MU blocks to topdrive. Hang bridle lines 18:00 20:00 2.00 MIRU MOVE MOB P Prep rig floor and floor equipment hang tongs, install bales, and load pipe in the shed. 20:00 23:00 3.00 MIRU MOVE MOB P RU on wellhead; IP Tubing=200 psi, IP IA=0 psi, OA= 190 psi. RU lubricator, PT lubricator and FMC rep pulled BPV, BPV hung in stack at the SSV, used T-bar to remove BPV. 23:00 00:00 1.00 COMPZ MOVE MOB P Secure well and RU manifold and hardlines to Tiger tanks. PT lines with air. Rig accepted at 23:59 8/4/2013. 08/05/2013 Bleed both sides to 0 psi. Reverse circulate 81 BBL when 8.9 ppg Brine was seen and choke. Circulated down tubing 326 BBL,shut down to pump out Tiger tank. SI Tubing=230, SI IA= 110 psi. Circulate another 75 BBL until clean 8.9 ppg brine at the choke then take returns to pits. Shut down and open well to atmosphere and monitor for 30 minutes-Static. Set 3"BPV,dynamic test to 550 psi with hole taking fluid, nipple tree, install FMC blanking plug, NU 13-5/8"BOPE, change bottom pipe rams to 7", rig up to test BOPE. Electrician tested h2S and methane gas alarms. Page 1 of$7 Time Logs • Date From ! To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 02:00 2.00 COMPZ WHDBO NUND P Continue to RU to well head and choke and tiger tank. Air test lines and hydro test lines. 02:00 04:00 2.00 COMPZ WELCTL KLWL P Secure well and bleed off pressure Ini. IA=0 psi,Tubing= 150 psi. Bleed to zero both side. Reverse circ 81 BBL of Brine to displace diesel from tubing side. Brine at manifold at 81 BBL away. Circulate forward 35 BBL of Deep Clean sweep and chase with 8.9 PPG brine from pits. Stage up pumps to 6 BPM at1250 psi. Pmp 326 BBL then shut down. 04:00 05:00 1.00 COMPZ WELCTL OWFF P Pump off kill tank,taking one hour while shut in Tbg=150 psi, IA=75 psi. 05:00 07:00 2.00 COMPZ WELCTL CIRC P Pump down tubing at 6 BPM with 1200 psi. Clean returns at the manifold with 435 BBLs away. Take returns to pits for 21 additional BBLs of 8.9 PPG brine. Observed well for 30 minutes to atmosphere: Static 07:00 08:00 1.00 COMPZ WELCTL CIRC P Secure well and set BPV per FMC. Attempted to test BPV but hole would not hold pressure. Pumped away 10 BBLs in the attempts. Checked surface equipment to 1000 psi-Good. Well static. Dynamic test to 550 psi while pumping 6 bpm. BPV holding. 08:00 09:30 1.50 COMPZ WHDBO NUND P ND Tree and NU BOPE. Inspect hanger threads=Good. Install FMC blanking plug with 11 1/2 turns Left into hanger and 9 1/2 turns top of BP. 09:30 12:00 2.50 COMPZ WHDBO NUND P NU BOPE 12:00 17:00 5.00 COMPZ WHDBO NUND P NU BOPE 17:00 20:00 3.00 COMPZ WHDBO NUND P NU BOPE;test Sierra gas monitoring system. Change lower rams to 7". Upper rams are 3 1/2"X 6"variable bore. 20:00 20:30 0.50 COMPZ WHDBO NUND P PU test tools and jet stack,then open-ended 3.5"DP. 20:30 21:30 1.00 COMPZ WHDBO NUND P PU test joints and RU to test BOPE. 21:30 00:00 2.50 COMPZ WHDBO BOPE P Test BOPS;Witness of test waived by AOGCC inspector Bob Noble on 8/5/2013. Pumping across the top of the IA during the day,206 BBLs of 8.9 ppg brine lost to hole. 08/06/2013 Test BOPE 250/3500 psi 5 minutes each. R/D test equipment,dry rod BPV out, M/U landing joint&BOLDS, wait on E-line and tools, R/U e-line&run CCL and 5'string shot, locate and fire shot at 8007'WLM, POOH and pull test tbg with 118K no movement, R/U CCL&RCT, RIH&locate at 8007'and fire RCT, POOH,and R/D down top sheave, Pulled 135K and lay down hanger and pups, circ hole at 10 bpm for 317 bbls, Monitor well, Pull tbg first three joints straight next 19 bent. Page 2 of 57 Time Logs I I Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 COMPZ RPCOM BOPE P Test BOPE,250 low 3500 high and chart same, Koomey test start 3000 psi,closing 1725 psi,200 psi 15 sec,final psi 88 sec, upper rams 6 sec, lower rams 6 sec, choke 1 sec, kill 1 sec,electric pump 23 sec,air pump 159 sec,5 bottles at 1950 psi avg. 03:00 03:30 0.50 0 0 COMPZ RPCOM BOPE P L/D test tool and R/D test equipment. Bolw down lines and choke, pull blanking plug. 03:30 05:30 2.00 0 0 COMPZ RPCOM PULD P Make up tools, BHA and R/U GBR, pick up landing joint and dry rod BPV well on vac. 05:30 07:00 1.50 0 0 COMPZ RPCOM PULL P Screw into hanger with landing joint and BOLDS, unseat hanger and pulled 114K not free,excerise several times,fill hole with 19 bbls. Brk circ 3 bpm with 215 psi,6 bpm with 650 psi, Re-arrange landing joint for wireline space out. 07:00 07:30 0.50 0 0 COMPZ RPCOM SVRG P Serviced torque boost on Top Drive. 07:30 10:15 2.75 0 0 COMPZ RPCOM OTHR P Wait on 3rd party tools E-line and cutting tools. 10:15 10:30 0.25 0 0 COMPZ RPCOM SFTY P BOP Drill, CRT=73 sec. 10:30 12:00 1.50 0 0 COMPZ RPCOM FLOG P R/U e-line while waiting on cutting tools. 12:00 12:30 0.50 0 0 COMPZ RPCOM ELOG P Make up CCL and 5'string shot 12:30 14:00 1.50 0 0 COMPZ RPCOM ELOG P RIH with CCL and string shot 14:00 15:30 1.50 0 0 COMPZ RPCOM ELOG P Locate center of 5'string shot @ 8007'MD and fire string shot @ 14:10 hrs, E-line noted pipe movement when shot fired, POOH with e-line. 15:30 16:30 1.00 0 0 COMPZ RPCOM ELOG P Check pull to 118K and did not get any pipe movement, M/U HES CCL and RCT. 16:30 18:00 1.50 0 0 COMPZ RPCOM ELOG P RIH with CCL and RCT, locate and fire RCT at 8007'MD WLM, at 15:10 hrs. POOH and L/D top sheave. 18:00 20:00 2.00 0 0 COMPZ RPCOM PULL P Pulled tbg hanger to rig floor with 135K up wt. break out and(L/D landing joint, Lay down 1.35'hanger, 3.36'pup,2.09'pup.)Disconnect SSSV line from hanger and hook up to spooler. 20:00 20:30 0.50 0 0 COMPZ RPCOM ELOG P R/D HES E-line. (seeing 13.3 bph static loss rate.) 20:30 21:30 1.00 0 0 COMPZ RPEQP1 CIRC P Circ down tbg 174 spm, 10 bpm, 1640 psi, circulated 317 bbls,with 25 bbl loss to well while circ,Take SPRs, Monitor well taking fluid at 14 bbls an hour. I Page 3 of 57 Time Logs 410 • Date From To Dur S. Depth F.Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 0 COMPZ RPCOM PULL P Statrt L/D tbg,first joints straight, next 19 joints bent, recoved 12 SS bands PUW= 130K, SOW=45K, Losses for this tour= 175.9 bbls. 38/07/2013 Lay down tbg to joint#57,pulled tight and could not get back down, Mix&spot lube pill,attempt to pull tbg with 135K, attempt to rotate and stage torque up to 3500 ft/lbs, unable to get free rotation, Consult town on plan forward, clean rig and service iron roughneck, Back out Joint#57&lay down, M/U cross over and 3.5" tbg pup for floor safety valve, change out elevators. 00:00 02:00 2.00 0 0 COMPZ RPCOM PULL P Pull tbg F/joint 22 to joint 25, PUW= 100K,several spots 115K,control line parted on Joint#25. Had indication of parted string while pulling joint#49, (135K)wt.dropped to 38K. Continue pulling to joint number 57 with up wt F/31K T/ 114K, pulled to 140K with 1'of movement. (Looks like the top of the SSSV is down inside of the well head.) 02:00 04:00 2.00 0 0 COMPZ RPCOM OTHR T Mix and spot 35 bbl lube pill, pump around and got pill back to surface with 230 strokes with 6 bpm and 55 psi. Indicates we did part some where below the SSSV 04:00 08:30 4.50 0 0 COMPZ RPCOM OTHR T Work pipe every 30 min.while pumping 2 bbl of lube pill into annulus every 30 min. and pulled up tp 135K and made 2 more inches up. Unable to slack off,work pipe with out any more pipe movement. 08:30 12:00 3.50 0 0 COMPZ RPCOM OTHR T Brk circ with 6 bpm and 100 psi work up to 10 bpm with 235 psi,attempt to rotate string ,stage torque to 3500 ft/lbs, unable to get free rotation, work pipe up and down to max of 100K, Lost 134 bbls loss during this tour. 12:00 14:00 2.00 0 0 COMPZ RPCOM OTHR T Consult town on plan forward,service rig and clean rig. 14:00 15:00 1.00 0 0 COMPZ RPCOM OTHR T Continue working stuck pipe PU to 50K and apply left hand torque, connection tbg connection broke at collar/pin on joint 57,stop for new plan forward. 15:00 21:30 6.50 0 0 COMPZ RPCOM OTHR T Consult with town on plan forward# 3. Make calls and arrangements to get need tools and cross over's to location. 21:30 23:30 2.00 0 0 COMPZ RPCOM OTHR T Back out joint#57 with collar from joint#58, UD#57(31.16'),break out collar from pin end,thread collar back onto joint#58, Break out cross over from top of joint#57. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR T M/U cross over and 3.5"tbg pup with TIW valve,C/O elevators, Loss 111.4 bbls this tour to well. Page 4 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08/08/2013 24 hr Summary M/U Baker driving BHA#1, Beat down on top of control line and SSSV made 1.56',Consult with engineer and called out digital slick line unit, L/D BHA#1, R/U slick line&run CCL logging tool,verified 30'joint of tbg on top of SSSV,W/O Orders, Run back in with CCL logging tool and tagged up at 282'MD, POOH,W/O orders, R/D slick line unit, M/U 4.5 joint for next driving BHA#2,slack over 3.5"tbg joint and beat down on SSSV with no movement gained, 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR T M/U Baker BHA#1 (Driving BHA) with one joint of 5.5"casing, cross over,6-1/4"bumper sub/jars,cross over, 10'dp pup screwed into the Top Drive. 01:00 05:00 4.00 0 0 COMPZ RPCOM OTHR T Tagged @ 25.5'in, Beat down with above BHA on SSSV fish.We have made 1.56'down movement. Called and discussed with Engineer to call out slick line for CCL run. 05:00 07:00 2.00 0 0 COMPZ RPCOM OTHR T SLB arrived on location, Lay down Driving BHA while they move truck over from another well on the pad, held PJSM with SLB and rig up slick line. 07:00 07:30 0.50 0 0 COMPZ RPCOM ELOG T RIH with digital slick line and CCL tool,verified 30'joint of tbg on top of SSSV with CCL logging run. 07:30 09:00 1.50 0 0 COMPZ RPCOM ELOG T Leave slick line rigged up and wait on orders from town. 09:00 09:30 0.50 0 0 COMPZ RPCOM ELOG T RIH with slick line and tagged at 282' MD, POOH 09:30 11:00 1.50 0 0 COMPZ RPCOM ELOG T Wait on order with slickline rigged up. 11:00 11:30 0.50 0 0 COMPZ RPCOM ELOG T R/D SLB digital slick line unit and release same. 11:30 12:00 0.50 0 0 COMPZ RPCOM OTHR T Wait on orders. 12:00 13:30 1.50 0 0 COMPZ RPCOM OTHR T Wait on orders. 13:30 14:30 1.00 0 0 COMPZ RPCOM OTHR T Remove IBT-M collar from top of tbg joint#58, M/U joint of 4.5"BTC with pin end cut off, cross over,bumper sub,jars and cross over for driving BHA. 14:30 17:00 2.50 0 0 COMPZ RPCOM OTHR T Slack 4.5"joint over 3.5"tbg,tag balled up control line at 27.5', continuously beat down on control line with no movement shown. 17:00 00:00 7.00 0 0 COMPZ RPCOM OTHR T Beat down on control line and SSSV with bumper sub for 15 min every hr, had no additional movement past 27.5'; (Total loss to the well this tour= 107 bbls.) 08/09/2013 Continue to beat down on SSSV with no movement gained using a 4-1/2"BTC jt of casing around 3.5"jt of tubing. Lay down BHA, install collar on jt of 3.5"tubing 1'below rotary table. Screw 3.5"IBT x 3.5"EUE x-o pup into joint. Rig up HES e line. RIH,then set Baker 2.5"x 7"IBP w/center of element @ 276.67',test to 1500 psi, RIH w/another 2.5"x 7"IBP,set w/center of element @ 260'. POOH w/E-line, rig down.RU table to dump 22 sx of sand for 50'+of coverage above fishing neck. M/U overshot BHA and back out 3.5"tbg joint across stack, M/U Baker rope spear and fish out the control line and 12 bands. Page 6 of 57 Time Logs • • Date From To Dur S. Depth E.Depth Phase Code 'Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR T Beat down on control line and SSSV with bumper sub for 15 min every hr, had no additional movement past 27.5' 01:00 02:00 1.00 0 0 COMPZ RPCOM PULD T Lay down BHA#2 and get ready for E-Line to run 2.5"Baker IBP plugs. 02:00 05:00 3.00 0 0 COMPZ RPCOM ELOG T Spot HES unit and held PJSM, Rig up E-line unit, lubricator, pump in sub and sheaves to run Baker IBP plugs 05:00 07:00 2.00 0 0 COMPZ RPCOM ELOG T M/U first 2.5"X 7" IBP run in, locate collar and set @ 280'MD Bottom of plug set @ 280', Center of element @ 276',Top of FN @ 269'MD.Allow stabilization till 0645 hrs. 07:00 08:30 1.50 0 0 COMPZ RPCOM DHEQ T Fill lubricator, purge air,then test IB P to 1500 psi f/30 minutes. Chart test. Lost 85 psi in 30 minutes-good test. Blled off pressure.Test w/ Annular,shut both kill line and choke line HCR valves. 08:30 09:00 0.50 0 0 COMPZ RPCOM ELNE T Remove tool string. Check conductivity of e line. Make up 2nd Baker 2.5"x 7"IBP. 09:00 10:30 1.50 0 0 COMPZ RPCOM ELNE T Run in the hole w/2nd Baker 2.5" IBP. Set w/center of element @ 260'.Top of fishing neck @ 253', bottom of plug @ 263.5'. 10:30 11:00 0.50 0 0 COMPZ RPCOM RURD T Rig down HES e line equipment. 11:00 12:00 1.00 0 0 COMPZ RPCOM RURD T Rig up sand table and beging to pour 5 sx of sand in hole to protect fishing neck of IBP, COE @260',top of fishing neck @ 253'. 12:00 18:30 6.50 0 0 COMPZ RPCOM OTHR T Continue to dump sand for a total of 22 sx down hole to protect FN on IBP plug,dump slow to prevent packing off.. 18:30 21:00 2.50 0 0 COMPZ RPCOM PULD T P/U Baker overshot BHA#3 as per Baker Rep. PUW=30K, SOW=30K, drain stack and slide over tbg joint, set down 5K, pulled 50 K over, rotate tq 4-6K over fish, back out fish and pull to rig floor,fish length=31.19'. Note:With a collar and MU loss,jt# 58 length would be 31.30'. 21:00 00:00 3.00 0 0 COMPZ RPCOM FISH T M/U Baker rope spear BHA#3 as per Baker Rep. PUW=30K, SOW= 30K, hook control line pulled 11K over, broke free, Remove control line from spear, recovered 12 bands wrapped up with the control line. Page 6 of 57 Time Cogs 110' • Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 08/10/2013 24 hr Summary Continue with rope spear, had bent barb on spear, UD and P/U 5.5"rope spear and attempt to fish out more control line hung up with 15K over pull, UD,call out welder and repair bent barb and re run, cunt.fishing operations, RIH and push control line down over fish,M/U ITCO spear and engage fish @ 32', pulled fish free with 65K, pulled up 6.56'with 50K over,W/O/O,work free spot 1.3'worked up to 85K(55K over)Grapple broke recovered 1 side of grapple other went do tbg, M/U magnet and recovered one piece of grapple, M/U burn shoe and mill over fishing neck on SSSV, made 1.5', M/U short catch overshot BHA. 00:00 00:30 0.50 0 0 COMPZ RPCOM FISH T Make another rope spear run and only recovered 8"of line, UD rope spear due to bent barb on bottom of spear. 00:30 01:00 0.50 0 0 COMPZ RPCOM PULD T M/U 5-1/2"rope spear and attempt to fish out more control line,spear hung up in 7"casing with 15K overpull and torque up to 3500 fUlbs POOH with spear, no control line recovered. 01:00 01:30 0.50 0 0 COMPZ RPCOM PULD T UD rope spear. 01:30 02:00 0.50 0 0 COMPZ RPCOM OTHR T Consult with Town Engineer,drain stack and take pictures,can still see some control line on top of SSSV. Town engineer wants to repair rope spear and try again to catch the control line sticking out on top of SSSV. (Ordered two more rope spears from deadhorse) 02:00 04:00 2.00 0 0 COMPZ RPCOM PULD T Call out welder and repair bent barb on first rope spear, M/U rope spear. 04:00 04:30 0.50 0 0 COMPZ RPCOM FISH T Attempt to fish out control line with repaired rope spear but unable to grab control line. Made three attempts. POOH and UD same. 04:30 06:00 1.50 0 0 COMPZ RPCOM PULD T Consult with town, M/U ITCO Spear BHA. 06:00 08:00 2.00 0 0 COMPZ RPCOM FISH T New rope spears arrived. Lay down ITCO spear assembly. Make several runs w/new rope spear to gather up more control line. Recovered a SS band and a little more control line on first run. Note: Control line weighs.089#/ft. Recovered 60.4#of control line= approx 678'of control line. 08:00 08:30 0.50 0 0 COMPZ RPCOM FISH T P/U 5.5"casing joint and push control line down over fish, UD joint. 08:30 09:30 1.00 0 0 COMPZ RPCOM FISH T P/U rope spear and make several more attempts, no junk recovered, UD spear. 09:30 10:30 1.00 0 0 COMPZ RPCOM PULD T Make up ITCO spear with 2.748" grapple,engage fish @ 32' 10:30 11:00 0.50 0 0 COMPZ RPCOM FISH T Pull on fish, broke free with 65K, pulled up 6.56'with up wt F/50K T/ 80K,did not pull more than 80K(50K over) 11:00 12:00 1.00 0 0 COMPZ RPCOM OTHR T Wait on orders. 12:00 13:30 1.50 0 0 COMPZ RPCOM OTHR T Wait on orders. Page 7 of 67 Time Logs I III Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 13:30 15:00 1.50 0 0 COMPZ RPCOM OTHR T Work free spot 1.3'travel untill hangs up, set down to 20K, P/U wt and warm up jars,work up to 75K, 80K, 85K, Grapple broke @ 85K, 55 over, recovered one side of grapple. 15:00 16:00 1.00 0 0 COMPZ RPCOM OTHR T Wait on third party tools,wait on grapple,spear from Baker shop. 16:00 18:00 2.00 0 0 COMPZ RPCOM SLPC T Slip on 150'new drilling line and cut off 500'bad line. 18:00 19:00 1.00 0 0 COMPZ RPCOM OTHR T Wait on Baker tools. 19:00 19:30 0.50 0 0 COMPZ RPCOM PULD T M/U BHA#9 magnet as per Baker hand, retrieve one pieceof grapple, one piece still in hole. L/D magnet BHA. T M/U BHA#10, as per Baker hand. 19:30 20:00 0.50 0 0 COMPZ RPCOM PULD p 20:00 22:30 2.50 0 0 COMPZ RPCOM MILL T Wash over fish with burn shoe,set down 5K, mill F/26'T/27.25', WOM= 1K, GPM 340, PSI=55 off, PSI=75 on, RPM=80,Tq off=550, Tq on=800, PUW=30K, SOW=30K, Rot wt=30K. 22:30 23:00 0.50 0 0 COMPZ RPCOM TRIP T POOH, Drain stack,observed control line in hole, M/U magnet and fish out. 23:00 23:30 0.50 0 0 COMPZ RPCOM MILL T TIH and mill F/27.25'T/27.50' WOM= 1-2K, GPM=475, PSI off=140, PSI on 180, RPM=80,Tq off=550,Tq on=800, PUW=30K, SOW=30K, Rot wt=30K. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD T Lay down mill BHA,drain stack, M/U BHA#11 as per Baker hand. (Short Catch Overshot) 38/11/2013 Attempt to get overshot over fish, unable to get over SSSV, Discuss with town, N/D stack and found control line bundled up under 7"pack-off,clean out pieces and had FMC look at pack-off, P/U 4'pup joint of 3.5"tbg and screw into top of SSSV and pull back up to get good measurements for Baker fishing, N/U stack and shell test to 1000 psi against IBP's. MU BHA to push fish down to 69.5'(collar of SSSV). L/D BHA, monitor well-static. ND BOPE,set to the side. RU hydratight on casing and tubing spool to allow 7"to grow. 00:00 00:30 0.50 0 0 COMPZ RPCOM FISH T Attempt to engage fish with short catch over shot. Unable to engage fish, POOH. 00:30 01:00 0.50 0 0 COMPZ RPCOM OTHR T Consult with town engineer, order out smaller grapples and N/D stack while waiting on grapples. 01:00 02:00 1.00 0 0 COMPZ WHDBO NUND T N/D stack and found control line balled up under 7"pack-off. 02:00 05:00 3.00 0 0 COMPZ RPCOM OTHR T Take pictures and consult with town, clean up any loose control line from well head. Remove 7-1/16"5 x 13-5/8"5m drilling spool adapter to clean junk out of it and make back up. Called FMC to look at 7"pack-off for any idea's. Note: 3-1/2"IBT-m collar on top of SSSV has an OD of 4.26". Page 8 of 57 Time Logs 1 Date From'. To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:30 1.50 0 0 COMPZ RPCOM OTHR T Make up 4'pup joint of 3.5"IBTtbg and pull SSSV back up to look at it and get correct measurements of the top of the SSSV for fishing later. Pull 5k over(35k on weight indicator) pulling f/27.5'to 26' RKB. Discuss with town to leave 3.1'of pup joint without collar, screwed into SSSV to enable fishing option after trying to push back to the top of sand @ 203'. Make up crossover to screw a 4' IBT pup jt into SSSV. Noticed collar on the SSSV turning through ball of control line while making up pup jt. 06:30 07:30 1.00 COMPZ RPCOM PULD T Break out of tubing pup jt that was screwed into fish.Cut off collar of pup, leaving 3.1'of 3-1/2"IBT pup screwed into fish,with no collar or threads on top(for fishing purposes). 07:30 09:00 1.50 0 0 COMPZ WHDBO NUND T Nipple up 13-5/8"x 7-1/16"drilling spool adapter to the top of the FMC tubing head. Nipple up 13-5/8" BOPE. 09:00 09:30 0.50 0 0 COMPZ WHDBO BOPE T Shell test BOPE to 1000 psi f/5 minutes against IB"s and sand(Top of sand'203'). Use blind rams,kill line. 09:30 09:45 0.25 0 0 COMPZ RPCOM OTHR T Pump out BOP stack after testing. 09:45 10:00 0.25 0 0 COMPZ RPCOM SFTY T Pre job safety meeting on MU BHA# 13(Push fish to top of sand @'203'. 10:00 11:00 1.00 0 26 COMPZ RPCOM PULD T MU BHA#13:4-1/2"BTC casing cut 5'long,x-o, (1)4-3/4"DC,x-o,6-1/4" bumper sub,x-o,6-1/4"DC,x-o, (1) 3-1/2" 10'pup w/HT38 connection. Total length 92.73'. BHA wt 35k. 11:00 11:45 0.75 26 60 COMPZ RPCOM FISH T Make a top drive connection. RIH and tag collar of SSSV @ 26'w/ 4-1/2"casing joint 5'long. Using bumper sub, push down hole w/BHA #13.Worked SSSV to 60'.This leaves the 3-1/2"stub on top of SSSV @ 57' RKB. PU wt 35k, SO wt 35k. 11:45 12:00 0.25 60 0 COMPZ RPCOM TRIP T POOH w/ BHA#13. Pump out BOPE stack. 12:00 13:00 1.00 0 0 COMPZ RPCOM PULD T Lay down BHA#13. 13:00 14:00 1.00 0 49 COMPZ RPCOM PULD T MU BHA#14:4-1/2"BTC casing cut 5'long,x-o, (1)4-3/4"DC,4-3/4"Oil Jar,x-o to 49.87'. 14:00 14:30 0.50 49 68 COMPZ RPCOM PULD T Pick up/make up 3-1/2"HT38 drill pipe and try to continue to push SSSV to the top of sand @'203'. Pushing f/60'to 69.5'the top of the SSSV(top of 3-1/2"stub @ 66.4'). Ran out of weight to push with. Page 9 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:30 14:45 0.25 70 70 COMPZ RPCOM TRIP T POOH w/BHA#14 f/69.5'(top of 3-1/2"stub @ 66.4'). PU wt 30K. SO wt 30K. Rotated 8 rpm w/500 ft lbs of torque getting over top of stub. 14:45 16:00 1.25 0 0 COMPZ RPCOM PULD T Lay down BHA#14. Clear and clean rig floor. 16:00 18:00 2.00 0 0 COMPZ RPCOM NUND T Monitor annulus for 30 min. (Static) Remove riser and turnbuckles, N/D BOP stack and stand back, Remove tbg spool, remove working valves. 18:00 22:00 4.00 0 0 COMPZ RPCOM OTHR T PJSM with PESI and install well head Hydra-tight tools and allow 7" casing to grow under control, SIMPOS, Change out wash pipe on Top Drive. (7"Casing growth up to midnite=20-3/8") 38/12/2013 Attempt to engage SSSV Fish. ND BOP Stack. Found"balled"Control Line. NU BOP Stack. Shell test. MU BHA#14 and work SSSV Fish down to 69.5-ft. ND BOP Stack. Prep to control 7"Csg growth with Hydra Tight tool. RIH and engage 7"casing with spear. Observed a total of approximately 5'of casing growth in the 7"casing. Casing grew on its own, 36", and then we were able to pull 20"more,total of 56". 00:00 02:30 2.50 0 0 COMPZ RPCOM OTHR T Continue to control the 7"Casing growth using hydra-tight tools from 20-3/8"to a final growth of 35 3/4". Starting cycle pressure= 13,000 psi which equates to—296,000 lbs upwards force. Max cycle pressure observed=16,000 psi/-345,600 lbs upwards force. Ending cycle pressure= 1,600 psi/'-34,560 lbs. Total number of cycles= 125. Release Hydra-tight tool and rig down same. 02:30 03:30 1.00 0 0 COMPZ RPCOM NUND T Cut-off 7"Mandrel Hanger and lay down same. 03:30 06:00 2.50 0 0 COMPZ RPCOM NUND T Make-up BHA#15, 5 3/4"ITCO Spear assembly. Engage the Spear in the 7"Casing. Pull to 180K to stretch Casing. Clean and prep Casing Head. Set Slips. Release Spear and lay down same. Prep to cut/dress 7"Casing with the Wachs Cutter. Observed a total of approximately 5'of casing growth in the 7"casing. Casing grew on its own,36",and then we were able to pull 20"more,total of 56". 06:00 08:00 2.00 0 0 COMPZ RPCOM NUND T Remove remaining seized up Wellhead bolts. FMC Serviceman rig up Wachs Cutter. Cut and dress off the 7"Casing. 08:00 10:00 2.00 0 0 COMPZ RPCOM NUND T Install new 7"Pack-off. RILDS. Nipple up tubing Spool. 10:00 11:00 1.00 0 0 COMPZ RPCOM PRTS T Test 7"Pack-Off at 3,000 psi x 30 minutes. Good test. Co Man witnessed test. Rig down test equipment. Page 10 of 67 Time Logs • • Date Fr"om To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:00 15:30 4.50 0 0 COMPZ RPCOM NUND T Nipple up BOPE Stack. Install a second valve on the Inner Annulus. Install new air boot. Install Riser. 15:30 17:30 2.00 0 0 COMPZ RPCOM BOPE T Install Test Plug. Shell Tewt BOP at 250/3,500 psi. Good test. Chart same. 17:30 19:00 1.50 0 61 COMPZ RPCOM FISH T Make-up BHA#16, Center Prong Rope Spear. Run in and tag top of fish at 61-ft. Set down 5K. Rotate slowly. Pick-up and POOH. No recovery. Lay down same. 19:00 20:00 1.00 0 63 COMPZ RPCOM FISH T Make-up BHA#17,6 1/8"Dress Shoe. Run in and slide over the SSSV fishing neck with no problem. Fishing neck is clean. POOH and lay down same. 20:00 23:00 3.00 0 62 COMPZ RPCOM FISH T Make-up BHA#18, S150 Overshot w/3.500"Grapple. Run in and tag the top of the SSSV Fish at 62.0-ft. Plant Grapple with 5K down weight. Pick-up 5K over weight. Set down 10K. Pull up hole. Fish is free. Pull BHA and SSSV Fish to surface. Recovered the upper section of the parted SSSV with an estimated of 100-ft of Control Line wound around the fishing neck and body. Note: see pictures in the"S"Drive Folder. Lay down the recovered Fish and BHA. Clean and Clean Floor. Discuss plan forward with Anchorage Engineer. 23:00 00:00 1.00 0 197 COMPZ RPCOM FISH T MAke-up BHA#19. 6"Fishing Magnet. Run in to the Top Of Sand at 197-ft. Set down 5K. 38/13/2013 Control 7"Csg growth with the Hydratight Tool. Cut off and dress the 7"Csg. Install Pack-off. Install Tubing Spool.Test Pack-Off. NU BOP Stack and shell test same. Make-up and RIH with Overshot. POOH and recovered the upper section of the SSSV Fish. RIH with a 6"Magnet and recovered the remaining Spear Grapple piece. Perform Weekly BOPE Test. Made several runs with a Reverse Circulating Junk Basket to clean Control Line pieces, SS Band pieces, and two pieces of the remaining Spear Grapple on top of the Sand. 00:00 00:30 0.50 197 0 COMPZ RPCOM FISH T POOH. Lay down Magnet BHA and recovered piece of the Spear grapple. also recovered metal filings and slivers. 00:30 01:30 1.00 0 0 COMPZ RPCOM FISH T Flush BOP Stack. Install Wear Bushing. 01:30 02:30 1.00 0 105 COMPZ RPCOM FISH T Make-up BHA#20, 5 3/4"x 6" Reverse Circulating Junk Basket. RIH. BHA sat down at 104.5-ft. Attempted several times to pass through with no success. POOH. Lay down BHA. Pull Wear Bushing. Page 11 of 57 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:30 03:00 0.50 0 0 COMPZ RPCOM PRTS T Perform a 1,000 psi x 10 minutes pressure test against the IBPs. The IA inter valve was closed. The IA outer valve was open. Blind Rams were shut. Good test. Recorded on chart. 03:00 10:30 7.50 0 0 COMPZ RPCOM BOPE T Set Test Plug. Rig up test equipment. Make-up Test Joint. Perform Weekly BOPE test at 250/3,500 psi x 5 minutes per CPAI/AOGCC requirements. Record test on chart. The State's right to witness the test was waived by J. Turkington,AOGCC Field Inspector. 10:30 14:00 3.50 0 0 COMPZ RPCOM BOPE T The HCR Valved failed the pressure test. Wait on new HCR Valve from NAD Shop in Deadhorse. Install new HCR Valve. 14:00 15:30 1.50 0 0 COMPZ RPCOM BOPE T Test new HCR Valve at 250/3,500 psi. Good test. Record on chart. Blow down lines. Rig down test equipment. Pull Test Plug. Install Wear Bushing. 15:30 18:00 2.50 0 202 COMPZ RPCOM FISH T PJSM. Make-up BHA#21,5 3/4"x 6"Reverse Circulating Junk Basket. Set down once again at 104-ft. However was able to work through this time. Continue down to 196.5-ft. Drop Ball. Bring Pump on line at 550 gpm/1,550 psi. Wash/rotate into sand down to 207-ft. 18:00 18:30 0.50 202 0 COMPZ RPCOM FISH T Trip out. Break-out Reverse Circulating Junk Basket. Recovered mangled pieces of Control Line and a few small pieces of SS Control Line Bands. 18:30 19:30 1.00 0 215 COMPZ RPCOM FISH T Make-up BHA#22 same as before. Run back in to the top of Sand, now at 202-ft. Bring Pumps on line at 550 gpm/1,555 psi. Wash/rotate through sand and work Junk Basket down to 213.-ft. 19:30 20:30 1.00 215 0 COMPZ RPCOM FISH T Trip out. Break-out Reverse Circulating Junk Basket. Once again recovered mangled pieces of Control Line and a few small pieces of SS Control Line Bands. 20:30 22:30 2.00 0 223 COMPZ RPCOM FISH T Make-up BHA#23 same as before. Run back in to the top of Sand, now at 215-ft. Bring Pumps on line at 550 gpm/1,505 psi. Wash/rotate through sand and work Junk Basket down to 223.-ft. Observed overpull (10K)with Junk beside the BHA. Worked free. Page 12 of 57 Time Logs II, Date From! To Dur ! S. Depth E.Death Phase Code Subcode T Comment 22:30 00:00 1.50 223 0 COMPZ RPCOM FISH T Trip out. Break-out Reverse Circulating Junk Basket. Continue to recovered mangled pieces of Control Line and a few small pieces of SS Control Line Bands. Also recovered two more pieces of the lost Spear Grapple. 08/14/2013 Make up and rerun Cutlip Guide shoe with reverse basket assembly to recover CL pieces and SS band junk. Make runs until hole cleaned up. No junk in baskets. RIH to wash off sand top above IBP. Make up and run IBP retrieving tool,to retrieve and pull both IBP's at 253',and at 271'DPM.We found the lower IBP 6'deeper than expected set depth. Fluid losses at 25 BPH initially. Run 5"Bullnose with limber assembly on drill pipe to verify fish top, and no fish at 282', continue to 310'. POOH. Make up 5 3/4" RCJB with 6"head to TIH and tag up at 290', repeat attempts to pass through, no go. Fluid losses slowed to 12-14 BPH. Make up 5" Bullnose run and trip in hole to find tubing fish top at 1816'DPM. Circulate bottoms up, spot 30 BBLS NEC fluid loss pill. Monitor well at 9.0 bbl/hr loss. POOH. Make-up 2 5/16"ITCO Spear.Trip in to the top of the Fish. Gently plant Spear. Pull Fish free at 135 K. Pulling Fish off bottom at 110K-105K. 00:00 01:30 1.50 0 228 COMPZ RPCOM FISH T Make-up BHA#24 w/cutlip shoe and washover boot basket. RIH to 224'. BHA sat down on sand at 228'with pump online at 502 gpm/200 psi. Wash/rotate at 10 RPM. POOH, LID BHA and recovered 4 pieces of control line. 01:30 02:00 0.50 0 0 COMPZ RPCOM FISH T Clean and clear rig floor. 02:00 02:30 0.50 0 0 COMPZ RPCOM RGRP T Change out gripper dies on Top Drive. 02:30 04:00 1.50 0 235 COMPZ RPCOM FISH T Make-up BHA#25 w/reverse circulation junk basket but no jars. RIH to 230'. Circulate and wash down to 235'at 350 gpm, 1500 psi at 10 RPM. POOH and recover rest of the spear grapple and small piece of tubing. 04:00 05:30 1.50 235 253 COMPZ RPCOM FISH T Make up BHA#26,w/Cutlip shoe and washover boot basket.TIH to wash sand and tag up on IBP element. Pumps at 502 GPM's-220 PSI. UP WT-32K, SO WT-32K, 10 RPM's. POOH recover minimal SS bands and CL pieces. 05:30 07:30 2.00 250 250 COMPZ RPCOM FISH T Make up BHA#27,Cut lip scoop guide and IBP retrieving head.TIH to above the IBP, obtain SPR's. RIH to engage IBP at 253'. Release IBP, and allow element to relax. Monitor well-static. POOH, lay down recovered 3 3/8" IBP. Page 13 of 67 Time Logs • Date From To. ! Dur S. Depth E.Death Phase Code Subcode T Comment 07:30 09:30 2.00 265 265 COMPZ RPCOM FISH T Make up BHA#28, Cut lip scoop guide and IBP retrieving head-rerun. TIH to above the IBP,obtain SPR's. RIH to engage IBP at 265'. Close annular,slowly tag the IBP,and set down 5K. Pick up to 5K over release IBP,and allow element to relax. Monitor well-static. Observed no gas or fluid loss. Open Annular. Monitor well-static. POOH, observed no IBP in retrieving tool. 09:30 11:00 1.50 271 271 COMPZ RPCOM FISH T Run back in hole with BHA#28, Cut lip scoop guide and IBP retrieving head-rerun. RIH to engage IBP at 271'.This is 6'below where wireline set the IBP.Close annular,slowly tag the IBP,and set down 5K. Pick up to 5K over release IBP,and allow element to relax, and equalize pressures. Monitor well, no pressure, no flow. Observed no gas.Open Annular, observing fluid fell in the well. Fill hole with 4 BBLS. Monitor well-fluid dropping in wellbore. Roll trip tank to verify fluid losses at 25 BBLS/HR. Note,did not go down as bottom of IBP at 282',top of fish?. POOH. Lay down 2 1/2"IBP. 11:00 11:30 0.50 271 0 COMPZ RPCOM FISH T Clean&clear rig floor send tools out, pull tools to rig floor. 11:30 12:00 0.50 0 0 COMPZ RPCOM SVRG T Discuss options with town engineer. 12:00 13:00 1.00 0 0 COMPZ RPCOM FISH T Service rig,top drive&draw works. Observed fluid losses at 12-14 BPH 13:00 14:30 1.50 0 310 COMPZ RPCOM FISH T Make up 5"OD Bullnose&crossover on 4" Dril pipe.Total length-3.66'. RIH to 310',verify fish top not hung up at 282'. No tag on anything. Decision to POOH, make up 6"OD head. POOH, lay down Bullnose assembly.Observed fluid losses at 12-14 BPH 14:30 15:30 1.00 0 290 COMPZ RPCOM FISH T Make up 5 3/4"RCJB with 6"OD head and crossover on Drill pipe.TIH to tag up at 290'.Total length=7.85'. Set down all the weight(8K) attempting to pass through, no go. Repeat 2 times.decision to POOH. Observed fluid losses at 12-14 BPH 15:30 18:15 2.75 0 1,816 COMPZ RPCOM TRIP T Make up 5"OD Bullnose&crossover on 4"Dril pipe.Total length-3.66'. Pick up singles form pipe shed& RIH to 1816' DPM', once again verify fish top not hung up at 282'. Observed fluid losses at 10-12 BPH. Repeat tag with 5K set down weight. Page 14 of 67 Time Logs 4 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:15 19:30 1.25 1,816 1,816 COMPZ RPCOM CIRC T Circulate bottoms up at 4 BPM-150 PSI. Pump and spot a 30 BBL HEC fluid loss pill in the 7"x 10 3/4" Annulus. Monitor well on slight vacuum. Calculated FL=9.0 bbl/hr. 19:30 20:30 1.00 1,816 0 COMPZ RPCOM TRIP T POOH(Up weight=60K. Down weight=58K). stand back drill pipe. Breakout and lay down Bullnose assembly. 20:30 21:00 0.50 0 13 COMPZ RPCOM PULD T Make-up BHA#32, ITCO Spear Assembly w/2.766"nom catch sse y range 2.718"-2.814"). 21:00 23:00 2.00 13 1,816 COMPZ RPCOM TRIP T Slowly trip in with Spear Assembly to top of SSSV Fish. 23:00 00:00 1.00 1,823 1,823 COMPZ RPCOM FISH T Spear Assembly at top of SSSV Fish. Kelly up and bring pump on line at 1.0 bpm/680 psi. Wash down to top of Fish at 1,816-ft dpmd. Up weight=60K. Down weight=55K. Make several attempts to enter Fish with Spear. Got in on the fourth attempt. Buried the Spear to the Stop Sub at 1,823-ft. Pulled the Fish free at 135K. Pull Fish off bottom at 105-110K. X8/15/2013 POOH with the lower section of the SSSV Fish. Lay down same. Rig up equipment to handle 3 1/2"Tubing. Single down the remaining 3 1/2"Completion under the SSSV to the cut-off joint from 8.002-ft. (Note:the Cut-off Jt was 13.14 OAL and was split...see pictures in the"S"Drive). MIRU HES E-Line. RIH to 7,950-ft elmd. Log back to surface and record a Caliper and Gyro log in the 7"Casing. Fluid loss remains at 8.5- 9.0 bbls/hr. 00:00 03:00 3.00 8,002 1,823 COMPZ RPCOM FISH T Pull the lower section of the SSSV Fish from 1,823-ft to below the rig floor slowly, in order to keep the overpull to a maximum of 10-15 klbs. 03:00 04:00 1.00 1,823 1,823 COMPZ RPCOM TRIP T Drain the stack, pull fish to rig floor and release spear from fish. Clean and clear rig floor. 04:00 05:30 1.50 1,823 1,823 COMPZ RPCOM RURD T Clear Baker fishing assemblies from rig floor and Rig Up GBR equipment for laying down 3 1/2"Completion Tubing. 05:30 09:45 4.25 6,186 -2,277 COMPZ RPCOM PULD P PJSM. Single down 3 1/2",9.2 lb/ft, J-55, IBCT Completion Tubing from below the SSSV Fish from 6,186-ft md. 09:45 10:00 0.25 2,277 2,277 COMPZ RPCOM SFTY P Stop for and un-announced BOP Drill. CRT=96 seconds. Crew did a good job staying calm and knowing where the required equipment was located. Discussed the required ConocoPhillips requirement for a hard shut-in. 10:00 10:30 0.50 2,277 1,736 COMPZ RPCOM PULD P Continue to single down the 3 1/2" Completion Tubing from 2,277-ft md. Stop to service rig 10:30 11:00 0.50 1,736 1,736 COMPZ RPCOM SVRG P Service Drawworks and Rotary Table. Page 15 of 57 Time Logs • 1 Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 11:00 12:00 1.00 1,736 1,736 COMPZ RPCOM RGRP T Discovered a hydraulic leak in the return hose for the Power Tongs. Replace hydraulic hose and test same. Good. 12:00 16:00 4.00 1,736 0 COMPZ RPCOM PULD P Complete single down the 3 1/2" Completion. from 1,736-ft. Recovered 200 Joints, 1 GLM, and a 13.14-ft Cut-off Joint. 16:00 17:30 1.50 0 0 COMPZ RPCOM PULD P Rig down GBP equipment. Clear and clean Floor. Prep for E-Line logging operations. 17:30 19:00 1.50 0 0 COMPZ RPCOM ELNE P Wait for E-Line equipment to arrive on Location. 19:00 19:30 0.50 0 0 COMPZ EVALWE SFTY P PJSM with Rig Crew HES, Gyro Data, and Co Man. 19:30 21:00 1.50 0 0 COMPZ EVALWE RURD P Spot and Rig up E-Line Unit. Make-up Caliper Memory and Gyro tool string. 21:00 00:00 3.00 0 0 COMPZ EVALWE ELOG P Run in with the Caliper Memory and Gyro tool string. Had no trouble passing tool string through the suspected subsidence area. Continue down to 7,950-ft. Park Tool String and wait for the Caliper Arms to open. 38/16/2013 Record a Caliper Memory and Gyro log from 7,950-ft elmd back to surface. Lay down tool string. Pick-up and run in with Cast-M Tool to 7,950-ft elmd. Record a Cement Bond log back to surface. Pick the top of Cement at 2,135-ft. Run in with a 240 gr String shot. Straddle the 7"Casing collar at 2,092-ft. Fire String Shot. Pull out of the hole. Rig down HES E-Line Unit. Pick-up a Baker 7"Model"G"RBP. Run in hole on 3 1/2"Drill Pipe.Depth at Midnight 4,369-ft. 00:00 00:45 0.75 0 0 COMPZ EVALWE ELOG P Continue to park Tool String at 7,950-ft while waiting for the Caliper Arms to open up. 00:45 05:00 4.25 0 0 COMPZ EVALWE ELOG P Record Caliper Memory and Gyro Logs from 7,950-ft back to surface. 05:00 07:00 2.00 0 0 COMPZ EVALWE ELOG P Lay down the Caliper and Gyro logging tools. Pick-up HES Cast-M tool to record a Cement Bond Log. HES Crew change-out at 06:00 hrs. 07:00 12:00 5.00 0 0 COMPZ EVALWE ELOG P Run in hole with E-line for cement bond log to 7950'MD. Record log from 7950'elmd back to surface. 12:00 13:30 1.50 0 0 COMPZ EVALWE ELOG P Complete cement bond log. 13:30 14:00 0.50 0 0 COMPZ EVALWE RURD P Lay down Cement Bond Logging tool per Halliburton. 14:00 15:30 1.50 0 0 COMPZ RPCOM RURD P Make up and pick up 240 grain string shot assembly. SIMOPS-Consult with town engineering to agree on locations of top of cement(2135' MD), location of collar to target with string shot(2092'MD)and locations of Retrievable bridge plugs(7905'MD &2640'MD). Page 16(4'67 Time Logs Date From! To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:00 2.50 0 0 COMPZ RPCOM ELNE P Run in hole with String Shot to collar at 2092'. Fire string shot at 2092' after postively locating collar. Pull out of hole with E-Line. 18:00 18:30 0.50 0 0 COMPZ RPCOM RURD P Rig down E-Line equipment. 18:30 19:00 0.50 0 0 COMPZ RPCOM PULD P Pick Up BHA-Make Up RBP"G" model(Retrievable Bridge Plug)and running tool. 19:00 20:00 1.00 0 1,813 COMPZ RPCOM TRIP P Trip in hole to 1813' MD with stands from the Derrick. 20:00 00:00 4.00 1,813 4,369 COMPZ RPCOM PULD P Begin to single in 3 1/2"Drill Pipe from the Pipe Shed to 4,369-ft dpmd. Up Weight=90K. Down weight= 65K. 08/17/2013 Cont RIH w/Model G RBP,set at 7905'MD.Test to 3500 PSI-15 minutes on a chart. POOH, PU Model B RBP, RIH w/RBP,set at 2640'MD.Test same to 3500 PSI-15 Minutes on a chart. POOH Make up mule shoe on 3 1/2"DP,TIH to locate and spot 25 sacks of 20-40 mesh sand(50')on top of upper RBP.Trip out of hole. Nipple Down BOP. 00:00 04:00 4.00 4,369 7,905 COMPZ RPCOM TRIP P Cont to single in 3 1/2"Drill Pipe from the Pipe Shed from 4,369-ft dpmd to 7940-ft DPM. PU: 175k SO: 90k. 04:00 04:30 0.50 7,905 7,901 COMPZ RPCOM PACK P Locate Retreivable Bridge Plug and set at 7905'(Center of element)and fish neck at 7901'. 04:30 05:00 0.50 7,901 7,901 COMPZ RPCOM PRTS P Rig up for and pressure test Model G RBP to 3500 psi for 15 minutes on chart. Good test. 05:00 09:00 4.00 7,901 0 COMPZ RPCOM TRIP P Trip out of hole from 7901'DPM to surface and rack back stands to derrick. 09:00 09:30 0.50 0 0 COMPZ RPCOM PULD P Inspect&L/D Model G RBP running tool. P/U Model B RBP plug#2 and running tool as per Baker Rep and M/U same. 09:30 11:30 2.00 0 2,642 COMPZ RPCOM TRIP P RIH with RBP plug#2 with 3 1/2" Drill Pipe from Derrick to 2642'DPM. PU:40k SO:40k.Well control drill while RIH, CRT=63 sec. Good drill 11:30 12:00 0.50 2,642 2,640 COMPZ RPCOM PACK P Locate, drop 1 7/16"ball. allow to fall &seat&hydraulically set Model B RBP plug#2. Pins sheared at 3160 psi. Center of element @ 2640' DPM. Bottom of element @ 2642'DPM. Top of element @ 2637.7 DPM. Fish neck at 2638'DPM. Crew Change 12:00 12:45 0.75 2,640 2,640 COMPZ RPCOM PRTS P Rig up for and pressure test Model B RBP to 3500 psi for 15 minutes on chart. Good test. 12:45 14:15 1.50 2,640 0 COMPZ RPCOM TRIP P POOH, inspect and lay down running tool.Clean&clear rig floor. Send tools out. 14:15 15:30 1.25 0 2,583 COMPZ RPCOM TRIP P Make up Crossover and mule shoe on drill pipe, and TIH to 2583'DPM. (54')above RBP. Page 17 of 57 Time Logs 1 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:30 17:00 1.50 2,583 2,583 COMPZ RPCOM PACK P Rig up table on drill pipe in slips. Dump 25 sacks of 20-40 grit sand in drill pipe.Allow to fall on top of RBP. POOH, racking back 3 stands DP. Allow sand to fall. 17:00 18:30 1.50 2,583 2,583 COMPZ RPCOM CIRC P Displace well with 115 deg 8.5 PPG seawater as planned. Pumps at 4 BPM- 200 PSI. Observed 91 Deg returns. 18:30 19:00 0.50 2,583 2,583 COMPZ RPCOM TRIP P Trip in hole with DP slowly to tag top of sand at 2594' DPM,with 3-4K set down weight. Repeat tag to verify top. Pull 1 stand. 19:00 19:30 0.50 2,583 2,583 COMPZ RPCOM OWFF P Perform negative flow test-30 minutes. No flow. 19:30 20:30 1.00 2,583 0 COMPZ RPCOM TRIP P POOH, racking back dril pipe. Breakout&lay down Mule shoe& crossover. 20:30 20:45 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew, BOT rep,and FMC rep. Discuss safety&hazard recognition issues for Nipple Down BOP, Pull packoff and Nipple Up BOP. 20:45 00:00 3.25 0 0 COMPZ RPCOM NUND P Nipple down BOP. 38/18/2013 Remove tubing head, pull 7"packoff, Nipple up BOP, Make up MS Cutter&TIH to locate collars and cut 7" casing at 2065'DPM.Attempt to circulate out arctic pack, but observed inner annulus fluid coming through emergency slips. POOH inspect cutter and lay down same. Make up 7"casing spear with packoff. RIH to engage 7"stub. Engage spear and pick up to observe 7"casing free at 100K. Held PJSM, ND BOP stack, and pull emergency slips. NU BOP Stack. Pull 7"Casing to the Rig Floor. Close Annular on the 7". Hold PJSM. Circulate Hot Diesel and Hot Sea Water to clean out Arctic Pack from the 10 3/4"x 7"Annulus. 00:00 01:30 1.50 0 0 COMPZ RPCOM NUND P Removing tubing head, pulling packoff. 01:30 08:00 6.50 0 0 COMPZ RPCOM NUND P Nipple up DSA and Adaptor Spool. Nipple Up BOP Stack. Torque Stack bolts. Cut riser for adjustment and install same. 08:00 08:30 0.50 0 0 COMPZ RPCOM RURD P Install cement lines to open top tank. Fill lines, and pressure test same to 500 PSI. 08:30 09:00 0.50 0 0 COMPZ RPCOM PULD P Make up BHA#33,5 1/2"Multi-string cutter as per BOT rep. Secure the 2 1/4"knives in tool. 09:00 11:30 2.50 0 2,100 COMPZ RPCOM TRIP P Trip in hole with MS Cutter slowly to prevent catching collar and breaking knives to 2100'. 11:30 12:00 0.50 2,100 2,065 COMPZ RPCOM CPBO P With pumps at 3 BPM,open knives and locate upper and loser collars at 2059',and 2099'DPM. RIH to locate knives at 2065' DPM.We decided to cut higher than mid joint tp prevent cutting in a centalizer and stop ring. Crew Change. Page 18 of 57 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 12:30 0.50 2,065 2,065 COMPZ RPCOM SFTY P Held PJSM with new crew,and BOT rep. Discuss safety&hazard recognition issues. Discuss procedure to make cut and take returns to open top tank. 12:30 13:00 0.50 2,065 2,065 COMPZ RPCOM CPBO P Rotate drill string at 80 RPM's 1500 ft lbs of torque. Bring pumps up slowly to engage knives and continue to 4.5 BPM-750 PSI with max torque observed at 2200 Ft lbs. Pipe cut at 6 minutes,verified with fluid dropping in the annulus, and pressure drop on tool to 350 PSI. Observed returns to OA and to open top tank,arctic pack.Work drill string to locate cut and verify 3"gap, and pressure drop once again indicating good cut.Tool would not pass through the cut and took 3K set down weight. 13:00 15:15 2.25 2,065 2,065 COMPZ RPCOM CIRC P Break out top drive and install head pin and hose. Close annular.With Little Red services pump down drill string with heated diesel at 2 BPM, observing good arctic pack returns initiallly to open top tank. Observed fluid cleaned up to indicate seawater form 3 1/2"x 7"annulus returns through the emergency slips. Shut down Little Red after 30 BLS pumped.Allow fluid to u-tube until dead. Pump down DP,&displace diesel with seawater, 30 BBLS. 15:15 16:15 1.00 2,065 0 COMPZ RPCOM TRIP P POOH, Inspect, breakout and lay down Multistring cutter. Drain BOP stack. 16:15 17:00 0.75 0 0 COMPZ RPCOM FISH P Make up 7"casing spear with 6.220" Nominal catch grapple. RIH to engage 7"casing stump. Pick up to 100K, observed pipe free. 17:00 17:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew and FMC rep. Discuss safety&hazard recognition issues. Discuss procedure to ND BOP stack,and pull emergency slips. 17:15 18:30 1.25 0 0 COMPZ RPCOM NUND P Nipple down BOP stack, raise high enough to pull emergency slips as per FMC rep. 18:30 19:00 0.50 0 0 COMPZ RPCOM NUND P Remove emergency slips per FMC rep. 19:00 20:00 1.00 0 0 COMPZ RPCOM NUND P Nipple up BOP stack, install turn buckles, make up flange on BOP. 20:00 20:45 0.75 0 0 COMPZ RPCOM RURD P Rig up Little Red to circ out arctic pack with diesel followed by seawater. 20:45 21:15 0.50 0 0 COMPZ RPCOM SFTY P PJSM for circulate out Arctic pack with all rig and 3rd party personnel. Page 19 of 67 Time Logs Date From To Dur S. Depth E.!Depth Phase Code Subcode T Comment 21:15 23:15 2.00 0 0 COMPZ RPCOM CIRC P Circulate 145 bbls heated diesel followed by 55 bbls heated seawater. 23:15 00:00 0.75 0 0 COMPZ RPCOM WASH P Soak arctic pack with heated diesel. 08/19/2013 Circulate out arctic pack with second diesel and seawater circulation. Lay down 7"casing. PU and RIH scraper assembly, no-go at 297'MD. LD Scraper assembly. PU 8 3/4"tandem milling BHA and RIH to 158' MD. 00:00 00:15 0.25 0 0 COMPZ RPCOM WASH P Soak arctic pack with heated diesel. 00:15 02:00 1.75 0 0 COMPZ RPCOM CIRC P Pump " " followed 40 by 145 bbls Deep bbls heated Clean diesel and 55 bbls heated seawater. 02:00 03:00 1.00 0 0 COMPZ RPCOM WASH P Soak arctic pack with heated diesel. 03:00 05:00 2.00 0 0 COMPZ RPCOM CIRC P Pump 40 bbls'0'Deep Clean" Pill followed by 18 bbls heated seawater. 05:00 06:00 1.00 0 0 COMPZ RPCOM RURD P Rig Down Little Red, blow down lines. SIMOPS circulate well. 06:00 06:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew&GBR casing rep. Discus safety&hazard recognition issues. Discuss procedure to rig up, pull&lay down 7"Casing. 06:15 07:00 0.75 0 0 COMPZ RPCOM RURD P Rig up GBR power tongs,and slips. 07:00 12:00 5.00 0 0 COMPZ RPCOM PULL P ay n M7"casing 2065'nd MD lato down D.50kupwtfrom. 12:00 14:00 2.00 0 0 COMPZ RPCOM PULL P Pull and lay down 7"casing from 868' MD to surface. 14:00 15:00 1.00 0 0 COMPZ RPCOM RURD P Rig down GBR power tongs and slips. 15:00 15:30 0.50 0 0 COMPZ RPCOM SVRG P Service Rig-drawworks,top drive. 15:30 18:30 3.00 0 297 COMPZ RPCOM PULD P PU Scraper BHA and RIH. No go at 297'MD. 18:30 20:30 2.00 297 0 COMPZ RPCOM PULD P LDI Scraper BHA from 297 to surface. Clean and clear rig floor. 20:30 23:00 2.50 0 0 COMPZ RPCOM PULD P PU " per w waiting/MU on 8-3/4 FMC scra 9.90"wear BHA ring hile to be machined and delivered. 23:00 23:30 0.50 0 0 COMPZ RPCOM RURD P Wear ring delivered. Install Wear ring bushing. 23:30 00:00 0.50 0 158 COMPZ RPCOM PULD P RIH and continue PU of scraper BHA to 158'. 08/20/2013 RIH with 8 3/4"Milling BHA to 295'MD. Mill to 298'. Observed mills pass through with little set down weight, continue TIH with no issues to tag 7"casing stump at 2065'DPM. Circulate sweep,and unload the hole with remining arctic pack and cement. POOH, lay down mills. RU and perform weekly BOP test.Witness of test waived by AOGCC rep Chuck Scheve. RU to run casing for Dummy Run. 00:00 00:30 0.50 158 295 COMPZ RPCOM PULD P PU/MU and RIH with 8 3/4"tandem milling assembly.Tag up at 294'. Page 20 of 57 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:30 05:30 5.00 294 298 COMPZ RPCOM MILL P Mill with tandem 8 3/4'mills from 296'MD to 300'. Mill with initial torque at 9K,and work mills to smooth out at 3-4K. UP WT-43K, SO WT-43K, ROT WT-45K. Rotate drill string 60 RPM's wit 1K free torque. Pumps at 6 BPM-100 PSI.WOB- 1-3K.With pumps off slack off through bad spot with 3-5K set down weight. Continue work mills through area to clean up with both mills. 05:30 07:30 2.00 298 2,062 COMPZ RPCOM TRIP P Continue in hole working string down with stands of DP to observe 8 5/16" Magnet tag up and push through with 5K, continue TIH with no issues to 2062'. 07:30 09:15 1.75 2,062 2,065 COMPZ RPCOM CIRC P UP WT 71K, SO WT-65K. Break circulation with pumps at 8 BPM- 300 PSI.Wash down to top of casing stub at 2065,set down 4K to verify. Continue pump 25 BBLS Hi-Visc sweep at 8 BPM observing hole unloaded with remaining arctic pack and cement.The sweep cleaned up the hole. Monitor well-static. 09:15 10:30 1.25 2,065 160 COMPZ RPCOM TRIP P TOH with 8 3/4"Tandem mill assembly. 10:30 10:45 0.25 160 0 COMPZ RPCOM SFTY P Well Control Drill 10:45 12:00 1.25 0 0 COMPZ RPCOM PULD P LD Milling BHA, monitor well static. Magnet cleaned(2 pieces of centralizers and 32 pounds of metal) 12:00 13:30 1.50 0 0 COMPZ RPCOM PULD P Lay down scraper assembly and BHA#35 13:30 14:00 0.50 0 0 COMPZ RPCOM PULD P MU/PU Stack Washer tool and XOs. 14:00 15:00 1.00 0 26 COMPZ RPCOM CIRC P Circ and Cond,flush stack at 12 bbl/min and 55 psi. 15:00 15:30 0.50 0 0 COMPZ RPCOM TRIP P LD stack washer BHA and XOs. 15:30 16:00 0.50 0 0 COMPZ RPCOM RURD P Remove 9-7/8"ID wear ring. 16:00 16:30 0.50 0 26 COMPZ RPCOM RURD P PU test tools, RU chart recorder, PU 3-V2' test joint.,make up dart. RIH with XOs and 3-'/2'test plug. Page 21 of 57 Time Logs 11,' Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:30 19:00 2.50 26 26 COMPZ RPCOM BOPE P Set test plug, perform weekly BOPE test with 250/3,000 psi low/high pressure. Tested Kill line,stand pipe, Manual and HCR Choke and Kill, manifold valves 1-11, 14-16'to 250/3,000 psi with chart recorder. Upper VBR,Annular, HT-36 floor valves andf IBOP,Air IBOP and lower Kelly valve, Super choke and orifice bean choke to 250/3,000 psi, holding for 5 minutes-all tests-good Note: Chuck Sheve of AOGCC waived witness of test, @ 07:30 hrs, 8/20/13. 19:00 19:30 0.50 26 26 COMPZ RPCOM BOPE P Performed Kommey unit drawdown test.After closing=1,700 psi. Initial drawdown pressure=200 psi in 17 secs. Had full 3000 pressure recovery after 96 seconds. Five Koomey bottles at 2,150 average psi. Tested electric pump at 22 sec to build up to system pressure and repeated using rig air in 250 sec. Closing times Annular= 17 sec, UVBR, SIM LPR, and Blind Rams= 6 sec. HCR, Choke and Kill-1 seconds-all good tests. 19:30 21:30 2.00 26 26 COMPZ RPCOM BOPE P Pull 3W test joint and plug, run and set 7"test plug.Test LPR,Annular, Blind rams, choke manifold valves, inner and outer test spool valves, 4-W Full opening safety valve to 250/3,000 psi hign and low holdinh 5 mins,-all good tests. 21:30 23:00 1.50 26 0 COMPZ RPCOM RURD P Lay down test tool and rig down test equip. Blow down lines and clear and clean rig Hoot. 23:00 23:30 0.50 0 0 COMPZ RPCOM OTHR P Install 9-7/8"wear ring. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Held PJSM with crew&GBR reps. Rig up GBR Casing equip to 7" casing for dummy test run. 38/21/2013 PU Dummy Run BHA. Run to tight spot at 136'MD. LD Dummy Run BHA. PU 9-1/2"x 9-5/8"milling assembly BHA. Mill tight spot at 136'MD, mill tight spot at 296'MD.After milling complete with bullnose to 536'MD,TIH,tag 7"casing stub. 00:00 00:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM, PU BHA for Dummy Run with Crew, GBR rep, BH rep. 00:15 02:00 1.75 0 136 COMPZ RPCOM PULD P PU BHA. MU BHA to include triple connect,7"tubing pup, HES cementer,7"tubing pup, 1 full joint of 7"casing. Up weight=35k, Down weight=35k,tag at 136',set down 5k. Page 22 of 57 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 02:00 03:00 1.00 136 136 COMPZ RPCOM PULD P Try and work through tight spot @ 136',turned string,tried multiple times,to include rotating while setting down.All attempt with no success. 03:00 04:00 1.00 136 0 COMPZ RPCOM PULD P Lay down BHA for dummy run. Clean and clear rig floor. 04:00 04:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew&BOT rep. PU BHA for 9-1/2"and 9-5/8"milling assembly run. 04:15 06:00 1.75 0 109 COMPZ RPCOM PULD P PU BHA for 9-1/2"and 9-5/8"milling assembly run. 06:00 12:00 6.00 109 254 COMPZ RPCOM MILL P Tag at 109'. Mill form 109'MD to 254' MD(Bull nose depth),WOB=1-3k, RPM=80, PSI =200, GPM=425, TQ(on)= 1-3.5k,TQ(off)=800 ft-lb, UWT=36k, DWT=36k, Rot=40 k. 12:00 12:30 0.50 254 71 COMPZ RPCOM TRIP P UD top of BHA from 254'MD to 71' MD. 12:30 14:30 2.00 71 307 COMPZ RPCOM PULD P P/U and M/U top of 9-5/8"milling BHA from 71'MD to 307'MD. 14:30 18:00 3.50 307 322 COMPZ RPCOM MILL P Ream tight spot in 10-3/4"casing from 307'MD to 322'MD(bull nose depths). RPM=80, PSI =230, BPM = 10,TQ(on)= 1.8k-4.0k,TQ(off)= 950, UWT=47k, DWT=47k, Rot= 47 k. 18:00 18:30 0.50 322 134 COMPZ RPCOM PULD P UD BHA from 322'MD to 134'MD. Clean BHA magnet,39 lbs milled cuttings recovered. 18:30 19:00 0.50 134 261 COMPZ RPCOM PULD P P/U BHA from 134'MD to 261'MD. 19:00 21:00 2.00 261 536 COMPZ RPCOM MILL P Ream tight spot in 10-3/4"casing from 261'MD to 536' MD(bull nose depths). RPM=80, PSI=230, BPM = 10,TQ(on)= 1.8k-4.0k,TQ(off)= 950, UWT=48k, DWT=50k, Rot= 50 k. 21:00 21:30 0.50 536 536 COMPZ RPCOM CIRC P Pump 15 bbl Hi Vis sweep. Circ Bottoms up at 8 bpm, 205 psi. 21:30 22:00 0.50 536 134 COMPZ RPCOM TRIP P POOH and L/D BHA from 536'MD to 134'MD. Clean BHA magnet, 15 lbs milled cuttings recovered. 22:00 22:30 0.50 134 536 COMPZ RPCOM TRIP P P/U BHA and RIH from 134'MD to 536'MD. 22:30 22:45 0.25 536 536 COMPZ RPCOM SFTY P Kick while tripping drill. Crew Response Time 120 seconds,After Action Review held,good crew response time. 22:45 00:00 1.25 536 2,064 COMPZ RPCOM TRIP P TIH from 536'MD to 2065'MD. UWT =73k, DWT=65k.Tag 7"casing stub,set down 3k, Pick Up to 2064' MD. 08/22/2013 Circulate Hi Vis Sweep, POOH and LD milling BHA. PU Dummy Run BHA and RIH. POOH Dummy Run BHA and LD. PU BH Back off tool BHA(w/bullnose)and RIH.Attempt to work BO assembly into 7"csg stub- unsuccessful. POOH and replace bullnose with tapered mill. RIH to top of 7"stub and attempt to enter it. Page 23 of 57 Time Logs S • Date From To Dur S.Death E. Death Phase Code Subcode T Comment 00:00 01:00 1.00 2,064 2,064 COMPZ RPCOM CIRC P Circulate Hi Vis Sweep at 425 gpm, 500 psi. 01:00 02:30 1.50 2,064 305 COMPZ RPCOM TRIP P Trip out of hole from 2064'MD to 305' MD. 02:30 04:00 1.50 305 295 COMPZ RPCOM MILL P Milled with lower 9.5"mill at 305'MD -295'MD. Ensure tight spot cleaned up. 04:00 06:30 2.50 311 0 COMPZ RPCOM TRIP P Continue POOH breakout&LD Milling BHA 06:30 07:30 1.00 0 0 COMPZ RPCOM PULD P Clean&clear rig floor area. Send tools out. Held PJSM with crew and GBR rep. Discuss safety&hazard recognition issues. Discuss procedure to make up and run 7" Dummy Drift assembly. 07:30 08:30 1.00 0 66 COMPZ RPCOM PULD P Make up 7" Dummy drift run with Triple connection sub, and ES cementer. 08:30 09:30 1.00 66 2,065 COMPZ RPCOM TRIP P Trip in hole with assembly. Observed Cut lip guide stopped at 100', rotate pipe 1/4 turn, continue in hole with no issues. Continue TIH to 2065'with no set down,or tight spot issues. Tag top of 7"stump lightly at 2065', verify depth. 09:30 11:00 1.50 2,065 2,065 COMPZ RPCOM CIRC P Circulate bottoms up, and pump a Hi Visc sweep with pumps at 355 GPM's-330 PSI. Monitor well- static. No fluid losses. 11:00 12:00 1.00 2,065 433 COMPZ RPCOM TRIP P Trip out of hole from 2065'-433'. Observed proper displacement. Crew Change 12:00 12:45 0.75 433 66 COMPZ RPCOM TRIP P Continue POOH from 433'-surface. 12:45 13:15 0.50 66 66 COMPZ RPCOM PULD P Rig up GBR power tongs. 13:15 13:45 0.50 66 0 COMPZ RPCOM PULD P Breakout&lay down 7" Dummy Drift assembly. 13:45 14:45 1.00 0 0 COMPZ RPCOM RURD P Rig down GBR power tongs. Clear rig floor area. Rig up to run Back-Off tool assembly. 14:45 15:00 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew and BOT reps. Discuss safety&hazard recognition issues. Discuss procedure to make up and run BOT back off tool BHA. 15:00 16:30 1.50 0 677 COMPZ RPCOM PULD P Make up BHA#39-7"back off tool assemnbly with pump out sub. Pick up 4 3/4"Drill collars from shed. Total length-676.98'. 16:30 18:00 1.50 677 2,065 COMPZ RPCOM TRIP P Trip in hole with BHA. Fill each stand with fresh water as per BOT rep. PU =68K, SO=63K, ROT=65K, RPM= 10-20,TQon/TQ/off= 1.1/1.5K. 18:00 19:00 1.00 2,065 2,065 COMPZ RPCOM BKOF P Attempt to slide and rotate through 7"casing stub top. Rotate mule shoe at 1/4 turns and repeat-no go. 19:00 20:30 1.50 2,065 677 COMPZ RPCOM TRIP P POOH from 2,065'-677' Page 24 of 57 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment - 20:30 21:00 0.50 677 0 COMPZ RPCOM PULD P Standback and LD BO assemply on pipe skate. LD mule shoe. 21:00 22:00 1.00 0 679 COMPZ RPCOM PULD P PU/MU 6-1/8"tapered mill assembly 22:00 00:00 2.00 679 2,065 COMPZ RPCOM TRIP P RIH to 2,065', PU=68K,SO=63K, ROT=65K. Rotate 10 rpm with 1.5- 2.2K ft-lb. -no-go.Attempt to slide into 7"casing stub slacking off 10- 12KK on each attempts. 08/23/2013 POOH without successfully backing off. RIH with BHA to centralize taper mill.enter once then can't get back in. POOH. RIH with Magnet BHA. Circulate hole volume, POOH. 00:00 02:00 2.00 2,065 2,065 COMPZ RPCOM BKOF P Continue to attempt to slide and rotate into top of 7"casing stub to clean out-no-go. PU=70K, SO= 63K ROT=65K, RPM 10-20, TQon/TQoff= 1.1 K/1.5K ft-lb 02:00 02:15 0.25 2,065 2,065 COMPZ RPCOM OTHR P Discussion with BH, Co Man, Drilling Engineer to set plan forward once we decided we could not backoff and would not be able to get into cut 7" joint. 02:15 03:00 0.75 2,065 679 COMPZ RPCOM TRIP P Trip out of hole to of BHA. 03:00 06:00 3.00 679 0 COMPZ RPCOM PULD P POOH and inspect BHA#40 for wear markings and prep for next attempt. Clear and clean rig floor. 06:00 06:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for PU Tapered Mill centralized by 9.5"Mill"BHA. 06:15 09:00 2.75 0 706 COMPZ RPCOM TRIP P P/U"Tapered Mill centralized by 9.5" Mill" BHA with 10'x 3-%2'DP stinger behind tapered mill. PU =50K. 09:00 10:00 1.00 706 2,065 COMPZ RPCOM TRIP P RIH to top of 7"casing stub. 10:00 12:00 2.00 2,065 2,065 COMPZ RPCOM MILL P Rotate at 20 rpm and successfully wash 15'into top of 7"casing stub. GPM=251, PSI=200 until no-go on XO. Pump Hi-Vis sweep. Pull out of 7"stub and attempt to RIH into 7" casing stub without pumping. Continue to reenter with multiple attempts both with and without pumping and rotating-could not re-enter 7"casing stub. Discussed options with Anchorage office. 12:00 13:00 1.00 2,065 706 COMPZ RPCOM TRIP P POOH to to of BHA at 706'md. 13:00 14:00 1.00 706 0 COMPZ RPCOM PULD P Stand back 4-3/4"DC and HWDP 14:00 15:30 1.50 0 0 COMPZ RPCOM PULD P Clean off string magnet recovering 21 lb of metal filings and small pieces of casing. LD taper mill,XOs,stinger pup,double pin sub and watermelon mill. 15:30 17:30 2.00 0 0 COMPZ RPCOM SLPC P Cut and slip 82'of 1-1/4"drill line. Discuss plan forward with Anchorage office. 17:30 18:30 1.00 0 0 COMPZ RPCOM SVRG T Inspect drawworks and brakes. Grease washpipe and blocks. Page 25 of 57 Time Logs •, Date From To. Dur ! S.Death E.Depth Phase Code Subcode T Comment 18:30 21:00 2.50 0 680 COMPZ RPCOM PULD T Calibrate block height. PU Fishing Magnet BHA. RIH to 680'with no tight spots or drag. PU=48K, SO= 48K 21:00 22:00 1.00 680 2,005 COMPZ RPCOM TRIP T TIH with 3-Y2"DP to 2,005' 22:00 22:30 0.50 2,005 2,064 COMPZ RPCOM CIRC T Circulate at 6 bbl/min,240 psi. PU= 70K, SO=64K, ROT=65K at 10 rpm, 1.2K ft-lb TQon/off. RIH and tag stump with 5K of SO weight at 2,065'.Tagged 3x while circulating and rotating at 10 rpm.Tag with 10K SO w/o circulation or rotating. Circ full hole volume at 6 bbl/min. Slow Pump at 2,064'and for both MP1 and MP2 @ 2 BPM=50 psi,3 BPM= 80 psi 22:30 23:30 1.00 2,064 680 COMPZ RPCOM TRIP T Hold fire drill with crew while monitoring well-static. Blow down Top Drive and POOH from 2,064'to HWDP @ 680'. PU=48K, SO=48K 23:30 00:00 0.50 680 380 COMPZ RPCOM TRIP T Monitor well-static. Stand back HWDP and DCs to 380'. 38/24/2013 RIH with magnet BHA#2.Work tubing stub area. POOH. RIH with slick assembly. Pump hot water in hole, displace well to clear fluid, RU wireline for camera run 00:00 01:30 1.50 380 0 COMPZ RPCOM PULD T Stand back collars and laydown BHA, Clean magnet, recover 3 small pieces of metal and 9 pounds of shavings. 01:30 02:00 0.50 0 0 COMPZ RPCOM SVRG T Service drawworks, changed out broken grease line. 02:00 03:00 1.00 0 680 COMPZ RPCOM TRIP T RIH with Magnet BHA. 03:00 03:30 0.50 680 2,065 COMPZ RPCOM TRIP T RIH to 2,065'. PU=70K, S0=65K 03:30 04:30 1.00 2,065 2,065 COMPZ RPCOM WASH T Wash stump with magnet rotating at 10 rpm. PU=70K, SO=65K, ROT= 67K,262 GPM, 260 psi. 04:30 05:00 0.50 2,065 680 COMPZ RPCOM TRIP T POOH to 680', PU=70K 05:00 06:00 1.00 680 0 COMPZ RPCOM PULD T Clean metal shavings from magnets. Recovered 9-3/4"x 4-1/4"piece of 10 3/4"casing. Picture on S drive 06:00 06:30 0.50 0 680 COMPZ RPCOM TRIP T Review plan forward, MU BHA and RIH 06:30 07:00 0.50 680 2,065 COMPZ RPCOM TRIP T RIH with flat head magnet to casing stub at 2,065'. PU=70K,SO=65K 07:00 07:30 0.50 2,065 2,065 COMPZ RPCOM WASH T Wash and work casing stub with magnet. PU=70K, SO=65K, ROT= 67K,262 GPM,260 psi 07:30 08:30 1.00 2,065 680 COMPZ RPCOM TRIP T POOH to BHA at 680'. PU=70K 08:30 10:00 1.50 680 0 COMPZ RPCOM PULD T LD Magnet BHA. Recovered only iron shavings, no large pieces. 10:00 11:30 1.50 0 694 COMPZ RPCOM PULD T PU/MU 6-1/8"Tapered Mill BHA with 3x Boot baskets and string magnet 11:30 12:00 0.50 694 1,641 COMPZ RPCOM TRIP T RIH to 1,641'md,crew change Page 26 of 57 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 1,641 2,019 COMPZ RPCOM TRIP T Continue RIH to 2,019'. PU=70K, SO=65K 12:30 14:00 1.50 2,019 2,065 COMPZ RPCOM MILL T RIH,tag 7"casing stub at 2,065'. Work tapered mill at stub,varry WOB 5-15K, RPM 10-60 and pump rates 0-4 bbl/min. PU=70K, SO= 65K, ROT=65K with 1.2K ft-lb of free rotating TQ. Unable to enter the 7" casing stub at 2,065' 14:00 15:30 1.50 2,065 2,015 COMPZ RPCOM CIRC T Circulate and reciprocate 2,064'- 2,015'while discuss plan forward with Anchorage office. 10 BPM at 670 psi and 40 RPM,with 1.2K ft-lb TQ. SPR @ 14:20 hrs,2,063'-MP1 &MP2-2 BPM=60 psi, 3 BPM= 80 psi. 15:30 16:00 0.50 2,015 2,015 COMPZ RPCOM OWFF T Flow check, stand back HWDP 16:00 17:30 1.50. 2,015 0 COMPZ RPCOM TRIP T POOH, LD Tapered Mill BHA. No recovery of junk in Boot baskets or from magnets. 17:30 19:00 1.50 0 2,065 COMPZ RPCOM TRIP T PU/MU BOT triple connect sub with MM shoe and RIH on DP.Tag up on 7"casing stub at 2,065', PU=60K, SO=55K 19:00 21:30 2.50 2,065 2,065 COMPZ RPCOM CIRC T Circulate and clean pits for filtered water displacement. RU to pump hot water 21:30 22:30 1.00 2,065 2,065 COMPZ RPCOM CIRC T Flush cement line and Standpipe with hot water. Displace well with 141 F deg hot water at 2,065'at 5 BPM and 176 psi. 22:30 23:30 1.00 2,065 2,065 COMPZ RPCOM WASH T Let pipe and Arctic Pak soak with hot water. Flush and blow down Trip tank lines 23:30 00:00 0.50 2,065 2,065 COMPZ RPCOM CIRC T Pump 40 bbl Hi-Vis sweep with 1/2 bbl of Deep Clean at 5 bbl/min and 160 psi. 08/25/2013 Run EV Camera to top of 7"stub. LD camera, POOH circulate clean water at 350'. POOH, run camera in inspect 10-3/4"casing. POOH and LD camera. PU tapered mill assembly, RIH and clean out top of 7" stub, POOH. MU 8-%2'x 7-W Dress-off BHA. 00:00 01:30 1.50 2,065 2,065 COMPZ RPCOM CIRC T Continue circulating hot water, dispacing well with 8.5 filtered fresh water,directly from truck,at 5 BPM and 200 psi. NTU's-1.77. 01:30 05:00 3.50 2,065 2,065 COMPZ RPCOM ELNE T LD single and PU HT38 DP pup to spaceout above top of 7"stub.Set in slips. Rig up HES wireline surface equip. Hange sheaves, install crossovers and pump out sub with packoff. MU and PU video camera. RIH and inspect top of casing stub. POOH and inspect camera. Note: camera covered with Arctic-Pak. Page 27 of 57 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T !Comment 05:00 05:30 0.50 2,065 2,065 COMPZ RPCOM CIRC T Clean off camera while circulating at 6 BPM and 250 psi. PU=S0=ROT =60K.Tag up on 7"stump while circulating. 05:30 09:00 3.50 2,065 2,065 COMPZ RPCOM ELNE T RU E-line and RIH with video camera to 2,063'. Continue pumping clear water at 2 BPM,70 psi while using camera. Camera view clear with good pictures. POOH with camera and RD E-line. 09:00 09:30 0.50 2,065 680 COMPZ RPCOM TRIP T POOH with BHA to DCs at 680' 09:30 10:00 0.50 680 680 COMPZ RPCOM CIRC T Circ at 680'to clean hole for camera run over the 10-3/4"casing milled areas.6 BPM at 90 psi. PU=45K 10:00 11:00 1.00 680 32 COMPZ RPCOM TRIP T POOH. PU single from shed and set in rotary table. 11:00 12:00 1.00 32 32 COMPZ RPCOM ELNE T RU E-line equipment and video camera 12:00 13:30 1.50 32 32 COMPZ RPCOM ELNE T RIH with E-line video camera to 350'. Make camera runs over milled trouble areas at 296', 136'and 96' observing casing and cement conditions. POOH with E-Line. Note:camera would rotate by inself through the buckled/milled areas following the well path. 13:30 14:00 0.50 32 32 COMPZ RPCOM PULD T RD E-Line 14:00 14:30 0.50 32 0 COMPZ RPCOM PULD T LD single joint of DP and Metal Muncher shoe assembly 14:30 16:00 1.50 0 67 COMPZ RPCOM PULD T PU 6-1/8"x String mill BHA 16:00 17:00 1.00 67 710 COMPZ RPCOM TRIP T RIH with HWDP aand DCs, PU= SO=50K 17:00 18:00 1.00 710 2,036 COMPZ RPCOM TRIP T RIH with 3-Y2'DP tp 2,036' 18:00 19:00 1.00 2,036 2,085 COMPZ RPCOM MILL T RIH slowly and tag up on top of fish at 2,065'and with 5K lb. Mill and ream top of 7"casing stub,working taper and string mill through top of 7" stub and down to 2,085'and without rotating. Continue working mills from 2,065'to 2,085 rotating at 12-85 RPM, 1.5K ft-lb of TQ. PU=72K, ROT=70K, SO=65K 19:00 19:30 0.50 2,085 2,085 COMPZ RPCOM CIRC T Circulate at 12 BPM, 1,250 psi. Circ 5x bottoms up recovering Arctic-Pak. SPR at 19:15 hrs and 2,085'-MP1 = MP2-2 BPM-60 psi, 3 BPM-100 psi 19:30 20:00 0.50 2,085 710 COMPZ RPCOM TRIP T Blow down Top Drive, Flow check- okay, POOH 2,085'to 710' 20:00 22:30 2.50 710 0 COMPZ RPCOM PULD T Stand back HWDP and DCs, lay down Taper mill BHA. Clean magnets and recovered 5 lb of metal shavings. Page 2$of 57 Time Logs .' • Date From To Dui. S. Death E.Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 COMPZ RPCOM PULD T PU/MU 8-%"x 7-%"Dress-off washover milling assembly as per Baker Rep. 08/26/2013 Dressoff 7"casing. CBU. POOH. Run cleanout assembly to 2,098', work up/down inside 7"casing 2x, pump 32 bbl sweep 00:00 01:00 1.00 0 507 COMPZ RPCOM PULD T Change out crews and continue PU/MU Dressoff BHA as per Baker rep. PU=45K 01:00 01:30 0.50 140 2,064 COMPZ RPCOM TRIP T TIH with Dressoff assembly. PU= 65K, SO=67K, 01:30 05:00 3.50 2,064 2,065 COMPZ RPCOM MILL T Dress off top of 7"casing stub. ROT=67K. Rotate and pump at 6 BPM,200 psi at 10-60 RPM, Free rotating TQ= 1.4K ft-lb.Wash down and tag up on 7"stump at 2,064.4'. Washover top of casing with 8-V2' OD x 7-W ID washover pipe.TQ while washing down 3,500-4,200 ft-lb, with no decrease after washing over the top.Washover and swallow 3'of 7"casing and engaged with the inner mill.Torque increased to 5,400-6,800 ft-lb range. Milled 8"inside of the 7" casing stub. PU and pulled out of casing stub without any excess drag. Re-entered 7"casing stub and tagged up on milled down stub at 2,065.27'. Pump 35 bbl Hi-Vis sweep around and only recovered Arctic-Pak. 05:00 06:00 1.00 2,065 507 COMPZ RPCOM TRIP T POOH to BHA at 507' 06:00 08:00 2.00 507 0 COMPZ RPCOM PULD T LD Dress-off BHA. Stand back HWDP and lay down DCs. Clean off magnets and recover 40 lb of metal. Discuss plan forward with Anchorage office. 08:00 08:30 0.50 0 80 COMPZ RPCOM PULD T PU Dress-off BHA and PU DCs. 08:30 09:00 0.50 80 0 COMPZ RPCOM PULD T Lay down DCs 09:00 10:00 1.00 0 570 COMPZ RPCOM PULD T Continue PU Dress-off BHA 10:00 10:30 0.50 570 2,064 COMPZ RPCOM TRIP T RIH to 2,064'. PU=65K, S0=67K 10:30 12:00 1.50 2,064 2,065 COMPZ RPCOM MILL T Rotate and pump at 6 BPM, 200 PSI,80 RPM. Free rotating TQ= 1.4K ft-lb.Wash down and tag top of 7"casing stub at 2.065.27'wash and dress casing stub. 12:00 14:00 2.00 2,065 2,067 COMPZ RPCOM MILL T Continue to mill over and wash down on 7"csg stub from 2,065-2,067'. WOM=8K, pump at 8 BPM and 310/300 psi on/off bottom 80 RPM, 5K/3K ft-lb on/off, PU=70K, SO= 65K, ROT=67K(torque spikes from 3-9K ft-lb at 2,067') Page 29 of 57 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:00 14:30 0.50 2,067 2,067 COMPZ RPCOM CIRC T Circ 25 bbl Hi-Vis sweep at 10 BPM, 480 psi,with 30 RPM and 1.7K ft-lb. SPR-MP1:2 BPM=50 psi, 3 BPM =80 psi, MP2:2 BPM=40 psi, 3 BPM=70 psi. 14:30 15:30 1.00 2,067 507 COMPZ RPCOM TRIP T Flow check-ok, blow down TD, POOH to 507'. PU=48K, SO=48K. 15:30 18:00 2.50 507 0 COMPZ RPCOM PULD T Stand back HWDP and DCs,clean 35 lb of metal from string magnet, breakout Dress-off shoe and inside dress mill. Recovered 5'length of milled 7"casing and several smaller pieces of casing. 18:00 18:30 0.50 0 0 COMPZ RPCOM SVRG T Service TD Review plan forward with Anchorage office. 18:30 19:00 0.50 0 0 COMPZ RPCOM PULD T Break out and LD inner mill and BOT Triple Conect sub. LD washover extension and Dress-off milling shoe, all showing very little wear. 19:00 20:00 1.00 2,119 560 COMPZ RPCOM TRIP T POOH to BHA. 20:00 21:30 1.50 0 0 COMPZ RPCOM PULD T MU cleanout mill assembly with 10'x 3-1/2"DP pup for cleaning out inside of 7"casing in prep for back-off. 21:30 22:30 1.00 0 539 COMPZ RPCOM TRIP T RIH with cleanout BHA 22:30 23:00 0.50 539 2,064 COMPZ RPCOM TRIP T RIH to 2,064'. PU=72K, S0=67K 23:00 00:00 1.00 2,064 2,093 COMPZ RPCOM MILL T Wash down at 6BPM, 300 psi.Tag up on top of 7"casing stub at 2,072'. Work mills up and down across top of stub. Slackoff without rotation at 6BPM, 300 psi, PU=72K,SO=67K, ROT=70K 00:00 00:30 0.50 2,093 2,093 COMPZ RPCOM CIRC T Circulate 32 bbl Hi-Vis sweep at 2,093'at 12 BPM and 1,029 psi. 00:30 02:00 1.50 0 0 COMPZ RPCOM PULD T MU cleanout mill assembly with 10'x 3-1/2" DP pup for cleaning out inside of 7"casing in prep for back-off. 08/27/2013 Cleanout 7"casing to 2,119'. POOH,Weekly test of BOPE.Witness of test by AOGCC rep John Crisp. 00:00 01:00 1.00 2,093 540 COMPZ RPCOM TRIP T POOH with 7"cleanout BHA. 01:00 02:30 1.50 0 0 COMPZ RPCOM PULD T Clean string magnet, recovered 40 lb of metal filings. Add 1 joint of drill pipe into BHA. 02:30 03:30 1.00 0 560 COMPZ RPCOM TRIP T Trip into hole with BHA for deeper 7" casing cleaning. PU=45K. 03:30 04:00 0.50 560 2,071 COMPZ RPCOM WASH T RIH and tag up on top of stub 2,071'. PU=71K, S0=65K. Wash down inside 7"casing to 2119.28' Page 30 of 57 Time Logs • Date From To Dur S. Depth E.!Depth Phase Code Subcode T Comment 04:00 05:00 1.00 2,071 2,119 COMPZ RPCOM CIRC T Wash down inside 7"casing to 2,098'pumping at 6 BPM and 300 psi, rotating at 40 RPM with 1.8K ft-lb of TQ. PU=70K, SO=65K, ROT=67K. Tag up on possible junk with 5K set down weight. PU 3'and circulate to ensure any junk was circulated past mills and BHA. Continue washing in hole smoothly to stinger TD at 2,119.28'. 05:00 08:00 3.00 2,119 2,119 COMPZ RPCOM CIRC T Circ. 30 bbl Hi-Vis sweep at 11.5 BPM,483 BPM and 920 psi. Pumped heated water circulating out Arctic-Pak. Displaced well back to brine. Flow check-static. 08:00 08:30 0.50 2,119 560 COMPZ RPCOM TRIP T POOH to BHA. 08:30 08:45 0.25 560 0 COMPZ RPCOM PULD T Handle cleanout BHA and clean string magnet recover 26 lb of metal filings. 08:45 09:00 0.25 0 0 COMPZ RPCOM SFTY T Held Kick while tripping drill.Time to secure well=52 sec.TIW valve was torqued up as soon as it was installed. 09:00 11:00 2.00 0 0 COMPZ RPCOM PULD T Lay down cleanout BHA. Clean and clear rig floor. 11:00 12:00 1.00 0 0 COMPZ RPCOM PRTS P Prep to test BOPE. Pull wear ring 12:00 13:00 1.00 0 0 COMPZ RPCOM PRTS P Change out to 3-%"elevators. PU/MU stack washing tool and string magnet. Wash out BOP stack. Pumped 552 gpm w/82 psi. Recovered 8 pounds and 4 more pounds 13:00 18:00 5.00 0 0 COMPZ RPCOM PRTS P PU test plug and set.Would not hold pressure. Replaced rubber seal on test plug and retest. Still leaking. Pull and replace seal on test lug again. Reseat and held. Rig up pressure recorder. 18:00 20:30 2.50 27 27 COMPZ RPCOM BOPE P Perform weekly BOPE test with 3-W test jt to 250/3,000 psi low/high pressure, all tests held f/5 min. Tested Kill line,stand pipe, Manual and HCR Choke and Kill, manifold valves 1-11, 14-16'to 250/3,000 psi with chart recorder. Upper VBR, Annular, HT-38 floor valves andf IBOP,Air IBOP and lower Kelly valve, Super choke and orifice bean choke to 250/3,000 psi, holding for 5 minutes-all tests-good Note:John Crisp of AOGCC witnessed the test. Page 31 of 57 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 27 27 COMPZ RPCOM BOPE P Performed Kommey unit drawdown test.After closing= 1,700 psi. Initial drawdown pressure=200 psi in 17 secs. Had full 3000 pressure recovery after 96 seconds. Five Koomey bottles at 2,000 average psi. Tested electric pump at 22 sec to build up to system pressure and repeated using rig air in 250 sec. Closing times Annular= 17 sec, UVBR, SIM LPR,and Blind Rams= 6 sec. HCR, Choke and Kill-1 seconds-all good tests. 21:00 23:00 2.00 27 27 COMPZ RPCOM BOPE P Pull 3-%"joint run 7"test jt. Test BOPs to 250/3,000 psi low/high pressure. Tested Lower Pipe rams, Annular,and Blind rams holding for 5 minutes-all tests-good. Pull 7" test jt. Tested gas detection system -H2S sensor in pits was changed out due to high level alarm not sounding. LEL sensor on rig floor was recalibrated. 23:00 00:00 1.00 0 0 COMPZ RPCOM BOPE P LD 3-1/2"and 7"test joints. Install 9.875"ID Wear Ring. 38/28/2013 RIH, clean out to 2,362'MD, POOH, PU Back-off assembly, RIH and break 7"casing connection 2,099'md. POOH, lay down back-off tools, PU spear and grapple. 00:00 00:30 0.50 27 0 COMPZ RPCOM PULD P LD test joint, blow down Top Drive, choke manifold, Choke and Kill lines 00:30 01:00 0.50 0 0 COMPZ RPCOM SVRG P Service TD, change oil 01:00 01:30 0.50 0 0 COMPZ RPCOM PULD P LD 6.5"DCs 01:30 02:00 0.50 0 0 COMPZ RPCOM PULD P Bring tools for Clean-out BHA to rig floor 02:00 04:00 2.00 0 704 COMPZ RPCOM PULD P PU/MU Clean-out BHA, PU=45K 04:00 05:30 1.50 704 2,360 COMPZ RPCOM TRIP P RIH with BHA to 2,071'PU=70K, S0=65K. Run mills into top of casing stub. Continue to RIH. Stacked of 5K lb on junk at 2,351'. PU 3',turn pumps on at 6 BPM,400 psi and wash in hole. Push junk to 2,362', PU to 2,042',slide back into 7"casing stub to 2,360'-no problems.. 05:30 07:30 2.00 2,360 2,360 COMPZ RPCOM CIRC P Circulate 40 bbl Hi-Vis sweep. Heavy load of Arctic-Pak seen on the shakers. Pumped a second 40 bbl Hi-Vis sweep 07:30 08:00 0.50 2,360 704 COMPZ RPCOM TRIP P POOH to BHA. 08:00 10:00 2.00 704 0 COMPZ RPCOM PULD P Clean magnets. MU 10:00 11:30 1.50 0 680 COMPZ RPCOM PULD P Bring Back-off tools to the drillfloor. PU/MU Back-off BHA. PU=67K lb. 11:30 12:00 0.50 680 1,059 COMPZ RPCOM TRIP P RIH with BO BHA to 1,059'md. Crews changeout I Page 32 of 57 Time Logs Date From To Dur S. Depth E.'Depth Phase Code Subcode T Comment 12:00 13:30 1.50 1,059 2,289 COMPZ RPCOM TRIP P RIH. Enter 7"casing stub w/o problem. Continue RIH to 2,289'. PU=70K, SO=65K lb. 13:30 14:30 1.00 1,059 2,289 COMPZ RPCOM TRIP P PU 3-Y2'DP pup joint, position Back-off tool to break 7"casing connection at 2,099'. RU to pump on tool to activate. 14:30 16:30 2.00 2,289 2,289 COMPZ RPCOM FISH P Set lower Back-off tool anchor with 1,100 psi,set upper anchor with 3,500 psi. Cycle back to 3,300 psi 11 times with 1/4-3/4 turns each achieving 5-3/8 total left hand turns 16:30 17:30 1.00 2,289 2,289 COMPZ RPCOM TRIP P RD surface lines. Blow down surface system. LD 3-W DP pup.Attempt to pull BO tool free with 10K lb over string weight,then 15K over-no-go. Pull 35K lb over string weight with PU= 105K and pull free. Drop ball and rod for circulating sub 17:30 18:30 1.00 2,289 680 COMPZ RPCOM TRIP P Flow ck-ok. POOH to 2,100'. Pressure up an Pump Out circulating sub to 2,200 psi and open.Continue to POOH to BHA. PU=SO=48K lb. 18:30 20:30 2.00 680 0 COMPZ RPCOM PULD P Stand back HWDP and DCs. LD pump out Circ sub, anchors. Cover on power section of BO tool was backed off 5-%turns and the other connection on the power section was backed off 2 turns. Continue to drain and LD BHA. Load fishing tool BHA tools in pipe shed. 20:30 21:30 1.00 0 0 COMPZ RPCOM PULD P Load fishing tool BHA tools in pipe shed. 21:30 23:45 2.25 0 163 COMPZ RPCOM PULD P PU/MU Fishing spear BHA to 163'. PU=40K, SO=38K lb. 23:45 00:00 0.25 163 163 COMPZ RPCOM SFTY P Trip drill.TIW valve installed and closed in 35 sec,well secured after 45 sec, CRT= 185 sec. 38/29/2013 RIH with Spear assembly, stab into 7"casing stub,confirm engaged, PU to put string in tension, rotate left 16 turns, PU 3'. Circ hot water,soak, circ,550 bbl of hot water, POOH and LD 7"casing stub. MU flat btm magnet assemblies and RIH and clean. POOH, LD flat btm magnet, PU Reverse circ basket assembly, RIH to clean junk from top of 7"casing. 00:00 01:00 1.00 163 2,070 COMPZ RPCOM TRIP P Continue RIH to 2,070'with Spear and Grapple BHA. PU=70K, SO= 64K lb 01:00 01:30 0.50 2,081 2,080 COMPZ RPCOM FISH P Engage 7"casing stub with Bullnose at 2,081.35'and No-Go at 2,071.83'. PU 35K over string weight. Slack off and PU a second time to verify. Hold 23K tension and left hand rotate at 2-3 rpm with an average torque of 5,500 ft-lb. String tension dropped to 10K and torque dropped to 1,500- 1,800 ft-lb after 16 turns. 01:30 02:15 0.75 2,080 2,080 COMPZ RPCOM FISH P Pumped 30 bbl of 140 deg water and let it soak. Page 33 of 57 Time Logs • �`" Date From To Dur ! S.Depth E. Depth Phase Code Subcode T ':Comment 02:15 04:30 2.25 2,080 2,080 COMPZ RPCOM CIRC P Circulate 550 bbl of heated water taking returns to the cuttings tank, at 6 BPM,212 psi 04:30 06:00 1.50 2,080 500 COMPZ RPCOM CIRC P Blow down Top Drive, POOH with spear BHA to 500'. PU=73K lb 06:00 08:30 2.50 500 0 COMPZ RPCOM PULD P Continue POOH to 125'and pull tight. Pull free and continue to pull spear assembly to rig floor with 7" casing stub fish. Remove spear from fish. Recovered cut joint with 26.45' length and one bow-spring type centralizer with three half broken and missing blades. 08:30 11:00 2.50 0 2,081 COMPZ RPCOM TRIP P PU fishing mill with 2x boot basket BHA. RIH and tagged up on junk at 125'. Set down with 5K and PU with 20K lb overpull.Worked free and continue RIH. 11:00 11:30 0.50 2,081 0 COMPZ RPCOM TRIP P POOH with magnet BHA.Clean magnets and remove 7"piece of centralizer blade. 11:30 12:00 0.50 0 0 COMPZ RPCOM PULD P LD boot baskets,9-1/2"water melon mill 12:00 13:30 1.50 0 420 COMPZ RPCOM TRIP P RIH with magnet BHA to 112'and hit junk with 5K of excess drag. MU to Top Drive, rotate at 10 rpm, from 109' -144'.Torque increased to 3.5K ft lb at 128'from 0.9K ft-lb and them broke back to 0.9 ft-lb at 144'. Continue rotating to 420'. PU=SO= 40K ft-lb. 13:30 14:30 1.00 420 1,934 COMPZ RPCOM TRIP P Continue RIH on elevators to 1,934', PU=65K, SO=60K. 14:30 15:00 0.50 1,934 2,039 COMPZ RPCOM WASH P Wash down from 1,934'to 2,029'at 10 BPM and 490 psi 15:00 15:30 0.50 2,039 2,093 COMPZ RPCOM WASH P Continue to wash down from 2,029' to 2,069'at 3 BPM,80 psi,with 2K of drag at 2,069'increasing to 10K lb of drag at 2,091'. PU 5'to 2,086', wash and ream down 2,086'to 2,093' with 3 BPM,620 psi, 20 RPM and 1.3K ft-lb of TQ. 15:30 16:30 1.00 2,093 2,093 COMPZ RPCOM CIRC P Circ at 2,093'with 10 BPM and 630 psi. 16:30 18:00 1.50 2,093 2,093 COMPZ RPCOM CIRC P Circ and spot 35 bbl of 130 F deg water and let soak 18:00 19:00 1.00 2,093 2,093 COMPZ RPCOM CIRC P Circulate 35 bbl Hi-Vis sweep at 6 BPM, 320 psi. Chase with 190 bbl of 130 F deg water at 6 BPM, 375 psi. Flow ck-static 19:00 20:00 1.00 2,093 420 COMPZ RPCOM TRIP P PU and tag up on 7"casing coupling 2x with 2-3K lb of set down weight. POOH to BHA at 420'. PU=SO= 40K lb. Page 34 of 57 Time Logs ' Date From To Dur S. Death E.Depth Phase Code Subcode T %Comment 20:00 21:00 1.00 420 0 COMPZ RPCOM PULD P Monitor well. Stand back HWDP, clean magnets a LD water melon mill. Recovered 4-1/4"piece of stabilizer blade from flat bottom magnet. 21:00 23:00 2.00 0 414 COMPZ RPCOM PULD P PU/MU Reverse Circ BHA PU=40K 23:00 23:30 0.50 414 982 COMPZ RPCOM TRIP P RIH to 982'PU=45K 23:30 00:00 0.50 982 982 COMPZ RPCOM SVRG P Service Iron Ruffneck and Drawworks 08/30/2013 RIH, Reverse Circ Sub run#2, Circ, POOH w/no recovery, RU run w/bullnose and magnets, no-go in 7" casing, POOH, RU slickline and run WL magnet to 2,099'WLD, POOH with no recovery, RU and run WL Lead impression block, POOH with 3/8"cut on the edge. POOH. Consult with Anchorage, RD slickline, PU/MU 8.5"LIB, RIH to top of 7"csg. 00:00 00:30 0.50 982 2,092 COMPZ RPCOM TRIP P Continue RIH and tag up on junk at 2,092' 00:30 01:30 1.00 2,092 2,097 COMPZ RPCOM WASH P Wash and rotate over 7"casing top at 6 BPM and 20 RPM. Circ bottoms up and had granulated cement and Arctic-Pak over the shakers. 01:30 02:30 1.00 2,097 300 COMPZ RPCOM TRIP P Trip out of hole with Reverse Circ Sub 02:30 03:30 1.00 300 0 COMPZ RPCOM PULD P Unload several pieces of metal from Rev Circ Sub but none larger than 2" x 6". Clean string magnet 03:30 04:30 1.00 0 2,092 COMPZ RPCOM TRIP P RIH for second run with Rev Circ Sub BHA#58 04:30 05:30 1.00 2,092 2,098 COMPZ RPCOM WASH P Wash without rotating. Continue washing at 7 BPM and rotating at 10-20 rpm. RIH to 2097.58 and tagged 7"casing with 5K lb. 05:30 07:00 1.50 2,098 0 COMPZ RPCOM TRIP P Blow down the top drive. Pull out of the hole w/run#2(Reverse circ junk basket). No recovery.Total of 1.7# of iron on magnets-metal filings and small pieces of casing. 07:00 07:30 0.50 0 0 COMPZ RPCOM OTHR P Talk w/town engineer. Decision to try a run w/5"bullnose and 4-1/2" extreme magnet to see if we can enter 7"casing and pull any metal from the inside of threads. 07:30 08:00 0.50 0 0 COMPZ RPCOM PULD P Lay down BHA, mobilize new BHA (Baker BHA#59). 08:00 10:30 2.50 0 546 COMPZ RPCOM PULD P PU/MU Baker BHA#59 to 546'. PU wt 48k, SO wt 48k. 10:30 11:00 0.50 546 2,060 COMPZ RPCOM TRIP P Trip in the hole w/BHA#59(5"OD bullnose and string magnet)f/546'to 2060'. PU wt 73k, SO wt 65k. Page 35 of 57 lime Logs 411 • Date From To Dur ! S. Depth E.Depth Phase Code Subcode T Comment 11:00 12:00 1.00 2,060 2,098 COMPZ RPCOM OTHR P Screw into stand#17 @ 2060'. Establish parameters: PU wt73k, SO wt 65k, rot wt 68k. Rotate 10 rpm w/ 1400 ft lbs of torque,pumping 336 gpm w/500 psi. Attempt to enter 7"casing stub: Rotate 40 rpm w/1.5k ft Ibs, rotate down and tag w/5k weight @ 2097'. Rotate down then tag w/10k weight @ 2097'. Slack off pumping 12 bpm w/1020 psi, rotating 20 rpm w/3k ft lbs of torque @ 2097.52'. Increase rpm to 60 rpm,still no movement. 12:00 13:00 1.00 2,098 546 COMPZ RPCOM TRIP P POOH w/bullnose and string magnet assembly f/2097.5'. Lay down BHA. 13:00 14:30 1.50 546 0 COMPZ RPCOM PULD P Stand back HWDP and drill collars. Lay down BHA. Recovered a pound of metal filings from the string magnet. 14:30 17:00 2.50 0 0 COMPZ RPCOM RURD P Rig up Halliburton slick line. 17:00 17:30 0.50 0 0 COMPZ RPCOM SLKL P RIH w/HES toolstring w/3.625"OD magnet to tag @ 2099'WLM. POOH. No recovery w/magnet. HES toolstring: Rope socket,quick connect, 5'of 2.125"stem,quick connect, 1.875"OD knuckle joint, 5' of 2.125"OD stem,quick connect, Oil jars 1.875"OD,quick connect, 1.875"OD knuckle joint, Spang jars, quick connect--total length of 319"or 26'6". BHA: Quick connect, 3'of 1.875" stem,3.91"centralizer,3.6"OD magnet. 17:30 20:30 3.00 0 0 COMPZ RPCOM SLKL T RIH w/HES toolstring w/5.9"OD LIB to tag @ 2099'WLM. POOH. Results: One indent 5/8"long, 1/4" wide, 1/8"deep on outside face of LIB. HES toolstring: Rope socket,quick connect, 5'of 2.125"stem,quick connect, 1.875"OD knuckle joint, 5' of 2.125"OD stem,quick connect, Oil jars 1.875"OD,quick connect, 1.875"OD knuckle joint, Spang jars, quick connect--total length of 319"or 26'6". BHA: Quick Connect, 3'of 1.875" stem,5.90"OD magnet. 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD T Rig down HES slickline. 21:00 22:00 1.00 0 0 COMPZ RPCOM PULD T PU/MU all BOT tools for 8.5" impression block BHA.Weekly crew change for Nabors. 22:00 22:30 0.50 0 0 COMPZ RPCOM PULD T Unload 8.5"lead impression block from truck, bring to floor. 22:30 00:00 1.50 0 1,500 COMPZ RPCOM TRIP T RIH to 1,500'. PU=60, S0=59K lb. Page 36 of 57 Time Logs • Date From To Dui. S. Depth E.Depth Phase Code Subcode T Comment 08/31/2013 24 hr Summary Continue RIH to top of 7"csg/junk w/LIB-tag @ 2096.98', POOH, lay down BHA. Service rig, PU/MU BHA #61 (camera run), RIH,tag 2098.32', circ 2 sweeps,then filtered water-total filtered water pumped 284 bbls, RU HES e line, run EV downhole camera to'2099'. Rig down HES e line and EV downhole camera. POOH to 1992', L/D 6-1/4"DC's f/derrick. POOH f/1992'w/BHA#61. PU/MU/RIH w/BHA#62 to get inside of 7" @'2099'-no go, POOH, MU BHA#63. 00:00 00:30 0.50 1,500 2,097 COMPZ RPCOM TRIP T Continue to RIH from 1,500'.tag @ 2096.98'. Set down 20k. PU=60, SO=59K lb. 00:30 01:15 0.75 2,097 2 COMPZ RPCOM TRIP T POOH f/2097'. 01:15 01:30 0.25 2 0 COMPZ RPCOM PULD T Lay down Lead impression block. Inconclusive. 01:30 02:00 0.50 0 0 COMPZ RIGMNZ SVRG T Service rig,change oil in the top drive. 02:00 02:30 0.50 0 0 COMPZ RPCOM PULD T PU tools to the floor for camera run (BHA#61) 02:30 03:00 0.50 0 8 COMPZ RPCOM TRIP T MU BHA#61 03:00 04:30 1.50 8 2,098 COMPZ RPCOM TRIP T Trip in the hole with camera assembly f/8'to 2006'. PU wt 58k, SO wt 56k, Rot wt 58k. Rotate 15 rpm w/950 ft lbs of torque. Pump 6 bpm(252 gpm)w/185 psi.Wash down f/2006'to tag @ 2098.32'. Set down 2k wt. Pick up 10',then rotate down w/15 rpm and lightly tag w/ 1-2k wt. Shut down rotary. Pick up 6". 04:30 06:00 1.50 2,098 2,098 COMPZ RPCOM CIRC T Circulate to clean hole for a camera run: Pump 35 bbl high vis sweep, then pumping @ 13 bpm(546 gpm) w/675 psi,circ 2.5 BU's. Pump another 35 bbl sweep,follow by pumping 13 bpm(546 gpm)for 1.5 bottoms up. 06:00 07:00 1.00 2,098 2,098 COMPZ RPCOM CIRC T Pump filtered water from Peak vac truck: Pumping 6 bpm(252 gpm)w/ 250 psi. Clean water back to surface. Pumped a total of 284 bbls of filtered water. 07:00 07:15 0.25 2,098 2,098 COMPZ RPCOM SFTY T BOP Drill with after action review. Crew response time 59 seconds. 07:15 08:15 1.00 2,098 2,098 COMPZ RPCOM ELNE T Ready to rig up HES e line unit. Unit reheading line off site. 08:15 09:15 1.00 2,098 2,098 COMPZ RPCOM ELNE T Spot HES e line unit. Rig up ground equipment. 09:15 09:30 0.25 2,098 2,098 COMPZ RPCOM SFTY T Pre job safety meeting on rig up of HES equipment on rig. 09:30 10:00 0.50 2,095 2,095 COMPZ RPCOM RURD T Pick string up a total of 2.9'above the top of 7"collar/junk. Rig up toolstring and attach EV downhole camera. Page 37 of 57 Time Logs • Date From To Our S. Depth E.Depth Phase _Code Subcode T Comment , 10:00 11:30 1.50 2,095 2,095 COMPZ RPCOM ELNE T RIH w/EV downhole video camera to top of junk @'2099'.Work camera while pumping .5 to 2 bpm.View appears to have 2-3 pieces of casing inside of the 7"collar at the top, in the box. Download pictures to the "S"drive pictures folder. 11:30 12:00 0.50 2,095 2,095 COMPZ RPCOM OTHR T Develop plan w/town engineer. 12:00 13:30 1.50 2,095 2,095 COMPZ RPCOM RURD T Rig down HES e line and EV downhole camera. 13:30 13:45 0.25 2,095 2,095 COMPZ RPCOM SFTY T Pre job safety meeting on trip out. 13:45 14:15 0.50 2,095 1,992 COMPZ RPCOM TRIP T Trip out of the hole w/BHA#61 f/ 2095 to 1992'(one stand and 10' pup jt). 14:15 14:30 0.25 1,992 1,992 COMPZ RPCOM SFTY T Pre job safety meeting on rearrange pipe in the derrick. 14:30 15:30 1.00 1,992 1,992 COMPZ RPCOM PULD T Lay down(3)6-1/4"drill collars f/ derrick. 15:30 15:45 0.25 1,992 1,992 COMPZ RPCOM RURD T Change elevators. 15:45 16:45 1.00 1,992 8 COMPZ RPCOM TRIP T Trip out of the hole w/BHA#61 (camera run)from 1992'to 8'. 16:45 17:15 0.50 8 0 COMPZ RPCOM PULD T Lay down BHA#61. Shoe,triple connect sub&crossover 17:15 17:45 0.50 0 0 COMPZ RPCOM PULD T Pick up tools f/BHA#62 to the floor(taper mill&string mill&string magnet). 17:45 18:00 0.25 0 0 COMPZ RPCOM SFTY T Pre job safety meeting on PU/MU BHA#62. 18:00 19:30 1.50 0 715 COMPZ RPCOM PULD T PU/MU BHA#62(Taper mill/string mill/string magnet)PU=S0=48K lb 19:30 20:30 1.00 715 2,040 COMPZ RPCOM TRIP T RIH with 3-W DP to 2,040' 20:30 21:30 1.00 2,040 2,098 COMPZ RPCOM WASH T Wash down with 6 BPM,410 psi and tag up at 2,097.64'with 5K lb.set down weight.Work string up and down with out rotating with 15K lb set down. PU rotate string 3x,turn off rotary and continue to work string with 10-25K lb set down. Could not pass 2,097.64'. Consult with Anchorage. 21:30 22:00 0.50 2,098 2,090 COMPZ RPCOM CIRC T PU to 2,090'. Circ btms up at 10 BPM and 933 psi. SPR at 20:50 hrs and 2,090'md, MP#1 -2 BPM at 50 psi,3 BPM at 100 psi, MP#2-2 BPM at 50 psi, 3 BPM at 90 psi. 22:00 23:00 1.00 715 715 COMPZ RPCOM TRIP T POOH to BHA. PU=S0=48K lb. 23:00 00:00 1.00 715 0 COMPZ RPCOM PULD T Inspect mills, no new markings, LD BHA 09/01/2013 RIH with 6-1/8"centralized, Concave mill with no-go. Rotate into casing and clean top 18'. POOH LD no-go, RIH and clean casing to 2,471'. POOH LD mills, PU Mult-string casing cutter, RIH and cut 7"casing at 2,104.5', POOH. POOH, LD cutter. PU spear and grapple assembly w/round bullnose, RIH and was unable to engage 7"casing cut-off section. POOH to change rounded bullnose to a cut-off muleshoe. 00:00 01:15 1.25 0 533 COMPZ RPCOM PULD T PU/MU 6-1/16"Taper mill and string mill(BOT BHA#63). Page 38 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T (Comment 01:15 02:00 0.75 533 2,098 COMPZ RPCOM TRIP T RIH and tag up at 2,098.18' 02:00 03:00 1.00 2,098 2,098 COMPZ RPCOM MILL T Work mill string without rotating setting down with 25-30K Ib, hitting hard and making zero progress. Circ btms up,confer with town on plan forward. 03:00 04:00 1.00 2,098 533 COMPZ RPCOM TRIP T POOH to BHA. 04:00 05:00 1.00 533 0 COMPZ RPCOM PULD T LD taper mill BHA. No damage or scarring on the milling assembly 05:00 05:45 0.75 0 530 COMPZ RPCOM PULD T PU/MU 6-1/8"Concave mill assembly with 10'x 3-%"DP stinger centralized by a 9-W watermellon mill. 05:45 07:15 1.50 530 2,116 COMPZ RPCOM TRIP T Trip in hole with Concave mill and tag up on top of 7"casing at 2098',work to get into top,then push junk to 2115.99'. 07:15 08:00 0.75 2,116 158 COMPZ RPCOM TRIP T POOH w/BHA#64(6-1/8"concave mill)f/2116'to 158'. 08:00 09:15 1.25 158 0 COMPZ RPCOM PULD T Lay down BHA#64 f/158'. Lay down (3)6-1/4"drill collars,etc. Mill looked good. 09:15 09:45 0.50 0 0 COMPZ RPCOM PULD T Pick up tools f/BHA#65(6-1/8" concave mill, (2)boot baskets,string mill, (2)string magnets. 09:45 10:00 0.25 0 0 COMPZ RPCOM SFTY T Pre job safety meeting on PU/MU BHA#65. 10:00 11:00 1.00 0 337 COMPZ RPCOM PULD T PU/MU BHA#65 to 337'. 11:00 11:45 0.75 337 2,098 COMPZ RPCOM TRIP T Trip in the hole w/BHA#65 on 3-1/2"HT38 drill pipe f/337'to 2098' (Top of 7"csg). 11:45 12:00 0.25 2,098 2,121 COMPZ RPCOM TRIP T Make a top drive connection, rotate to enter 7"casing,slack off and tagged junk @ 2115.99', pushed junk down to 2121'. 12:00 12:15 0.25 2,121 2,348 COMPZ RPCOM TRIP T Trip in the hole f/2121'to 2348.6', pushing junk ahead w/3-7k.Took 15k wt @ 2348.6'. PU wt 75k, SO wt 66k, Rotating weight 68k. 12:15 13:15 1.00 2,348 2,392 COMPZ RPCOM MILL T Make a top drive connection,then ream/mill on junk f/2348'to 2392'. Rotate 60 rpm w/1500 ft lbs of torque to 2200 ft lbs.Weight on bit 2k. PU wt 75k, SO wt 66k, Rot weght 69k. Pumping 6 bpm(252 gpm)w/540 psi. 13:15 13:45 0.50 2,392 2,471 COMPZ RPCOM TRIP T Slack off while pumping 6 bpm(252 gpm)w/540 psi to 2471', pushing junk down hole.Took 10k @ 2471'. Decision to call it good for now. 13:45 14:45 1.00 2,471 2,471 COMPZ RPCOM CIRC T Circulate bottoms up pumping 10 bpm(420 gpm)w/1440 psi. Blow down top drive. Page 39 of 57 Time L ogs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 14:45 15:30 0.75 2,471 1,040 COMPZ RPCOM TRIP T POOH w/BHA#65(concave mill, string mill,magnets)f/2471'to 1,040". 15:30 15:45 0.25 1,040 1,040 COMPZ RPCOM SFTY T Trip Drill at 15:02 hrs-35 sec TIW valve closed,45 sec to simulate closing top pipe rams and opening HCR choke. CRT= 125 sec 15:45 16:15 0.50 1,040 705 COMPZ RPCOM TRIP T Continue POOH w/BHA#65 (concave mill, string mill, magnets)f/ 1,040'to BHA. 16:15 18:00 1.75 60 0 COMPZ RPCOM PULD T Stand back DCs and LD BHA tools. Clean magnets(top one had 13.7#of iron, bottom one had 11#'s. Boot baskets were empty. Recovered 2.5 lb of metal filings from ditch magnets. Concave mill looked good, string mill looked good. Lay down all. 18:00 18:30 0.50 0 0 COMPZ RPCOM PULD T Clean floor, lay down tools, pick up tools f/BHA#66(multistring cutter). 18:30 20:00 1.50 0 24 COMPZ RPCOM PULD T PU/MU BHA#66(multistring cutter). 20:00 21:30 1.50 24 2,013 COMPZ RPCOM TRIP T RIH on 3-1/2"DP to 2,013'. PU= 70K, SO=67K lb. 21:30 22:00 0.50 2,013 2,105 COMPZ RPCOM WASH T Wash down to 2,098.5'at 6 BPM and 435 psi. Rotate down with 10 rpm and 1,500 ft-lb torque to 2,104.5'. SO=61K lb with pumps on. Increase pump rate to 560 psi at 4 BPM. Continue rotating for 10 min. at 60 rpm and 1,600 ft-lb of TQ.After 10 minutes pump pressure dropped to 190 psi and torque dropped to 1,200 ft-lb.Turn pumps and rotary off. PU out of 7"casing. 22:00 23:00 1.00 2,105 24 COMPZ RPCOM TRIP T POOH to Multi-String cutter BHA. 23:00 00:00 1.00 24 0 COMPZ RPCOM PULD T LD Multi-String cutter BOT BHA#66. X9/02/2013 Dress off 7"casing stub to 2,007'. POOH, RU and run 50 Jts of 7", 26 ppf, L-80,TCII casing. Locate casing patch over stub. Pull casing and set in tension with 75K lb overpull. Pressure test to 2,020 psi for 10 minutes, pressure up and open ES cementer and CBU. 00:00 00:45 0.75 24 0 COMPZ RPCOM PUCM T Continue to LD Multi-string cutter BHA 00:45 01:15 0.50 0 672 COMPZ RPCOM PULD T PU Spear and grapple BHA with rounded bullnose 01:15 02:15 1.00 672 2,098 COMPZ RPCOM TRIP T RIH to 2,098'and tag up on top of fish.Work string but could not get spear inside casing cut-off. 02:15 03:00 0.75 2,098 672 COMPZ RPCOM TRIP T POOH to change BHA configuration 03:00 03:30 0.50 672 0 COMPZ RPCOM PULD T LD rounded bullnose, PU cut muleshoe 03:30 04:15 0.75 0 2,098 COMPZ RPCOM TRIP T RIH to top of fish 04:15 04:45 0.50 2,098 2,007 COMPZ RPCOM FISH T Engage fish and PU on stand and observe well-static. PU wt 70k,SO wt 65k. No go @2097.84', bottom of mule shoe @ 2105.74'. Page 40 of 57 Time Logs III - Date From! To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 06:15 1.50 2,007 0 COMPZ RPCOM TRIP T POOH. Handle BHA and handle 5.75' cut-off of 7"casing with one piece of 10-3/4"casing -8.5"wide x 9.25" long wedged in the top along side of the spear. Pictures on the"S"drive in well folder. 06:15 06:30 0.25 0 0 COMPZ RPCOM OTHR T Discuss possible junk still in hole w/ town engineer. Pictures of dressoff shoe on the"S"drive.Went over the Baker BHA#69. Decision is to continue with present plan forward. 06:30 07:30 1.00 0 0 COMPZ RPCOM PULD T Prepare BHA#69. Install brass tattle tail on inner mill for better identification of dressoff. 07:30 09:15 1.75 0 695 COMPZ RPCOM PULD T PU/MU Baker BHA#69(Dressoff 7" csg). 8.5"OD cutlip dressoff shoe w/ 7-3/16"x 6-1/8"inner dress mill, extension,triple connect bushing, x-o,(2)string magnets, bumper sub, oil jar, (9)4-3/4"drill collars,x-o, (12) 3-1/2"HWP=695.45'. 09:15 10:00 0.75 695 2,020 COMPZ RPCOM TRIP T Trip in the hole w/Baker BHA#69 f/ 695'to 2020'. Obtain parameters: PU wt 69k, SO wt 65k. Rotating wt 67k. Rotate 15 rpm w/1300 ft lbs of torque. Pumping 8 bp mw/580 psi. Trip in and tag top of 7"casing @ 2104'w/cutlip guide. 10:00 10:15 0.25 2,020 2,109 COMPZ RPCOM MILL T Work over the 7"stub @ 2104'with cutlip guide dressoff shoe.Continue down,then set 5k wt on top of 7" with inner dressoff mill. Bottom of outer dressoff shoe @ 2109.35' 10:15 10:45 0.50 2,109 2,109 COMPZ RPCOM MILL T Dress the top of the 7"casing stub: Rotating 40 rpm w/3000 ft lbs of initial torque. Final torque 1750 ft lbs. Pumping 8 bpm w/630 psi. Polish the outside of the 7"csg rotating 80 rpm w/2000 ft lbs of torque. Backrea over top of casing twice. Slide over the top of the casing w/no problems. 10:45 13:00 2.25 2,109 2,101 COMPZ RPCOM CIRC T Pickup above the top to 2101'.Then circulate to clean up the annulus. Pumping 13 bpm w/1375 psi. Pump 35 bbl hi vis sweep,circulate surface to surface,still dirty after 4BU, mix another 35 bbl sweep. Circulate 12 bpm w/1335 psi till mud man is happy. Obtain slow pump rates:#1 mp @ 2 bpm=40 psi,3 bpm=70 psi.#2 mp @ 2 bpm=40 psi, 3 bpm=80 psi. 13:00 13:15 0.25 2,101 2,101 COMPZ RPCOM TRIP T Monitorwell-static. 13:15 13:30 0.25 2,101 2,101 COMPZ RPCOM OTHR T Remove blower hose f/top drive. 13:30 14:00 0.50 2,101 695 COMPZ RPCOM TRIP T Trip out f/2101'to 695'. Page 41 of 57 Time Logs • Date From l To S Dur S. Deoth E. Depth Phase Code Subcode T Comment eat ept ase Co e 14:00 16:00 2.00 695 0 COMPZ RPCOM PULD T Stand back 3-1/2"HWDP and 4-3/4" DC's. Lay down BHA#69 per Baker Oil Tools. Recovered 2.2#metal f/top magnet, 2.7#f/lower magnet and 1.9#f/possum belly magnets. Pictures of dressoff shoe, inner mill and magnets on the"S"drive. 16:00 18:00 2.00 0 0 COMPZ RPCOM OTHR T Remove FMC wear bushing.Wash BOPE stack with washing assembly w/(2)string magnets. String and ditch magnets had very little metal filings. 18:00 19:30 1.50 0 0 COMPZ RPCOM RNCS P RU casing equipment for 7",26 lb/ft, TCII, R2 casing 19:30 23:00 3.50 0 2,098 COMPZ RPCOM RNCS P PU/MU BOT-Bowen packer type 7" casing patch. PU XO pups and HES ES cementer pinned for 3,300 psi with 6 shear pins. Baker-Lok Casing patch, pups and ES cementer. Run 50 jts of 7",26 lb/ft, L-80,TCII, R3 casing.Average MU torque= 10,000 ft-lb. 23:00 23:30 0.50 2,098 2,107 COMPZ RPCOM RNCS P PU/MU spaceout 9.83'and 9.76' pups. PU=75K, SO=74K lb. MU XO to Top Drive and screw in. Rotate at 10 RPM with 1.5K ft-lb TQ. Rotate over 7"casing stub 1',turn off rotary and slide over stub to 2,007'setting down with 35K lb. PU to 20K lb of overpull. Set down to verify with 45K Ib, PU and put casing string in 75K lb of tension. Pressure up to 2,020 psi and hold for 10 minutes-good. Pressure up to 3,250 psi and open ES cementer. CBU to condition for cementing. 09/03/2013 PJSM, PT cement line to 4000 psi, Pump 5 bbls water,followed by 10 bbl NEAT AS1 15.7 ppg, Pumped 140 bbl w/2 ppg pressurenet/cement 15.7 ppg, Pumped 10 bbl NEAT AS1 15.7 ppg, Drop HES plug and displace with rig, Bumped plug with 1245 stks, pressure up to 2150 psi and close cementer, Hold for 1 min, R/D cementing equipment and blow down lines, N/D BOPs, Set slips with 65K in tension,Cut casing,set stack on stump and N/D adapter&DSA, C/O bails, Install 7"pack-off, Set tbg spool and adapter spool and PT pack-off to 250 psi for 5 min and 3000 psi for 5 min, N/U BOP stack and test BOPE 250 psi for 5 min and 3500 psi for 5 min each,Witness of test waived by AOGCC Rep.Jeff Jones. 00:00 02:45 2.75 2,107 2,107 COMPZ RPCOM CIRC P RD casing equipment, circ and cond. well @ 6 bpm w/200 psi. Load HES plug in Dowell cement head, RU cement head and lines. 02:45 03:00 0.25 2,107 2,107 COMPZ RPCOM SFTY P PJSM on cementing while still circulating 6 bpm w/200 psi. Circulated a total of 535 bbls. Page 42 of 57 Time Logs • I Date From To Dur S. Depth E. Deoth Phase Code Subcode° °T- Comment - ` 03:00 05:30 2.50 2,107 2,107 COMPZ RPCOM CMNT P Dowell flood line w/5 bbls water. Pressure test surface lines to 4,000 psi for 10 minutes. Bleed off pressure and pump 10 bbl of neat 15.7 ppg ASI cement(Yield.93 cuft/sx, mix water 3.541 gal/sx),followed by 140 bbl of 15.7 ppg,AS1 cement(Yield .96 cuft/sx, mix water 3.516 gal/sx, .04 gal/sx of D110,4.295 lb/sx of B056)with 2 lb/bbl of Pressnet LCM additive,followed by 10 bbl of 15.7 ppg, neat AS1 cement(Yield.93 cuft/sx, mix water 3.541 gal/sx)at 5 BPM. Drop wiper plug,dowell pump 1.8 bbls neat cement(Yield .93 cuft/sx, mix water 3.541 gal/sx), follow w/5.2 bbls water,then the rig displace with 73 bbl 8.4 ppg vis water using rig pumps. Started w/5 bpm for the first 19.6 bbls(cement back to surface),then at 2 BPM w/450 to 790 psi,and decreasing to 1 BPM w/ 716-800 psi for the last 10 bbl of displacement. Bumped plug with 1,246 strokes. Pressured up to 2,150 psi and closed ES cementer. CIP at 05:19 hrs. 05:30 07:00 1.50 2,107 2,107 COMPZ RPCOM RURD P Bleed off pressure,cementer is closed. RD cement head and lines. Displace fluid in 7"w/stand of 3-1/2" dp w/valve closed on end. Drain stack. 07:00 08:00 1.00 2,107 2,107 COMPZ WHDBO NUND P Break bolts on BOP's to 7"casing head. Raise stack to set slips and packoff and to cut 7"after install of emergency slips. 08:00 08:30 0.50 2,107 2,107 COMPZ RPCOM CMNT P Cement in the 10-3/4"x 7"was 6.7' below the casing head. Mixed 2sx (160 pounds)of AS1 cement and poured into void(yield.93 cuft/sx, 3.5 gal/sx mix water, 15.7 ppg). left the height 1.5' below top of csg head --4"below load shoulder in the casing head(to the bottom of the OA valve). 08:30 08:45 0.25 2,107 2,107 COMPZ WHDBO NUND P Set FMC emergency slips w/65k tension on the 7"string. (145k on weight indicator). 08:45 09:30 0.75 2,107 0 COMPZ WHDBO NUND P Rig up Wachs cutter. Cutjt#50 of the 7"26 ppf L-80 TCII casing @ 5-3/4"above casing flange. 09:30 10:30 1.00 0 0 COMPZ WHDBO RURD P Pull two 10'TCII pups, cementing x-o (BTC box x TCII pin)and cut joint (9.99'removed)out of the hole. Break pups. Page 43 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T !Comment 10:30 12:00 1.50 0 0 COMPZ WHDBO NUND P Nipple down 13 3/8"Stack and set back on the stump. Nipple down Adapter Spool and DSA. Change long bales to shorter drilling bales. 12:00 14:00 2.00 0 0 COMPZ WHDBO NUND P FMC Serviceman install the 7" Casing Pack-off 14:00 16:00 2.00 0 0 COMPZ WHDBO NUND P Nipple up the 7 1/16"5K x 11"3K Tubing Spool. Nipple up the 7"5K x 13 5/8"5K Adaptor Spool.Test Pack-off to 250 psi/3000 psi for 15 min, good. 16:00 18:00 2.00 0 0 COMPZ WHDBO NUND P N/U BOPE and test Sirra gas monitoring system. 18:00 19:00 1.00 0 0 COMPZ WHDBO OTHR P Chnage lower rams from 7"to 3-1/2" x 6"VBR's 19:00 20:00 1.00 0 0 COMPZ WHDBO BOPE P M/U test joint and test plug with dart valve&TIW valve,set test joint and _ fill stack and lines with water. 20:00 00:00 4.00 0 0 COMPZ WHDBO BOPE P Test BOPs with 3-1/2"test joint,250 psi for 5 min, 3500 psi for 5 min, Witnessing of test waived by AOGCC Rep. Jeff Jones. 39/04/2013 Finish testing BOPE, P/U BHA#70, RIH to 1928'MD, Slip and cut drilling line, Service rig&Top Drive, CBU and rig up and put quick test on 7"casing above cementer to 2500 psi 10 min,Wash down to HES Cementer @ 2090'MD,drill plug and cementer,wash down to 2445'MD, CBU, R/U&test 7"to 3500 psi for 30min, POOH&L/D BHA, M/U BHA#71, RIH and mill junk on top of sand down to 2592'MD, CBU, POOH&L/D BHA, M/U BHA#72, RIH to 2503'MD. 00:00 01:00 1.00 0 0 COMPZ WHDBO BOPE P Perform draw down test, Start=3040 psi, Closing= 1750 psi,200 psi= 17 sec, Final=97 sec,Closing time: Bag= 18 sec, UPR=7 sec, Blinds sim=7 sec, LPR=7 sec, Choke=1 sec, Kill= 1 sec, Bottles avg=2050 psi, Electric pump=40 sec,Air pump=5 min 37 sec. 01:00 02:00 1.00 0 0 COMPZ WHDBO BOPE P L/D test joint and test plug,set wear ring 6-3/8"ID, Blow down lines and line up manifold. 02:00 03:00 1.00 0 330 COMPZ WHDBO PULD P P/U BHA#70, to drill out HES cementer F/surface T/330'MD 03:00 04:00 1.00 330 1,928 COMPZ WHDBO TRIP P RIH F/330'T/1928'MD, PUW=67K, SOW=64K. 04:00 04:30 0.50 1,928 1,928 COMPZ WHDBO PRTS P Circ drill pipe volume and test 7" above HES cementer to 2500 psi for 10 min and chart same. 04:30 06:00 1.50 1,928 1,928 COMPZ WHDBO SLPC P Slip and cut 102'of drilling line and service rig Top Drive and blocks. 06:00 07:00 1.00 1,928 2,090 COMPZ WHDBO REAM P Wash down F/1928'T/2090'MD, (Top of Plug)Tagged cement stringers @ 2054'clean up stringers down to top of plug @ 2090'MD, 120 rpm,Tq off= 1800,8 bpm with 885 psi, PUW=71K, SOW=62K, Rot wt=65K, No WOB needed to clean up stringers. Page 44 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment° ~~ 07:00 09:00 2.00 2,090 2,093 COMPZ WHDBO DRLG P Drill up plug and stage collar F/2090 T/2093' MD, 120 rpm,Tq off= 1800, Tq on=3000,WOB=5K, 8 bpm, 800 psi, PUW=70K, SOW=62K, Rot wt=65K. 09:00 10:00 1.00 2,093 2,445 COMPZ WHDBO REAM P Wash/Ream F/2093'T/2445'MD, Tag and set down 15K,60 rpm,Tq on 1800,8 bpm, 885 psi, Unable to go past 2445'MD. 10:00 10:30 0.50 2,445 2,398 COMPZ WHDBO CIRC P Circ and cond.with 8 bpm, 885 psi, Rotate and work pipe with 60 rpm, Tq= 1800,Afte back reaming up to 2397'unable to go down past 2404' MD,set down a5K with rotary,Tq= 2350. 10:30 12:00 1.50 2,398 2,398 COMPZ WHDBO PRTS P Rig up to test 7"casing,fill lines, sensor failed, C/O same and retest casing up to 3650 psi, chart same for 30 min, Good. Bleed off,open rams, and blow down lines. 12:00 13:00 1.00 2,398 782 COMPZ RPCOM TRIP P Monitor well and POOH F/2398'T/ 782'MD. PUW=75K, SOW=64K. 13:00 14:30 1.50 782 0 COMPZ RPCOM PULD P Lay down BHA F/782'T/surface, satnd back hwt&DCs. 14:30 15:30 1.00 0 699 COMPZ RPCOM PULD P P/U BHA#71,to 55' and RIH with DCs and Hwt to 699.0 15:30 16:00 0.50 699 2,449 COMPZ RPCOM TRIP P RIH with BHA#71 F/699'T/2449' MD, PUW=75K, SOW=64K. 16:00 16:30 0.50 2,449 2,469 COMPZ RPCOM MILL P Dry Mill F/2449'T/2469'MD,2K WOM,stack 20K at 2469'MD 16:30 18:30 2.00 2,469 2,563 COMPZ RPCOM MILL P Mill F/2469'T/2472' MD, 8K WOM, 8 bpm, 1183 psi, 1065 psi off,Tq on= 3K,Tq off=2K, PUW=75K, SOW= 64K, Rot wt=67K,80 rpm, Continue milling F/2472'T/2563'MD, Observed sand at shakers. 18:30 19:00 0.50 2,563 2,592 COMPZ RPCOM MILL P Dry Mill F/2563'T/2592'MD, 5K WOM, 10K WOM @ 2592'MD. 19:00 19:30 0.50 2,592 2,525 COMPZ RPCOM CIRC P Circ and cond. @ 2525'MD, Circ 80 bbls 8.4 ppg @ 8 BPM, 1183 psi, Monitor well(static) 19:30 20:30 1.00 2,525 699 COMPZ RPCOM TRIP P POOH F/2525'T/699'MD, PUW= 74K, SOW=65K. 20:30 22:00 1.50 699 0 COMPZ RPCOM PULD P Stand back HWT and DCs, UD BHA F/699 T/surface. Recovered 28.6# metal from magnets and no recovery from boot baskets. 22:00 23:30 1.50 0 704 COMPZ RPCOM PULD P P/U BHA#72, RIH with DCs and HWT T/704' MD. 23:30 00:00 0.50 704 2,503 COMPZ RPCOM TRIP P RIH with BHA#72 F/704'T/2503' MD, PUW=75K, SOW=65K. 09/05/2013 Continue Fishing operations with concave mill and RCJB runs with string magnet's and Boot Baskets, Recovered 86 lbs of metal from magnet's and 30 pieces of various sizes of metal. Now running 6"OD Flat bottom magnet BHA with 2 X String magnet's. Page 45 of 57 Time Logs I Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:00 00:30 0.50 2,503 2,537 COMPZ RPCOM MILL P RIH and tag at 2590'MD, PUW= 76K, SOW=67K, Rot wt=70K, 15 rpm, Tq= 1400 off,7.5 bpm, 1800 psi, Dry rotate down to 2592'20 rpm Tq on=2-3K, P/U and pump/rotate down to 2597'MD,20 rpm,WOB= 5K,7.5 bpm, 1800 psi. Pull up to 2537'. 00:30 01:00 0.50 2,537 2,537 COMPZ RPCOM CIRC P CBU X 2 shaker clean,7.5 bpm, 1800 psi. 01:00 02:00 1.00 2,537 704 COMPZ RPCOM TRIP P POOH F/2537'T/704'MD. 02:00 03:00 1.00 704 704 COMPZ RPCOM PULD P Stand back HWT and DCs L/D BHA, recovered 15 pieces of metal from boot baskets and 23 lbs of metal from magnets, M/U BHA#73 to 704' MD. 03:00 04:00 1.00 704 2,598 COMPZ RPCOM TRIP P RIH F/704'T/2598'MD, PUW=76K, SOW=65K. 04:00 04:30 0.50 2,598 2,604 COMPZ RPCOM MILL P Dry Mill @ 2599'down to 2600'MD, with 20 rpm,TQ=2/4K,WOM=5K, P/U and Pump/Rotate down to 2604' MD with 25 rpm, TQ=4k,7.2 BPM, 2025 PSI. 04:30 05:30 1.00 2,604 704 COMPZ RPCOM TRIP P POOH F/2604'T 704' 05:30 07:30 2.00 704 0 COMPZ RPCOM PULD P Stand back HWT and DCs,clean RCB and boot baskets. Recovered 8 lbs of metal from the magnets. Also recovered 12 pieces of metal from Boot Baskets and the Reverse Circulating Junk Basket. 07:30 08:30 1.00 0 2,592 COMPZ RPCOM TRIP P Make up BHA#74, Bladed Junk MIII. Trip in to 2,592'MD. Up weight= 76K. Down weight=65K. 08:30 11:30 3.00 2,592 2,620 COMPZ RPCOM MILL P Continue in hole and tagged the junk at 2,604-ft. Dry drill on top of junk and debris. Parameters as follows: RPMs=80, off btm torque=2K,on btm torque=2.5-5K,WOB=5- 20K, up weight=76K,down weight =65K, RTW=70K, Bring Pump on occasionally to kick metal up into the Boot Baskets and the Reverse Circulating Junk Basket. Worked down to 2,620-ft dpmd. 11:30 12:00 0.50 2,620 2,620 COMPZ RPCOM CIRC P Pull up hole. Circulate and condition btms up x 2 at 336 gpm/1,360 psi. Shut down Pumps. Run back in and tag junk at 2,620-ft dpmd. 12:00 12:30 0.50 2,620 2,623 COMPZ RPCOM MILL P Continue to dry drill from 2,620'- 2,623'. WOM= 10K, RPMs=80, torque on btm=3.6K,torque off btm =2.0K, up weight=75K, down weight=65K RWT=70K. 12:30 13:00 0.50 2,623 2,620 COMPZ RPCOM CIRC P Circulate btms up x 1.5 volumes, 336 gpm/1,300 psi. Page 46 of 57 Time Logs • I Date From To Dur S. Depth E.Depth Phase _Code Subcode T Comment 13:00 13:30 0.50 2,620 2,592 COMPZ RPCOM TRIP P Obtain SPR's 2600' MD, 2277'TVD, 8.4 ppg MWT,#1 pump @ 2 bpm= 110 psi, @ 3 bpm=260 psi,#2 pump @ 2 bpm= 120 psi, @ 3 bpm= 280 psi, P/U to 2592'MD and blow down TD, Monitor well, (Static) 13:30 14:00 0.50 2,592 699 COMPZ RPCOM TRIP P POOH F/2592'T/699'MD, PUW= 75K, SOW=65K, @ BHA PUW= 50K, SOW=50K. 14:00 15:30 1.50 699 0 COMPZ RPCOM PULD P Stand back HWT&DCs, L/D mill and clean off magnets&junk baskets, recovered 31 lbs of metal. 15:30 16:30 1.00 0 704 COMPZ RPCOM PULD P P/U BHA#75, RCJB, RIH with DCs _ &hwt to 704'MD. 16:30 17:30 1.00 704 2,597 COMPZ RPCOM TRIP P RIH from Derrick with dp F/704'T/ 2597'MD, PUW=77K, SOW=64K. 17:30 18:00 0.50 2,597 2,634 COMPZ RPCOM MILL P Slide down F/2597'T/2623'MD, Dry mill F/2623'T/2624'with 60 rpm, Vac F/2624'T/2629'MD with 60 rpm, 1.9 Tq,6.5 bpm, 1950 psi, PUW=75K, SOW=65K, Rot wt= 72K, Stop rotating&circ, slack down and tagged @ 2634'MD with 5K DWT. 18:00 19:00 1.00 2,634 704 COMPZ RPCOM TRIP P Pick up to 2597'MD and monitor well (Static)POOH F/2597'T/704'MD. 19:00 20:30 1.50 704 0 COMPZ RPCOM PULD P Stand back HWT&DCs,clean off magnets&junk baskets, recovered 24 lbs of metal from magnets and several pieces of metal from RCJB. 20:30 21:30 1.00 0 0 COMPZ RPCOM PULD P Lay down Boot Baskets and RCJB. 21:30 22:30 1.00 0 690 COMPZ RPCOM PULD P M/U BHA#76, 6"OD Fishing magnet(Flat Bottom)Bit Sub, Ported Sub,2 String Magnets, Bumper Sub, Oil Jar, Pump Out Sub and run in with DCs&HWT to 690' MD. 22:30 00:00 1.50 690 2,634 COMPZ RPCOM TRIP P RIH with dp F/690'T/2634'MD, Tagged 2634 with 4K WOM, P/U 10' and tag again with 3K, PUW=77K, SOW=64K. 09/06/2013 Finished fishing operations(Recovered 5 pieces of aluminum from RCJB, 50 cent size and two quart size pieces from water course of RCJB head, recovered one broken finger from RCJB on the magnet), M/U RBP retrieving tool and RIH @ 2638'MD and retrieve upper IBP, POOH and M/U second retrieving tool for lower RBP and RIH to top of lower RBP 0 7901'MD,engage lower R BP and release as per Baker, CBU. 00:00 01:30 1.50 2,634 690 COMPZ RPCOM TRIP P POOH F/2634'T/690'MD, PUW= 77K, SOW=65K. 01:30 02:30 1.00 690 690 COMPZ RPCOM PULD P Stand back HWT&DCs,Clean out magnet's, Recovered 9.1 lbs of metal shavings and one quarter sized chunk of metal, M/U BHA#77 to 690'MD. 02:30 03:30 1.00 690 2,634 COMPZ RPCOM TRIP P RIH F/690'T/2634'MD, Set down 3-5-K x 3, PUW=76K, SOW=63K. 03:30 05:00 1.50 2,634 690 COMPZ RPCOM TRIP P POOH F/2634'T/690'MD. Page 47 of 57 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment r. 05:00 06:30 1.50 690 0 COMPZ RPCOM PULD P Stand back HWT&DCs,clean off magnet's, Recovered 7.2 lbs of metal shavings, LID flat bottom magnet and M/U RCJB BHA#78. 06:30 07:30 1.00 0 2,598 COMPZ RPCOM TRIP P Trip in the hole w/BHA#78 to 2598'. PU wt 77k, SO wt 65k. 07:30 08:15 0.75 2,598 2,631 COMPZ RPCOM WASH P Wash down f/2598', pumping 8 bpm w/2150 psi.Rotate 20 rpm w/1800 ft lbs of torque. Rotating weight 70k. Wash down f/2598'to 2636.67'(no weight taken). PU 5'and saw 5k overpull @'2634'.Wash down slowly to 2636.67'again, picked up and saw 5k overpull again. P 9 08:15 08:30 0.25 2,631 2,631 COMPZ RPCOM OWFF P Monitor well-static. 08:30 10:00 1.50 2,631 48 COMPZ RPCOM TRIP P Trip out of the hole f/2631'to 48'. Pulled first 2 stands slowly w/no overpull or swabbing observed. 10:00 11:00 1.00 48 0 COMPZ RPCOM PULD P Clean and lay down BHA.#78(rev circ junk basket). Recovered .5 pounds of metal shaving on magnet, Clean junk baskets-only 2 small penny sized pieces of aluminum.A few small pieces of aluminum in the reverse basket. One finger of reverse basket missing. 11:00 11:15 0.25 0 383 COMPZ RPCOM PULD P Make up BHA#79(Model"M" retrieving head,x-o,string magnet, x-o, (12)3-1/2"HWDP-383.2'). 11:15 12:00 0.75 383 2,560 COMPZ RPCOM TRIP P Trip in the hole f/383'to 2560'. PU wt 70k, SO wt 62k. 12:00 12:30 0.50 2,560 2,636 COMPZ RPCOM TRIP P RIH F/2560'T/2636'MD, PUW= 71K, SOW=62K. 12:30 13:00 0.50 2,636 2,636 COMPZ RPCOM CIRC P Pump 42 bbl hi-vis sweep @ 2636' and circ with 8 bpm,928 psi. 13:00 13:30 0.50 2,636 2,642 COMPZ RPCOM OTHR P Engage upper RBP @ 2638'MD, Set down 5K and allow to release, Pull up 8'and slack off to 2642' 13:30 15:00 1.50 2,642 0 COMPZ RPCOM TRIP P POOH F/2642'T/Surface with RBP. 15:00 15:30 0.50 0 0 COMPZ RPCOM PULD P UD RBP and running tool. 15:30 16:00 0.50 0 0 COMPZ RPCOM PULD P P/U Model M retrieving tool for lower RBP set @ 7901'MD. 16:00 18:00 2.00 0 2,759 COMPZ RPCOM TRIP P RIH F/Surfce T/2759'MD, PUW= 72K, SOW=62K. 18:00 19:00 1.00 2,759 2,759 COMPZ RPCOM CIRC P Pump 20 bbl high vis sweep and displace 8.4 ppg brine with 8.9 ppg brine with 10 bpm @ 935 psi. 19:00 22:30 3.50 2,759 7,930 COMPZ RPCOM TRIP P RIH F/2759'T/7901'MD @ top of lower RBP. Engage RBP and release as per-Baker,well on vac, PUW= 180K, SOW=92K,Slack off to 7935', P/U to 7930' 22:30 00:00 1.50 7,930 7,930 COMPZ RPCOM CIRC P Circ @ 5 bpm with 850 psi with 1 bpm loss during circulation. Page 48 of 57 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 39/07/2013 24 hr Summary Circ well,at 2435 stks had flow increase, Shut well in, Circ throught choke&gas buster, Open well up,Well on vac. Monitor well, Circ STS no more gas, Monitor well for 30 min, Good,Well on vac. POOH, L/D RBP, Wash out stack and test Annular 250/3500 psi, R/D test equipment, Service Top Drive&C/O saver sub, M/U Fishing BHA,#81, RIH to 7980', Circ STS no gas,Tag fish @ 8016'and work over fish, POOH to 4195'MD. 00:00 01:30 1.50 7,930 7,930 COMPZ RPCOM CIRC P Pump 5 bpm with 850 psi,at 2435 strokes,flow increased,shut down and observe the well,flowing with 10 bbl gain,shut in well, ISICP=50 psi, SIDP=0 psi, build to 100 psi in 10 min, circ gas out through choke @ 3 bpm 390 psi holding 50 psi backpressure, lost 25 bbls circulating,finished circulating surface to surface. 01:30 02:00 0.50 7,930 7,930 COMPZ RPCOM OWFF P Shut down pumping,open choke no flow, open Hydril and observed well on vac. 02:00 02:45 0.75 7,930 7,930 COMPZ RPCOM CIRC P Circulate surface to surface with 5 bpm 900 psi, had 27 bph loss while circulating. 02:45 03:15 0.50 7,930 7,930 COMPZ RPCOM OWFF P Monitor well for 30 min,well on vac. 03:15 03:30 0.25 7,930 7,930 COMPZ RPCOM CIRC P Obtain SPR's 7930'MD, 5806'TVD, 8.9 ppg brine,#1 pump with 2 bpm= 160 psi,3 bpm=340 psi,#2 pump 2 bpm= 170 psi,3 bpm=340 psi. 03:30 09:00 5.50 7,930 367 COMPZ RPCOM TRIP P POOH with lower RBP F/7930'. Up weight= 185K. Fluid loss on the trip =59.4 bbls(Avg bph loss=10.8). BHA at surface. 09:00 09:30 0.50 367 0 COMPZ RPCOM PULD P Lay down BHA#80 and the Baker Model"G"Retrievable Bridge Plug...complete. 09:30 11:00 1.50 0 0 COMPZ WELCTI BOPE P Rig up test tools. Pull Wear Bushing. Make up the swizzle stick. Wash and flush out the BOP Stack at 13.5 bpm/125 psi/40 RPMs. Cycle Rams. Set Test Plug. Fill system with water. Keep Well full with 8.9 lb/gal Brine below the Test Plug. 11:00 11:30 0.50 0 0 COMPZ WELCTL BOPE P Test the Annular as per ConocoPhillips/AOGCC requirements at 250/3,500 psi x 5 minutes. Good test. Test recorded on chart. 11:30 14:00 2.50 0 0 COMPZ WELCTI BOPE P Lay down test tools and test joint. (Leave test plug in the hole). Suck out the stack. Inspect for any remaining junk/debris. Fluid loss during the Annular test=26 bbls. (Losses for tour= 118.3 bbls) 14:00 15:00 1.00 0 0 COMPZ RPCOM SVRG P Service Top Drive and C/O saver sub. 15:00 16:30 1.50 0 401 COMPZ RPCOM PULD P M/U BHA#81 (RCJB BHA) F/ Surface T/401'MD. Page 49 of 57 Time Logs ` Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 20:00 3.50 401 7,980 COMPZ RPCOM TRIP P RIH F/401'T/7980'MD, PUW= 195K, SOW=85K, Rot wt= 115K, Wash down F/7885'T/7980'@ 6 bpm, 1920 psi. Calc fill=49.62 bbls, Actual fill=32.87 bbls. 20:00 20:30 0.50 7,980 7,980 COMPZ RPCOM CIRC P Circ @ 7980'MD 6 bpm 1920 psi, (No gas to surface)Obtain SPRs. 20:30 21:30 1.00 7,980 7,979 COMPZ RPCOM FISH P Wash down F/7980'T/8016'MD to top of fish, PUW= 195K, SOW= 85K, Rot wt= 115K, P/U off&rotate 20 RPM,Tq= 11K,over fish, Stop rotation and slack down to 8022'MD with 10K, P/U took 230K to break free, P/U 10'off and slack down and tagged high @ 8013'Pull up to 7979'. 21:30 00:00 2.50 7,979 4,195 COMPZ RPCOM TRIP P Monitor well, POOH F/7979'T/4195' MD, PUW=90K, Calc fill=20.44 bbls,Actual fill=38.7 bbls,(Losses for tour=94.0)(Total for the day losses=212.3 bbls) X9/08/2013 POOH with BHA#81, No fish recovered, Discuss options with Town Engineer, M/U fishing BHA#82, RIH T/ 7973' MD, Slip&cut drlg line, Service Rig, Slack off and work over fish @ 8015'MD, POOH to surface, No fish recovered, Service Rig while waiting on fishing tools, M/U BHA Fishing#83, (Rolling Dog Overshot)RIH to 7990'MD, Circulate surface to surface and obtain SPR's. 00:00 02:30 2.50 4,195 401 COMPZ RPCOM TRIP P POOH F/4195'T/401'MD, PUW= 80K, Calc hole fill=29.76 bbls, Actual fill=56.3 bbls. 02:30 03:30 1.00 401 0 COMPZ RPCOM PULD P Stand back HWT and lay down BHA, No fish recovered,four finger broken in reverse basket catcher, 1 chunk of iron recovered,4 lbs of metal recovered from magnet,wire grabs missing from cut lip shoe. 03:30 04:30 1.00 0 0 COMPZ RPCOM OTHR P Monitor well on trip tank,12.21 bbl loss in one hour, clean&clear rig floor while discussing next plan for fishing BHA with town Engineer. Ready next BHA to rig floor. 04:30 05:00 0.50 0 402 COMPZ RPCOM PULD P M/U BHA#82, Short catch overshot with 4'grapple to 402'MD. 05:00 06:00 1.00 402 1,800 COMPZ RPCOM TRIP P RIH with BHA#82, F/401'T/1800' MD. 06:00 08:15 2.25 1,800 7,973 COMPZ RPCOM TRIP P Continue trip in the hole w/Baker BHA#82 from 1800'to 7973'. (Calc. displacement= 18.4 bbls,Actual displacement=49.9 bbls). 08:15 08:30 0.25 7,973 7,973 COMPZ RIGMNT SLPC P Make a top drive connection,set stump in table for planned slip and cut drilling line. 08:30 09:30 1.00 7,973 7,973 COMPZ RIGMNT SLPC P Slip and cut 82'of 1-1/4"drilling line. Service rig. Grease crown. 09:30 09:45 0.25 7,973 7,973 COMPZ RPCOM FISH P Make a top drive connection. Obtain parameters: PU wt 188k,SO wt 89k. Page 50 of 57 • Time Logs Date From! To Dur ! S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:15 0.50 7,973 7,973 COMPZ RPCOM FISH P Slack off f/7973'to find top of fish @ 8016'. PU with extra drag up to 225 setting off jars,then pulling a little drag. Slowly/carefully POOH and stand back a stand f/8016'to 7973'. 10:15 15:00 4.75 7,973 0 COMPZ RPCOM TRIP P Pull out of the hole w/Baker BHA #82 from 7973'to surface. (Cale. displacement= 17.4 bbls,Actual displacement=36 bbls). . 15:00 18:30 3.50 0 0 COMPZ RPCOM PULD P Discuss plan forward with Anchorage Engineer. Wait on Fishing Tools to be delivered. Service Rig and handling equipment. 18:30 20:00 1.50 0 419 COMPZ RPCOM PULD P M/U BHA#83(Rolling Dog Overshot with shoe)to 419'MD. 20:00 23:00 3.00 419 7,990 COMPZ RPCOM TRIP P RIH F/419'T/7990'MD, (Wash down F'7895'T/7990'5 bpm 920 psi)PUW= 175K, SOW=90K, Rot wt= 118K, Calculated displacement= 50.2 bbls,Actual displacement= 29.5 bbls. 23:00 00:00 1.00 7,990 7,990 COMPZ RPCOM CIRC P Circulate surface to surface @ 7990' MD, 6 bpm 1200 psi, No gas back to surface, Obtain SPRs, Pump#1=2 bpm 210 psi, 3 bpm 380 psi, Pump# 2=2 bpm 200 psi,3 bpm 370 psi. (Losses=-36 bbls) X9/09/2013 Check parameters and engage fish with BHA#83 @ 8016'MD, POOH, Fish recovered,3-pieces AOL= 28.96', LID same, M/U BHA#84 Spear with 4.010"grapple, RIH above fish, Circ STS, Engage fish @ 8026' MD, Circ STS, No gas, POOH to BHA, Recovered PBR, FHL packer, 1 jt tbg, GLM and cut jt,AOL=64.64', LID same, M/U BHA#85 Overshot with 3.5"grapple, RIH to 1911' MD. 00:00 00:30 0.50 7,990 8,030 COMPZ RPCOM FISH P Fishing-Check parameters, PUW= 185,SOW=90, Rot wt= 119,40 RPM,Tq= 10.5, 5 bpm 900 psi, Slack down F/7990'T/8016'set down 4K, P/U and rotate down over TOF,stop rotary, S/O to 8030'MD, Total swallow of fish= 14.5'with 50 psi increase,set down 10K. 00:30 01:00 0.50 8,030 7,990 COMPZ RPCOM FISH P P/U slow to 200K,allow jars to open, P/U in increments of 10K to 230K, Broke over @ 230 up wt. P/U dragging 210-220K, P/U to 8010'S/O to 8020',did not see top of stub @ 8016' POOH to 7990'MD. 01:00 01:30 0.50 7,990 7,990 COMPZ RPCOM OWFF P Monitor well for 15 min,fluid dropping in stack. Remove blower hose. 01:30 05:00 3.50 7,990 419 COMPZ RPCOM TRIP P POOH F/7990'T/419', PUW= 180K. 05:00 05:30 0.50 419 419 COMPZ RPCOM PULD P Stand back HWT and UD BHA, Recovered the fish(SBE)Calcuated displacement=50.2 bbls,Actual displacement=86.6 bbls. Page 51 of 57 • • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05:30 07:00 1.50 419 0 COMPZ RPCOM PULD P Brk down BHA as per Baker and L/D fish. Fish recovery included cut jt 5', 12.59'remaining cut,4.10 pup on seals and 12.59'Baker FHL seal assembly. Driller measured overall length 28.96'. I displacement 50.2 bbls, (Calculated d p , actual 86.6 bbls.) 07:00 08:15 1.25 0 681 COMPZ RPCOM PULD P PU/MU Baker BHA#84(9487"C" DIM Spear w/4.01 grapple,4-3/4" bumper sub,4-3/4"jar, (9)4-3/4" DC's, intensifier, pump out sub,x-o, (12)3-1/2"HWDP=681.30'. Will be fishing for PBR/FHL pkr, 1 jt of 3-1/2"J-55 9.2 ppf IBT tubing, Camco 3-1/2"x 1"KBUG GLM and 1/2 of a jt of tubing).Top @ '8022.97',bottom was cut @ WLM 8096'. 08:15 11:00 2.75 681 7,968 COMPZ RPCOM TRIP P Trip in the hole w/Baker BHA#84 f/ 681'to 7,968-ft. Up weight= 198K. Down weight=88K. Stop to circulate and condition hole. Calculated displacement=55.05 bbls,Actual displacement=28.7 bbls. 11:00 12:00 1.00 7,968 7,768 COMPZ RPCOM CIRC P Circulate and condition at 5.0 bpm/1,475 psi. Perform SPR as follows: MP#1 =2.0 bpm/290 psi, 3.0 bpm/600 psi. MP#2=2.0 bpm/270 psi, 3.0 bpm550 psi. A total of 18.7 bbls were lost to the formation while circulating surface to surface. 12:00 13:00 1.00 7,768 8,026 COMPZ RPCOM FISH P RIH F/7986'T/8026'tag top of PBR @ 8026' Plant spear and release FHL packer as per baker. 13:00 15:00 2.00 8,026 8,020 COMPZ RPCOM CIRC P Circulate surface to surface through gas buster @ 8020'MD,3 bpm 600 psi, No gas back to surface. 32 bbl loss during circ. 15:00 15:30 0.50 8,020 8,020 COMPZ RPCOM OWFF P Monitor well for 30 min(4.7 bbl loss) 15:30 19:30 4.00 8,020 681 COMPZ RPCOM TRIP P POOH F/8020'T/681'MD, Calculated displacement=53.29 bbls,Actual displacement=88.3 bbls. 19:30 22:00 2.50 681 0 COMPZ RPCOM PULD P L/D BHA#84, F/681'T/Surface, recovered PBR= 13.28', FHL packer = 7.00', 1 joint 3-1/2"tbg=31.54', GLM=6.57',tbg cut joint= 13.25. (21 bbl loss during BHA) 22:00 23:30 1.50 0 680 COMPZ RPCOM PULD P M/U BHA#85(Overshot with 3-1/2" grapple)RIH F/Surface T/680'MD. 23:30 00:00 0.50 680 1,911 COMPZ RPCOM TRIP P RIH F/680'T/1911'MD, PUW=63K, SOW=60K, Calculated displacement= 11.24 bbls,Actual displacement=4.4 bbls. Page 52 of 57 • Time Logs Date From To Dur S.Deoth E. Deoth Phase Code Subcode T Comment 39/10/2013 24 hr Summary Continue RIH with BHA#85 T/7969'MD, Circ STS, obtain SPR's, Engage fish @ 8103'MD with 5'of swallow,work pipe&fire jars for 2 hours, Fish came free, CBU+losses, No gas back, Pumped hi-vis sweep around, Monitor well for 30 min,well went static,observed well for 15 more min, Fluid dropping in stack, POOH T/6644'MD, Service rig while repairing Iron RoughNeck, POOH, Recovered 191.63'of Fish, Left 13'in, Parted @ AVA nipple. Service drawworks while waiting on tools,due to rig move on spline road, M/U BHA# 86, RIH T/8159'MD, Obtain SPRs. 00:00 02:30 2.50 1,911 8,087 COMPZ RPCOM TRIP P RIH with BHA#85 F/1911'T/7967' MD, PUW= 190K, SOW=92K, Calculated displacement=38.15 bbls,Actual displacement=21.2 bbls,wash down F/7967'T/8087' MD, PUW=200K, SOW=90K. 02:30 04:00 1.50 8,087 8,087 COMPZ RPCOM CIRC P Circulate Surface to Surface+ losses, (No gas)Obtain SPR's. Losses while circ=27.23 bbls. 04:00 05:30 1.50 8,087 8,110 COMPZ RPCOM FISH P Obtain parameters, PUW=200K, SOW=90K, Rot wt= 125K,Work over fish with Overshot&3.5"grapple @ 8103'MD,Worked over fish 20 RPM, 11K free TQ, Pumping 1.5 bpm 140 psi, Saw psi increase as worked over fish,stopped pump& rotary,swallowed 5', Picked up to 225K,worked up to 250K,slacked down with 10K, P/U to 250K,fire jars, P/U to 300K, Fire jars @ 295K and pull up to 314K Max. Continue working pipe and jars. Fish came free. Down wt now is 95K. 05:30 07:00 1.50 8,110 8,090 COMPZ RPCOM CIRC P CBU, No gas back, Pump hi vis (150/200 vis)sweep around with 336 GPM/8 bpm with 2240 psi. No Junk or debris came back with sweep, Saw 100 psi increase when sweep neared surface, loss rate increased F/27 bpm T/60 bph.62.22 bbl loss during circ. 07:00 07:45 0.75 8,090 8,090 COMPZ RPCOM CIRC P Monitor Well x 30 minutes=static. Monitor for an additional 15 minutes =fluid level slowly dropping. 07:45 09:00 1.25 8,090 6,644 COMPZ RPCOM TRIP P Start to trip out with 3 1/2"Drill Plpe. Up weight=205K-210K. Stop to service the Iron Roughneck. Up Weight at 6,644-ft=175K. 09:00 09:30 0.50 6,644 6,644 COMPZ RPEQP1 TRIP P Service Top Drive, Blocks,and Drawworks.While repairing Iron Roughneck. 09:30 13:00 3.50 6,644 681 COMPZ RPCOM TRIP P Finish tripping out with 3 1/2"Drill Pipe to BHA#85. Calculated displacement=37.96 bbls,Actual displacement=67.4 bbls.Total losses for tour= 146.9 bbls Page 53 of 67 • Time Logs _ 4110 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:00 17:30 4.50 681 0 COMPZ RPCOM PULD P Rig up GBR to help lay down the Fish as needed. Lay down BHA #85...incomplete,expected Fish as follows: 3 1/2"Cut-Off Joint, 17.85-ft, 7 ea 4 1/2"Blast Joints with an overall lenght of 141.31 ft. (the Blast Joints all had minor pitting), 1 Joint of 3 1/2"Tubing, 31.55-ft(major pitting. Also found several holes). AVA Nipple...parted at the ports, 1.18-ft....Left in the hole remainder of the parted AVA Nipple,3 1/2" Pup Joint, Locator Sub,and a Baker Seal Assembly. 17:30 19:30 2.00 0 0 COMPZ RPCOM SVRG P Service Rig while waiting on fishing tool from Deadhorse. Rig move on the Spine road on the BP side prevented a timley delivery of the needed tool. 19:30 21:00 1.50 0 682 COMPZ RPCOM PULD P Make-up BHA#86, F/Surface T/ 682'MD 09/11/2013 Continue RIH with BHA#86 T/8250'MD, Brk circ and tag fish @ 8292'MD,Wash down to 8305'MD, Latch onto fish and pulled up to 220K when it broke over, pulled up past perfs and Circ STS, Monitor well,fluid dropping in stack, POOH with fish, Fish recovered= Partial AVA, Pup jt and seal assembly OAL=20.25', UD fishing tools, R/U&wash out BOP's, R/U and test BOPE,Test Pressure 250/3500 PSI as per Sundry. (Witness of test waived By AOGCC State Rep. Lou Grimaldi)Service Top Drive, M/U BHA#87(clean out) RIH T/8194' MD, Clean out to 8316'MD, Pull above perfs and circulate STS, Monitor well for 30 min. Pump& spot 40 bbl HEC pill. 00:00 03:45 3.75 8,063 682 COMPZ RPCOM TRIP P POOH F/8063.0'T/682' MD, Calculated displacement=55.04 bbls Actual displacement=84.5 bbls. PUW=205/210K. 03:45 04:45 1.00 682 0 COMPZ RPCOM PULD P Lay down BHA. Lay down the expected Fish recovered complete as follows: remainder of the AVA Nipple with the isolation sleeve inside,3 1/2" 10-ft Pup Joint, Baker Seal Assembly. Total lenght of recovered Fish=20.25-ft. 04:45 06:45 2.00 0 0 COMPZ RPCOM BOPE P Pull Wear Bushing. Flush Stack. 13.0bpm/140 psi/40 RPMs. Set Test Plug. Fill system with water. 06:45 11:45 5.00 0 0 COMPZ RPCOM BOPE P Perform the weekly BOPE Test per ConocoPhillips/AOGCC requirements at 250/3,500 psi. Good test. Recorded test on a chart. Perform Koomey drawdown test. Good test. The State's right to witness the test was waived by AOGCC Petroleum Inspector, L. Grimaldi. Install wear ring 6-3/8"ID. 11:45 12:15 0.50 0 0 COMPZ WELLPF SVRG P Service Top Drive-Inspect Top Drive. 12:15 14:15 2.00 0 718 COMPZ WELLPF PULD P M/U BHA#87(Clean out BHA)F/ surface T/718'MD. Page 54 of 57 Time Logs I Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:15 17:00 2.75 718 8,099 COMPZ WELLPF TRIP P RIH with BHA#87, F/718'T/8099' MD, Obtain SPR's, Calculated displacement=53.0 bbls,Actual displacement=26.0 bbls, Parameters PUW= 198K, SOW= 127K, Rot wt= 127K,Tq= 12K, . 17:00 19:00 2.00 8,099 8,316 COMPZ WELLPF REAM P Wash and ream down to 8179'MD, Took wt @ 8179'and 8243' MD, Perf. depths, Ream tight spots @ 8179'& 8243'at lower mill depths, Continue washing down into the FB-1 packer @ 8310'MD to 8316' MD. 19:00 19:30 0.50 8,316 8,099 COMPZ WELLPF WASH P Pump&Wash back up above perfs F/8310'T/8099'MD.5 bpm 880 psi. PUW=200K, SOW=90K. 19:30 21:15 1.75 8,099 8,099 COMPZ WELLPF CIRC P Circulate Surface to Surface+ losses, 7 bpm 1600 psi, Monotor - well for 30 min. Pump and spot 40 bbl HEC pill with 3 bpm 295 psi. X9/12/2013 Finish spotting HEC pill, POOH laying down dp to 5735'MD, Slip&cut drlg line, Service rig, Continue LID dp to BHA, RIH with 10 stand from derrick and LID same, LID BHA, recovered 14.2 lbs of metal shavings, pull wear ring, R/U GBR to run 3.5"completion, PJSM with all, Run 3.5"TBG as per-program to 4908'MD, Discovered loose pin on elevators, call and borrowed elevators from Nodric 3 and change out same. 00:00 00:30 0.50 8,099 8,099 COMPZ WELLPF CIRC P Spot 40 bbl HEC pill, Blow down& line up trip tank. 00:30 02:30 2.00 8,099 5,735 COMPZ WELLPF TRIP P POOH laying down 3.5"dp F/8099' T/5710'MD. PUW=200K 02:30 03:30 1.00 5,735 5,735 COMPZ WELLPF SLPC P Slip and cut 102'drlg line. Inspect drawworks,adjust brakes. 03:30 04:00 0.50 5,735 5,735 COMPZ WELLPF SVRG P Service Blocks,Top Drive and Iron RoughNeck. 04:00 07:30 3.50 5,735 717 COMPZ WELLPF TRIP P Continue laying down 3.5"dp F/ 5710'T/717'MD, Calculated displacement=56.52 bbls,Actual displacement= 100.8 bbl. 07:30 08:00 0.50 717 1,664 COMPZ WELLPF TRIP P RIH with 10 stands of dp from derrick T/1664'MD 08:00 10:00 2.00 1,664 74 COMPZ WELLPF TRIP P POOH laying down dp and HWT and DC's F/1664'T/74' 10:00 11:00 1.00 74 0 COMPZ WELLPF PULD P UD rest of BHA and clean magnets, 14.2 lbs metal shavings recovered. Junk baskets were clean. 11:00 12:00 1.00 0 0 COMPZ WELLPF TRIP P Remove wear bushing, Flush BOP stack with swizzle stick and magnet 13.5 bpm 60 rpm 12:00 13:00 1.00 0 0 COMPZ WELLPF PUTB P R/U GBR to run 3.5"compleltion string. 13:00 13:30 0.50 0 0 COMPZ WELLPF SFTY P PJSM with all personnel running completion. 13:30 21:30 8.00 0 4,908 COMPZ WELLPF PUTB P Run 3.5"9.3 ppf L-80 EUE-mod tbg. Optimum M/U 2240 ft/lbs,To 4908' MD, PUW=50K, SOW=50k. 21:30 00:00 2.50 4,908 4,908 COMPZ WELLPF OTHR T Discovered loose pin on 3.5"tbg elevators handle,went to Nodric 3 and brought back a set of elevators and change out. Page 55 of 57 • Time Logs Date From To Dur S.Death E.Death Phase Code Subcode T Comment 09/13/2013 24 hr Summary Finish running 3.5"tbg completion, (Ran 259 joint)CIO to long bails and M/U TIW valve and pump down to 8318'MD saw pressure increase,Top of lower packer, Continue to No GO, Btm of seals @ 8323.83', P/U 12', Spot 10 bbl 8.0 inhibited brine down between packer's, Dropped ball&rod,space 1'off no go, Pressure up as per program and set Premier packer @ 7965'MD and shear out with 20K over, Spaced out tbg, Pumped 210 bbls of inhibited 8.9 brine followed with 140 bbls of brine, land tbg hanger&RILDS,Test tbg to 3500 psi, (Good)PT csg/packer to 3500 psi(Good) Bleed down tbg and SOV, L/D landing jt, Install BPV and test in direction of flow 1000 psi, (Good)N/D stack&adapter spool, N/U adapter spool&tree, Pull BPV&install TWC valve. 00:00 03:30 3.50 4,908 8,281 COMPZ WELLPF RCST P Continue running 3.5"9.3 lb/ft L-80 EUE TBG F/4908'T/8281'MD as per program. Ran 259 joints to 8281' MD. 03:30 05:00 1.50 8,281 8,323 COMPZ WELLPF OTHR P Change out to long bails for well control continency, M/U TIW on jt# 260 and make up to tbg string,Went down did not see press increase, M/U TIW to jt#261 and saw prssure increase @ 8318'MDTop of PBR, No Go @ 8323.83'MD, Difference in dp tally&TBG tally=7.83' 05:00 06:00 1.00 8,323 8,318 COMPZ WELLPF CIRC P P/U to 8318'MD and Pump 10 bbl inhibited 8.9 ppg and spot outside of tbg with 78 bbls 6 bbls chasing pill.4 bpm 320 psi, brk off jt and drop Ball &rod. 06:00 07:00 1.00 COMPZ WELLPF PACK P Sting back into PBR 1'off no go, Pressure up to 2700 psi&hold for 5 min, Slack off 15K, Pressure up to 3500 psi&hold for 5 min, Pressure up to 4000 psi&hold for 10 min, Bleed off pressure to1500 psi, Pulled 20K over(120K)and shear PBR from Premier Packer Top Premier packer @ 7965'MD. 07:00 09:00 2.00 COMPZ WELLPF PUTB P Space out completion, L/D jt#261, #260&#259, M/U 5'pup and P/U jt #259 and M/U TBG hanger on top of jt 259, P/U jt#260 as landing jt. 09:00 10:30 1.50 COMPZ WELLPF CIRC P Pump 210 bbls of 8.9 inhibited brine with 5 bpm 530 psi chase with 140 bbls brine 5 bpm 550 psi. 10:30 11:30 1.00 COMPZ WELLPF PUTB P Land TBG hanger as per-FMC and RILDS 11:30 12:00 0.50 COMPZ WELLPF PRTS P Pressure test 3.5"TBG to 3500 psi 30 min(Good) 12:00 13:00 1.00 COMPZ WELLPF PRTS P Pressure test csg/packer to 3500 psi 30 min(Good)Bleed down TBG pressure and SOV. 13:00 13:30 0.50 COMPZ WELLPF PULD P UD landing joint and blow down kill and cement lines. 13:30 14:00 0.50 COMPZ WELLPF OTHR P Install BPV as per-FMC 14:00 14:30 0.50 COMPZ WELLPF PRTS P Pressure test in direction of flow to 1000 psi for 30 min(Good) 14:30 17:30 3.00 COMPZ WELLPF NUND P N/D BOP's and stand back, N/D adapter spool. Page 66 of 57 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:30 20:30 3.00 COMPZ WELLPF NUND P NH/U adapter spool and tree. FMC tested adapter void, 250 psi-5 min, 5000 psi-5min. (Lee Martin witnessed test). 20:30 21:30 1.00 COMPZ WELLPF OTHR P Pulled BPV and install TWC valve. 21:30 22:30 1.00 COMPZ WELLPF PRTS P R/U and pressure test tree 250 psi/ 5000 psi and chart same, R/D. 22:30 23:30 1.00 COMPZ WELLPF FRZP P R/U LRS and pressure test lines 1500 psi, pump 75 bbls diesel down OA ICP=500 psi, FCP=700 psi, Let well U-tube. 23:30 00:00 0.50 COMPZ WELLPF SEQP P Install BPV, Finish cleaning pits, Rig released from 1A-07 @ 23:59 9/13/2013, begin MOB for 1A-25. Page 67 of 57 7i i s 1 (370 Regg, James B (DOA) From: Nabors 7ES Company Man [n2364©conocophillips.com] 2� /��i3 Sent: Wednesday, August 21, 2013 3:13 PM f� I To: Regg, James B (DOA); Barr, Kevin; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Jolley, Liz C; Guo, Haibin; Kanady, Randall B Cc: Tiedemann, Brian; Bordelon, Toby; Schwartz, Guy L (DOA) Subject: RE: 7ES BOPE 8-20-13 Jim, You are correct we are working under Sundry Approval 313-276. The I A-07 has a FMC GEN I casing head which is only rated to 3000 psi, therefore limiting the test pressure to 3000 psi. The MASP, listed in the workover procedure, on 1A-07 is well below the test pressure at 2037 psi. The 3000 psi casing head limit was listed in the workover procedure and the rig recognized the 3000 psi casing head limit and only tested the BOP to 3000 psi,however a request to the AOGCC for a waiver to lower the test pressure to 3000 psi was missed. We acknowledge that the 3000 psi BOP test pressure should have been requested in the sundry. We appreciate the AOGCC catching this error and will work to not repeat this same mistake in the future. Scott Heim/ Lee Hinkel/ Edward Oglesby Nabors 7ES Rig Supervisors 659-7844 Office 659-7247 Rig Floor DEC�,��A"•"'_Q 1 0 ZU 13 From: Regg, James B (DOA) [mailto:jim.regg@aalaska.gov] Sent: Wednesday, August 21, 2013 12:45 PM To: Barr, Kevin; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA) Cc: Nabors 7ES Company Man; Tiedemann, Brian; Bordelon, Toby; Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: 7ES BOPE 8-20-13 Are you working under Sundry Approval 313-276? if so,required BOPE test pressure is 3500psi unless you have some other approval from AOGCC. Jim Regg AOGCC 333 W. 7th Ave,Suite 100 Anchorage, AK 99501 907-793-1236 From: Barr,Kevin [mailto:Kevin.Barr @nabors.com] Sent: Wednesday,August 21,2013 7:09 AM To: Regg,James B(DOA);DOA AOGCC Prudhoe Bay;Brooks,Phoebe L(DOA) Cc:n2364conocophillips.com;Tiedemann,Brian;Bordelon,Toby Subject: 7ES BOPE 8-20-13 Kevin Barr Tour Pusher Nabors Alaska Drilling Rig 7ES Direct(907)6597847 Cell(907)602-0767 kevi n.barr(&nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly confidential. If you are not the intended 1 • 'recipient of this message, you may not disclose, print, copy, or disseminate t is information. If you have received this in error, please reply and notify the sender(only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. 2 ` V OF Thy • • I s THE STATE A.1 011 Gas °f s C II5C rvatio Commission At) ik. _ = ,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue f3• 44.LASI - Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Haibin Guo p,NNE4 SUN 1 2° Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 1 3r/ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-07 Sundry Number: 313 -276 Dear Mr. Guo: Enclosed is the approved Application for 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 'c" Daniel T. Seamount, Jr. Commissioner DATED this / a day of June, 2013. Encl. 4-2 a „ i n `cam', Li; STATE OF ALASKA ,! � � A KA OIL AND GAS CONSERVATION COMA ION � , i :, `' ''n' APPLICATION FOR SUNDRY APPROVALS b'� r 20 AAC 25.280 A' )c. -.. v 1. Type of Request: Abandon I Plug for Redrill f""` Perforate New Pool r Repair w ell jam". Change Approved Program r- Suspend E" Plug Perforations E Perforate j"""" Pull Tubing I. Time Extension E Operational Shutdown l Re -enter Susp. Well r Stimulate E Alter casing ; Other: r`" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1--- Exploratory r 181 -137 • 3. Address: Stratigraphic r J Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20658 - 00 . 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes E No 57 1A - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25647. Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8704 • 6443 8071' 8537' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 88' 88' SURFACE 2439 10.75 2470' 2213' PRODUCTION 8624 7 8656' 6404' Perforation Depth MD (1 8126 -8220, Perforation Depth TVD (ft): 5971 -6049, Tubing Size: Tubing Grade: Tubing MD (ft): • 8232 - 8249, 8404 - 8413, 8422M8443, 8445 - 8466 6058 -6072, 6198 -6205, 6212 -6230, 6231 -6248 3.5 x 2.875 J -55 8324 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 8037 TVD= 5899 - PACKER - BAKER FB -1 PACKER W /SBE CROSSOVER TO 2 7/8" TI MD= 8301 TVD= 6114 • SSSV - CAMCO TRDP -1A ENC SSSV MD= 1781 TVD =1740 • 12. Attachments: Description Summary of Proposal 1;;,- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch E Exploratory E Stratigraphic r" Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil E Gas E WDSPL r- Suspended E 16. Verbal Approval: Date: VVINJ GINJ I` WAG ri gf Abandoned E Commission Representative: GSTOR I SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265 -1487 Email: Haibin.Guoeco0.com Printed Name Haibin Guo Title: Drilling Engineer r Signature �' _ , Phone: 265 -1487 Date v 6- 4 2 - 6 s Commission Use Only Sundry Number: 3 -al (49 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 1 BOP Test V Mechanical Integrity Test 19 Location Clearance r Other: B f�St ¢O 35 9O /DSc. , \ l - �-I d --1,-- . ,mot /7 rrl v/'rec/ G ftr to l !► 3 rc� c�/a �"�`� Spacing Exception Required? Yes D No Subsequent Form Required: /0 -4 0 4- APPROVED BY (./J/13 Approved by' COMMISSIONER THE COMMISSION Date: Approved application is valid tor 12 months trom the date of approval. Form 10 -403 (Revised 10/2012) Submit Foac and Attachments in Duplicate 1/& ORIGINAL RBDMS JUN 11 201. �/ � (4\4\') • • ConocoPhillips : .e Alaska 2 O13 P.O. BOX 100360, ANCHORAGE, ALASKA 99510 -0360 01 C May 30, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 1A- 07 (PTD# 181 -137). Well 1A -07 was originally completed in October 1981 as a 3 -1/2" selective water injector. The well has been shut in since 2009 due to subsidence induced tubing /casing damage and surface casing leaking. The purpose of the workover is to remove the existing 3 -1/2" tubing completion, cut and replace 7" casing at –2000' MD (just above TOC), cement 7" casing to surface; pull the upper Baker FHL casing packer, mill & retrieve the lower Baker FB -1 packer, cleanout to PBTD; run new 3 -1/2" selective completion string. If you have any questions or require any further information, please contact me at 265-1487. Sincerely, —1±CVI; (9 Haibin Guo Drilling Engineer CPAI Drilling and Wells II • • 1A -07 Rig Workover Subsidence casing repair Replace -1 2" selective completion e ace 3 / s p p (PTD #: 181 -137) Current Status: This well has been shut in since September 2009. CV lock ring fish was left in hole at 8,537' RKB. Well is secured with WRP at 8,071' RKB in 3 -1/2" tubing. Scope of Work: Remove the existing 3 -1/2" tubing completion, cut and replace 7" casing at 2000' MD (just above TOC), cement 7" casing to surface; pull the upper Baker FHL casing packer, mill & retrieve the lower Baker FB -1 packer, cleanout to PBTD; run new 3 -1/2" selective completion string. General Well info: Well Type: Water Injector MPSP: 2,037 psi (Current surface pressure T /I /0= 500/180/250 psi) Reservoir Pressure /TVD: 2,640 psi / 8,200' MD/ 6,032' TVD (8.5 ppg) from Panex gauges on 05/28/13. Wellhead type /pressure rating: FMC Gen 1 Retro, 7- 1/16" 5M top x 11" 3M bottom BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: CMIT -T x -IA, passed on 05/24/13. Earliest Estimated Start Date: July 01, 2013 Production Engineer: David Lagerlef / Dana Glessner Workover Engineer: Haibin Guo (265 -1487 / Haibin.Guo @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. CMIT T x IA to 2,500 psi. (Completed on 05/24/13) b. Pull WRP plug @ 8,071' RKB. c. Pull dummy valves @7,979' RKB and 8,701' RKB. d. RIH w/ dual Panex gauge, obtain 30 min. SIBHP. (Completed on 05/28/13) 2. RU E -line: a. RIH & fire a string shot at 8,096' RKB (in the middle of the first full joint above the blast joints). b. RIH with 2.5" RCT cut the tubing at — 8,096' RKB (in the middle of the first full joint above the blast joints). c. RIH & fire a string shot at 8,002' RKB (in the middle of the first full joint above PBR). d. RIH with 2.5" RCT cut the tubing at - 8,002' RKB (in the middle of the first full joint above PBR). 3. Set BPV within 24 hrs of rig arrival. Proposed Procedure 1. MIRU Nabors 7ES. 2. Pull BPV. Bleed off tubing and IA pressure. Kill the well with KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV, ND tree, NU BOPE & test to 250/3,500psi for 30min and chart. 4. Pull BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH and laying down the 3 -1/2 "" tubing. • • 1A -07 Rig Workover Subsidence casing repair Replace 3 -1/2" selective completion (PTD #: 181 -137) 6. PU and RIH with 7" casing scraper to top of tubing stub @8,002' RKB. Circulate hole clean. 7. RU E -line. MU and RIH with CBL, log from top of tubing cut to surface. 8. Determine the TOC and fire a string shot across the 2 collar above TOC. R/D E -line. 9. M/U and RIH with l 7" casing RBP and set at -100' above tubing cut and test. 10. M/U and RIH with 2nd 7" casing RBP and set at -500' below the TOC and test. 11. RIH with open ended DP and dump -50' sand on the top of RBP. 12. ND BOPE. ND tubing head with Hydratight Tensioners. 13. Spear 7" casing, pull into tension and re -land in slips. Cut off 7" casing growth. Tack weld slips to casing. 14. NU BOPE on casing head. 15. MU and RIH with 5 -1/2" MSC and cut 7" casing in the middle joint of the 2 full joint above TOC. TOOH. 16. Circulate out Arctic Pack from the 7" x 10 -3/4" annulus with heated diesel and seawater. 17. RU casing handling tools. POOH 7" casing and lay down. 18. MU and RIH with back -off tool and back -off casing stub. POOH. 19. MU and RIH with casing spear. Spear and recover backed off 7" casing stub. 20. RIH with new 7" TC -II casing with Halliburton ES cementer. Screw into top of 7" casing and pressure test. - 21. RU cement head and cement 7" x 10 -3/4" annulus to surface. 22. ND BOPE. Pull casing into tension and land in slips. Cut 7" casing and install packoff. 23. NU new tubing head and BOPE, pressure test to 250/3,500psi for 30min and chart. 24. MU and RIH with cement clean out assembly. 25. Drill out ES cementer and circulate well clean. Pressure test. POOH. - 26. MU and RIH with RBP retrieving tool, reverse circulate sand out. Latch top RBP and POOH. 27. MU and RIH with RBP retrieving tool and retrieve the lower RBP. 28. MU and RIH with overshot dressed for 3 -1/2" tubing with grapple. Engage tubing stub at 8,002' RKB, pull free and POOH. 29. MU and RIH with spear for 80 -40 PBR, latch into PBR and pull FHL packer free. POOH. 30. MU and RIH with overshot dressed for 3 -1/2" tubing with grapple. Engage tubing stub at 8,089' RKB, pull free and POOH. 31. MU and RIH with packer milling assembly. Mill the packer. 32. MU and RIH with spear. Engage with the packer and POOH. 33. MU and RIH with 7" casing scraper assembly clean the hole to PBTD. Circulate hole clean. 34. MU and RIH with new selective completion string. 35. Set packers and land tubing hanger and test. 1 j /t- 36. Pull the landing joint, install two -way check. 37. ND BOPE. 38. NU and test tree. Pull two -way check. . • 1 A -07 Rig Workover Subsidence casing repair Replace 3 -1/2" selective completion (PTD #: 181 -137) 39. Freeze protect through the SOV, set BPV. 40. RDMO Nabors 7ES. Post -Rig Work 1. Pull BPV. 2. RU Slickline: Pull SOV, run DV. Pull ball plug and rod, RHC plug from 2.813" nipple. 3. Turn well over to injection. Attachments: • Current Schematic • Proposed WO Schematic • Cement Program • Example wellhead drawing it nt. KUP • 1A -07 ConocoP ilhps '' ', Well Attributes Max Angle & MD TD Alaska, If Wellbore API /UWI Field Name Well Status Inca ( °) MD (ftKB) Act Btm (11613) rnrwcuhdnps , 500292065800 KUPARUK RIVER UNIT INJ 63.55 4,150.00 8,704.0 "' Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date ••• Well Conte - 1A -07, 1/30/2013951'12AM SSSV: LOCKED OUT Last WO: 12/9/1985 39.01 10/17/1981 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,419.0 8/25/2009 Rev Reason: WELL REVIEW osborl 1/30/2013 - -- Casing Strings HANGER. 27 ,� , ' r Casing Description String 0... String ID ... Top (111(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 31.6 88.0 88.0 65.00 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Stang ... String Top Thrd SURFACE 103/4 9.950 30.6 2,469.5 2,212.6 45.50 K - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.0 8,656.0 6,403.7 26.00 K -55 Tubing Strings Tubing Description String 0... String ID ... Top (1KB) Set Depth (f... Depth (TVD) ... ng Wt... String ... String Top Thrd TUBING 3.5'x2.875" I 31/2 I 2.992 I 27.0 I 8,323.8 'Set D 6,132.4 !String I J -55 BTC -AB MOD Completion Details Top Depth (TVD) Top Incl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) CONDUCTOR, 27.0 27.0 - 0.28 HANGER FMC GEN 18 HANGER 3.500 32 - 88 1,781.0 1,740.3 31.56 SAFETY VLV CAMCO TRDP- 1A -ENC SAFETY VALVE (Locked Out 10/20/94) 2.812 SAFETY VLV, 8,023.7 5,887.7 34.64 PBR BAKER PBR 3.000 1,781 8,037.3 5,899.0 34.87 PACKER BAKER FHL PACKER 3.000 mou 8,114.0 5,961.5 35.21 BLAST JTS STEEL BLAST JOINTS (7) 2.296 8,286.0 6,101.7 35.83 NIPPLE AVA BPI PORTED NIPPLE. SET 11/27/2005 2.296 8,298.9 6,112.2 35.78 LOCATOR BAKER LOCATOR 2.438 8,300.7 6,113.6 35.54 PACKER BAKER FB-1 PACKER w /SBE CROSSOVER TO 2 7/8" TUBING 4.000 8,315.7 6,125.8 35.51 NIPPLE CAMCO D NIPPLE NO GO 2.250 SURFACE. • • 8,323.1 6,131.9 35.49 SOS CAMCO SHEAR OUT SUB. **ELMD TTL @ 8322 ON (PROF 2.441 31 - 2,470 8/22/2007" fi Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) f ) Top Depth GAS LIFT, (TVD) Top Inc! 7,979 Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 8,070.5 5,926.1 35.08 PLUG WRP w/2.78" RUNNING OD 8/29/2009 0.000 8,286.0 6,101.7 35.83 SLEEVE -C AVA 2.75 "BPI 11/27/2005 2.313 8,537.0 6,306.4 35.12 FISH Baker PKR Assembly Milled & pushed to rathole during 12/9/1985 0.000 H. workover PBR, 8,024 Perforations & Slots Shot PACKER. 8,037 r - Top (TVD) Btm (TVD) Dens III Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 8,126.0 8,220.0 5,971.4 6,048.5 C-4, C-3, C -2, 2/10/1982 4.0 IPERF Enerjet 1A -07 PLUG, 8,071 /L it 8,232.0 8,249.0 6,058.1 6,071.8 C -1, 1A -07 2/10/1982 4.0 IPERF Enerjet 8,404.0 8,413.0 6,197.7 6,205.1 A -5, 1A -07 2/11/1982 12.0 IPERF Thru- Tubing INJECTION, 8,422.0 8,443.0 6,212.4 6,229.6 A-4, 1A -07 2/11/1982 12.0 IPERF Thru - Tubing - 8,078 _ - - - - , 8,445.0 8,466.0 6,231.2 6,248.4 A-4, 1A -07 2/11/1982 12.0 IPERF Thru - Tubing Notes: General & Safety . End Date Annotation 1/24/2001 NOTE: Obtained C -Sand static © 8000' 8 8188' RKB IPERF, - 11/27/2005 NOTE: LEAK @ 8283' 8,126 - 8,220 l = 7/30/2010 NOTE: View Schematic w/ AlaskaSchematic9.0 5/14/2011 NOTE: Erratic weight swings from 8071' -4600' & 1900' -1500' IPERF. 8,232.8,249 = - - SLEEV8.286 I E -C, n NIPPLE. 8.286 -- LOCATOR, 8,299 • , PACKER, 8,301 jti'_ a NIPPLE,8,316 - i t SOS, 8,323 -� IPERF. Mandrel Details 8,404 -8,413 Top Depth Top Port (TVD) 1961 OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 7,978.7 5,850.9 34.94 MERLA TPDX 1 12 GAS LIFT DMY RM 0.000 0.0 10/26/2009 8,422-8,4 3 111 2 8,075.9 5,930.5 35.11 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 6/9/1988 IPERF, II 8,445,468 468 FISH, 8.537 -4 PRODUCTION. 32 -8,656 I TD, 8.704 • • ConocoPhillips Well: 1A-07 2013 RWO PROPOSED COMPLETION (New (term in RED) API: 500292065800 Conductor: PTD: 181 -137 16 ", 62.5 #, H -40 to 88' Wellhead: FMC Gen I Retro X -mas Tree: 3 -1/2 ", 5K psi Surface Casing: Lift Threads: 3 -1/2" 8rd EUE DS 10 -3/4 ", 45.5 #, K -55 to 2469' BPV: 3" 'ISA' Proposed 3 Completion Production Casing: 7 ", 26.0 #, K -55 to 8656' • Tubing, 3 9.3 ppf, L -80, 8rd EUE. • Camco 2.875" DS nipple at -500' r r 1 Perfora MD. � MD Zone • Gaslift Mandrel MMG at - 7872' MD. 8126' - 8220' C2 -C4 • Packer, Baker FHL packer w /PBR at 8232' 8249' 01 7954' MD. 1 8404' - 8413' A5 •Water injection Mandrel MMG -W at 8121' MD. 8422' - 8443' A4 • Backer CMU sliding sleeve at -8176' A IL 8445' - 8466' A4 MD. I • Baker FB -1 packer at -8301' MD. J 1 GLM MMG at -7872' MD • HES 2.813" XN nipple at -8366' MD. PBR at 7927' MD Gas Lift Mandrels: ~Baker FHL Packer at 7954' MD Type MD TVD MMG, 1.5" -7872' -5764' J • Water Inject MMG -W at 8121' MD Water Injection Mandrels: — Type MD TVD = • _�_ Baker CMU sliding sleeve w/ MMG -W, 1.5" -8121' -5967' 2.813" X Profile at - 8176' MD E ~ Baker FB -1 Permanent Packer at -8301' MD Directional: XN ~- HES 2.813" XN nipple at -8366' MD Max Incline: 63.6° @ 4150' Max Dogleg: 14° @ 325' — / \ — A ■ Fill at: 6,549' SLM Last Updated: 31- May -13 TD: 8,704' RKB Updated by: HB • • 1 A -07 Schlumberger CemCADE Preliminary Job Design 7" Tieback (Vi ) Preliminary Job Design based on limited input data. For estimate purposes only. Rig: 7ES Location: Kuparuk Client: CPAI Revision Date: May 30, 2013 Volume Calculations and Cement Systems Prepared Anchorage, he mp Houston Volumes a re based on casin /casin annulus volumes. Standard practice is to pump Anchorage, AK g g p p p Phone: (907) 263 - 4207 - 20% excess on top of this to ensure good cement to surface, but this can change based Mobile: (907) 223 -8916 on current well conditions and losses. email: jhouston2 @slb.com Tail Slurry Minimum thickening time time: -360 min. (client request) AS1 - 0.93ft3 /sk 0.2727 ft /ft x 2000 = 546 ft 0.2148 ft /ft x 80 = 18 ft Add 17 ft to kick out plug 546 ft + 18 ft + 17 ft = 581 ft Previous Csg. 581 ft 0.93 ft /sk = 625 sks 10 -3/4 ", 45.5# casing at 2,000 MD BHST = 62 °F, Estimated BHCT = 71 °F. (BHST calculated using a gradient of -2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulat Comment Stage Volume the Time (bpm) (bbl) (min) (min) Fresh Water 5.0 5.0 1.0 1.0 Fresh water ahead AS1 10.0 10.0 2.0 3.0 Neat AS1 ahead AS1 80.2 42.5 16.0 19.0 AS1 with 2 lb/bbl CemNET AS1 10.0 10.0 2.0 21.0 Neat AS1 behind Drop plug 0 0 5.0 26.0 AS1 3.0 3.0 0.6 26.6 Kick out plug with AS1 Fresh Water 5.0 5.0 1.0 27.6 Fresh water behind Seawater 6.0 55.5 9.3 36.9 Displace Top of Cement at surface Seawater 3.0 10.0 3.3 40.2 Slow to bump plug MUD REMOVAL Expected Mud Properties: -8.6 ppg Seawater 7 ", 26# casing at 2,000' MD Mark of Schlumberger ■ • • 7 / - 3 1/8 -5000 (R -35) 0 rji =11 a ¢.1 III11ii Ii I =61.1 CI I I 7 1/16 -5000 (R-461 `� 0 Ian a�= 0 .I! ��. ...L A 101 • I,_ • il I-- �6 r i I 54-59 I -V ---------IS �ii EMI ■ t i - III J Q �I I II I • O -1 1� - I 1 #� 1 e W I 41.69 0 lNI ' : all t!iIIIJl , •., ® M :11 -3000 (R -531 3000 I I ' I 0 1i1 �', _ 11 1925 0 I - III ` - • I II a� II \ ri lb:0 1 11 � ` I II Iv �_ I_I �, ► 0' IIi I 0 1 3.6o DS p I •II ' 52 7 11 i s 5 -1 _- '��ONERTER HEAD 19-100 -230 L. k I I - O 16'0D 9 5/8' CSG J ^,---___,\ 7'00 CSG `3 I /2'T8G A I'z CO ALASKA INC. (KUPARUK FIELD) 1ITEM II PART NUMBER II DESCRIPTION I 13 -140 -660 LANDING RING. 16' 5.0. 2 12- 130-319 CASING HANC.FR .9 5/R R (ST 0 3 13- 300 -4414 CASING HD 0557.0 -29 11 3/4' B CSG X C 11 -3K W/ 2 I/16 -3K STDD OUT O 4 12- 090 -IT7 SLIP BOWL ASSY, II X 7 REF: SH - 10925 5 83- 600 -6274 TWO HO 8 55 0 M - . , > 11 -3K X 7 1 /16 - M I/16-5K W/ 2 1 /16 -SK OUT'S �� DM maw 0 6 83 -160 -328 REDUCER BUSHING ASSY. 9 % 7 _ 0 T 82- 747 -236 HUNGER, IC- IA -EN, 7 /16 X 3 1/2'00 EUE. IS-B WELLHEAD SYSTEM, . , , - ,- _, OWOR.,o, o B 02-043 - 61BA ADAPTER, 8 -4,7 1 /16 -5K % 3 1 /8 -5K W/ GEN. IV KUPARUK "`KZ - 55 "MT. ^I+ O BTM PREP F/ 5.495 EN SLICK HGR sma 9 12- 140 -212 PACKOFF ASSY. C - 75. IL X 7 EU I PMENT 76...7„r 01-1T5 3.. """°' :c ._,,_ 00000141000549 I ■ • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, June 04, 2013 3:38 PM To: 'Guo, Haibin' Subject: RE: Sundry Application: KRU 1A -07 (PTD 181 -137) Thank you. Your email will be sufficient. Patricia From: Guo, Haibin [ mailto :Haibin.Guo ©conocophillips.com] Sent: Tuesday, June 04, 2013 3 :35 PM To: Bettis, Patricia K (DOA) Subject: RE: Sundry Application: KRU 1A -07 (PTD 181 -137) Hi Patricia, Yes, you right it should be stated as a wag injector. It has been a wag injector before and is also planning to inject water and gas in future. Can you help to mark the "wag" box? If you need us resubmit the application please let me know. Thanks. Haibin Guo Senior Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.227.6048 From: Bettis, Patricia K (DOA) [ mailto :patricia.bettis ©alaska.gov] Sent: Tuesday, June 04, 2013 3:11 PM To: Guo, Haibin Subject: [EXTERNAL]Sundry Application: KRU 1A -07 (PTD 181 -137) Good afternoon Haibin, The AOGCC records show the current status of the KRU 1A -07 well as a wag injector. In Box 15 of the application, water injector is indicated. Would you verify which is correct? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 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 1 • • 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 Patricia Bettis at (907) 793 -1238 or patricia.bettis@alaska.gov. 2 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM JAN 2 0 20 To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Attachments: CPAI Failed MITIA Monthly Data 12- 10_edit.xls Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1B -02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1A-12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. rom: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Se • Saturday, January 01, 2011 10:55 AM To: Res ► James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK We tegrity Proj; NSK Problem Well Supv Subject: Conoco' • illips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the Conoco' . illips monthly injector report for December 2010. Please contact me at your convenience if you ha - questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2011 • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 - 7000 #909 • • ConocoPhillips Well 1A-07 Injection Data • Tbg Psi IA Psi • OA Psi I 4000 3500 3000 2 2500 - o. a 2000 - 1500 - 1000- 500 0 NM M 09/10 10/10 11/10 12/10 01/11 Date PTD# 181 -137 MITIA failed on 11/13/09 Suspected TxIA Communication 7/28/2009 Suspected Surface Casing Leak 12/15/2009 Well last injected 4/08 • • ConocoPhillips Well 1A-07 Injection Data • Water Injection ® Gas Injection I 4000 3500 - 3000 - .2 2500 - a a 2000 1500 1000 - 500 - 0• 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 7 500 150 30- Dec -10 0 0 1 500 150 29- Dec -10 0 0 -4 500 150 28- Dec -10 0 0 -3 500 150 27- Dec -10 0 0 -1 500 150 26- Dec -10 0 0 3 500 150 25- Dec -10 0 0 10 500 150 24- Dec -10 0 0 12 550 150 23- Dec -10 0 0 -5 550 150 22- Dec -10 0 0 -20 550 150 21- Dec -10 0 0 -14 500 150 20- Dec -10 0 0 -14 500 150 19- Dec -10 0 0 -19 500 150 18- Dec -10 0 0 -20 500 150 17- Dec -10 0 0 -20 500 150 16- Dec -10 0 0 -18 500 150 15- Dec -10 0 0 -18 500 150 14- Dec -10 0 0 -19 500 150 13- Dec -10 0 0 -16 500 150 12- Dec -10 0 0 -19 500 150 11- Dec -10 0 0 -21 500 150 10- Dec -10 0 0 -19 500 150 9- Dec -10 0 0 -19 500 150 8- Dec -10 0 0 -19 500 150 7- Dec -10 0 0 -20 500 150 6- Dec -10 0 0 -20 500 150 5- Dec -10 0 0 -19 500 150 • • 4- Dec -10 0 0 -16 500 150 3- Dec -10 0 0 -19 500 150 2- Dec -10 0 0 -19 500 150 1- Dec -10 0 0 -18 500 150 30- Nov -10 0 0 -22 500 150 29- Nov -10 0 0 -20 500 150 28- Nov -10 0 0 -17 550 150 27- Nov -10 0 0 -16 550 150 26-Nov-10 0 0 -15 550 150 25- Nov -10 0 0 -13 550 150 24- Nov -10 0 0 -11 550 150 23- Nov -10 0 0 -7 500 150 , 22- Nov -10 0 0 -9 500 150 21- Nov -10 0 0 -12 500 150 20- Nov -10 0 0 -10 500 150 19- Nov -10 0 0 -13 600 150 18- Nov -10 0 0 -10 600 150 17- Nov -10 0 0 -9 600 150 16- Nov -10 0 0 -16 600 150 15- Nov -10 0 0 -19 600 150 14- Nov -10 0 0 -19 600 150 13- Nov -10 0 0 -16 600 150 12- Nov -10 0 0 -16 600 150 11- Nov -10 0 0 -15 600 150 10- Nov -10 0 0 -16 600 150 9- Nov -10 0 0 -15 600 150 8- Nov -10 0 0 -13 600 150 7- Nov -10 0 0 -13 600 150 6- Nov -10 0 0 -13 600 150 5- Nov -10 0 0 -9 600 150 4- Nov -10 0 0 -11 600 150 3- Nov -10 0 0 -15 600 150 2- Nov -10 0 0 -16 600 150 1- Nov -10 0 0 -14 600 150 31- Oct -10 0 0 -13 600 150 30- Oct -10 0 0 -10 600 150 29- Oct -10 0 0 -10 600 150 28- Oct -10 0 0 -14 600 150 27- Oct -10 0 0 -13 600 150 26- Oct -10 0 0 -12 600 150 25- Oct -10 0 0 -9 600 150 24- Oct -10 0 0 -10 600 150 23- Oct -10 0 0 -9 200 700 22- Oct -10 0 0 -9 200 700 21- Oct -10 0 0 -10 200 700 20- Oct -10 0 0 -14 200 700 19- Oct -10 0 0 -10 200 700 18- Oct -10 0 0 -11 200 700 17- Oct -10 0 0 -12 200 700 16- Oct -10 0 0 -13 200 700 15- Oct -10 0 0 -14 200 700 14- Oct -10 0 0 -13 200 700 • • 13- Oct -10 0 0 -13 200 700 12- Oct -10 0 0 -13 200 125 11- Oct -10 0 0 -13 200 125 10- Oct -10 0 0 -13 200 125 9- Oct -10 0 0 -15 200 125 8- Oct -10 0 0 -15 200 125 7- Oct -10 0 0 -13 200 150 6- Oct -10 0 0 -11 200 150 5- Oct -10 0 0 -8 200 150 4- Oct -10 0 0 -8 200 150 3- Oct -10 0 0 -9 200 150 2- Oct -10 0 0 -10 200 150 • 410 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, December 15, 2009 2:31 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark Subject: KRU 1A -07 (PTD# 181 -137) Report Of Surface Casing Leak Attachments: 1A -07 Wel!bore Schematic.pdf; 1A -07 TIO Plot.pdf Jim /Tom /Guy, Kuparuk WAG injector 1A -07 (PTD# 181 -137) is suspected of having a surface casing leak based upon results of a survey using an echometer and OA gas injection. Additional troubleshooting will begin as soon as feasibly possible. The well is shut in and is on the monthly report. Attached is a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. JAN 0 ?)$ Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2011 Well Name 1 A -07 Notes: End Date 1/1/2010 Days 120 Start Date 9/3/2009 Annular Communication Surveillance 400 _ — - 1.2 WHP _ IAP 350 OAP U" – 1 300 ' – 0.8 • 250 L1 cr1 Q 200 0.60 150 0.4 100 – 0.2 50 0 — 0 Sep -09 Oct -09 Nov -09 Dec -09 1 0.9 — DGI 0.8 — �MGI 0 —amem 0.s - -SWI c o.5 •BLPD v 0.4 — 0.3 0.2 0.1 0 Sep -09 Oct -09 Nov -09 Dec -09 Date WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 5, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 1A -07 Run Date: 9/25/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 20658 -00 Eit,MNED D 2 2D09 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 1 3 3 6900 Arctic Blvd. Oa Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburton.com `LOC`) Date: Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 11, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1A -07 Run Date: 8/29/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 20658 -00 ;:3LVINED NO J 2 7 2009 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto it/ 1 3 r 35v 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto@halliburton.com E 7; Date: NOV 11 70n Signed: laska ()ii l<4 Gas Cots Co!p Tv5 pop Anchoraac ~ .__ ~ ~;;.~, ~ 3~~ PrtoAcme Dinynosric SeevicES, I~. 1/tfELL LOG TR~4~~~1/7°T'~4L To: A~C Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTJ The technical data tisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, lnc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~~ _ _ `~~~°,~~ ProActive Diagnostic Services, Inc. Attn: Rabert A. Richey 130 West lnternational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ~~re l~l - ~3~ ~ ~S ~~~1 1) Caliper Report 11 Sep-09 1 A-07 1 Report / EDE 50-029-2065&00 2) Signed : Print Name: Date . _ - _ , ~ _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, QK 99518 PHONE: (90T~245-8951 FAx: (907)245~8952 E-MAIL : C WEBSITE . . ;, C ~Documznts and Settings\Owne[\Desktop\Transmit_BP.docx I ' ,11 ~ _ ; • • Memory Multi-Finger Gsliper LQg Resufts Summary Company: Conor,oPhillips Alaska, Inc. Well: 1A-07 Log Date: September 11, 2009 Field: Kuparuk Log No. : 10589 State: Afaska ' Run No.: 1 API No.: 50-029-20658-00 Pipe1 Desc.: 3.5" 9.3 Ib. J-55 AB MOD BTC Top Log Intvi1.: Surt~ce Pi e1 Use: Tubing Bot. l.og Intv11.: 8,054 Ft. (MD) Inspection Type : Corrosive 8 Me+chanical Damage /nspection COMMENTS : ^ This caliper data is tied into the PBR @ 8,022' (Driller's Depth). ' This log was run to asse5s the condition of the tubing with respect to corrosive and mechanic~l damage. The caliper recordings indicate the 3.5" tubing logged is in good condition, with no significant watl penetrations or areas of cross-sectional wall loss recorded. Although not presenting a significant I.D. restriction, the caliper reeordings indicate scale-fike deposits throughout the interval logged. ' The caliper recordings indicate slight to moderate buckling over the interval above SSSV (surtac~ - 1,774'), and slight buckling over the interval betow SSSV (1,786' - 8,054'). MAXIMUM RECORDED WALL PENETRATIONS: Na significant watl penetrations (> 16%) are ~ecorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTlONAL METAL LOSS: No significant areas of cross-sectional wall loss (>'%) are reeorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. •,r:~~, ' .,N ~ _ ~~U~;; Field Engineer: G. Etherton Analyst: HY. Yang Witness: R. Ober I~ ProActive Diagnostic Services, Inc. J F,O. Box 1369, Staffiard, TX 7?497 Phone: (281} or (888) 565-9085 Fax; (281) 565-1369 E-mai(: PDSC~memaryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax; (907} 659-2314 ' ''i I u~ ~~ r=~ 3~- ~~ ~~~s • ~ Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (-12.7' - 8047.6') Well: 1 A-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: September 11, 2009 . A pprox. Tool D eviation ^ A pprox. Boreho le Profil e -6 739 1501 22 78 3051 ~ ~ 3818 ,i c t ~ Q. a~ 4588 ~ 5350 6123 6899 7668 GLM 1 261 8048 0 5 0 1 00 Dam age Pr ofile (°/a wall) / Tool D eviatio n (degre es) Bottom of Survey = 261 7 25 SO 7~ 100 w ~ 125 ~ Z c ° 150 175 200 225 250 • • PDS Report Overview ; s. Body Region Analysis Well: 1 A-07 Survey Date: Septernber 11, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fngers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 93 f -55 Aft MOD BTC 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetretion and Metal Loss (%wall) ~ penetration body ~ metal loss body 250 200 750 100 50 ~ 0 to 1 to 10 to 20 to 40 ro over 1% 10% 'L~% 40% 85% 85% Number of'oints anal s ed total ~ 266 pene. 0 217 49 loss 178 88 0 0 0 0 0 0 0 Damage Configuration ( body ) 10 0 isola[td general line rirQS hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body . r-~, ~; metal loss body 0 50 100 n GLM 1 Bottom of Survey = 261 -_ Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 AB MOD BTC Well: 1 A-07 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 11, 2009 )oint No. )t. Depth (Ft.) 1'c•n. t l~,sc~t Iin~.) Pen. Body (Ins.) Pc~n. % Metal I oss `i~ Min. I.D. (Ins.) Comments Damage Profile (°/a wali) 0 50 100 .1 -13 i~ 0.01 Z I 2.96 PUP .2 -8 ~~ 0.01 ~ ~1 2.94 PUP 1 -6 u 0.03 1 1 ? .96 li ht buckli . 2 26 U 0.03 i l) 2.96 3 57 U 0.03 1 Z ' 2.94 4 90 (~ 0.03 1~' _' 2.9 5 1 0 l) 0.02 ~~ I 2.93 6 152 U 0.02 tt i j 2.93 Sli h buckl~n . 7 183 O 0.03 1l1 I 2.94 8 215 O 0 02 '~ 1 2.94 9 246 O 0.01 5 1 2.93 10 276 l) 0.01 5 ~~ 2.94 11 305 O 0.01 (> ~) 2.93 Sli htbucklin . 12 336 t~ 0.02 ~~ ' .95 13 367 ~~ 0.01 - ~' 2.93 14 99 u 0.01 5 I 2.95 15 430 u 0.02 ~~~ ~. ~ 2.93 16 462 U 0.02 9 U 2.93 Sli t bucklin . 17 490 t~ 0.02 7 .' 2.93 18 522 i1 0.03 12 u 2.92 19 552 ~~ 0.03 11 ~~ 2.94 20 584 !~ 0.01 -1 ~~ 2.95 21 6 6 ~1 0.03 1 U 1 2.93 SI' ht buck in . 22 647 (1 0.03 1O I 2.95 23 677 t) 0. 2 (3 ~~ .94 24 708 l) 0.02 ~) 1 2.94 25 739 U 0.01 0 1 2.94 26 768 U 0.01 2 1 2.93 Sli ht bucklin . 27 799 t) 0.0 ~~ ~' 2.92 28 831 t~ 0.01 2 ~' 2.93 29 861 U 0.01 5 I 2.93 30 893 ~~ 0.01 ? 1 2.89 31 923 ~~ 0.01 1 ~~ 2.92 Sli ht b cklin . 32 951 t a 0.01 ~~ 2.93 33 983 t~ 0.0 1,? 2.93 34 1014 U 0.01 4 2.91 35 1044 U 0.01 4 _' 2.90 36 1074 ti Q.01 ? ~' 2.92 Sli ht ucklin . 37 1105 ~~ 0.01 5 s 2.96 38 1137 U 0.02 i) ~ 2.94 39 1167 U 0.01 2 U .90 40 1196 U 0.01 4 I 2.94 41 1227 U 0.01 2 2 .94 Sli ht bucklin . 42 1258 (~ 0.01 Z I 2.94 43 1289 ~'~ 0 01 ~' i 2.91 44 1319 ~~ 0.01 ~t u 2.92 45 1351 ~~ 0.01 2 ~ 1 2.90 46 1380 ~~ 0.01 4 I 2.95 Sli ht bucklin . 47 1410 0.01 ~i ' 2.96 48 7 440 0.01 a 2.94 ~ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 93 ppf J-55 AB MOD BTC Well: 1 A-07 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 11, 2009 Joint No. Jt. Depth (Ft.) I'c~n. l lE,.ct I'In~.) Pen. Body (Ins.) Pc~n. % :Vtetal I o~s °~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1471 U 0.01 5 .96 50 1501 u 0.02 9 3 Z.96 51 15 0 t~ 0. 8 ~' 2.95 Sli tbuckli . 52 1561 ~ ~ 0.01 ' ~ ~ 2.90 53 1589 ~ ~ 0.03 I i i I 2. 6 4 1619 U 0.02 t3 I 2.93 55 1650 U 0.01 `> ~~ 2.9 56 1682 ~~ 0.02 `i 2.94 Sli h bucklin . 57 1712 0 0.01 d .9 58 1743 l? 0.01 4 1 95 58.1 1774 t~ 0 ~) U 2.81 Camco TRDP-1 A-ENC SSSV 59 1786 c~ 0.02 ti 1 2.96 60 1817 ~~ 0.0 8 ~1 .93 61 7 848 t~ 0.01 (~ ' .9 ~ 62 1877 ~~ 0.02 ~~ _' 2.94 Sli ht bucklin . 63 1907 ~~ 0.01 4 u 2.93 64 1937 ~~ 0.01 4 I 2.94 65 1969 ~ ~ Q03 1 ;t ! .96 6 2000 ~ ~ 0.01 4 ' .96 67 2031 U 0.01 ~_' U .92 Sli ht ckli . 68 2061 U 0.02 ~? ~ 2.94 69 2093 c) 0.01 5 ~ 2.95 70 21 4 ~) 0.02 9 U 2.93 71 2154 U 0.02 9 2 2.91 7 21 5 U 0.03 11 U .93 73 2216 U 0.03 11 ~ 2.94 74 2247 U 0.03 12 I 2.9Q Sli ht buckfn . 75 2278 ~) 0.03 13 i) 2.93 76 2310 ~~ 0.03 1:3 I 2.97 77 2342 u 0.01 -~ i~ 2.95 78 2372 t) 0.01 -1 ~! 2.94 79 24U3 u 0.01 5 ~. i 2.93 8U 24 4 ! ~ 0.02 ~~ ~~ 2.93 81 2466 t1 0.01 5 I 2.94 82 2497 0 OA 9 I 2.94 Sli 1 t bucklin . 83 2529 U 0.01 ~' ~ 2.94 84 2560 ~1 0.01 ~' u 2 90 85 2590 t~ 0.01 4 I 2.93 86 2621 ~~ 0.01 -~ i i .94 87 2653 ~1 0.01 5 ' 2.97 Sli htbucktin . 88 2683 (~ OA2 f3 _' .93 89 2713 ~) 0.03 I U 1 2.96 90 2743 l1 0.03 I f 2 2.94 91 2773 ~) 0.02 9 ~~ 2.97 92 2 804 O 0.02 i3 ? 2.96 93 2833 ~~ 0.01 a I 2.96 94 2863 ~~ 0.01 4 I 2.94 95 2894 tl 0.03 I~? 2.95 Sli ht bucklin . 96 2925 0.01 1 2.94 97 2956 ~ 0.01 ~ 2.93 ~ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 AB MOD BTC Weil: 1A-07 6ody Wall: 0.254 in Field: Kuparuk Upset Wail: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 1 1, 2009 )oint No. Jt. Depth (Ft.) I'c~n. ( lF,tic~t (In,.j Pen. Body (Ins.) Pc~n. % ti1c~i,il I oss °~~, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 98 2987 U 0.03 10 2.95 99 3019 t) 0.01 2 ~ 2.96 1 0 3051 ~1 0.01 2 I 2.95 Sli ht bucklin . 101 3080 ~~ 0.02 ~3 I 2.93 102 3110 i) 0.01 2 ' 2.94 103 3141 ~~ 0.02 ~) i 2.93 104 172 u 0.02 '~ I .96 105 3202 ~~ 0.03 1> ; 2.97 Sli htbucklin . 106 3233 l1 0 01 4 4 2.96 107 3262 (~ .01 4 l1 2.94 108 3293 tl 0.01 2 ? 2.97 i09 3324 U 0.03 IU 6 2. 7 110 3355 ~~ 0.03 1 I 5 2.95 Sli ht bu klin . 111 338 t> 0.04 I~l i> 2.98 112 3414 i! 0.04 1-1 c, 2.97 113 3445 ~> 0.01 (~ -l 2.97 114 3475 U 0.01 4 1 2.95 115 3506 l) 0.01 5 U 2.95 Sli ht buckli . 116 3537 l~ 0.01 5 t) 2.94 117 3568 ~? 0.03 l:; 1 2.94 118 3598 i~ 0.02 ~~ (~ 2.94 119 3629 ~ i 0.01 ~3 U 2.94 120 3661 ll 0.01 ~ I 2.96 Sli ht bucklin . 121 3692 l) 0.02 t~ I 2.93 122 37 4 l) 0.01 ~1 i ~ 2.93 123 3756 tt 0.03 1 U F, 2.96 124 3787 ~) 0.02 ~) 2.94 725 3818 ~~ 0.01 4 3 2.96 Sli htbucklin . 126 3848 U 0.01 2 1 2.94 127 3879 (1 0.02 ~) 3 2.96 128 3910 U 0.01 Z I 2.94 129 3941 t~ 0.02 ~~ ~~ 2.92 130 3972 U 0.02 ~> (~ 2.98 Sli ht bucklin . 131 4003 U 0.01 5 ~~ 2.92 132 4035 t) 0.02 ~ ~~ 2.93 133 4065 ~) 0.02 9 I 2.93 134 4097 O 0.01 ~~ I 2.95 135 4129 t~ 0.01 t, t~ 2.93 Sli ht bucklin . 13 4160 ~~ 0.01 ~ 1 2.93 137 4191 U 0.01 ? I 2.93 138 4222 u 0.02 t5 I 2.94 139 4253 ~1 0.01 -1 ~) 2.95 140 4282 t) 0.01 4 I 2.94 Sli t bucklin . 141 4310 t~ 0.02 ~? U 2.93 142 434 ~) 0.01 4 ~ 2.92 143 4372 (~ 0.01 5 ~' 2.93 144 4404 (~ 0.01 t> ~~ 2.94 145 4436 c~ 0.02 fi I 2.90 Sli htbucklin . 146 446 ~' 0.01 4 2.95 147 4496 ~~ 0.02 ti ~.~ 2.93 Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Nipe: 3.5 in 9.3 ppf )-55 AB MOD BTC Well: 1A-07 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: September 11, 2009 Joint No. Jt. Depth (Ft.) Pc~n. t 1F„c~t (In~.j Pen. Body (Ins.) f'rn. °i<~ ~1~tctal I vss ",~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 148 4527 t) 0.01 i ' 2.93 149 4557 U 0.02 9 ~l 2.90 Lt De osits. 150 4588 t~ 0.01 (~ i~ 2.93 Sli ht bucklin I 151 4620 n 0.01 (~ !~ 2.93 152 4651 U 0.03 II i 2.93 1 3 4682 t) 0.01 ~ I 2.94 154 4714 t 1 0.01 5 ~~ 2.94 155 4744 U 0.02 ~) i 2.94 Sli ht bucklin . 156 4775 !~ 0 03 1 Z I 2.93 157 4806 t~ 0.01 4 ti 2.94 158 4836 ~~ 0.02 t~ _' 2.9 159 4865 i~ OA1 -~ ~~ 2.95 160 96 ~~ 0.01 _' 292 Sli ht bucklin . 1 1 4926 ~~ 0.01 -7 2.91 162 4957 U 0.03 13 I 2.92 lb3 4986 (l 0.01 4 ~i 2.93 164 5 17 U 0.01 ~ -1 2.95 165 5047 U 0.02 ~) ' 2.95 li ht bucklin . 166 5076 U 0.01 2 ~' 2.94 167 5107 t~ 0.01 5 Z 2.94 168 5136 !~ 0.03 1 1 1 2.93 169 5168 t ~ 0.01 1 I 2.93 170 5198 t~ 0.02 ti ~ i 2.89 Sli t bucklin . 171 5226 ~? 0.02 ~~ I 2.94 17 5256 U 0.0 t I 2.95 173 5287 !~ 0.02 9 U 2.93 174 5319 u 0.0 1l1 1 2.95 175 5350 U 0.03 12 ? 2.94 Lt. De osits. Sli ht bucklin . 176 5381 U 0.0 t3 ( ~ 2.94 177 5413 ~~ 0.03 1 1 I 2.95 178 5442 U 0.01 5 I 2.95 179 5472 U 0.02 ~~ I 2.94 180 5503 U 0.01 4 I 2.93 Sli ht bucklin . 181 5534 U 0.01 ~ 1 2.95 182 5567 ~~ 0.02 9 1 292 183 5599 i) 0.01 4 (1 2.93 184 5630 O 0.02 ~3 1 2.95 185 5660 t~ 0.~2 ~~ 1 2.94 Sli ht bucklin . 186 5691 ~~ 0.02 t3 1 2.92 187 5721 i~ 0.03 1; 2.96 188 5751 ~~ 0.04 I 4 ~± 2.94 189 5782 U 0.01 ~' I 2.93 190 5812 l~ 0.03 1tl t! 2.93 Sli htbucklin . 191 5843 U 0.02 ~) ; ti 2.93 1 2 587 ~) 0.03 1 1 6 2.96 193 5906 c~ 0.01 4 1 2.94 194 5938 ~? 0.03 1(1 -1 2.95 195 5968 t) 0.01 ? I 2.92 Sli ht bucklin . 196 5998 ~~ 0.02 t3 ~ 2.93 197 602 9 ~~ 0.01 ? 2.92 ~Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOfNT TABULATION SHEET Pipe: 3.5 in 93 pp( J-55 AB MOD BTC Well: 1 A-07 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 11, 2009 Joint No. )t Depth (Ft.) I'c~i~. UFxc~t Iln..) Pen. Body (ins.) Pc~n. ",b 1Actal I osc °i~ Min. I.D. (ins.) Comments Damage Profile (% wall) 0 50 100 198 6059 ~~ 0.02 9 1 2.93 199 6092 ~ ~ .02 '! ? 2.95 200 6123 U 0.0 t3 t! 2.94 Sli t bucklin 2 1 6154 ~~ 0.03 I~ ~ I 2.93 202 6186 ~~ 0.03 1 i_) ~ i 2.94 203 6216 U 0.02 ~ I .94 204 6247 c) 0.03 1 ~' ~ 2.93 205 6279 U OA ~~ I 2.93 Sli ht bucklin . 206 6309 U 0.0 I U 1 2.93 207 6341 t) 0.03 I<' s 2.93 t. D osits. 208 6373 O 0.02 ~) 1 2.96 209 6403 U 0.04 1 C~ I 2.92 210 6434 U 0.01 6 I 2.94 li ht buckl' 2 1 6465 ~~ 0.02 £~ U .93 212 649 7 t~ 0.02 '~ I 2. 94 21 6529 U 0.02 ~~ I 2.9 214 6559 U 0.02 8 I 2.94 215 6588 U 0. 2 9 U .91 Sli ht bucklin . 216 6619 ~) 0.04 14 ~ 2.94 217 6649 t) 0.03 1 U ~. ~ 2.92 21 S 6681 l 1 0.01 S 1 2.91 219 6711 t~ 0.02 ~~ I 2.94 2 6742 U OA2 8 t~ 2.93 Sli h bucklin . 221 6774 ~~ 0.02 ~) > 2.94 6805 U .03 11 1 .91 223 6837 U 0.02 9 U 2.93 224 6867 (~ .03 1t) t~ .92 225 6899 ~) 0.03 1(1 2.94 Lt. De osits. Sli ht bucklin . 226 6929 i1 0.03 11 l1 2.91 227 6960 (~ 0.02 t3 1 2.95 228 6991 u 0.03 13 4 2.88 229 7022 ~~ 0.03 1 I 1 2.94 230 7053 u 0.02 ~~ I 2.93 Sli ht bucklin . 231 7081 ~? 0.02 f3 1 2.93 232 7113 ~ ~ 0.03 13 1 2.92 233 7144 u 0.03 1~ 1 2.91 234 7175 U 0.01 ~ I 2.94 235 7206 ~~ 0.03 I ~! 1 2.93 Sli ht bucklin . 236 7238 ~~ 0.02 2.93 237 7268 U 0.03 1 ~) _' 2.93 238 7299 t~ OA ~~ _' 2.95 239 7329 u 0.03 11 1 2.92 240 7361 t~ 0.0 t; 1 2.92 Sli ht bucklin . 241 7391 ~~ 0.01 5 1 2.94 242 7423 U 0.0 ~i ~ 2.92 243 7452 U 0.03 11 1 2.93 244 7483 n 0.02 I 2.92 245 7515 U 0.02 t9 t~ 2.93 Sli ht bucklin . 246 7545 t~ 0.04 1 S 2.93 247 7577 U 0.04 15 2.93 ~Penetration Body Metal Loss Body Page 5 • ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 AB MOD BTC Well: 1 A-07 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USn Survey Date: September 11, 2009 Joint No. Jt. Depth (Ft.) I'c~n. llE~s~~t (In~.) Pen. Body (-ns.) Pc~n. °b Mct,~l Ic~~~ ",~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 248 7607 n 0.02 ~) ? 2.94 249 7640 c~ 0. 2 ti ~~ .93 250 7668 ~~ 0. 3 12 Z 2.92 Sli ht uc in . 51 7699 ~~~ 0.01 ~~ t~ 2.91 5 7730 ~~ 0.03 11 1 2.93 253 7760 U 0.03 11 1 2.93 254 7792 ~? 0.01 (~ ~~ 2 91 255 7824 ~~ 0.03 11 I . 3 Sli ht buckl~n 256 7855 U 0.03 1:; I 2.93 257 7886 ~ ~ 0.02 ~~ I .9 258 7915 t~ 0.04 1 b I 2.93 59 7947 U 0.02 ~3 ; 2.95 259.1 7978 c~ 0.01 4 1 .96 XO 59. 7982 ~~ 0 ~~ ~~ N A G M 1 Latch ~ 11:00 260 7991 i~ 0.01 (~ I 2.92 Sli ht buc.klin . 260.1 8022 t~ 0.02 i~ 2.96 Baker PBR 260.2 8027 u 0.0 ~) I 2.99 P P 60.3 80 7 cl 0 U U 3.00 ker'F L' Packer 2 61 8048 ~~ 0.02 £~ ~~ 2.9 ~Penetration Body Metal Loss Body Page 6 ~ ConocoPhillips Alaska, Inc. ~ KRU 1A-07 ~ 1A-07 API: 500292065800 Well T : INJ An le TS: 35 d 8129 sssv SSSV Type: LOCKED OUT Orig Cwn letion: 10/17/1981 Angle @ TD: 35 deg @ 8704 ~i~e~-~~az, OD3~~ Annular Fluid: Last W/O: 12/9/1985 Rev Reason: TAG FILL, set BPI, found leak 8283 Reference L: Ref L Date: Last U ate: 1222l2005 Last Ta : 8432 TD: 8704 ftKB Last Ta Date: 11I25/2005 Max Hole An le: 63 d 4100 Gas Lift Casin Strin - ALL STRINGS ~ndreUDUmmy ~ Descri tion Size To Bottom ND Wt Grede Thread vaNe 1 CONDUCTOR 16.000 0 88 88 65.00 H-40 ~797&~9~9' OD:5 953) SURF CASING 10.750 0 2469 2213 45.50 K-55 . PROD CASING 7.000 0 8656 6395 26.00 K-55 Tubin Strin - TUBING pBR _ SIZ9 To Bottom ND Wt Grede Thread ~ao22-soza, 3.500 0 8309 6111 9.30 J-55 AB MOD BTC ~3~) 2.875 8309 8324 6124 6.50 J-55 8RD EUE Pertorations Summe Interval ND Zone Status Ft SPF Date T e Comment 8126 - 8220 5962 - 6039 -d C-3 C-2 C 94 4 2/10/1982 IPERF Ene 'et PKR 8232 - 8249 6049 - 6063 C-t C 17 4 2/10/1982 IPERF Ener'et (soa~-aoas, 8404 - 8413 6189 - 6196 A-5 O 9 12 2/11/1982 IPERF TFuu-Tubi , ~ 6~~) 8422 - 8443 6203 - 6221 A-4 O 21 12 2/11/1982 IPERF Thru-Tubin ' 8445 • 8466 6222 - 6239 A-4 O 21 12 2/t t/1982 IPERF Thru-Tubin Gas Lift MendrelsNalves i ~ St MD ND Man Men Type Mfr V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt ~~ ~~~p~my 1 7978 5841 Mer~ TPDX BST POV 1.5 CEV 0.000 0 1/2/1990 vaNe z 8 I~t 9Cti0~1 MerldfelsNelVes ~ ~:~~3j St MD TVD Man Mfr Man Type V Mfr V Type V OD Letch Port TRO Dete Run Vlv Cmnt Pe~ 2 80 5 5921 Camco KBUG DMY 1.0 BK 0.000 0 6/9/1988 O n ~a,z~-azzo~ Oth er lu s ui et c - SLEE VE D ND . T . e th 8285 6092 NIP Descxi tio AVA BPI P l ET 11/27/2005 ID P~ 8285 6092 SLEEVE C orted Ni e. S AVA 2 75" BPI 11/ 7/2005 2.750 ~ezaz~zas~ - . 2 2.313 Other lu s ui . etc. - JEVVELRY De ND T Descri tion ID 1781 1740 SSSV Camco TRDP-IA-ENC Locked Out 10/20/94 MCX INJ Pulled 11/14/95 2.813 8022 5877 PBR Baker 3.000 SLEEVE-C ~$z8~-g2as 8037 5890 PKR Baker'FHL' 3.000 " oo2.~eo~ I I 8309 6111 PKR Baker'FB-1' 4.000 8316 61 f 7 NIP Camco'D' Ni le NO GO 2.250 8323 6123 SOS Camco 2.441 TUBING 8324 6124 TTL 2.441 ~~3~~ Fish - FISH OD:3.500, ID'2 992) ~ ~ Descr' tion Comment . PKR 8537 Baker PKR Assembl Milled to rathole durin arorkover ~eaoasa,o, o s General NOtes o:s.~ s~ Date Note 1/24/2001 Obtained "C" static 8000' 8 8188' RKB 1l27/200 NOTED LEAK 8283' NIP (8316-8317, OD2.875) TUBING (8309-8324, OD2.875, ID2.441) 505 (83238324, OD2.875) PeR (8404-8413) Pert (8422-8443) Pert (844~8466) B k PKR a er Assembly (8537-8538, OD2.000) NL~~I~:-D ly lEl~~~3~ ?: 5t ~u11 ~' ~? r>c - Fl~'~ i~._..~.~ ~~;, 1 _ ~C: ":t:5~~ '-'l!S F'tu^ ;r. ~ . _ ~ ,T~~~`~ , ~ J tl ' ~ ~ ~. ~ ~~~~ ~ tue~r~~ r L~M~~ -t'~ , ~~~ ' DI~IL'. S;tE.~., -` DATt. ~?5r AR~t} Al~-sk~ ln~c. ~ ~~~ ~~`~~ pa~~g ~ s~w~ ~~ aw~;~at+~~~*- .~ .w. , I-tTE~riB GOMPLETEOiSCfiIP7lON C?~ EQUlPMENT Fit:wl ~~~NGTH OEPT~i ~' .r m ''?i ~ a - i , , r ' a " ~~ (o . ~ '' ~_ 3}i,,~ Q a` J~5~5 ~.ire.~~~-m r pc. r~e ~ .~•'~ c• +~ i ___ ~. ~~~~ ~~ -~,~.~~~ ~ ~~ . ~3~~.~~ ~ ~.~~ ~~' ~~ _ .~.~. -- ~ - 1 ~ e~ ~ $ .. ~.. / M 17'~OK•a~.L} ...~ ` . ~ ~ _ __ ' i / ~ ~ ~fa '~... ~ ~ 7 ~~. ~ .~ N .. ~„ _ .~~ N - ~ , 3~ ' 7 517 $.Q+i- . ~' „ • ~ ~ ~ ~f , ' ~ ~`~~, ,~ - x~ s~ 748~~ i 1 ~..... ~..~. ~ c~~= ~~ _ ., _ ~...m... ~ ; arr .. . N . ~...~ ' / N ..i A { ~ ~~ M Y ~ ~., .. ~ ~r~ ~~r~r~ _~ °~ ;~ "' , ~. " -~ r ' ~ , , _ ~o. a ~ t.• - - •Fg;~ ,3 -T~~ ~ ~ _ .~~ . '' ~~- u w ~ 4R ' ~ f F . ~ +y.~ # &g~ ~ f ~ ~ y~r f ~ ... . _ ~.~ !., ~ ~'~ ! r r 4~ A~c. ~-. ~; ~ . ~ ~ ~xb= ~, ~ ) ' ~ -~ N r ~ ~ , ~ ~ ~~ ,~ _ ~ "~~-~--° -- ' ~ ~ H r ~, ,, ~..'SS ' --~----~ ~ $l t3•3t ~ ~~~~i-~ r, ~ ~ ~~. Q'~ "~~q~.l ~QQ, ~ a ~ ~, ~ ~e .~~ ~~. ~ ? i~~a ~-- 3~ ~ '~' _~' F?~.g 4.t3 rit ~ '~ , ~c~t~ i ~n t3r+r. ++~ ~'d..~ ..:d~ s4~ ~ 3? ~~,,~+ Z ~' +.~•~~ „~ ~' ' ~r• ~i-_.~v~ nl-ri~° R~t~e~0 ~ a , - ,a~r-rr~~l~.. ..~. ~` , __... ~, -~'a a~ ~ 'T _ r+.~ i.~..-_ ~ iA KRU 1A -07 (PTD# 181 -137) Rep1Of Failed MITIA Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, July 28, 2009 11:07 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark Subject: KRU 1A -07 (PTD# 181 -137) Report Of Failed MITIA Attachments: 1A -07 Wellbore Schematic.pdf; 1A -07 TIO Plot.pdf Jim/Tom /Guy, Kuparuk WAG injector 1A -07 (PTD# 181 -137) failed a diagnostic MITIA on 7/27/09. Troubleshooting will begin as soon as feasibly possible. The well is been shut in and will be added to the monthly report. Attached is a wellbore schematic and 90 day TIO plot. «1A -07 Wellbore Schematic.pdf» «1A -07 TIO Plot.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor StiANNED JAN 2 0 2011 ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2011 Well Name 1A-07 Notes: End Date 8/1/2009 Days 120 Start Date 4/3/2009 Annular Communication Surveillance 2000 ��. — _._ --_ -- - - -- 1.2 WHP IAP 1800 - OAP WHT 1 1600 1400 0.8 • 1200 LL Q 1000 - 0.6a 800 - — _.. - ■ 0.4 600 -- -- - _ 400 I 0.2 200 0 0 Apr -09 May -09 Jun -09 Jul -09 • 0.9 I •DGI 0.8 • �MGI 0.7 • � PWI g 0.6 -SWI d 0.8 •BLPD u 0.4 2 0.3 0.2 0.1 0 Apr-09 May -09 Jun -09 Jul -09 Date l~ 7007 08/30107 Sc ,._ee">>';if" 5Ci~'\!NED SEP 18 2007 NO. 4398 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /1\ ~ Field: Kuparuk Well Job# Log Description Date BL Color CD 2H-02 11846438 INJECTION PROFILE t )T,(' 1"6L( - O"T"'=<:: 08/21/07 1 2P-427 11846437 INJECTION PROFILE l" I (' ..Q(") ~ - H,o)( 08/20/07 1 1A-07 11850429 INJECTION PROFILE I \ I é' l'fr l - 1 ~~ 08/22/07 1 10-08 11850427 SBHP SURVEY I~ -().ç~ 08/20/07 1 3A-09 11850426 GLS ¡q/-/~q 08/20/07 1 2W-09 11850428 INJECTION PROFILE UXC- I~- ~l~ 08/21/07 1 1 L-17 11839642 INJECTION PROFILE L)TC' ,~ J -Ö47, 08/23/07 1 2M-13 11839643 PRODUCTION PROFILE 08/24/07 1 1G-04 11837494 INJECTION PROFILE {)It'. 1~:1-J~1 08/24/07 1 2N-350 11839644 DDL ,qÖI- /~.< 08/25/07 1 2N-350 11839645 PMIT ..0" I _ l.g ,<; 08/26/07 1 1A-05 11839646 INJECTION PROFILE ( )T ('. / ~ I -/~ 08/27/07 1 2H-15 11837498 INJECTION PROFILE OJ::C- I "ki..{-r\'XL 08/29/07 1 2A-04 11839649 INJECTION PROFILE ,) ':1"'"(\. l1r11- b~~ 08/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg í7 1:1 P.I. Supervisor 1<\-'1/ 71'3D/D 7 DATE: Friday, July 20, 2007 FROM: Bob Noble Petroleum Inspector SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-07 KUPARUK RIV UNIT IA-07 Src: Inspector \~1 \~\~ NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,3i3'2- Comm Well Name: KUPARUK RIV UNIT IA-07 API Well Number: 50-029-20658-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070719125256 Permit Number: 181-137-0 Inspection Date: 7/15/2007 R.~! I!!sp ì'lum: Packer Depth P ì'"~test Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i IA-07 ¡Type Inj. ; w I y'IA I -,--------- TVD 5890 550 1870 1860 1860 I I I ¡ ---r---- I 1811370 ITypeTest ! SPT Test psi I 1870 .....rOA I 180 180 180 180 P.T.D1 , I ! I I I ---+-- 4YRTST P -../ Tubing I 1170 1170 1170 1170 i Interval P/F [ ~---- Notes: S~ AUG 0 6 2007 Friday, July 20, 2007 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg -:--J i k(' ¡')t" ........... 1<.... j'~?/~ bJ':::> '- ~ P.I. Supervisor '-tr DATE: Wednesday, May 31,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-07 KUPARUK RIV UNIT lA-07 /\~1 \%\ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::\'R/2- Comm Well Name: KUPARUK RIV UNIT IA-07 API Well Number 50-029-20658-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060530162429 Permit Number: ISI-B 7-0 Inspection Date: 5/30/2006 ReI Insp Num ../ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! IA-07 ¡Type Inj. I G i TVD 5890 ! IA ! 450 2000 1960 1915 1915 - I i i -- P.T. ! 1811370 !TypeTest I SPT ! Test psi i 1500 I OA I 140 150 150 150 150 Interval 4YRTST P/F P Tubing! 1270 1310 1385 1415 1420 Notes 1,4 bbls diesel pumped, I well house inspected; no exceptions noted, NON-CONFIDENTIAL . .'" ,,¡ '~,ri\ìF;( ""I :.1¡,~. ~ ._....; ....¿ v\" IW .', ~ . 1. 3 2nGb Wednesday, May 31,2006 Page I of I Schlumbergep (::f'I=IVED NO. 3638 Rl.-V_ - Schlumberger -DCS - - - . " 9 "006 2525 Gambell Street, Suite 400 ,J/~,N u L Com pany: Anchorage, AK 99503-2838 A TTN: Beth ~¡askaJ¡¡ .~ G8s CooS. CommiSSIDf1 Anchcrag.e Field: Well Job # Log Description Date BL 2D-02 N/A SHUT IN BOTTOM PRESSURE 12103/05 1 1A-07 IB/-Ia? N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE WIDEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE W/DEFT 12/27/05 1 2U-08 11166750 PROD PROFILE W/DEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 30-09 11166737 LDL 12/17/05 1 35-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE WIDEFT 12/26/05 1 30-09 11144055 LDL 12/23/05 1 2V -01 11144056 INJECTION PROFILE 12/24/05 1 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 tt6i- 137 SIGNED&è)oQ001'¡ SCANNED JAM 3 1 2.006 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD -..,/ ~ ) ConocriP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 16, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 A-07 (APD # 181-137) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 A-07. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, I , >,t "",f .lti' ¡ I/l~?ð M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNEC~ NOV 2, 4 2004 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell 0 Pull Tubing 0 Operat. ShutdownO Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 100' 1. Operations Performed: Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well D 5. Permit to Drill Number: 181-137 1 6. API Number: 50-029-20658-00 Plug Perforations 0 Perforate New Pool D Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory 0 Service 0 9. Well Name and Number: 1 A-07 8. Property Designation: ADL 25647, ALK 465 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 8707' feet true vertical 6436' feet measured 8450' feet true vertical 6226' feet Length Size MD 80' 16" 118' 2431' 10-3/4" 2469' 8618' 7" 8656' Plugs (measured) Junk (measured) 8537' TVD Burst Collapse 118' 2210' 6394' Measured depth: 8126'-8220',8232'-8249',8404'-8413', 8422'-8443', 8445'-8466' true vertical depth: 5962'-6039',6049'-6063', 6189'-6196', 6203'-6221', 6222'-6239' Tubing (size, grade, and measured depth) 3.5" 12-7/8", J-55, 8309' 1 8324' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 8037'; 8309' SSSV= 1781' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8404'-8413',8422'-8443',8445'-8466' 13. Treatment descriptions including volumes used and final pressure: 708 bbls of slick seawater Oil-Bbl n/a Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 742 881 Tubinq Pressure Casinq Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 GasD WAG0 GINJO WINJ 0 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: Contact Printed Name Signature WDSPLO Mike Mooney @ 263-4574 Mike Mooney }If IJ/~ Title Phone Kuparuk Wells Team Leader Date it } 2 Z/r)1^ Prepared bv Sh(,on Allsup-Drake 263-4612 RBDMS BFL NOV 2 2 2004 Submit Original Only Form 10-404 Revised 04/2004 ') 1A-07 Well Events Summary ) Date Summary 10/30/04 POOR BOY HPBD COMPLETED. PUMPED 708 BBLS OF SLICK SEAWATER (55 DEGREES)MAX WHTP = 3950 PSI AND MAX RATE 10.8 BPM. WELL RETURNED TO PW INJECTION POST BREAKDOWN. [HPBD] ) ) ConocoPhillips Alaska, Inc. 1A-07 SSSV (1781-1782, 00:3.500) PBR (8022-8023, 00:3,500) PKR (8037-8038, 00:6.156) 1'~ I~ I J b -~ -r- ~ ~ -~ J')n í Perf (8126-8220) Perf (8232-8249) SLEEVE-C (8285-8286. 00:2.750) TUBING (0-8309. 00:3.500, 10:2.992) ~-" ~.,.. ~ NIP r u (831ß.831ì, 00:2.875) i TUBING (8309-8324. .....--- 00:2.875. I 10:2.441) Perf =t +- (84048413) --- +- --.- -L- ---< ~ Perf :t ..A.- (8422-8443) -- 4>-- ¡L +- I Baker PKR ¡ Assembly (8537-8538, 00:2.0(0) KRU 1A-07 API: 500292065800 SSSV Type: LOCKED OUT Well Type: INJ Orig 10/17/1981 Completion: Last W/O: 12/9/1985 Ref Log Date: TD: 8707 ftKB Max Hole Angle: 63 deg @ 4100 Angle@ TS: 35 deg @ 8129 Angle @ TD: 35 deg @ 8707 Annular Fluid: Reference Log: Last Tag: 8450 Last Tag Date: 1/23/2001 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURF CASING 10.750 PROD CASING 7.000 Tubing String - TUBING Size Top 3.500 0 2.875 Rev Reason: Waiver cancelled Last Update: 2/5/2003 Top Bottom TVD Wt Grade Thread 0 88 88 65.00 H-40 0 2469 2213 45.50 K-55 0 8656 6395 26.00 K-55 TVD Wt Grade Thread 6111 9.30 J-55 AB MOD BTC 6124 J-55 EUE Bottom 8309 Interval TVD 8126 - 8220 5962 - 6039 8232-8249 6049-6063 8404-8413 6189-6196 8422-8443 6203-6221 8445 - 8466 6222 - 6239 Gas Lift MandrelsNalves St MD TVD Man Mfr 1 ,7978 5841 Merla It'lJè~tiòn\IJan(lrøl$IVê'ilVØ$ St MD TVD Man Man Mfr Type 2 8075 5921 Camco KBUG Other (Jlugs, equip., etc.' - SLEEVE Depth TVD Type 8285 6092 NIP AVA BPL Ported Nipple. 8285 6092 SLEEVE-C AVA 2.75" BPI set 3/27/02 - CLOSED Other {Jlugs, equip., etc.: - JEWELRY Depth TVD Type 1781 1740 SSSV 8022 5877 PBR 8037 5890 PKR 8309 6111 PKR 8316 6117 NIP 8323 6123 SOS 8324 6124 TTL Zone Status C-4,C-3,C-2 C C-1 C A-50 A-4 0 A-4 0 Ft SPF Date 94 4 2/10/1982 17 4 2/10/1982 9 12 2/11/1982 21 12 2/11/1982 21 12 2/11/1982 Type IPERF IPERF IPERF IPERF IPERF Comment Enerjet Enerjet Thru- Tubing Thru- Tubing Thru- Tubing Man Type TPDX V Mfr V Type V OD Latch Port TRO Date Run CEV 0.000 0 1/2/1990 Vlv Cmnt BST POV 1.5 V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt BK 0.000 0 6/9/1988 Open DMY 1.0 Description ID 2.750 2.313 Description Camco TRDP-1A-ENC (Locked Out 10/20/94) MCX INJ Pulled 11/14/95 Baker Baker 'FHL' Baker 'F B-1' Camco 'D' Nipple NO GO Camco ID 2.813 3.000 3.000 4.000 2.250 2.441 2.441 "C" static @ 8000' & 8188' RKB MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount ~~ Commissioner ~~_ ~d~ THRU: Blair Wondzell .~ P.I· Supervisor t~rjr$o ~ FROM: John Cds~ J~,.~ ~_~,, Petroleum Inspector DATE: August 26, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. lA Pad 1A-07 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 1A-07 I Typelnj. I G I T.V.D. I 5908 I '1~oo I ~oo I ~oo I lntervall 4 P.T.D.I 1811370, p I I I I g ..... I, I I ..I I .~ / Yy etest P Test Psi 1477 Casin I 675 1550 1550 1550 P/F P Notes: Ann. was fluid packed & pressure was achieved wi 3 bbl. pumped· Wel'I ITyPe Inj' I I T.V'i'D'i [ ' I''Tubing I I I ] '11ntervall P.T.D.I }Typ'ete,s,tI ITestpsil '}Casingl ,,, I I I I PIE Notes: 'WellI P.T.D.I Notes: WellI p.T.D.I Notes: WellI P.T.D.I Notes: [Typelnj.[.... 'I~~.~.I, I'."I . I 'llnterva'l" I T petest }Test psi I Casing I I I I I P/F I ITypelnj. I ' I T.V.D. I I Tubing l [ I I ' ' 'llntervall TyPe test} "I Test psi} I Casing,,I ........... I . I I I P/F ,,, I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillip's Alaska Inc. Kuparuk River Field to perform a series of 4 year MIT's on lA Pad. An attempt was made to perform MITs on lA-02, lA-07 & 1A-09. lA-02 & 1A-09 inner annulus were not fluid packed w/diesel when the MIT's were attempted. After very time consuming fluid packing on these wells, and after discussion with Peter Peter Nezaticky( problem wells for Phillip's Kupamk), it was decided that it would be to everyone's advantage to have these wells prepped before our arrival to' witness MITs. · l.T.'s performed: ,one Attachments: none Number of Failures: non.e Total Time during tests: 8 hours CC: MIT report form 5/12/00 L.G. V1 uebtfc.xls 8/30/00 ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 December 28, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas ConservatiOn Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Applicaton for Sundry Approvals (Form 10-403) and in duplicate are multiple Report of Sundry Well Operations (Form 10-404) on the following Kuparuk wells. Well Form Action 1A-07 1 O-4O4 1B-09 1 O-4O3 1R-01 1 O-4O4 1R-01 10-404 2V- 12 10-404 Other(Injection Valve) Other (Cement Squeeze) Perforate Stimulate Stimulate If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (attach only) File: FTR122896 (w/o attach) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA[[,' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing ~ Alter casing ~ Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X__ 4. Location of well at surface 659', FSL, 308' FWL, SEC 5, T11N, R10E, UM At top of productive interval 6. Datum elevation (DF or KB) RKB 100 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 A-07 9. Permit number/approval number 81-137 10. APl number 50-029-20658 11. Field/Pool Kuparuk River Field/Oil Pool 1386' FSL, 1197' FEL, SEC 7, T11N, R10E, UM At effective depth 1250' FSL, 1240' FEL, SEC 7, T11N, R10E, UM At total depth 1053' FSL, 1304' FEL, SEC 7, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 8 7 0 4 feet true vertical 6434 feet Plugs (measured) None Effective depth: measured 8 5 6 6 feet true vertical 6321 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 1 6" 200 SX PF 118' 118' 2431' 10-3/4" 1400SXASIII & 2469' 2210' 250 SX AS II 861 8' 7" 850 SX Class G 8656' 6394' meaSured 8126' 8220', 8234' - 8248', 8404' - 8413', 8422' - 8443', 8445' - 8466' true vertical 5962' - 6038', 6050' - 6060', 6188' - 6195', 6204' - 6220', 6222' - 8238' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8323' Packers and SSSV (type and measured depth) PKR: BAKER FHL @ 8036' & BAKER FB-1 @ 8300'; SSSV: CAMCO_ T_RD..p-__I,A,E~I; ~/OTIS MCX @ 1780' 13. Stimulation or cement squeeze summary Install Injection valve. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Avere, ge Pr0d~jction or ~ R i V DEC 2 9 '1994 ~JLL .& Gas Cons. ComiTY_It OiI-Bbl Gas,Mcf Water, Bbl Casing Pressure Tubing Pressure Prior to well operation 3OOO 1760 3163 Subsequent to operation 45 0 0 1760 3227 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended __ Service X (WAG) 17. I hereby certify that the foregoing is 'true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date l SUBMIT IN DUPLICATE CONTRACTOR I KEY PERSON HES/HANSEN UNIT# 3437 OPERATON AT REPORT TIME IFIELD EST: ~'] COMPLETE r'~ INCOMPLETEI $4,030 DATE I0/20/94 DAY 2 TIME 0700 0950 1045 1120 1150 1210 1225 1300 1345 1445 ,,, IAFCICC# - SCA# 230DS 10AIJ40115 ACCUMULATED COST $4,030 LOG ENTRY SITP=2200# INNEPJCP=1000# OUTER/CP=50# Page 1 of 2 MIRU-HES & LIL RED SERVICES, HAVE SAFETY MTG,PT-3500g,GOOD R.IH-W/RS,QC,5' X 1.875",KJ,5' X 1.875",KJ,LSS,QC, & CAMCO 3"Z-5 LOCK-OUT TOOL LENGTH FROM NO-GO TO Z-5 KEYS = 97" LOCATE BOTTOM PROFILE @ 1787'WLM EXERCISE FLOW TUBE-POOH,PERFORMED CLOSURE TEST,NO-GOOD RIH-W/3"Z-5 LOCATE PROFILE @ 1787'WLM EXERCISE FLOW TUBE-POOH PERFORM CLOSURE TEST, UNABLE TO CLOSE FLAPPER RIH-W/3" Z-5 SET LOCK-OUT TOOL @ 1787'WLM-POOH ~ RIH-W/2.250" BLIND BOX,SET DOWN @ 1788'WLM BEAT DOWNWARD FOR 15,MIN's-POOH RIH-W/3" RB PULLED LOCK-OUT TOOL@ 1789'WLM-POOH R/H-W/3"RB,PULLED 3"F-COLLOR STOP,@ 1823'WLM,DUMPED CONTROL-LINE,PRF.3URE PASS BACK THRU FLAPPER UNABLE TO HANG-UP ON FLAPPER (BOTTOM PROFILE IS LOCKED-O~. RIH-W/2.79" GAUGE RING,PASS DOWN TO 2100'WLM PULL BACK THRU SSSV TO VERIFY FLAPPER IS LOCKED-OUT-POOH RIH-W/3"X-LINE RUNNING TOOL W/2.813" CR-LOCK W/HES MCX-INJECTION VALVE,(SER# 303 W/A 1.080" BEAN) SET @ 1782'WLM (1780'RKB)-POOH W/MCX VALVE Illl RIH-W/SAME TOOLS & MCX-INJECTION VALVE SET @ 1782'WLM (1780'RKB)-POOH PERFORMED CLOSURE TEST, DROPPED THP-F/2175# TO 125# HELD TEST FOR, 10 M1NS II I TEST GOOD RDMO TO 1L-04 FINAL PRESSURES: SITP=2175g INNER/CP=1000g OUTER/CP---50g SUMMARY _ ABLE TO MOVE FLOW TUBE,UNABLE TO GET TRDP- 1AE31C,FLAPPER TO CLOSE LOCKED BOTTOM PROFILE OUT, RAN HES MCX INJ,VALVE SER#303 W/2.813 CR LOCK (NOTE TO PULL MCX YOU NEED 3"GS & PRONG 24") i I I Ic"Ec TH~s CLOCK ~F SUMMARY IS CONTINUED on BACK _ Repo~ °F , °F miles ~0~ , , AR3B-7031 298-~486 STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension_ Stimulate _ Change approved program _ Pull tubing _ Variance X Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service R10E, UM R10E, UM R10E, UM 8704 6434 4. Location of well at surface 659', FSL, 308' FWL, SEC 5, T11N, R10E, UM At top of productive interval 1386' FSL, 1197' FEL, SEC 7, T11N, At effective depth 1250' FSL, 1240' FEL, SEC 7, T11N, At total depth 1053' FSL, 1304' FEL~ SEC 7, T11N, 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 100 feet 7. unit or Property name Kuparuk River Unit 8. Well number 1A-07 9. Permit number 81-137 10. APl number 5O-029-20658 11. Field/Pool Kuparuk River Oil Field/Pool feet feet Plugs (measured) None RECEIVED Effective depth: measured 8 5 6 6 true vertical 6321 Casing Length Size Structural Conductor 8 0' 1 6" Surface 2431' 1 0-3/4" Intermediate Production 861 8' 7" Liner Perforation depth: measured feet feet Cemented Junk (measured) None ~0V 1 4 1994 ~,~ O[t .& Gas Cons. Com ', Measured depth v(~ rt i~l~l~.t.~ 200 SX PF 118' 118' 1400 SX AS III & 2469' 2210' 250 SX AS II 850 SX Class G 8656' 6394' Tubing (size, grade, and measured depth) . UkI[ /NAL 3.5", 9.3#, J-55 @ 8323' Packers and SSSV (type and measured depth) PKR: BAKER FHL @ 8036.' & BAKER FB-1 @ 8300'; SSSV: CAMCO TRDP-1AENC @ 1780' 8126' - 8220', 8234' - 8248', 8404' - 8413', 8422' - 8443', 8445' - 8466' true vertical 6238' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ I 14. 16. Estimated date for commencing operation 10/20/94 If Proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service X (WAG) 17. I hereby certify that the fo~.,re~s true and .correct to the best of my knoWledge. Signed Title Wells Superintendent FOR COMMISSION USE ONLY Conditions of approval: Notify COmmission so representative may witness PlUg integrity _ BOP Test _ Location clearance__ Mechanical Integrity Test _ Subsequent form require Original Jign-e l By David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 IAppro__val I)1o. ~,. 1 O-/-[ ~Approved._ Copy Returned c omm,ss,oner D,'[~ II- /(~- SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1A-07 As per Conservation Or Commission, ..... ..,. der No. 173. failed surfa _ (' !. ('2), ARCO Al - In Injection Well lA-07 with a downhole, s rin b"""~'~:e safety valve · -~P~uva, ro rep/ace th(~ Rule 5, paragraph a injection valve will act as ce control/ed, su ~,,.~.._?ska. requests · a one-way che u .._,.P g.-controlled. 'hi....,;- . C,, v~ve. alan,,,; .... . i..,,,u[~on w~,,, This and gas. While Preventing upward flow o! these flu. ids: The injection valve ..... '"'U aOWnward injectig'n'~o'f Water Preventing uncontrolled flow by automatically closing if Such a flow sh*ouldis capable of OCCUr. REEEIVED NOV '1 4 1994 Alaska Oil & Gas Cons. Commission Anchorc ~ AL~KA STATE OF ALASKA (~- OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing ...... Alter casing Stimulate Repair well Plugging Perforate Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 659' FSL, 308' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1386' FSL, 1197' FEL, Sec. 7, T11N, R10E, UM At effective depth 1250' FSL, 1240' FEL, Sec. 7, T11N, R10E, UM At total depth 1053' FSL, 1304' FEL, Sec. 7, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 8 5 6 6' feet true vertical 6221 ' feet Plugs (measured) 6. Datum elevation (DF or KB) - ~ 100' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-07 i/t~ Ecr~ u-, 9. Permit number/approval number 81 -137/8-855 10. APl number 50-029-20658 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 51 6' feet true vertical 6285' feet Junk (measured) Casing Length Size Structural 88' 16" Conductor 2469' 10 Surface Intermediate Production 8656' 7" Liner Perforaiion depth: measured 8126'-8220', true vertical 5962'-6038', 3/4" Cemented Measured depth True vertical depth 200 Sx Permafrost 88' 88' 1400 Sx AS III & 2469' 2210' 250 Sx AS II 850 Sx Class G 8656' 8325' 8234'-8248', 8404'-8413',8422'-8443', 8445'-8466' 6050'-6060', 6188'-6195', 6204'-6220', 6222'-6238' Tubing (size, grade, and measured depth) 3 1/2" J-55, 8323' Packers and SSSV (type and measured depth) Baker FHL @ 8036'MD~ Baker FB-1 @ 8300'MD~ TRDP-1A @ 1780'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) L~UL 2 0 ]989 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0mr~issi0n Reoresentative Daily Average Production o~ Iniegtion' Date Anc~0rage ' OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operati, on 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector ~ Daily Report of Well Operations X. Oil _ Gas . Suspended "i 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 R~ 0'5/17/89 / Date . SUBMIT I~1 DUPLICATE Report of Sundry 1A-07 Water Injector Approval to continue injection on Well lA-07 was granted 11/88 via Sundry Application Approval Number 8-855. Injection in this well has continued. MIT's will be performed at 6 month intervals per the conditions of approval in the Sundry Notice Application. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate ~ Change approved program_ Pull tubing _ Variance X Perforate _ Other 99510 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 659' FSL, 308' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1386' FSL, 1197' FEL, Sec. 7, T11N, R10E, UM At effective depth 1250' FSL, 1240' FEL, Sec.7, T11N, R10E, UM At total depth 1053' FSLr 1304' FELt Sec. 7~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8566' true vertical 6221' Effective depth: measured 8516' true vertical 6285' Casing Length Size Structural Conductor 88' 1 6" Surface 2469' 1 0-3/4" Intermediate Production 8 6 5 6' 7" Liner ,,, Perforation depth: measured 81 26'-8220', 8234'-8248', true vertical 5962'-6038', 6050'-6060', Tubing (size, grade, and measured depth 3 1/2", J-55, 8323' MD Packers and SSSV (type and measured depth) 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-07 //1)~'¢¢ r ~ 9. Permit number 81-137 10. APl number 5o-029-20658 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth 200 Sx Permafrost 88' 1400 Sx ASIII & 2469' 250 Sx ASII 850 Sx Class G 8656' 8404'-8413', 8422'-8443', RECEIVED NOV 1 6 1988 Alaska Oil& Gas Cons. Comm~ True ve rt~h~[:~ ' 88' 2210' 8325' 8445'-8466' 6222'-6238' 61 88'-61 95', 6204'-6220', 011 Baker FHL @ 8036' MD, Baker FB-1 @ 8300' MD, TRDP-1A @ 1780' MD 1'3. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch 14. Estimated date for commencing operation Continued operatiQp 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil m Gas _ Service _Water Iniector Suspended 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' ~' FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mecb.anical Integrity Test ~ -- ~ubsequent form'"~'equire 10- Approved by the order of the Oommissioner : :/-.,~ Oommissioner Form 10-403 Rev 06/15/88 ~" . JApprov~l No.,~, . --~ Approved Oopy Returned Date 1t-/ ~) -~ ~ /---~_SU~MIT IN I H1pLICATE lA-07 Witter In_iector Sundry Notice to Continue Injection Reauest Approval to continue injection on Well lA-07. Slight communication from the tubing to production casing has been noted, yet is not enough to cause the well to fail an AOGCC witnessed MIT nor to subject the production casing to a pressure that exceeds the hoop stress regulation set forth in Rule 4 of AOGCC Area Injection Order No. 2. The present condition of the well is operationally safe and poses no threat to the integrity of the production casing. The communication will be monitored closely to note any changes in its present condition. Background This water injector was noted to have slight communication from the tubing to production casing. The production casing would be bled below 2000 psi (tubing=2550 psi), only to have the pressure increase back to 2500 psi over the course of 7 days. Continued bleeding of the production casing was halted in fear of drawing water up into the permafrost region of the production casing. Sequence of Events 2/5/8 8: No communication found in wellhead test. 4/2/88: Repacked dummy valve in GLM gl. Appeared to correct problem. Production casing slowly pressured back to tubing pressure. (Well Service Report attached) 5/16/88: Repacked dummy valve in GLM gl. Same results as previous attempt. (Well Service Report attached) Well passed an internal MIT. (Lost 6% in 30 6/5/88' minutes-Well Service Report attached) 6/9/8 8' Pressure tested tubing. Slight leak from tubing~ production casing. (3500 psi to 3200 psi in 50 minutes, liquid packed-Well Service Repot~la$~ Oil Il, Gas Cons. Coramissi0~l attached) 8/1/88: Passed an AOGCC witnessed MIT. Report attached. Attachments- 1) 2) 3) 4) 5) 6) Well Service Report (WSR) of 4/2/88 WSR of 5/16/88 WSR of 6/5/88 WSR of 6/9/88 AOGCC MIT of 8/1/88 lA-07 Well Schematic 88/6/6 'SOQ EPOF WEU. I~DT I FIELD- OISTRICT - STATE CO.TR~C'rO. IOPER~O~ AT REPORT nME ~LD O0 - ~ ~ ~ uz ¢,.-c 3ooo~ "Pu, ~ ~ ~ ~,~,Ls ! R ~ ~ ~/R'S, 5' z'/~'' 'S.Tm,,.,,, K:r~ o'~ ~j xo,~0_. D~- I , J 15ODit L~,t.L ~]E.£b ~. Ftn~q,'Ti~rt __ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. t~Jbs,d~lry of Atlantic i=lichfield · WC. LL _/~ '7 CONTRACTOR Or/~ - IPBDT REMARKS]4/~ 5 0 ~ WELL SERVICE REPORT IFIELD - DISTRICT. STATE iDAYS ,kkl'A~,#l~ ~lJ,,~.,~ Ul~lT J / [DATE /OPE~TION AT RE~RT.TIME /# ~ [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK SJ · ' ARCO Alaska, Inc. ("% REMARKS WELL SERVICE REPOR' FIELD- DISTRICT- STATE IDA'eS KR v I OPERATION AT REPORT TIME C e/m/o,Z ~'"~ DATE Io II 49 /o ;5' /o lo_Po CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. l~7 OTsS JPBDT WELL SERVICE REPOR1 J FIELD . DISTRIC~I' - STATE J DA/YS lC)ATE IOPERATION AT REPORT TIME ,,., I ~ f ,,S~ ~ ! $',~ /'/,2,,," CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK wo, tlmII, pm J Te,q~. ~ J Chill F.ctor J Visibility ~ mllel' jWlnd Vol. DrLLl~te: I I Ir I I$ i I lif I~t · -- : _ ~ ,.imml I l= II I I CA.~l~ t I I~l~l I I ~l(m~ I I ~zl/ I I IIQ.D jI · I I /I II // // /1 I ! I... l.._ t _ ...... I ........ 1. I I I I I I ..... I _ I ...... I,,. _ __ I I__, I ....... 1 ,l_I iI I i I I I .... I ,I .... I I _ Illl I ilI .......I // l! l! ~l~t lot hlltllr Rmld: 61~ool -- i --___ Z -- ii -- i ~_l Il I i iiii i i .... _ _ _ ~ - _ 111allll ~1~! '. ! A- 7 Spud [)ate:09-2?- 61 ~-mpletion Date: 12- 09- 85 ,x~mum Hole An~le; 65 deg. · 0riginal I~g RKB: 26' All deptk ere RKB MD te ted et equipment. 7,8 A~O ALASKA INC.-KUPARUi~ r'I£LD APl w 50- OZg- 20656- O0 C Send: OPEN A Send: OPEN 41 $0' t4D Well Type: WATER INJECTOR Tree Type: FI1:: GEN :5 SO00e Tree Cap Type: Tree Cap Size: Tree Cap O-d~ ASN: Lest Workover Date: 12- I0-85 Jevelrl Hinimum ID' 2.25' IIOGO Casing and T.bbg Size Veiaht 6fade To~ Bottom 16' 6~e H-40 0 88' 10.75" 4.%.5e K-55 0 2469' 7" 2~e K-55 0 8656' 3.5" 9.3e ,J-55 0 8.309' 2 7/8' 6.5e J-55 8Z4~' 8324' Descrbtio~ CASI~ TUBH} TU~K~ TAL Oas Lift bfermatkm Depth Stne Vahe TEDe 797~' I 8075' I 0/v 62E~' 2 AVA Sz. Latch 1.5' T-2 Pert Sz. 12/64 0912 Date Run 12-10-85 03-03-88 03-03-88 Perforation Data bterva! SPF Date 8126-8220 02-10-6'2 8252-8249 02-10-82 8404-8413 0r'2-11-82 8422-8443 02-1 !-82 8445-8466 02-11-82 C C A A A Comments Comments: 23' BAKER PKR ASSEMBLY · 8537'. ALSO BPI-275-O4g SHOULD READ BPI-275-00C BOTTOM ARCO Alaska, Ir~ Post Office t~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-15-86 TRANSMITTAL ~ 5761 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run #3 7585-8532 lA-14 -12-05-85 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85 'Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #I 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt Acknowledged: Vault*films ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComl~afiY Mr. C..V. ChaI"~,rton KUPARUK Well Number lA-9 lA-11 lA-12 1A-13 1A-14 1A-15 1A-16 Well Number 1E-lA 1E-4 1E-9 1E-t3 1E-14 1E-16 !E-19 1E-21 1E-23 1E-27 1E-30 Well Number ~ :~./, ..,:v '.> ::: !986 RIVER UNIT INJECTIng'LoGS , ,-,!~..::": -::.: ';x ',:,'.:; ', '-1., i]':~'.:l:i;~2S: INJECTION PROFILES. ' Date of Initial Injection Date of Injection Profile 3/21/83 3/25/83 3/1/83 3/22/83 3/7/83 3/21/83 3/1/83 3/6/83 2/4/83 10/17/83 2/22/83 4/11/83 3/1/83 3/18/83 3/1/83 3/24/83 Date of Initial Injection Date of Injection Profile 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Date of Initial Injection Date of Injection Profile 1F-10 8/13/84 10/30/84 1F- 11 8/12/84 9/24/84 1F- 13 8/16/84 9/25/84 1F- 15 8/16/84 9 / 26/84 ... Well Number ~ 1G-3 1G-6 1G-9 tG-14 1G-16 Date of Initial Injection Date of Injec. tion Profile 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 Drill Site lA Well No. 1A-4 1A-5 ~Au7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KU?ARUK RIVER UNii . Production Logs FEBRUARY 19, 1986 Log Date Drill 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB Site Well No. lB-1 lB-2 lB-3 lB-6 lB-7 lB-8 1B-9 Loo. Date 12/26/81 6/25/81 11/16-18/81 3/12/82 11/18/81 9/10/82 tl/23/81 12/28/81 8/4/82 6/24/82 8/3/84 Drill Site lC Well No. lC-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8 ' Log Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Wel 1 No. 1D-1 1D-3 1D-4 1D-5 1D-6 1D-7 ~..~D-~ (WS-8) Log Date 1/80 5/23/83 8/5/80 7/30/80 8/13/80 6/11/81 6/9/81 6/8/81 5/i0/78 Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date Drill Site Well No. Lo9 Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/8O 9/2/81 11/5/81 10/2'7/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Log Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. Log Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 1F 11/19/85 /7 '~~'0~ 1/22/83J~[.~-~ Alaska Oil & 6as Cons. Anchorage 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 1F-7 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment Page 3 Drill Site Well No. L. og Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~mq 5 / 10 / 83 ~. 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2128/85 2C-7 10/15/84 Drill Site Well No. Lo9 Date 2Z' l~llm~_- 7/10/83, 2Z-2 '" 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF: pg: 0052 Anchorage Drill Site lA Well No. ~ lA-4 ,~lA-5 1A-7 ~1A-9 ~1A-11 ~1A-12 '~IA- 14 '~1A-15 '~lA-16A AI"FACF~4ENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~x,z 5/7/82x/-~ 1/25/82-.~ 3/23/83,/ . 1/19/83">, ~ 3/21/83,/ :' 3/8/82 4/1182 6/5/82 5/11/82~, < ~,6/8/82/ Drill Site 18 Wel 1 No. Log Date '"~18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81"--~ ~_ ~ 3/12/82/ '~18-6 11/18/81~ ,-, "~ 9/10/82/ ~ '~18-7 11/23/81 ~18-8 12/28/81',,> ~ 8/4/82/ ~'"' ~IB-g 6/24/82 ~ · 8/3/84/>~ Drill Site 1C Wel 1 No. Log'Date 5/9/8'1 5/8/81 7/13/81 ~]/8/8~>j~-. 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date __ 'N~iD.1 1/80~, ~,. 5/23/83// '"'"1D-3 8/5/80 1D-4 ~'7/30/80'~ .-, ~ 8/13/80, ~ ~lD-5 6/11/81 ~'1D-6 6/9/81 '~1D-7 6/8/81 ',~1D-8 (WS-8) 5110178 RECEIVED FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, InC. B(°x Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1A-7 Dear Mr. Chatterton' Enclosed is a copy of the 1A-7 Workover Well History to include with the Well Completion Report, dated 01/21/86. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L46 Enclosure cc' 1A-7 Well File RECEIVED F E B 0 4 1986 Naska 0il & Gas Cons, C0mmismlon Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i ' AtlanticRiChfieldCOmpany Daily Well History- Initial RepOrt: Inllmati~al: Prepare and submit the "lnillal Rel~' on the first Wednesday after a well la spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving Inclusive dates only. Dlatdct ~ County or Parish Alaska Field ILeeae or Unit I Kuparuk River Auth. or W.O. no. ITitle I North SloPe Borough ADL 25647 Recompletion State Alaska tell no. 1A-7 -Roll'N 4 AP1 50-029-20658 Operator ARCO Alaska, Inc. Spudded or W.O. blg~a:- Ioa~ Workove~ 12/03/85 12/04/85 12/05/85 12/06/85 Complete ~ord for each d~ relxzrted~ I A.R.C,o'a W.I. · [.ou, 2100 rrt°r st~tu' it · w.°. 11/28/85 :. -hfs;:, ' 56.24% 71'" ~ 865~~r~ ..... 8560~ PBTD, HIE.' v/bit::, l~ scrprI~?~;:' 9;5 PP8 NaC1/NaBg: Accept. rig ~' 2100 hfs, 11/28/85~. PuI~..:.B~V:a re~ O,W' vlv'~ 7~1", ~ O~[~ Bridgesal pill & 35 bbIs 9.5 pp~ brine 8126'-8466~. Displ ann v/9.5 pp~ br~e,-, on pkr ~ 8015~, circ, POH. RIH v/bit t 7" @ 8656' 8560' PBTD, Prep to retry BP 9.2+ ppg NaCi/NaBr RIH v/bit & scrpr, ta$ fill @ 8432', vsh to 8560' PBTD, rev circ h°le vol, POH. RD Schl, RIH w/CET, lo$ f/8538,-7580', POH, RD Schl. 7" @ 8656' 8560' PBTD, Tst retry BP 9.2+ ppg NaCl/NaBz RD Schl. RIH w/7" retry BP, attempt to set @ 8004' w/o success; pipe parted.~ POOH & rec'd 37 Its. RIH w/FTA, latch fsh @ 1747', POOH w/3½" tbs & BP assy, full rec'y. RIH w/retry BP, set @ 8000'. Prep to tat BP. 7" @ 8656' 8560' PBTD, POOH w/BP 9.2+ ppg NaCl/NaBr Tst. reCrv BP to 2000 psi, POOH. ND BOPE. Chg out tbg spool to Gen III (FMC) tbg adapter. RIH, retrv BP, POOH. · 7" @ 8656' 8560' PBTD, Prep to rn magnet 9.2 pp~ NaC1/NaBr Fin POOH w/BP. RU WL, rn gage ring/JB to 8400'. RIH & set FB-1 pkr @ 8302' WLM. ~U compl equip. Rn 62 its, 3%" tbg, lost slip die out of tb~ slips dn hole. POOH, did not rec die~ Prep to rn magnet. RECEIVED F E B 0 4 1~85 ~ 0il & Gas Cons. 6ommissic- Anchorage The above is correct For form preparation and distribq~ion, see Procedures Manual, Section TO, Drilling, Pages 86 and 87. Date · · Title Drilltn; Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting District I County or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River [ ADL 25647 Auth. or W.O. no. [Title AFE 603058 [ Recompletion loll'N 4 AP1 50-029-20658 Operator [ A.R.Co. W.I. ARCO Alaska, Inc. [ 56.24% Spudded or W.O. begun [Date Workover I cost center code Alaska IWell no. lA-7 Date and depth as of 8:00 a.m. 12/o7/85 thru 12/09/85 Complete record for each day reported 11/28/85 Iotal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our [ Prior status if a W.O. 2100 hrs. 7" @ 8656' 8560' PBTD, Displ'w/diesel 9.1 ppg NaCl/NaBr RIH w/magnet, no rec'y. RU & RIH w/pkr mill, mill pkr @ 8302', push to btm w/TOE @ 8537'. Rn GR/JB, would not go past 8123'. Rn 5.995" gage ring/JB. RIH w/pkr, set @ 8300', POOH, RD Schl. -Rn 3½" tbg, set & tat pkr. ND BOPE, tflJ tree. RU to displ well w/diesel. (Note: Rn total of 258 its, 3½" BTC AB Mod tbg & 4 its, 3½", 8RD AB Mod tbg w/SSSV @ 1781', FHL pkr @ 8037', FB-1 pkr @ 12/10/85 8309', "D't Nipple @ 8316', TT @ 8323'.) 7" @ 8656' 8560' PBTD, RR Diesel Displ well to diesel. 1400 hfs, 12/9/85. Tst tbg to 1000 psi. Set BPV. RR @ RECEIVED FEB 0 4 1986 0il & Gas Cons. Commission , ~ch0rage Old TD Released rig 1400 hrs. Classifications (oil, gas, etc.) Oil New TO [ PB Depth PBTD 8560' IDate [Kind of rig 12/9/85 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling Superintendent ARCO Alaska, Inc. Post Office B(;X'~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 30, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton. Enclosed are Subsequent Sundry Reports for the following wells' 1H-4 1H-8 If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU13/L43 Enclosures RECEIVED N~ska 0~[ ~ ~s C¢~"~$. (~o~nmissi0n Anchor3ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -O STATE OF ALASKA O(M ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-1 COMPLETED WELLx~ 2. Name of Operator 7. Permit No. ARCO A1 aska, I nc. 81-137 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20658 OTHER [] 4. Location of Well Surface: 659' FSL, 308' FWL, Sec.5, T11N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' 12. 9. Unit or Lease Name Kuparuk River Uni~ 10. Well Number 1A-7 11. Field and Pool Kuparuk River Fi eld 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool ADL 25647 ALK 465 I Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig @ 2100 hrs, 11/28/85. Killed well. ND tree. NU BOPE & tested - ok. Pulled 3-1/2" completion assy. Milled on pkr & recovered. Ran CET f/8538' - 7580'. While attempting to set the bridge plug, the pip( parted; fished & recovered. Set FB-1 pkr ~ 8302'WLM. Attempted to run 3-1/2" tubing; lost slip die f/tbg slips. POH w/tbg. Unable to recover the slip die. LD pkr/PBR assy. Milled on pkr ~ 8302'WLM. Pushed pkr to 8537'. RIH & set pkr ~ 8300'WLM. Ran 3-1/2" completion assy w/tail ~ 8323', SSSV ~ 1781', & pkrs ~ 8300' & 8037'. Set pkrs. ND BOPE. NU tree & tstd. Disp well w/diesel. Tstd tbg to 1000 psi - ok. Secured well & released rig ~ 1400 hfs, 12/09/85. RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~o ~.~ Title Associate Engineer The space belo r Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU13/SN02 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.#~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1A-7 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1A-7. I have not yet received the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L25 Enclosure RECEIVED JAN 3 1 1986 Ataska 0il & Gas Cons. (;omm~ssiot~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SI:ATE OF ALASKA ALASKA{["- AND GAS CONSERVATION C(~ ~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-137 · 3. Address 8. APl Number i~. 0. Box 100360, Anchorage, AK 99510-0360 50-029-20658 , 4. Location of well at surface 9. Unit or Lease Name 659' FSL, 308' FWL, Sec.5, TllN, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1386' FSL, 1197' FEL, Sec.7, TllN, R10E, UM 1A-7 At Total Depth 11. Field and Pool 1053' FSL, 1304' FEL, Sec.7, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Fool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16, No. of Completions 09/27/81 10/10/81 10/17/81'I N/A feet MSLI 1 , 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21.. Thickness Of Permafrost 8704'MD, 6434'TVD 8566'MD, 6321 'TVD YES [~X NO [] 1781 feet MDI 1700' (approx) 22. TYpe Electric or Other Logs Run D I L/SI"/GR/BHCS, FDL/CNL/GR/Cal , CBL/VDL/CCL/GR ,,. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT.. PER FT. GRADE TOP .BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 16" 65# H-40 Surf 88' 24" 200 sx Fermafrost _ 10-3/4" 45.5# , K-55 Surf 2469' 13-3/4" 1400 sx AS Ill & 250 s; AS II 7" 26# K-55 Surf 8656'~ 8-3/4,, 850 sx Class G ' , .24. Perforations open tO Production (MD+TVD of Top and Bottom and 25. TUBi~NG R ECOR D interval, size.and number) SIZE DEPTH 'SET (MD) PACKER SET (.MD) 8404 ' - 8413 ' 3-1/2" 8323' 8300 ' 8422' - 8443' w/4 spf 8445 ' - 8466' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL ~MD) AMOUNT.& KIND OF MATERIAL USED ' N/A 27. PRODUCTION TEST Date First. ProduCtion I Method .of Operation (Flowing, gas lift, etc.) ' N/A 1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PER.IOD' J~ Flow Tubing ' Casing PressUre CAL~CULATED ~ OIL-BBL GAS-MCF WAT.ER-BBL OIL GRAVITY-APt (corr) ' Press. 24-HOUR R ATE ,,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JAN :[986 Alaska Oil & Gas Cons. Cop, lmission Anchorage Form 10-407 * NOTE: We11 was recompl eted 12/09/85. TEMP3/WC43 Submit in duplicate Rev. 7-1-80 CO.NTINUED ON REVERSE SIDE MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Kuparuk River Form N/^ Top Upper Sand 8128 ' 5961 ' Base Upper Sand 8198' 602:$' Top Hi d Sand 82:$6' 6049' Base Mi d Sand 8250' 606:$' Top Low Sand 8:$96' 6185' Base Low Sand 8421' 6200' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ X/~~ Title Associate Engi neer 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- lng 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 January 14, 1986 Mr. C. V. Chatterton Commi s s i oner State of /11aska /11aska Oil & Gas Conservation Commi ssion 3001 ?orcugine Drive /1nchorage, AY, 99501 SUBJECT' State Regorts Dear Mr. Chatterton' Enclosed are the December monthly re~ortS for the following wells' 2H-6 3A-13 3~-12 3J-11 4-29 L2-~9 1/1-13 2H-7 3/1-14 3F-13 3J-12 16-15 L3-5 lA-14 2H-8 3/1-15 3F-14 4-23 16-19 L3-!9 1H-4 2}t-9 3A-16 3F-15 4-24 16-20 LB-15 3F-11 3J-lO 4-27 L2-21 1H-8 2~-8 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tW GRU13/L05 Enclosures RECEIVED JAN 1 4 1986 ARCO AlaSka, Inc. [sa Subsidiary ot Atlar~tlcl:lichtieldC°mpan¥ STATE OF ALASKA ALASKA O(' AND GAS CONSERVATION CO~i,,ISSION MONTHLY'REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operationX~-] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-137 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20658 4. Location of Well atsurface 659' FSL, 308' FWL, Sec.5, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB ADL 25647 ALK 465 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1A-7 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool For the Month of. December ,19 85 12. Depthatend of month, footagedrilled, fishingjobs, directionaldrillingproblems, spud date, remarks Accepted rig ~ 2100 hfs, 11/28/85. Killed well. ND tree. NU BOPE & tstd. Pulled 3-1/2" completion assy & pkr. Fished and recovered FB-1 pkr assy & remaining completion assy. Ran CET. Pi'pc parted; fished & reCovered. Set FB-1 pkr. Attempted to run 3-1/2" tbg; lost slip die f/tbg slips. Pulled tbg. Pushed pkr to 8537'. Ran 3-1/2" tbg & pkr. ND BOPE. NU tree & tstd. Displaced well w/diesel. Secured well & RR @ 1400 hrs, 12/09/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 3-1/2" tbg, $SSV ~ 1781' FB-1 pkr ~ 8300', TT ~ 8323' 14. Coring resume and brief description None 15. Logs run and depth where run CET f/8538' - 7580' 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN 986 Aladm 0Il & Ga~ Con~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR17 .. Rev. 7~1-80 Submit in duplicate Alaska, Inc./ ('~ ARCO Post Office B(~x'~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1A-7 Dear Mr. Chatterton. Enclosed is a Sundry Notice for the subject well. We propose to convert well 1A-7 to a selective single completion. Since we expect to start this work on November 25, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4944 or Jeff Quintana at 263-4620. Sincerely, J. Gruber Associate Engineer JG/tw SN/L073 Enclosure RECEIVED' Alaska Oil & Gas Cons. Corllrrl]s8~oll Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLxI~] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 659' FSL, 308' FWL, Sec.5, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' I 6. Lease Designation and Serial No. ~OL 25647 ALK 7. Permit No. 81-137 8. APl Number 50-- N2q-?N6R8 ' 9. Unit or Lease Name 10. W~iYN-~.;i~e; ....... 1A-7 11. Field and Pool Kuparuk E~ver F~e~d Kuparuk R~ver 0~ Poo~ 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubing ~ Other J~ Pulling Tubing (Note: Report multiple completions on Form i0-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A-7 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally t~'ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: November 25, 1985 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ ~ Title The space below/'Jor Commission use RECEIVED NoV 41aska 0il & fi~s Cons Cornrnissior~ /~nchorage ' Associate Enqi neer Date Conditions of Approval, if any: Ol~IGilikL $16iiE9 eT LOItl~IE 't;. SI~ITII .. Approved by . Approved Copy l~®turned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate (JLQ) SN/108 ARCO Alaska, Inc. Post Office Bot,~ ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 June 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Revised Well Completion Report - 1A-7 Dear Mr. Chatterton' Enclosed is a revised completion report for well 1A-7. This report is being resubmitted due to an RKB change. Sincerely, J. Gruber Associate Engineer JG' llm Enclosure GRU1/L30 RECEIVED JUN 1982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~: STATE Of ALASKA (~i ALASKA AND GAS CONSERVATION C ~ ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ~'~/'I'S~_,D Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 81-1 37 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 s0-029-20658 4. Location of well at surface 9. Unit or Lease Name 659' FSL, 308' FWL, Sec. 5, T11N, R10E, UM ]LOCATIONSt Kuparuk 25647 At Top Producing Interval VERIFIED 1 10. Well Number 1386' FSL, 1197' FEL, See. 7, T11N, R10E, UN 'Surf. ~ I 1A-7 At Total Depth B.H. ~ 11. Field and Pool . 1053' FSL, 1304' FEL, Sec. 7, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River 0il Pool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/27/81 10/10/81 10/17/81 -- feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8704'MD, 6434'TVD 8566'MD, 6321'TVD YES1~] NOI-] 1625 feetMD 1700' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDL/CNL/GR/Cal, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 88' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surf 2469' 13-3/4" 1400 sx AS III & 250 sx AS II 7" 26# K-55 Surf 8656' 8-3/4" 850 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) 3-1/2". ' 8098' 8014 ~ N/A · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,, N/A · 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I Flow Tubing 'Casing Pressure CALCULATED I~' OIL!:BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN 2 41982 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 GRUY/BG/7/8 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Kuparuk River Fo rm. Top Upper Sand 8128' 5961' Base Upper Sand 8198' 6023' Top Mid Sand ' 8236' 60d9' Base Mid Sand 8250' 6063' Top Low Sand 8396' 6185' Base Low Sand 8421' 6200' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed J~-~~~' ~ Title ~'. F)r l 0. Fnn~r; 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- lng 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 KUPARUK ENGINEERING TRANSMITTAL TO: ~~. ~ ~ FROM: DATE: .~/~~~ WELL NAME: D. W. Bose/Ann Simonsen Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIVED · ' ~ .," . .. .~: JUN 1 0 1982 RETURN RECEIPT To: '. AhCO'ALASKA, INC. Anchorage ? · ~' ATTN: · ANN SIMONSEN - AFA/311 P. O. BOX 360 . ANCHORAGE, AK 99510 L STATE OF ALASKA C~ ALASKA ,LAND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~( OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Ine. 81-137 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20658 4. Location of Well SL: 659' FSL, 308' FNL, Sec 5, T11N, RIOE, UN BHL: 1156' FSL, 1315' FEL, Sec 7, TllN, RIOE, UM 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-7 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. K U p a r u k KB=100' I ADL 25647 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field River 0 il NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~/( Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Poo 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On, May 6, 1982, Kuparuk Well 1A-7 was stimulated with 120, /0 hydrochloric acid. A mud and silt remover was mixed with the A total of 153 bbls of acid were squeezed across the following intervals using a coiled tubing unit. 8126-8220' 8232 8249' 8404-8413' 8422 8443' 8445 8466' MD ~ -- ~ ~ -- ~ -- acid. Diesel was used to displace the acid. Nitrogen was circulated intermittently with diesel to expedite the cleanup. All pressure equiPment was tested to 4000 psi. All injected and produced fluids were flowed to surface vessels and disposed of. The Kuparuk Well 1A-7 test rate increased from 1130 ~D to 1752 BOPD as a result of the ac~ion~[~ A-21 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed · ; Title Thespaceb I~vforCommission~ Conditions of Approval, if any: Engineer Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo~:.' 0 April 21, 1982 Mr. C. V. Chatterton State of Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Attached please find Sundry Notices of Intention for Kupaurk Wells 1D-2, 1D-4, 1D-5, 1E-3, 1E-5, 1D-3, 1C-1, ilA,7,~1A-9, 1A-10, and 1A-11. The work on these wells is scheduled for the latter part of April, 1982. Also attached is the subsequent notice for Well 1B-gGI which was perforated in late December, 1981. We apologize for the untimeliness of this report. A' recent review of our records revealed this submission had been .overlooked earlier. Sincerely, bl Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-137 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20658 4. Location of Well SL: 659'FSL, 308'FWL, Sec 5, T11N, RIOE, UM BHL: 1156'FSL, 1315'FEL, Sec 7, TllN, RIOE, UM 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-7 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i I Poo KB-100' ADL 25(,47 i 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give Pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposed to stimulate the Kuparuk Sands with acid. Acid will be sPotted with a coiled tubing unit with BOP assembly tested to 4000 psi. All circulated and flowed fluids will be diverted to tankage on location. The well will be tested subsequent to .the stimulation. Expected start date is April 27, 1982. ~ ~ ~o. ~~t~a ~I~~ APR 2 6 .i982 14. I hereb, y certify that t~oregoing is true and correct to the best of my knowledge. ~ ~_ ~~C~ Area Operations Engineer Signed Title Date ~l-he,i~l~ce ~ ow for Corem ission usei~ '(~on~litions of Approval, if any: V Approved CopY' Returned Approved by COMMISSIONER the Commission Date___ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska,'lnc. ~ Post office B~"~60 April 14, 1982 C. V. Chatterton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Enclosed is the subsequent report for Kuparuk Well~7 which covers the water injectivity test and the reper- forations of the Lower Sands. Also enclosed, per our phone conversation, are copies of the revised sub- sequent reports for Wells 1C-3 and 1C-4, correcting surface and bottomhole locations which have not been received by your office. Sincerely, ./. Simonsen slz Attachments P EC£:IVED AP}{ 2 3 ]982 Gas Cons. ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-137 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 5o- 029-20658 4. Location of Well Surface Location: 659'FSL, 308'FWL, Sectlon 5, Tl lN, R10E, UM Bottomhole Location: 1156'FSL, 1315'FEL, Sectlon 7, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB = 100' I ADL 25647 12. 9. Unit or Lease Name Kuparuk 25647 10. Well Number 1A-7 1 1. Field and Pool - Kuparuk River F ietp~' Kuparuk River Oil 1 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Re- Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) [~ Altering Casing [] [] Abandonment [] [] Other ~3 [] (Injectlvity Test (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any Commenced operation 12/4/81. Perforated Lower Kuparuk Sands with 2 5/8" Slimkone guns, 4 SPF, 180' Phasing over intervals 8406'-8414' MD, 8424'-8466' MD. Flowed on 64/64", 32/64", and 16/64" choke in attempt to stabilize intermittent flow rate. Rate did not stabilize with flowing tublng pressure varying from 0 to 140 psi-132 bbls of 22.6'API crude with a trace BS&W produced over 14 hfs 40 min. SI well. Obtained sample at 8060' MD which was water with 0.5% solids and oil skim. Sample obtalned at 4500' MD was 23.2°API crude. On 12/6/81, began injectlvity test by pumping diesel. Injection was not established until exceeding parting pressure of the of the rock (2750 psi surface pressure). Main- rained injection at approximately 200 BPD at 2500-2800 psi surface pressure.. Pumped 120 bbls diesel followed by 150 bbls 40/60 glycol/water followed by 60 bbls diesel. On 12/9/81, reperforated Lower Kuparuk Sands with same type guns and shot density used )reviously. Attempted injection again on 12/10/81 with the same result: formation would ~ot take fluid below fracture pressure. Pumped 90 bbls diesel at average rate of 237 BPD at 2500 ps1. SI for pressure fall.fl test. Terminated injectlvity test on 12/11/81. On 2/9/82, RU to perforate Lower Sands for short flow test. Perforated 8406'-8414'MD and 8424'-8466'MD with 2 1/8" Inerjets, 4 SPF, O* Phasing. Well flowed for 9.5 hfs and produced 49 bbls fluid. Perforated Upper and Middle Sands at 8126'- 8220'MD and 8232'- 8249'MD with same type guns and shot density used last on Lower Sands. Opened well on 176/64" choke for 28.5 drawdown test. Well flowed 1474 BOPD of 24.4°API etude with 0 BS&~ for a cumulative production of 1740 bbls. ISIBHP:2923 psi, FTP:105 psi, FFBHP=ll70 psi, GOR=619 SCF/BBL. Dynamic production logs were run and a 15.3 hr buildup began 2/12/82. FSIBHP:2915 psi. Well returned to production 2/13/82. 14. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. . SignedV. ~1~..~ . ~~~--'~ Title Area Operat ions Eno:[neet The space t~w for Commission use - Conditions of Approval, if any: RECEIVED' Approved by Form 10-403 Rev. 7-1-80 TW-B-6 APR 2 1982 ., By,..Order .~f co~/~,~o.~r:a-""" uas~~ission Date__ . Anchora~ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ('"( STATE OF ALASKA~" ' ALASKA ~-,~. AND GAS CONSERVATION CO%;'~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Ataska, Inc. 81-137 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20658 4. Location of well at surface 659'FSL, 308'FWL, Sec 5, TllN, R10E, gM 9. Unit or Lease Name Kuparuk 25647 At Top Producing lnterval 1386'FSL, 1197'FEL, Sec 7, T11N, R10E, UM 10. WellNumber 1A-7 At Total Depth 1054'FSL, 1305'FEL, Sec 7, T11N, R10E, UM 11. Field and Pool Kuparuk River FieId 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 100' RKB] ADL 25647 ALK 4~5 Kuparuk R~ver 0ii PooI 12. Date Spudded 9/27/81 13. Date T.D. Reached 10/10/81 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re ~ 16' N°' °f C°mploti°ns 10/17/81 -- feet MSL 1 17. Total Depth(MD+TVD)18.PlugBackDepth(M~D)19. DirectionalSurvey [ 20. Deoth~hereSSSVsot ~ 21.Thicknessof~ormafro~t 870fi' 6~17' 8566' 6316' YES Ux NO U 161~ feet MD 1700 (approx) 22. Type Electric or Other Logs Run DIL/Sp/GR/BCHS, FDC/CNL/GR/CAL, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ., 7" ?~ K-55 S~r~ R~5~' R ,~/~" RSO~x C1 a~ ~ I T , 24. PerforatiOns o~en tO pr°du~ on (MD+TVD of Top and Bottom and 25. TUBING RECORD interval~size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , , 3 1/2" R098' 8014' 8404' 8413' 8422' -8443' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8445' 846B'. w/4 SPF ~. ,....~.~. .:.. DEPTH INTERVAL (MD). AMOUNT & KIND OF MATERIAL USED . ~/A , 27. PRODUCTION TEST " :Method of Operation. (Flowing, Date:First Production . ~ . .~ . . gas i'ft, etc.) ' 12/25/81 I' 'Flnwinn " - ' ' "'" ' ' '" '~'~'· ' CHOKE SIZE GAS-oIL Date of ~est Hours Tested PRODUCTION FOR~ Gl L-BBL GAS-MCF WATER-BBL ' RATIO ~11~1~? ~_~S " TEST PERIOD ~. ~7~n ~n~ !7~/6~ FIo~.Tubng. Casing Pressure CALCULATED ~ OId-~ O~-~F WA~R-BBL" OILGRAVITY-API (corr) ' Press~ !05 24'HouR'RATE ~ · .'.-~ ·...:~. !474 9~ . -- .... . 24.4 28. CORE DATA , . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit cOre chips. N/A ':. " ' . , , . - 7 :: · ~.' :"" :, :'h'.::., '.~, --. 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~'6~6'~i~: in duplicate MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,,, Top Kuparuk N/^ River Form. 8128' ! 5964' Base Kuparuk River Form. 8526' 6288 ' c , .. 31. LIST OF ATTACHMENTS 32. .I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.. t;~,_ (~/~4,~/~ TitleArea Ops. Eh,qr. Date MARLO 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". Transmi~ted here,..;ith are the following' ... PLEASE I;OTE' BL -'BLUEL!i~E, S - SEPIA, F - FILM, T - TAPF / x¢-_~ ~,~ ,.~K :Owl_!~i';~:'~/ /t.,~ ,.~ .,- ~..t,~..~_. . T~- J~L-'-;..~£ ,SETUP;; I-',ECZ;2T T0: ARCO AI_AS~t.~, I;;C. . ATTIC' A~;t~ SI;.iO;iSEF! - AFA/3ll P.0. 80't'; 360 A;;C:-iO2AGZ, ,AK 9E~lO ARCO Alaska, Inc. if.' Post Office B~ 60 Anchorage, Alaska 99510 Telephone 907 277 5637 Febru.ary 9, 198~,o~ Mr. Chat ChatEerton State of Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska. 99504 Comm, Dear Mr. Chatterton: Attached please find Sundry Notices of Intention for Kuparuk We 1~§ _!A~7-~ and lB 11 G1 Due to the immediate action proposed for these wells, these Notices were discussed today with 3ack Trim. ble of your office, who extended verbal approval. Sincerely, T. Wellman bl Attachment RECEIVED FEB 0 9 1982 Alaska Oil & Gas Cons. C0mmissi0~ Anchorage ARCO Alaska. Inc. ~s a subsidiary of AtlanticRichlleldC0mpany STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0.Box 3607 Anchoraqe, AK 99510 4. Location of Well 7. Permit No. 81-137 8. APl Number 5o- 029-20658 9. Unit or Lease Name Kuparuk ;>5647 Surface Location: 659' FSL, 308' FWL Sec. 5, T11N, R10E, UM Bottomhole Location: 1156"FSL, 1315' FEL See. 7, Tl lN, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. __ KR : 1OO' I ADL 25647 12. 10. Well Number 1A-7 . 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) e Perforate X [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent oetails and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to reperforate and test the Lower Kuparuk Sands in this cased hol. e. This action follows our unsuccessful attempt in December, 1981, to establish water injection into this- interval. In light of its importance to Increment I waterflood planning, we are planning another attempt to inject into the Lower Kuparuk Sands in the recently drilled 1A-13 well. This will be detailed in a future Sundry Notice. Expected start date for the reperforation and test is February 9, 1982. Subsequent Work Reported on orm 1 o. ii.zll atea RECEIVED FEB 0 9 1982 Alaska Oil & Gas Cons. Commissior~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~,~,,ii, TitleSI'' Operations Engineer Date ~,/~/~1~ Approv~c~ CoD:~ - The space below for Commission use Conditions of Approval, if any: Utilize ~re line lubereator, pres~re tested to 3000 psi~ for all wire line ~. 'ORIG. INI[ S G ED Approved by ~Y [9HH!E C. SMITH COMMISSIONER the Commission Da,e Form 10-403 Submi~ "lmentions" in Triplicate Rev. 7-1-80 and "Subsequen~ Repoas" in Duplicate r,u,-,ln %LOPE Ei:GIREERI~;G T=,,,I iS,.! T-" ,' .... /I) 'C Z...., · ' _ ~j¢--~ FROM'" d.d. Pawelek/Ann Simonsen D.-".TE' /.2 - / ?-~'/ WELL NAME' Transmi;ted here:.:ith are the following' -... PLEASE ~,n~.-. "~ - - T - TAPE ~1~ BL - BLUELi~I~, S SEPIA, F FILM, . . :.Ct,, .... L .... uED D~ F_.. RECEIPT "" .... n'.: F.;;" · *'""-- ?LEA2 RECEIVED' Alaska Oil & Gas Cons. ¢ornrnissio~ ARCO ALAS}CA, I~C. ATT~: A~.~; SIH0~SE~ - AFA/311 P.O. BOX 36O A;~CHORAGZ, AK 99510 A;RCO Alaska, In~C,~/ Post Offid[ ~x 360 Anchorage, ~,,laska 99510 Telephone 907 277 5637 November 25, 1981 Mr. Hoyl e Hamil ton State Of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 11-3 DS 15-11 DS 12-14 DS 14-12 DS 13-8 DS A-7 DS 14-13 DS lA,9 DS 14-14 DS B-8 DS 14-15 DS B-9GI Dear Sir' Enclosed please find the following' (1) ~The Completion Reports for DS 13-8, DS 14-14, DS 14.-15, DS 15-11, DS 15-12, DS A-7, DS lA-9 and DS B-8. (2) The Monthly Drilling Reports for DS 11-3, DS 12-14, DS 14-13, DS 15-12, DS lA-9 and DS B-9GI. Sincerely, P. A. VanDusen District Drilling Engineer PAV' GA' 1 tc Enclosures DECO ? i981 Alaska Oil.& Gas Cons. Commissio~ Anchorage ARCO Alaska. thc is a subsidiary of AtlanlicRichfieldCompany ALASK ,~: AND GAS CONSERVATION ,~-_, ~..:~1 ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-137 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o-029-20658 4. Location of well at surface 9. Unit or Lease Name 659'FSL, 308'FWL, Sec 5, TllN, RIOE, UM 'iLOCA~iONS1 Kuparuk 25647 At Top Producing Interval i VERIFIED I 10. Well Number 1386'FSL, l197'FEL, Sec 7, TllN, R10E, UM ISurf.- F__~_~ A-7 At Total Depth ~B. H. ~ 1 1. Field and Pool I 1054'FSL, 1305'FEL, Sec 7, TllN, RIOE, UH Kuparuk River Field 5: Ele~a~on in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 100'RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions .9/27/81 10/10/81 10/17/81I --feetMSLI 1 17. Total Depth(MD+TVD, 18. PIugBaokDepth(MD+TVD, 19. DireotionalSurvey [ 20. Depth where SSSV set ] 21. Thickness of Permafro~t' 8704' 6417' 8566' 6316' pES[~ NO[] 1625 feetMD 1700' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDL/CNL/GR/Cal, CBL/VDL/CCL/GR 23. . CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# .. H-40 Surf 88' 24" .~OOsx Permafrost 1.0-3/4" 45.5# K-55 Surf 2469' 13-3/4" 1400sx AS III & 250s( AS II 7" 26# K-55 Surf 8656' '~ ~8-3/4". 850sx 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) · 3½ 8098' 8014 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - ,, " :,: . ~ DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A i ' , 27. PRODUCTION TEST Date First'Production ~ .,.. . .I "Method of Operation (F!owing.f. gas lift, ~tc.} . ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ , ,: FioTM Tubing Casing Pressure ' . CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 'Press. ' ' . 24-HOUR RATE ~ , 28. CORE DATA · -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · : _. N/A · .. · . , ,. Form 10-407 Submit in' duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Kuparuk River Fo 'm Top Upper Sand 8128' 5961' Base Upper Sand 8198' 6023' Top Mid Sand 8236' 6049' Base Mid Sand 8250' 6063' Top Low Sand 8396' 6~85' Base Low Sand 8421' 6200' N/A 31. LIST OF ATTACHMENTS · , Drilling History '32. ~ hereby certify that the foregoing is true and correct to the best of my knowledge Signe - -~-~/..ff_.~z ' ,_ , TitleSr. Dri 1 1 i ng Engr. 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 1.6 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 .")e 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- lng 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". - Drilling History - NU Hydrill & Diverter. Spudded well @ 0330 hrs, 9/27/81. Drld 13-3/4" hole to 2733'. Pumped cmt plug fr/1500' - 2000' w/660 ASI. Drld 13-3/4" hole to 2489' Ran multishot. Ran 59 its 10-3/4" 45.5#/ft K-55 csg w/shoe @ 2469'. Cmtd i0-3/4" csg w/14OOsx AS III and 250sx AS II. ND Hydrill & diverter. Instld 10-3/4" packoff & tstd to 2000 psi-OK. NU BOPE & tstd to 3000 psi-OK. Tstd csg to 1500 psi-OK. Drld FC & cmt. Tstd csg to 1500 psi-OK. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-OK. Drld 8-3/4" hole to 8704'. Ran DIL/SP/GR/BHCS, FDL/CNL/GR/Cal & CBL/VDL/CCL/GR. Ran 212 jts 7" 26#/ft' BUTT csg w/shoe @ 8656' Cmtd 7" csg w/850sx Class "G". Bumped plug with NaC1/NaBr brine. Instld'7" packoff and tstd to 3000 psi-OK. Ran CCL/GR & CBL/VDL/CCL/GR. Ran Gyro. Arctic packed 7"x10-3/4" annulus w/300 bbl H20, 200sx Arctic Set II and 99 bbl Arctic Pack. Tstd csg to 2000 psi-OK. PU 3½ D.P. clean out to FC @ 8566'. Ran.3½ packer assy. on wireline w/tail @ 8097 and pkr. @ 8014'. ~Test packer w/3000 psi pressure-OK. LDDP. Ran 3½" tbg. Land tbg, ~Test pack off to 3000 psi-OK. Test tbg and annulus. Leak. Reland tbg. Test~ tbg., seal assy. & pkr. to 3000 psi-OK. Test pack off to 3000 psi-OK. Check SSSV-OK. ND BOP. NU tree. Test pack off and tree to 3000 psi-OK. Displace NaC1/NaBr brine to diesel. Test tbg. to 3000 psi-OK. Test SSSV-OK. Close SSSV. Bleed tbg and annulus to 0 psi. Close all valves. Install BPV. Secure well. Release rig @ 0930 hrs., 10/17/81. sun April 27, 1982 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16905 Well: A-7 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: October 12, 1981 Operator: Chris Willoughby Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Direct.ional Survey on the above well. This survey is being resubmitted due to a Kelly Bushing error on the original survey dated October 14, 1981. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. KB/pr Enclosures Ken Broussard District Manager . .. ~'FASUR. ED :7 F P T H .... !.E!J..F ........ s U_.F - SE A VERTICAL VERTICAL P F P T H D F P T H ..... 0 .......... 0',"'6'0 - 1 o o ,"o loo lOO.OO ,, , . c q9 300 299.91 199.91 ~00 399.91 299.91 f O O 5 99.89 q99 · 89 7~0 699,89 599.89 qnO Ncq.8~ TUg 1000 999.87 899 . 1.! 00 ~, 0 ~',.p ~,,,~6 ............... 999 1200 11D9,25 1099.23 I ZOO 1297.72 1197.72 14 O0 1394.66 129~ ,66 1~.00 ] fl,qg.37 13~lg.37 1~'50 I ~' ~r4.62 l.q'~r-'' 62 ..~- ~ ~, .. ,...~ ~.. ] LO0 ] 58].14 lqS1,] 4. 1650 1625.99 1525.99 1700 1678.11 1570,1 li'00 1755,96 1655.96 ..................... 1900 1P:Z~.47 1738.47 2C00 1q17.35 1817,35 21 OO ] 9~ I · 73 1E~91 · ............ 2150 2026,90 1926. 2200 20A0.51 1960.51 2250 20¥2. ~,8 1.992. 2 3 fi 0 2' i 22.8 t 2 [} 22. S t ') ~ ':' 0 ,S:2 P,~. ~ 2105.44 2 500 22'2g. 05 2128. SPE R R Y-SUN ,.~ C HOP AGE, Cor, IPUTAT I kELL ,.,cUF:VrYING,~ COI',!PAi"-iY .. · :'.)_.¢..ZE._OF .... E.u..P:.V.._E.Y oc DATE ?,OSS GYROSCOPIC SURVEY JOB NUM~E~ ~OSS-~.~-.eOt ............... ~ F.k.N,L~.:~,%W_,L~.P.Z.LZ.v. = OPERATO~-~ILLOU6HflY COURSE COURSE INCLINATION DIRECTICE C~EG MIN DEGREES: o o N o. o ~ O '~8 ~' A. 29 W 2 13 ~C 22 · 50 FL 0 49 S 8.69 E. 0 '55 S 86.1.0 W 0 48 g 5.10 E 0 21 S ~q.79 W 0 26 g 52. 0 W 0 2A S 55.10 J 0 =8 e 62,8q 3 56 g 8.69 W . 7 =~ ¢' 9 50 W 23 27 c, 25 21 S 8.60 W 27 6 S 6.29 W 29 O S ~ .89 W "2 40 o 6.7° ~q 42 ~' 7.6° W '+S 26 S 7.79 49 4 ? 7,89 .... 5 ~' 7,8c ..: ,_~ ~::a ~o c- 7.69 ~,~ 60 22 c 7,60 W 60 59 S 7.79 DOC.-LEO _. ¢,.EVER I TY PEG/lDO TOT/~L RECTANGULAR COOFDIr.J~TES N 02 TH/SOUTH EA ST/WE'ST 4.05 65.29 S 14.65 4 9° 96 "+9 S 21 7~ . /' · 4.80 115,06 S 25.52 4.27 135.42 S 2C~, 10 ~+,0~ 157.32 S 31,95 4.0~ 180.72 S 3a,,,$5 W 3.79 231.70 S ~$,50' W 5.67 34B.42 g SE.lO W 4.~4 41fl.63 S 6a.99 W 5,2~ 486.51 S 7a.q] W q.7O 52~.57 S 80.09 ,J 4.93 563.94 S RS.a8 ~., 4 .qq 646,45 c 95.6~ 3.02 689.18 S 102.3P W .6 6 7 ~'~' ~' ~"2' ' S ............. i '~ 8.2 ~ 12 , ] C:,c,] l!'/O.CO ~'T. VE!:I'IC;,L c~ CT I O~.', ¢. l! 0 ,,- r.,7 4.f c:- 7.2b 7.~,,4 f~.qq 1~ .. ~ A2.22 q~, I 37.7" 232.42 . . ~ 4q. "P 5 · 4 6 .A .. 5 ?3 · 26 ':' 62 · ,, ~ 4 729.3 ~: ........ TRUE .................... SU~- SEA '"',r A S U'R E O VERTICAL N/E~,T I C/~ L E'r' P 1" ~' DE P 1 i.~ DE PT H 2 700 2329.57 2229.57 2 ~.O 0 2.38_1,,,22 .......... : ....... 2281,2. 2. 29£;0 2432.60 2:5.32.60 3000 2q~.07 23~'4.07 31 O 0 253 7 .. B.5 ............. 2,.~t. 3900 °":' q 1.69 24 al 3300 26a6.26 25~6.26 ~. ~9 o~. 9q . $ 4 O fl .......... 26.9 9, ~ .................. ~..u .... · .5 9 $500 2752, ] 1 2652 5c00 ..... 2,qO~. 33 270q · 3~/.00 2507.0~ 2~07. O~ ~ ~.- 00 29~'., 5. ~ 6 z~ C [) O 300 l .Bq o0~7.79 2947,7~; ~+200 ~..0. .16 .... 3,16 q3(!0 ~ . .:141.~q 3~1,05 q4OO 3192.~2 3G92 ~SOO 72qE,.68 ....... qGO0 .~0~...~4... 32U3.c-~ 47 n 0 '~ ' ..... 64.53 ~96q ~00 '<" '')° 7.5 . 3 4qo0 z~cr. 1~ 33°6.1q 5000 3565.85 3q 5100 . 363.6,70 ..... 353.6,70 5200 ~707,71 36C7,71 5300 '3778.97 3e 78 · 97 .5~0~ ~50,. ~7 . 7~ ~00 =c2= " ,SPERRY-SUN WEL. L SURVEYING ANCttORAGE, ALASFA COMPUT.~TICN D~,TL .. OA.]'.g .... OE._.,~UE?_f:..¥. ...... ()CT 0SE R BOBS GYROSCOFIC SURVEY JOB NUMBER EOSS-16905 ..... KELLY .... bI~SH.I..%G .... EL£V,. ~ OPERATOR-WILLOUgHbY 12, 1,'Fl 1CG.C:t! FT'. COURSE INCLINATION f3 E G r,~ I N C OUR S E .D I RE CT I ON DEGREES , · 9.50 1.0 6~ 12o19 13o50 14 16.10 16.79 17.1~ 17.$9 lsd. $9 18 ~50 15.79 ~9.2~ 19.50 20.50 20.60 21.50 22 · $9 2n 2° 2~ 3~ 2~ .89 24.3~ 24, 24 50 2 q. 6 q gO.1° ,' 25.50 D 0 G - L E G .................. . ............... 1.0 I.....A L .................... SEVER ITV RECTANGULAR COORF.~INATES OEG/lOO NORTH/SOUTH [iAST/WEST VF:~TIC~:L 1.44 818.0q S 120.26 1,21 902.75 S 133.44 · 1.29 1071.12 S 165.49 1,] 4. 1154,71 $ 184.b6 " 2,0 z~ .1.216_., ]Z_ _S .............. 2. Q.~., 1'5 ..W W 1,3"..~ 1_317.73 S 227.311 V W .79 1398,09 S 251.03 · W ....... 1.21 - .......... ~fl ,~._8_$ 2.7~.,..7 6 .... ,., W .15 ' 1560.25 S 301.07 ~,.' ',.! .75 !.S41.45 S 327.07 .~ W · 39 .. 1.7..22 ,...7.Z_~. .................. 55 ~, ~ 8 ..... W. W .50 180q,33 S 381.09 W W 3.21 1986,97 $ fl09,8] W 'W ..... !, 07 ............ K?_.g..8,_ 7~ ..... ~ ................ ~ 2.&.,.6 ;~ ..... ~ .... :, .37 !q70.aq S qxc '~3 W W 1.38 2053,9~ S 46~.72 W 2.85 2219.49 S 532.03 ~ W 1.85 2299.50 S 562.97 W ',.' . 2.28 2~77.,~?.~ .............. 59.~.,36 W W 2.16 2'~52.89 S 626.24. k W 2.7~.., ,..~'26.., 0=~, S 657."2. ~W · 63 · 50. ,. · 38. .27 25?.6 = ° ................... ,- - .. ef~..Q. ..... :4 .......... ¢,87.64 I,,~ ?6. F. 1 ?-~ 2663.90 S 717.8q W 27f:,q.70 _m729,05 g 7~7,7~ N 292=...~=.,.~ .27..'73.,..~_1 .... K ................... 7.7.6 · 57 . W 2 ¥ 9 6. ] 2 9257.61 $ fl05.59 W 2966.1 q "q21.qO. _ S 834.P. 0 N 30=5,R8,., ...... 67 W .,17.. 1 SP=RRY-SUN W£LL SUqVEYINS ANCHORAG[~ ALASKA COMPU T AT I SOMP2NY TOTAL T-~-Ni~Ui_'-/~-t~, ........ -~"0-~,~-~'~ -'~'A"T ['7. $ ' ¥' F F I I F'_/' t. NORTIt/SOUTH :'AST/WEST S-^TiSL 5700 q069,18 ' 5~00 4195,10 fiqO0 421~.11 41.18,11 6 C 00 42~4.09 4194. Oq 62 C 0 4 ~)q 8,58 4Z-98 6300 4526,81 ' 4426,81 6500 46~5,19 4fi~5 66 fi 0 476 l~. 76 6~; 00 ~915,75 4815,75 6o00 q 5°0 · 73 q890,7'~ 6~50 ~02~ · 7180 51q2.83 5042.&3 7200 5220 ..... ........ . ............... ~ .. 7300 5298.21 519P.21 7~ 00 5~,76,11 .... 75~0. ~q54.73,., 53~,7=,..: , ............................................ 7~00 "'"'~4.42 ' '7 ,¢-- ~ 0 r:' ~' 74 59 ~a74 · ~ ,..; ..,- ~ ..+ , ~ .. 77 O 0 561/) · 93 551 ~ · ........ 7~! 00 56~5.6~ 5595. 7900 5777.58 5677 7950 ~:81~i. q I 5Vl 8. .......... gPfiO, 585~.=9. ,. ~'75°. ., ,~ ,~ . ,. 81.00 .... ~"~41.12 ~;~1¢,., .12 8200 6622,67 5~:~<22 · 67 ~500 6] 03.96 6003 42 41 40 58 37 57 41 41 3 g ~;8 35 46 55 12 18 52 10 12 11 40 17 26 ,.~ 57 ~2 7 ~0 5 27 S S S S S S S S S S S S S S S S S S S S S .. 27,6 28.8 25.6 50.6 31.5 ~0.2 29.5 25.60 26.29 W .56 26.29 W 0 W 1.30 o W 1.10 0 " 1,00 0 ~ ,~ 9 W . .82 0 9 W .82 0 W 2.0~ ~169.95 S °5~,, ,.,.06 W 3289,27 S 1012,86 W 3346.5fl S 1043.63 W 3~57,05 S 1106,21 W ~669.08 S 12~1.5~ w 5 5 22.79 1~,.60 15. 0 15.10 15.2'? 15.39 14,6. f; 14 14,6~ 15.10 15.50 15.60 16,59 17.3S 16.89 2.73 .'$785,~ S 12g.$.11 '~ ~.12 5867,70 S 1311,41 W 5,02 .~B79,19 S 1320,2~ W .68 .9~ 1.11 .2~ 1.21 ,62 ._ / ,61 eP~'R. RY-SUN WELL SURV£YIN3 ANCttORAGE, 4LASKA COi-' F; LI T~. T I C ~..~ DAlE ~O~PA Y TRUE ............. SU.E-~- SEA COURSE COURSE VFfF'TICLL VER T I C,~.I. INCLINATION DIRECTICN DEPTH DFF'TH [;EO MIN DEGREES i3500. ~,26,7,. .00 6167.00 ,.:"~5 7 ,..,g 18.69 H. ORIZONT4L [.','ISPLACEMFNI' '- 027.23 FEET [)OG-L, EG SE;VERITY .92 .32 ~T SOUTH~ lg DES. ..................... T O.TA.L .................. P-. :CT/~NG UL A R COORDINATES ~JOP'rH/SOUTf~ .F'Ae oTi~E ST V [ ~': I ]C~L S,E C l 1 CI'.' 4bE9.55 5 P 27 . 2,-', ~ TttE CALCULAI'ION..[TB~DCEDUEES A.qE BASED ON THE USF OF THREE· DIMENSIONAL BA,DI.~.S .... Q.? .... C.URV~TLI.9- X=FHO'· . a-7 (.SEC ~ TIIN RiOE) KUD A'RUK ANCt',OP ~- GE, ALASKA CO!,!PUTATI ON DAl'-- COMPANY O/~TE OF SURVFY CCTOPER 12, JO~ NUMBER BOSS-1.$905 ~FLLY BUSHII',iG FLEV, : OPERA TOR-W I LLOUGH BY · V,~,LUES FOR EVEN lO00 FEET OF .f":E,t',SURE'7)._D..E.P_.T.,I"_.t ..................................... TRUE SUB-SEa '?.[ P, 'L!.q.~._L ............. ¥'..E F!.._'[ !.c A L DEPTH : . DEPTH ........ q .,...o.._o._ .............. :. D.. Q..-P ~, 5'~ . 87 ~; 9~ , 87 2O 60 70 ,q C THE OD 1517,~5 O0 3001.S4. 2901,9~ O0 ~5'65'85 O0 5066,'.51 4966,51 O0 5~i59,39 5759,30 O0 g257.00 6167,00 . . CALCULA!'ION PROCEDURES ARE TOTAL A ? C 00 R D ! DJ A T f-s .......... N F!- T v.,r.)_ .................... ~5~.,,~_.T.._[....C. &_..._L~ DiORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION o.oo 34~.42 S 56,10 ] 154,71 R 124.56.i~ ,., 1.~70.44.. ,,e 439.33 W 2729.05 S 747. ..... ~10.$3 g 13©& 4h97,86 S 148&o 477A.28 g 1574. .... 0°30 .13 .13 ~2.65 82.51 ....... ~,:..~.. ,~..? ,_.~ ........... A 33 · 29 $98.06 482.13 74 .W 14'3~.15 436.09 63 N ............. !70.~,.~.~ ...................... __'87_~_~..Z.6 ......................... 57 W 1~33.4a 227.58 44 W 214~.6l 207,12 ,gASED ON THE USE OF THRLE DIMENSIONAL RADIUS OF CURVATURE · SPERRY-SIIN WELL SUF, VEY]NG ANCHORAGE, ~.L ASK5 COMPUTATION DATF C C, ~-~ P a N Y 3~Tr OF..,$_.U.B.t/..SY .... OClO~f.,~? 12, I ~'~'1 ,JOE! NUN[":ER PCSS-16905 K E L L.Y._LU.SHi~LG .... E L E.V., OPERATOR-WILLOUGHBY :. iL 3.,.. C FT. ................... INI.~.RL.OL IED VALUES FOR EVEN 1O0 FEET OF ~l..in-~A OEP_TH .................................................. TRUE SUB :,.,:~- A S U P. ED . VEP. T I,C.A L ....... V.,L .R T 7; E P T I.~ O EPTH DF -SEA TOTAL IC, 2L RECTA~;GULAP COORDiNA PTH NORTH/SOUTH EAST/W T~£S . MD-T'¢D ..................... ~.E.B.I..I.£.AL ............... EST DIFFEE~NC~ CORRECTION 0 ]CO 200 500 ~00 600 700 ,00 O. O0 -100. O0 ]00.C'0 2,0.0 · 00. ................. lOO 500.00 200.00 400.00 3OD.Off .... b.0 d.,.O O .................. .~_00 · 00. ~CO. O0 500.30 700. C 0 60 O. PC .~O0..CO ............... 7~0,00 900,00 ~:OO,O0 1000 1000.00 °OD000,' . 1 ! ~. ~ ....... :1 1._O ~;!.,.. 0. ~ ...... :._., .... !.o_.0..0. ,. o (~ 1200 I '502 1,0.,5 lbll 16,20 1.754 1200.00 1100.C[) ]3C0.00 1200.00 1 q O. 0: 00 ........... 1. &.(!.O., 0 1500,00 ] ~00.06 1600,00 1600,0C 1 '7 o o ,.. P_¢ ...... ~ f.< f! o. !', o O,O0 0,00 0.00 9,00 ,55 $ . 2.90 S ,58 5.4! S 6,15 S 1 .06 6.B9 S 7,80 g.24 ~ .06 8.71 g .71 5.20 S I .57 10.~ S 2.51 14,g3 ~ ~ 47 24.89 ~ .... 1~ 42.02 c_, r..O0 66-85 S !5-00 100,~0.. ~. 22,65 !57,69 S 55.80 o. 0.,9. ................................................. :';) , O O O ,00 W ,90 .O0 [, .~ .....................,¢.fl .....' E .09 E .0~ .01 g ... ,.19 ........................... ,..0.1 ..................... E · 11 W .11 ,0 0 W ,l~ ,00 W ,12 ,00 w W 15 ,01 ... 2.~ ................................... ,_! ! .............. , 78 2..l., ~+ ] 5 ,. 5 ~ .......................... ~' ? 2..9. ......... !.l.40 5.82 oq A;'C() ALASKA,..!h~.? A-7 (SEC $ T1]N PiOL) &LASKA . , INTERPOL~TE.D T R Li E c,: lJ n~ - ,.~' E A r,<,:/-, S U F E D VERTICAl VERTICAL TH 3 EF'TH DEPTH . 1577 I SO O. CO lh, O0 · O0 2111 2000.00 1SO0.O0 2262 2 ! 0.0., q.~ ...... 2.C n 0 · 00 2q~5 2200.00 2100.00 26~2 2~00.00 2200.~0 28~"6. 2q 00 · 0 0 23~,nO · 0 O ................................................ 3030 2500.00 2480 .CO 3215 2~00. [)O 2500 · O 0 ~00 2700. O0 2600. OO ............................... 5591 2800.00 2700.00 5726 ~qO0 · O0 2t, O0.00 3995 ~C (30. O0 2900.06 421 q '! I Oil · [30 3f' O0 . CO 4414 3200.00 3100 45c~. ,,;~00.00 3200 . 4755 ~ 00. O0 Z3 O0. 4905 ?.500.00 5aO0.O0 5Ca8 3~ O0.O0 3500.~0 S:P~RRY-SUN WELL SURVFYI~,JS ANCtlORAGL~ .aLASKA COKPUTATTCN DATE; . VALUES FOR 'EVEN 100 FEET TOTAL RE'.CTANGULAR COORDiNAT · NORTH/SOUTH FAST/WE 250.72 S 4~.2 33 q,. 36, S 54.17 422.-.0_,. ,_,'-' 6F..05 ~,3z ~5 *' ~.~9 683.18 S 101.58 85~.~5 S 125.53 1017.79 g 15~.27 11~0.40 q 190.72 ].32c~.~7 S 23fi.~.0 ] a7~.62 S 275.96 ~634.67 S 52~.85 1792.98 1966.07 S ~F,.iO F'iAg. TC $ 505.64 t~310, f"~ o ~,g7.45 2447.91 S 6,2A. 02 2667.59 ;76~. 2 CC.~;PANY DATE OF SLIRVEY OCTOBER JOB NUMBER 50SS-16905 ~rLLY. BU~HI~;G¢ rLEV.,. OPERATOR-WILLOU3HRY OF SUf?-SEA DEPTH [ S !~ F;- TV D VE ItT I CAL ST DIFFEPCNCE CORRECTION 52. ~-~B 1P. 48 77.58 24.70 111.52 33.94 2,'~3.03 80.94 342. R 1 99.78 4Z5.49 93.67 5sO. 85 94 615.13 2 ¢. 2fl 703.7~ 85.56 791.26 90.88 P~'6.ll 94.45 q~5.8~ 109.73 .1 I lq -"_'"~ ................................. 118,.T'-"-~9 ................ I 2 ~ a. 39 99.5~ 12~:'~_.,.°~. 78.90 1~,5. ~.R 62.5q 1405.81 49.73 [' !. C.[:' 7 1.00.(.(' ry. SFERRY-SUN WELL SUF:VEYING Ar"CHOR~G[,,,, . ~,LACFA COMPUTAT I 0',; COMP/', ~.~Y JOB NUMBER BPSS-15905 .... KE..LL~ ...... E.U.S_i-L~LG._.L.LE.V, .... OPER~TOR-~!LLOUGHB¥ ................ I.NIE. E. PDL.~TED V,~L. UES FCR EVEN 100 F'[ET CF..SUB-SEA Q.ER]'..H .................................................... 4 !Z A £ U [:, E. IS. 9 E P T H TRLJr ,:,¢'d~,. -SFLI . VE.Rf I C.A_L ............. V. EE T.I,£.A L EEC B;EPTH DEPTH NOR TCT,~ L. TANGLJLAR COORD'INATr~ TH/SOUTH FAST/WEST M D -. T .~ D .................. ~LE,~]'_L~ ....L ........................... DIFFERENCE CORRECTION 5.185 ..... 3700,0.0 ....... 3L~. 00.,,0 O 5 Z 2 r¢.' 3,8 O0. O0 3700. O0 2 5a67 5':,n O. O 0 3300.00 . ,t.,, b ~ 05 ...... ~ C O0 ..O.Q ..........3_Y.O 0 .,,00 ........ 3 5 741 4 ] O O. O 0 q 000 · 00 3 850.63 9q0.05 026.87 112.11 ]95.49 5{!76 q200.O0 4100.00 5275.36 5 O 0 7 .... ~.3. 00...0.0.i ........... ].LflZO.O.,:'.Q. G ...........3350 · 91 6157 qq 00. CO. 430 O. 00 o~q25 . O0 6265 4t. 00 · 0 O qq Cfl. ~ ~ 3492.67 ........... uO...CO 3559.61 55q2 qcO0.O.O ....... ~q G5~8 4700.00 · 4~00.00 3625.19 6646 q 800. 00 4700. 0 O 6°12 ~no0. O0 4~00 · O0 7O~q 5] O0.O0 5['OO.CO 7174 . -;~..00.,00 5..!.~.,00 7&02 5300,00 5200,00 '1~30 5~00,00 5~00,~0 7 5 ~ 7 "~ q Q 0 ,..00. ..... .;_~ "~ . , ,~t ~ ............ 694.95 772.63 855.50 938.43 qO] 409~ qo ...~ ~ . 4173,41 4248.21 S S S S S S S S · ,.. S S S 1 1 10 1] 11 12 12 12 13 13 13 lq ,qfl., '~ · 37 88q.16 S2q,89 965.69 005.59 F~F:. 61 67,08 06.25 "5.90 13.74 36,03 ~7.64 7~.91 00.26 ., . 32.14 1 r~12 · 3q 33,37 194't · 16 3 1°74,.0..! 2002.50 28.. 30 20-~0.&2,_, 28.31 2 C (', 7.0 ~ ................................... ?. 6....~..2. .......... ' ..... ~F"CO ALASKA,, INC. A-7 (SEC !3 TI lr, i R].[i[ ) !t !.!F' AR UK of*ERRY-SUN WELL SUHV[YING ANCHORAGE, ALASka. COfiPUTZ:TIOF~ DATE. ............. INTEgPQgA.TED VALUES FOR EVEN 100 F-ET ]'~uE SUU-S~:A DEP 1 I- [')EF Tki !']E PTH T 0 ~ [C T A r','. c u L ~p NOR l H/SOUTh 7805 5700.00 5600 7927 58C O. 00 570 fi. S c'. ~.? 5 ?...~!..C, ,¢2 ................. 5fl ~ 0.., .o 0. 8] 72 6ti00.00 5900.00 8295 6100.00 6~00.00 8 ~ 1.7 ...... 6.2 O q .'A e.,9 ........ ~ .... 6 ]...,0 .q. ,. 00 gS[)O 6267. O0 6167. O0 THE C$1. CUL~TI..OF¢ .... F'.E.Q_g...ED!J.RE.~' USF ~ LINESR I~'~ THE kEARES'f 20 FOOT MD (FROI4 RADIUS OF COORDINATES E ~. ST/WES T TE_RPOLATION CURVATURE) POI C -.,~, A N Y PACE DATE OF Sd~VEY O"'TOB'-~ 12, 1"?~1 JOB NUME~ER E:.0SS-16905 KELLY [~USH~f.J6 ELEV. - OPERATOR-WILLOUGHBY 100.1',0 SUB-SEA OEPTH r,'D-TVD VERTIC/~L 2o81.57 24.48 21G5.14 23.62 2149.64 22.07 2172o17 22,.52 21 9%. t.1. 22,9~ 2,:4,3°03 15o00 TWF E~',; NT e A-7 (SEC 5. TI.I~,; P, iOE) < UP ;~ F UK .:, LA S~,~ SPErRY-SUN WF-.LL SURVEYIN3 COMPSN'F ANCHORAGE, ALASKA CO!'?F'U T A T I 0~,,' D^lE :)ATF ....OF SU.R._.VF.Y. OClO['!E.F 1;", la~,l ,.JOB NUME;ER F~[iS5-16905 ' K.ELL.¥._._B.I, LS.HL.,."; G r-,,,,,.,. F..Y ,. --' 1 r',. {) ,, r:r,. _ ,F 'f · OPERATOR-W ILLOU.~H~Y ......... I.N.TER...P...OLATEE: VALUES FOR SFECI$~L SURVEY POIN.TS T R LiE F;U[!-S E.~ TOT A L ¢;EA"-'U R ED .VEF: T I.CAL ............. VE.EIiCAL g, ECTANGULAR COORDi~,'ATES T:~.P TH DEPTH DEPTH r.JORIH/SOUTH EAST/WEST MARKER "~E~IwED~_, ,. ,USING SURVEY [)ATA DEPTH TVE'- IT!: K 5 S U F: - S E t~ 61E: 7. O0 · ..................................................... TH,[CKMESS t,!IlH REF. TO ~,~[LLHEAC. VERTICAL (OFI(;TN- OSNL t ) FR(]F! L1KExNP EXTRAPOLATION t-!:ELC)I,~ DEEPFST SlAT!ON. L!)COr*,F~UTF..']F: PFiE'~qR~,.H-SFERRY SUN THREF DIF!EN~ ,. .... ..... oIONAL ~;AE:IL~S OF CURVATURE', DATA CALcJLaTI'O~' a'N"3'iDJ1ER:DO~aTION E,Y R&DIUfi OF CUkVATLJRz COKI:-'UTAT I Ok [)ATE' L')ATE .... OF ~URV",r.'Y CC :roE'ER ,_lOB NUM!;ER POSS-16905 K~'[E'y-'iLus'H']]i.i!G <:'~E-V ,'"~L ] [j[l" ,r!, [t F I . spenn -sun Mr. Bob Hines ARCO Alaska, Inc. P' O. Box 360 Anchorage, Alaska 99510 October 14, 1981 Re: Our Boss Gyroscopic Survey Job No. Boss-16905 Well No. A-7 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: October 12, 1981 Operator: Chris Willoughby Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures I £CEIv£1 OCT ~ 6 1581 0il & ~as Cons. ~c,~orage DEPTH DEPTH TVD . NO R'T~' SLOPE~' A'LASKA ...................... BOSS SURUEL BOSS-16905 D. EG ~IN BEG ~IN DEG/IO0 NORTH/SOUTH EAST/UEST SECTION ~00,00 399,91 368,]1 0 33 S 86 6 ~ 1,02' 6,15 S 1,07 E 5,50 S 62 5~ U .18 9.20 S 1.57 ~ 9.22 900.00 899.88 868.08- 0 39 .. 1000.00 ........ ~99.87 ....... 968.07 ~1 19 ......... S 29 .....0 W .83 ~0.44 S .2.5~ W IO,Z~ ........................ ::::::::::::::::::::::::::::: ..: .S.:: ::::~ -':9 ::.~.~.:;:~3::'0~:';:< ~:;~:~;~:~:~3 ~::.t~':.{~:~:~j~;~:~:~:~/:~-~;~;~!i:~<~;~.~:':78 :.;~/~ S:: :.;~::. :~ ~ :~::~;;~:~: ::~:~:;;~:~:~::~:;:~' 5 ~. :: 0 '8 ~.:~'. ~::':W.::.~';.t;~:~:~;:~::~::;:::;.;~:~;:::~:.:.'::.' :. 25 2 . 12 0 O. 0 O :;.~:::;: :.~-: .:.:~:::.::l.. ~ 99 ,.::..23:.:::~c::~:.~.::;:.~. 11.67 ,::~3 .::::.:~<:~::..:~:.?~.:::~:?.;~:~:: .: 7...~..;::,:~ 9 /::..:.:::.: ::::..,~... i:!~: :.~:~!;;:.:?~.;~:.~;:i:::::. ~:.. ;: .:;.::;!.:~:ii;.;;~!~;~:;~.::::.~:~;:.~:.::.:~;~.:~:~:;.~:::. :~;:?.:.: ..~;.:.:~. ::::::::::::::::::::::::: 1400,00 139~,66 1362.86 16 10 S 12 48 W 4.05 65,29 S 14,65 W 66.58 1700.00 1670.11 1638.51 29 i S ~ 5~ ~ 4,0~ 180.72 S 3~,23 W 182.29 .. 1800.00 1755.96 172~.16 32 40 S 6 ~8 W 3,79 231.70 S 39,50 W 2200,00 2060,51 2028,71 ~+9 ~ S 7 5~+ W 5.2~ /+86.51 S ~ 7~.81 W 485~2_5. 2~50.00 2203.~q 2171.6q 60 23 S 7 36 N 3.02 689.18 S 102.38 W 686.27 I: :WELL ~. NO .~ A ' 7 SE'c~ 5;'!:!'i;:T'i'~N ~::. R:i OE?.~:i:~!!!:ii:iii:iii::'i'!'i :i:i i ~.i..: ~ii"~il;i!¥;!'! ilili ¥!!!i~ii~!il]i~i;!~ili?'i!/i'ii?i:i~:i! OF!.: .,SU R~VE'Y.!i~ii,] i~:., ;'..'OCT OB:ER~:. 12, ! 981 BOSS SURWEL BOSS-36905 NL SPERRY-SUN DEPTH DEPTH TVD DEG MIN DEG MIN DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 2500.00 2228.05 2196.25 60 40 S 7 ~+8 W .6G 732.52 S 108.21 W 729.03 ................. .......... ~..~.~ ....... ~,~.~-~.~,~. ~, ...... ,-*~,~-~-~.~,~-~ ~ ~,-~~'~ ,. , :~... ~; ... ~ -.:.~ -7..: .~ ~ - ~'~~ ~ - :' ' .> .... , - .... : ~ .... ' 78' ' '':~' ...... '":" ' '2 ~: 6~;~1 ::'~?'"'~:?~' :"59' :1 6' ~'~ "~:~'~"' ~ S:~ ' 8 :~'12 '~::W'~'~""~':~'-'~'?~;~'I';; ~ 8.0 ~ ~ S ~. '~ ~' ',. ~:~:?' 120 ' 26 ~' 81 · ~ 27 O0 W 00::~~ ~:::: 23 ,75:~:. S' .::~;~. ~:':: W }.~ :::~.'. ::'::~. 898 · ', 80 O' 0 O:: 8I .:.2 2.?~?~?~ ':'23 ~.~, , ~:. ~ ~: :~,~.,,,. ~,~ ~..,~,~, ~.. .... ~.-- :,~.~';:;~:~?~;~I';'~ ~. :..~.. , :~:S: ~,:,,,~, ~?~'87'05'. , ,. _.,, ~:::.. ___ . 983 ', 5 00.00 --2~32.60 2~00.80 59 8 S 12 ~2 ~ 1.29 1071.Z2 S ~65.~9 ~ 1068.60 29 3000.00 2484.07 2Z+52.27 58 55 S 13 30 W 1.14 1154.7i S 184.56 W i153.93 --.-~.--.-: ..... ~-,-~-~,-~rr--?---~.---~,~,-,~.--~-~,o~.,,,,-,:-~-r-~L~,,~.~?~,?~~'~-~.~?'~"~?'~'~."~ ~..~:~-.~:~.,~i~:.!~ "~.:~"~7~~~'' '~' '~~'~; '~;'~'.; ;.~': ..~.~ :" :' :' ":. '' .... ~'" ~:: ':;" ' ~ 8 ~3400.00 2699.59 2667.79 58 2~ S 17 ~2 ~ 1.21 ~478.98 S 275.76 ~ 1~90.~1 3500.00 2752.11 2720.31 ..... , ..... 58 17 S 17 ~ U .18 1560.23 $ -~ 301.07 U 1575.50 3900.00 2955.~6 2923.66 62 32 S 19 ~B W 3.21 1886.97 S q09.81 W 1919.85 3950.00 2978.63 2946.83 62 14 S 19 18 W 1.07 1928.72 S 424.63 ~ 1964.~ ~300.00 31~1.05 3109.25 59 58 S 20 ag W 2.85 2219.~9 S 532.03 ~ 2273.96 4400.00 3192.42 3160.62 58 13 S 21 30 Y 1.85 2299.50 S 562.97 W 2359-6~+ , .. ~~-~-,~.~-, ~~~'-~,-,--~,~--'~~~,~'~'~,~ ~,~"~--'~-'~'~"~"~"','~r'?~'~,~ ~... '.: .:{:~}....:. <.~..:~ ~.~.~:.~::..~ :~ ~:.~.: '::: '~.:;~ ~:' ~~ :.' :': '..' '.~ '.:.~:.,'..:..~'.:< '" -;" "::: :' ' '~'~ ~:-' ~ "' ' ' ' · ~ ~ 00 · 00. :L:.~:::::~;:::3 2.~:6~:6' .1 ~.;'~'.88~:~::~:-~h~;..~;::;.~'~;;;~;~: ~ 6~:~.:~::;:'::.:': :~ .:.;;::'..:.~: ~ :. S :.. .~ :2 -: .3 9; ;.~:.~ $ .: .:..: ;-.". 36.:~...?.W:~.: :::...: .~ 2 ~ ~ 3 ~ 6 7 o o ~800.00 3~28.75 3396.95 q8 ~ S 23 2q W 2.63 2596.50 S 687.6~ W 2680.81 4900,00 3q96.1q 3q64.3q q6 31 S 24 54 W 2.49 2663.90 S 717.84 W 275~.29 .... : ~ ~'~ ':-::~"~'~ ~?'~5::~-:~'~ 'S 2~"'2'~'"~~' ..... 1,~6'''~'''''~ 272~5 S 747,7~ W 5200"00:': .':::3707'7~. ':::~:" .50 :' : S 2~30:~:W'::.':'::::~?~:~:~.::.:::::::":38:':::?:';::;~'-'~2857'6Z~ S .. :'~;:':":~'::805'59'W :" 2965.80 ' ........ .... BOSS SURWEL BOSS-IGC05 :: .:: <':' :: ~:.:::. :: :.~ ~ ~:.: .:.? ::.~':. 2: :':: :~-~: ?~?:'.::~?F:~?:~:?:;Y...:~ :::::.':.:27~?.:~ .?~ R E e:o:R. D ~::~.O:F:.~:'?.R ,::: ::' ~'::..::: : . OEPTH DEPTH TVD DEG ~[N BEG B]N DEG/IO0 NORTH/SOUTH EAST/~EST SECTION 5~00,00 .3850,87 3819.07 ...... 5 5 o 0 · 00 :: :: ',, ':'~. 3 '923 ': 21 :: ::~:3891'' ~:1~: :?:'~?~,:.~::~:::~3:::.~:3 0,0 0.": ": :: 0 6 9 - 8 ". 4': :~ 0 3 ?:": 8, ......... 5800.00 ~Z~3.~0 ~111.30 ~ 53 S 26 18 ~ .89 ~230.32 S 982.90 6300.00 4526.81 ~495.01- 38 11 S 30 ~2 W .82 3510.80 S 1137.67 W 3690.42 6s o o ' o o:ii i:: ~+"7 7 ~ s:i 2:9':.'.~ '0 ...: I::2 ~ ~.:3 9. :w. :':: 3~ ~ o. 1~ 6800.00 ~915.75 4883.95 ql 37 S 22 48 W 2.73 3785.~ S 1289.11 W 3998.81 7500.00 5298.21 5266.~+1 58 57 S 15 24 W .28 409~+.50 S 1378.52 W i: :7500' 0 ~:::5 5~:22'9:1'1"~1'7 ..W ~.59 7650.00 557~,59 55q2.79 36 20 S 1~ ~2 W .80 ~301,86 S 143q.00 W ~53~,58 NOR-T~' SLOPE~ A'LASKA' : ' ............. BOSS SUR~EL BOSS-~6905 NL SPERRY-SUN 8100.00 59q, 1'12 5'909.32 :35 16 S 16 2~ W .18 q, 553o13 S 1504.71 W ~795.,31 ~o o- o o:~:.~::::~.: :~ i ~ i5::~ :::::::::::::::::::::::::: ~ ~ 9. ~ ~ · ~ .~, ...:,-:.:. ~ · -' .'.' · -' ~-..' ~"-:.".-".-'~~' ..' :'~."" :~'~1_~: . :.2 .~."~,.:'L'.L'~' :~.~. ,:.2::.:: ~= ~.::- :' ~ , · · · 8500,00 6267,00 62.35,20 35 7 S 18 42 W ,32 ~77~,28 S 157~,59 W 5027.21 START OF SuRvEy WAS ,31.80 FEET ABOVE SEA LEVEL WELL:: :NO' A.7 ~SE NORTH' SLOPE, /~'LASKA BOSS SURWEL BOSS-16905 TED ~. R]E'C' O'R . · ; "' ";'.]:.:qt;':. ;....t .:: t 1] .'....,.:c:;..t'.t,...t'LC..{q:t.S't.;t?.Lc:-t"':t!t~;;:L /.L;L 2 '-.'t · ' ;.' ,' . L. ,tit ..t~ .L.;..t..tt..;t.; &r'.t..'.'...:.;::..,Q'?'t.t?::4;',Y.L";.'tT ~' .?', .' 't.:: .: .t' · :., ', ' ':;.:~1: · '' .] ]; .l; /.] .'1;-2.'? .1. ;~'-- ~ ~' ~L.'::-.~?;~: ..;'.: '; :. ; .; t ; :;. t: .ttt~V'.;. :';{..... ?:.; -.'-: '.-'.;'?-?::.;;;'-:.i'~:;':;'L'{.;.; ':..' :ti":' ~ L" ~'..L:;:~:_. ' .... ~ .... DEPTH DEPTH TVD ELEVaTiON NORTH/SOUTH EAST/g~EST 065 e;:' ?.: ::':.:' ;: ;'."; :'.'?.:!: .::::' "i :... ".: ."/-;'.'!!.::~::.: :;.;:'?'::!:~.::::::'.:::":.' :::~:' ::- ......... :.' ~: ':: ~..~!:;i:~:....-:.~.. i::; :: :~:: '.: : ~'.- '~ !'!..'~.?.::!.' : : · ..... '' ~ ~~6~7, 3332. 3300. -3300, 2~87. S 6ql. W ~805, 3432. 3~00. -3400. 2600. S ~8S. ~ 5093.'::!::::: : :' ::!: 360 :~i?!:!:.i~?:!!ii:~?!i~?::.:.?i:i??~ii:i:i:?i:~::3.~'O0. ;ii!.'~:.:~::-: 537~. 3832. 3gO0. -3800. 296~. S 856, 5512, 3932. 3900. -3900. 3054. S 897. 5649..:..:..:' ..... .?,...:.::....:- /~000.- .. ..... ...:.. :,~.. . ... ........ 60~9. ~332. ~300, -~300, 337~. S 1059. 6178. q~32. fl~O0. -~+00. 3~5. S 1099. 6689, 6821, --4832. 4932. 4900. -4900. 3799. S 129A. 7343, 5332. 7~71. 5432. 5300. -5300, ~121, S 13~6, W 51+00. -5400, 4197. S 1~07. W 7966. 5832. 5800, -5800. 4~79. S 1~+83. W 8089, 5932. 5900, -5900. 4547. S 1503, W ~/~ - , ?" .~.. . /.-----. ARCO ALA:SKA~ .:~' 5 uEL L NO ";:A'7 :~' S EC;~ : T E':" 'OF~.:: ~, SURVEY':'~..;:: 2 e. 1981 oss BoSS-Z .05 . HEASURED VERTICAL SUB SEA TRUE RECTANGULAR COORS]NATES DEPTH DEPTH TVS ELEV~TZON NORTH/SOUTH EAST/~EST ---~332.' 332. ~00. -300, 6. S 1. E ~32. ~32. ~00. -~00. 6. S l. E :5 ~'2':'? ::: :: ::::::::::::::::::::::::::::::::::::::::: :::~:?::~:~.:8~'.t ':::::: :: :., .;' '0,1 · EE 8~2.-- 8~2, 800. -800. 9, S ~, : 11 1100 './ ::::::::::::::::::::::::::::::::: ::?:S':::' :::::~: '.. :':.::-: :;:,. -z oo. s ~892, ~8~2. ~800, -~800. 28~, S ~7, . :: :': 2157 ,::~.? ::: 20 ~ 2'. ::::::::::::::::::::::::::: : 2000 ':-:-:'~:~:~ ~~.: :?:.: ..~:: 5':::..S:::.: 70 · 250R" ~:. : ::':: 2232 2200 ':.. 7'39 ::: :~ ._.1 ~-- __ :.. .: . .. ,, ; ..- ........... .. ....~ ..... · . ....,.,.:..,::: .~:.~..,.:,..,~:::~...:;~_.. _ ...... ~,~ .......... 270~, 2332, 2300, -2300. 906. S ~3~, 2898. 2~32. 2~00. ' -2400. 1070. S ~65, W .... · ...... ·.-'-"'-'. ' · - : .-. ;..---'-. :.:' .. -.--..:-....:...-..:-.~ ::::~..:':..':..':u..'.....:.:.A.::~ :.:.. ·: .... · :....:..,:-.,.::.:..'::.......-.::.... '.:.:..: ...:. '..'.......::..... · ... · .:.:..; ,:,...: ....': :.. , · ' .' '.. · ' · ':L:':'::': :.:~' :;:';'~'c!:h:-'?;.::':-;:.:: ': .::'":' ::' ~f~:: :-.:.:'." ':: .?:~;:~ ;: "- :: ' ' .' . :~': :::. ;;..~ ;:::.:..": : :: .: : ~ ::: ::~::.: :: : . .:::.~: : .:. ::.:~::..: zn~n_ 3c,~_ pqnn. -2900. ]8~5. S 395. -NORT'H'SLOPE~ ALASKA BOSS-16905 BOSS SURWEL ............................... ,~.-~.~,~,t,-.,.~"~,-~?~-~?~""~'~"~'~~" :.;'~'??~"~r~!~:.'i~.:::'~'.:'~::~:~i~i~~:::.:i-::~::<'-~:~:'~:~''~-::!''~}:!:~:::'~:].~~~ :: ~ ~]";.~:~'~ ~:' ' .] '~ ~' :'~:~:'~'<:' ;~ ~'~'~ ' L_:.~ ':.S ,':~::~:::'' : · ::~ ~:'~'::'";.;~?~::~::~S:~L.~:~ ~-'~~ ......... .................... '"'"' ...... ' ............... RE'C ~ANGUL~R COORD INA TES MEASURED VERTICAL DEPTH DEPTH TVD ELEVATION NORTH/SOJTH EAST/WEST ..................... · I'3 2 -,~:.. ........... '.: ~ ~ ~ ~ e ::-':: ::.:: :.: :~ :: .:~ ::~:-~'~:~'~:~L::..:~-:-~S-'- :.;..:~:~:S:.~ : . :.... .:. ,~ ~ ~ ~ e. :;:,;:.::. :: ::~'.:~:::'[:.: .~::,.'::.~..::'~.~ :::.~':.?:. · :: ~ ~. u ~ ~ ':~::'~'::~'~":': :.' Suggested form to be inserted in each "Active" well folder to d:eck for timely compliance with our regulations. .... Operato'?, ~'el 1' Name and Number Reports and Materials to be received' by: //-/~" Date Required Date Received Remarks Completion Report Yes /o~_~ ~--~ Well HiStory Yes .............. .... Mud Lc~ · ~ ,~ Core Chips /~~ ~--'~... . Core Description /~¢ ~ ~ ..... ..R. egistereS Survey ,Plat 7~,. Inclination Survey ,'~ Directional Survey Yew-PI ,Drill Stem Test Reports /~ ,,,~.t..-. ----'--'---*' ~¢~", . Production Test Reports /~O ?er}~ ~ , , , .... . Logs Run Yes · Digitized Data, .. , . ~ //.__ O,,~_~, ..,,~.~/ ¢/.~ ', J. J. Pav/elek/Ann Simonsen i,r,,uE ' DATE' //i '~-~S t WELL . Trans~i ~=d here,si th are th~ follov;inc' PLEASE NOTE BL BLUELT''~' ' - .,,c, S - SEPIA, F- FiU.!, T - TAPE Z)t · · //' ,.Cr,,,O.';L EDGED RECE'r PT" ...... ~'~'~' REC£IVE NOV (') 9 Alaska 0il & Gas Cons. Anc!~orage ARCO ALAS~LA, I~C. ATT~: A~;~, SIbi0~SE~I - AFA/3tl P.O. COX 36O A:;C~02ALt2, AK 99510 lt0,~T,, ~LOPE E~GI~',EERI~G J. J. Pawelek/Ann Simonsen Transmitted herewith are the following' PLca~: IIOTE' BL - BLUEL,~c., S SEPIA, F FILM, · T - TAPE RECE ! PT AC K;;O',.;L EDGE ~ECEiVED NOV 0 9 ]~8_~ ARCO ALAS~tA, I!4C. ATT~!: A:,4r; SIMO~iSD! - AFA/311 P.O. BOX 360 A;~CHORAGE, AK 99510 Alaska Oil & Gas Cons. Commission Anchorage IlORTii ~LOPE E;:GI;~EERI~:G TRAi!SMITTAL ~ ~--~ FROM' J.j. P a'..,'e 1 n,.~ h~, ,,.,,p Simonsen DATE- //- Z- 8'/ WELL NAME- Transmitted here:.:ith are ~h~. follo'...,'inc' PLEASE IIOTE' BL - BLUZL!~iE, S - SEPIA, F - FILM, T~TAPE EECE!PT ACKF:O'.'ZL[~i)GE[~!'C/ /~L~,,,.--,~ DATE' PLEAE? ,-RETUR:; P, ECEi?T TO' ARCO AI_AS}t~I, IIIC. ATT[I: A[;~i SI~.iO~iSE[I P.O. g-OX 360 - AFA/311 A( STATE OF ALASKA C( ALASK L AND GAS CONSERVATION .,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20658 4. Location of Well 9. Unit or Lease Name Kuparuk 25647 10. Well Number Sec. 7 TllN R10E lA-7 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB=100' I ADL 25647 KuDaruk River Oil 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Othe~ Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) , (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other X [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Pool 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAc 25.105-170). In order to establish the ability to inject water into the Lower Kuparuk Sands, ARCO Alaska, Inc. intends to perform a second water injectivity test. The water injectivity test performed in August 1981 proved unsuccessful in establishing injection into the Lower Kuparuk Sand in Well lB-1. In light of its importance to Increment I Waterflood planning, we plan another attempt to inject into the Lower Sand in the recently drilled lA-7 well. We plan to perforate and test the Lower Sand in lA-7, inject water for 1 - 2 days, shut in for pressure fall off and run a step rate test, then perforate and flow test the upper and Middle Sands. The test is planned for early November and should last no longer than 5 days total. RECEIVED NOV 0 2 198! Alaska 0il & Gas 00ns. C0mmJssi0n 14. I h true and correct to the best of my knowledge. Signed.~/'~'~' SeNior Operations Enqineer Date /O ~7-~/ The s~ce below for Commission use Conditions of Approval, if any: Approved Copy Returned 0111 G~H,,s,I. / '- -- // Approved by COMMISSIONER the Commission Date_ / Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCo Alaska, Inc. ~,,~ 'J '~ Post office I~'~ 360 October 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 7-14 DS 11-2 DS 11-4 DS 12-13 DS 13-6 DS 13L7 DS 15-11 Kuparuk A-4 Dear Sir: · Enclosed please find the following- a) The Completed Well Reports for DS 11-2, DS 13-6, & DS 13~7. b) The Monthly Drilling Reports for DS 13-7, DS 15-11, c) The Sundry Notices of Intent for DS 7-14 and DS 11-4. The completed ~vroscopic Survey for DS 12-13, Kuparuk A-4, i~and Kuparuk A-7~. Sincerely, P. A. VanDusen District Drilling Engineer PAV: GLA: cm Enclosures RE'EEIVED OCT 2 6 198 Oil & Gas Cons. Commission ( ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Hoy le ~. ~amilton Chairman Lonnie C. Smith Commissioner Ben LeNorman Petroleum Inspector October 5, 1981 Witness BOPE Test on Arco's Kuparuk A-7,_ U.M. .K_uparuk River Undefined Thursday October 1 - I departed my home at 5:40 a.m. for a 6:10 ~m~-i Sh~ a~d 7~15 a.m. departure via Wien flight #15 for Deadhorse arriving at 8~50 a.m. Weather.. +30CF, light snow, no wind. F~iday.,.. 0ctober~_~ - BOPE tests on Arco's DS 11-3 completed, the subject of a separate report. ~at~.r..day,~0ctg~_e_r_~3 - BOPE tests on Arco's Kuparuk A-7 began at 12~45 a.m.. and were completed at 2~15 a.m. BOPE inspection report is attached. I departed Deadhorse via Wien flight #72 at 10:15 a.m. arriving in Anchorage via Fairbanks at 12..55 p.m. and at my home at 1:25 p.m.. In summary, I witnessed successful BOPE tests on Arco's Kuparuk A-7. OaG #4.' 4/8 . ~ . ~ STATE OF ALAS ALASKA OIL & CAS OONSERVATION CC~ISSION B.O.P.E. Inspoction Report Operator ~ ~ Wel 1 ~C; ~,,~ aqt.~ ~'. /~ - ~ Location: Sec ~- T/./~R/O~-~ f//9~ Pril linq Contractor~u~~~- Date Representative Permit # ~f9 /~ ~//.~Jing Set Rig # ~ Y Representative.. location, Genera] ~/~ Well Sign ~D/~ Ceneral Housekeeping ____~.Z< Reserve pit _ _ .~D/_~ BOPE Stack Annular Preventer Pipe Rams -~ Blind Rams Choke Line Valves.__ H.C.R. Valve Kill L~ne Valves- ~ Check Va 1 ve Test Pressure ACCUMUIATOR SYSTEM __ Full Charge Pressure -~ ~(~{9 psig Pressure After Closure /,~ o psig Pump incr. clos. pres. 200 psig mind-sec. Full Charge Pressure. Attained: ~ min~ ~ sec. Controls: Master Remote ~p/_~._B__l_i_D_ds switch cover Kelly and Floor Safety Valve's · Upper Ke 1 ly Lo~r Kelly Ball Type Ins ide BOP. . Choke Manifold No. Valves .... No. flanges. Test Pressure Test Pres sure Test Pressure Test Pressure Test Pressure Adjustable Chokes / Hydrauically operated choke Test Results: Failures~ Repair or Replacement of failed equipment to be made within Inspector/Conmi~sion office notified. Remark s :_, ~~3- ~-7~.__-~.~/ .~?~ /oQ .' f~z j-- ~ Test Time' . days and Di str ibut ion orig. - AO&GSC cc - Operator ' cc - Supervisor Inspector ARCO Alaska, Inc. B~I Post Office .360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 18, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk A-7 Dear Sir: Enclosed please find copies of "Letters of Non-Objection" from BP Alaska Exploration, Inc. and Sohio Alaska Petroleum Company for the Kuparuk A-7 well. The application for the "Permit to Drill" and related documents were forwarded to you in our letter dated September 10, 1981. If you should have any questions, please do not hesitate to contact me at 263-4270. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cm Enclosures RECEIYEI) SEP 1 8 1981 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany BP Alaska Exploration Inc. One Maritime Plaza, San Francisco, Ca~i!ornia 94~, ~ 1. T September 11, 1981 ARCO Ala§ka, Inc. P.O. Box 360 Anchorage,'Alaska 99510 Attention: Mr. Sylvester R.'Jaime, Landman RE: Letter of Non-Objection ARCO Alaska Lease ADL' 25647 Gentlemen: . .,~ We refer to your letter of 9 September 1981, in which you advised us of your intention to drill Kuparuk Well lA-7, on Kuparuk Drill Site A, with the following location's: ~ Surface'Hole Lo'cation: 659'FSL, 308'~L Section 5, TllN, RiOE, U.M. Bottom Hole Location: 1320'FSL, 12~8'FEL Section 7, TllN, RIOE, U.M. · BP Alaska Exploration Inc., as an affected Lessee of Record, hereby confirms that it has no objections to the application for Permit to Drill or Deepen the above well. This Letter of Non-Objection is, however, written on the understanding that timely and bonafide measures to unitize the Kuparuk Reservoir in a 'fair and equitable manner are adopted by the parties involved, such that said parties may agree upon the terms of such unitization and their respective rights and obligations therein, prior to the commencement of any production from the Kuparuk Reservoir. Yours very truly, - .D I::/~ I:: ! President Alaska-Oil & Gas Cons. Commission Anchorage cc: Mr. G.J. Abraham, Sohio, SF SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 17 September 1981 CC ==34,73.6 (B12) Mr. Paul Norgaard ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Subject: AoGcC 20 AAC 25.050 Kuparuk Drill Site 'A' Well lA-7 Dear Mr. Norgaard: As requested in your letter dated September 9, 1981, Sohio Alaska Petroleum Company (Sohio) has reviewed your proposal to drill a deviated well on ADL 25647. Sohio, as an affected Operator of ADL's 25652, 25646 and 25653, has no objection to this activity. Very truly yours, DJN:PJM:dj -. Z~ .~(, .~- '"~ "~ :' ' ' ,~:' -'~ ~- '"'~', .':., '."." ..,,... · 'ce: Sylvester R./~aime, ARCO Paul J. Martin Assistant General Manager' Operations/M~nagement RECEIVED SEP 1 8 1981 Alaska Oil & Gas Cons. Commission Anchorage September 18, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Res Kuparuk 25647 A-7 ARCO Alaska, Inc. Per, it No. 81-137 Suro Loc~..~ 6.59~'FSL, 308~FWL, SEc 5, T11N, RIOE, Bottomhole Loc.~ 569tFSL, 1478~FEL, Sec Dear Mr. VanDusen ~ Enclosed is the approved application for permit to drill the above referenced well. Well .-samples and a mud log are not required. A directional is required. If available, a tape containing the zed log information shall be submitted on all logs for copying except'experi~enta! logs, velocity surveys and ~ipmeter su.rveys~ Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.5'0.870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is 9rohibited by AS 46, Chapter ~, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25647 A-7 -2- September 18, 1981 commencing operations you may 'be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified, so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness, present. Very truly yours, Hi. ~amilton of BY Alaska Oil & Gas Conservation Enc 10 sure cc~ Department of Fish & Game, Nabitat Section w/o encl. Department of Environmental Conservation w/o/eno1. HHN'~be ARCO Alaska, Inc./' Post Office ER 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September, lO, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk A-7 Dear Sir: Enclosed please find the following: · 2. 3. 4. 5, 6. 7. The application for Permit to Drill Kuparuk A-7 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. An as-built drawing of "A" pad indicating the proposed surface location. A 'proximity map indicating the relative locations of Kuparuk wells A-6, A-7, and A-8 (West Sak #12). A determination of maximum pressure to which BOP equip- ment could be subjected. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. In addition, please note that a recent change in this well's bottom hole location will require new letters of Non-Objection from BP Alaska Exploration Inc. and Sohio Alaska Petroleum Company. A copy of the letter requesting such Non-Objection is enclosed for your files with replies from the affected operators to be forwarded to your office as soon as possible. If you should have any questions, please do not hesitate to contact me at 263-4270. Si ncerely yours, P. A. VanDusen District Drilling Engineer PAV/ELP:sp Enclosures RECEIVEI) SEP 1 5 1981 Gas Cons. Commissi Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL][] SlNGLEZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address I~ ~ ~ [ J V [ ~ 1 P.0. Box 360, Anchorage AK 99510 4. Location of well at surface S EP 1 5 !98] 9. Unit or lease name 659'FSL, 308'FWL, Sec. 5, TllN, R10E, UM Kuparuk 25647 At top of proposed producing interval ~aska 0il & Gas Cons. Cc--t° Well number 1320'FSL, 1228'FEL, Sec. 7, TllN, R10E, UN Amch0rage :m~.-/'~i0n At total depth 11. Field and pool 569'FSL, 1478'FEL, Sec 7, TllN, RIOE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 61 'GL, 66' Pad, lO0' RKB ADL 25647 ALK 465 Kuparuk River Oil Pool 12. Bond information (see ~20 AAC 25.025) Type Statewide surety and/or numberFed. Ins.Co. 8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi NW of Deadhorse re,es (at TM) 569 feet well @1645' TVD 63' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9114,' MD/ 6561,' TVD feet 2469 9/21/81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2574 psig~ 60OF SurfaCe KICK OFF POINT 1 000 feet. MAXIMUM HOLe ANGLE 51 o J(see 20 AAC 25.035 (c) (2) 3072 psig@ 591 0 ft. TD (TVD) , 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF OEMENT ' Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" 65# 'H,40 Welded 80' Pad I Pad 114' !114' + 200 CF 13 3/.1 10 3/~ 45.5# K-55 BTC 3005' Pad I Pad 30~700' i160sxFondU+250sxASI] 8 3/~ 7 26# K-55 BTC 9'080'i,.Pad Pad 1.~14!~' 107~.sx ClasS G I 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River Oil Pool develop- ment well to approximately 9ll4,', MD, 6561.' TVD, Selected intervals will be logged. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA MOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2574 psig based on cooling of a gas bubble risi.ng' at constant volume. The well will be completed With 3½" 9.2#' J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafroSt interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed 'and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the .best of my knowledge SIGNED ,-~/~, 7~~--~.~,.~..~ ' TITLE b/,~p-~(,,~-Z~,, ~"'/~, DATE The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number I-lYES ~AIO []YES [~:NO [~A~.ES []NOI 50-- ~ 7..C- Permit number ' Approval date gl-/~i'7 09/18/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS BY_~~~~. ,COMMISSIONER DATE ,qR_p~-_Pml-~_r 1R: 1 981 APPROVED by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 !. ! !-! RRCO ~! ! ~. !PRD CRSING! I'NTi THD~3039 THD=3;=44 24 FT OEP=5196 ' ' pEP=5~O ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3072 psig from RFT & pressure buildup date. This pressure @ 5810' SS = 5910' TVD will be balanced by 10.0 ppg mud wt. Normal drilling practice calls for a 10.5 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 155 psi over- balance. It is anticipated the surface BOPE equipment could be subjected to a max- imum of 2574 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160°F, 3072 psi), gas migration to the surface w/o expansion, and cooling to 60°F summer cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) Pf = pressure final (surface) T¢ : temperature final (surface) v~ : volume final (surface) P.V, :P__~ Since Vi = Vf ie no expansion Then Pf = P-T = (3087 psia)(60°F + 460) ~ (160OF + 460) Pf = 2589 psia = 2574 psig RECEIVED SEP 1 5 198i Alaska Oil & Gas Cons. Commission Anchorage Surface Divester System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEiVE ) SEP 1 5 Oil & Gas Cons. Ar~chorage Maintenance & Operation 1. Upon initial installation close annular ~ preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 't 7 · I .® q WEGT ~A6 ~1'2 WELL A 1 Y = 5,971,467.25 x = 540,'1 78.17 LAT : 7~)°19' 58.741'~ LONG =.- 149°40'26.679'' : WELL 'A2 ~Y = , X LAT = LONG = t WELL A3 Y = X = LAT = ~LONG = WELL Ab' Y X = LAT = LONG = WELL A5 yX LAT LONG WELL A6 Y X - 1 LAT ...... 1I LONG WELL A7 Y = X-- LAT = ,, LONG = WELL /~8 Y = X = LAT = LONG = RECEIVED I : SEP 1 5 198I Alaska Oil:& Gas Cons. Commission · , Auui~uiage . 5,971,346.82 540,178.32 70019, 57. 557" 149040'26.693'' 5,971,227,31 540,178.51 70o19'56. 381" 149o40' 26. 707" 5,971 ,\106.83 540,178,52 70°19'55. 196" 149°40'26. 725" 5,970,986.86 ~'40, 1'78.61 70o19'54.016'' 149o40'26.741'' 5,970,866,70 540,178.71 70o19' 52. 834'' 149o40' 26. 757" 5,970,746.73 540,178.55 70o19' 51.654'' 149o40'26.781'' ;5,970,626.78 540,178.59 70o19' 50.475'' 149040'26.798" I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ..' ~9 ' ~'~:,.".'[' "ig ~ TO PRACTICE LAND SURVEY lNG IN ..... ""."'-; ". ~-', .. THE STATE OF ALASKA AND THAT ",";:'./////,//..l.j~i.:.".~'.~] ........ ~"]" THIS PLAT REPRESENTS AN AS- /~ ....,. ~ , '~;;"~ ~: ; .." ~ ,~..,..: ~, ,,,,,,,;.m,, . ~, :,: THAT ALL DIMENSIONS AND OTHER ~.:9' .',;,. .: .q~" C -' .~<' .;. :.-'.'-'"~. "'-"-'-' .' ¢.-,.--, DETAILS ARE CORRECT, AS OF: ': , 'L', '. ' ',,. ,,o ' :.',, ' .,." .... .-", '-'?.,;-' DATE: ·" .." '~;~'~.r:~ kt ' ~' ..,~" AtlanticRichfieidCompany ~) NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT- KUPARUK DOOATION AG' tDbll bTG i i IDATE: I, DRAWING No: IO.~..~,o _ . ! . i I-il ........ t .................. : ................................................................ t ............... . ..................... : ..................................................... :- ~ ................... _L::---T ......... :---.-':' : i' RCO--~LRSKR' .... 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'.-.i.- ' -.~----~ ..... ~ ....... : - RNNULRR PREVENTOR 9 BLIND RRM$ 8 ~J-5/8" 5000 PSI RSRRA BOP STACK 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACC~IULATOR CAPACITY TEST PIPE RRHS 7 DRILLING SPOOL PIPE RRHS 5 1. CHECK AND FILL ACCUHULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING Title AND 1200 PSI REMAINING PRESSURE. _1.3.-5/8" BOP STACK TEST l. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETEB, iIN'E 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 MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. f 4 j 8. CLOSE VALVESDIRECTLY UPSTREAN OF CHOKES. I t BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST ~ ~ VALVES. TEST R~IAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTRE~H OF T BG VALVE AND ZERO PSI DOWNSTREAM, BLEED SYSTEM ~ HD ~ . TOZEROPSI. - ' 9 OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM 3. . lO SET OF PIPE RAMS. 'J, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. CS~ ~ ll. OPEN BOTTOH SET OF PIPE RAHS. BACK OFF RUN- D RAHS AND TEST TO 3000 PSI FOR lO HINUTES. BLEED TO ZERO PSI. 12 OPEN BLIND RAHS AND RECOVER TEST PLUG. MAKE ¢ SEP 15 198t ' SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. ' [. 1~ · ~ ~13sk~Oit &GBsGBs GODS. Commission3. TEST STANDPIPE VALVES TO 3000 PSI. ~3Sk~O~ &AQ~ i TEST KELLY COCKS, AND INSIDE BOP TO 3000 PSI Anchorag~ 14. WITH KOOIiEY PUMP. 15. RECORD TEST INFO~4ATION ON BLOWOUT PREVE;iTER TEST FO~l SIG,; AriD SEND TO DRILLING SUPER- VISOR. 6. PERFOB.1 C~IPLETE BOPE TEST ONCE A WEEK A~ID FUNCTIO[IALLY OPERATE BOPE DAILY. ARCO Alaska, Inc( Post Office ~:~,..x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 9, 1981 ~Mr. Peter Hardwick BP Alaska Exploration, Inc. 255 California Street San Francisco, California 94111 Mr. Richard A. Flohr Sohio Alaska Petroleum Company 100 Pine Street San Francisco, California 94111 Re: 'Letter of Non-Objection ADL 25647 Kuparuk Project - Drill Site A North Slope,' Alaska Gentlemen: Pursuant to 20 AAC 25.050, ARCO Alaska, Inc. is required to obtain a Letter of Non-Objection from affected operators when any well is to be intention- ally deviated. ARCO hereby .requests a Letter of Non-Objection (LNO) for'Kuparuk Drill Site A, Kuparuk Well lA-7. The location of the proposed well is: ~ Surface Hole Location: 659'FSL, 308'FWL Section 5, TllN, R10£, U.M. Bottom Hole Location: 1320'FSL, 1228'FEI, Section 7, TllN, R10E, U.M. Spud Date: September 21, 1981 T° facilitate timely acquisition of the drilling permit, ARCO requests that you submit the Letter of Non-Objection directly to my attention at: ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 · . The LNO will be included in the application to the Alaska Oil and Gas Conservation Commission. Very truly' yours,o Syl}te. ster R. Jaime[ Lat/dman .~/ Please advise if I may be of further assista £ /V $£P 1 5 Alaska Oil & Gas Coos. AnChorage C°~iSSio~ SRJ/jh ARCO Alaska, Inc. is a Subs[diary of AllanticRichlqeldCo~'pa.ly bcc: Tom Brassfield CHECK LIST FOR NEW WELL PE~ITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin ~(p/thru (4) Casg '~ ~:t ¢-~ / (l%f thru 2~0) 2, 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. YES NO Is the permit fee attached .......................................... / Is well to be located in a defined pool ............................ well located proper distance from property line .................. ~.~ Is Is well located proper distance from other wells .................... Is suffi'cient undedicated acreage available in this pool ............ Is well to be _deviated and is well bore plat included ............... Is operator the only affected party ....... , ~.~ Can Permit be appr°ved bef°re ten-day'w~i['i[i i ]i[i[ii[i'[i]i].[!'i]i']![i]![i]i%]i].2. . Is a conservation order needed .............. Is administrative approval needed .......... / Is conductor string provided ........................................ 'Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in Collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. _~_ Is old wellbore abandonment procedure included on i0-403 ............ Is adequate well bore separation proposed ........................... (5) BOPE ~ R-I.G- ~_ [ (2I thru 24) 21. 22. 23. 24. Is a diverter system required ............ Are necessary diagrams of diver[;[ ~g~'~;P'e~ul;~;~; Does BOPE have sufficient pressure rating - Test to ~OOO ' , , Doe's the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. / Additional Remarks: , ,/~d:C~f /~' REMARKS Geology: Engin~r ing: HWK ~_ LCS ~ BEW~ WVA~ JKT~~ ~ JAL .,, ? rev: 03/10/81 - INITIAL' ~GEO. ' UNIT' ' '~'N/OFF POOL CLASS STATUS AREA NO. SHORE ,, 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 RE£E~¥ED Gas Cons. Commission LYP 009.H05 VERIFICATION LISTING PAGE *~ REE]J HEADER SERVICE NAME :SERVIC DATE :81110114 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL COMMENTS :REEL COMMENTS $~ TAPE HEADER ~* SERVICE NAME ISERVIC DATE :Bi/lO/14 ORIGIN :FS1A TAPE NAME : CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS $* FILE HEADER FILE NAME :SERVIC.O01 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ~ INFORMATION RECORDS MNEM CONTENTS CN WN : FN : RANG: TOWN: SECT: COUN: STAT: CTRY: MNEM ATLANTIC RICHFIELD KUPARUK 25647 A-7 KUPARUK RANGE TOWNSHIP SECTION NORTH SLOPE ALASKA USA CONTENTS ~m~mm PRES: ,, NEDI~4F ** RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 018 O65 000 000 018 065 000 000 008 065 00 000 005 065 O0 000 008 065 00 000 007 065 O0 000 012 O65 §~ 000 006 O65 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 OO7 065 LVP 009.H05 VERIFICATION LISTING ** RECORD TYPE 047 *~ RECORD TYPE 047 *~ ** COMMENTS ** ************************************************ JOB # 20707,62226 RUN #1, bOGGED lO'OCT'8! BOTTOM LOG INTERVAL TOP LOg INTERVAL CASING'LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY PH FLUID LO$8 RM M MEAS. TEMP. RMF ~ ~EA$. TEMP. RMC ~ MEAS. TEMP. RM 8 BHT 8678 FT. =,7.4 C3 Mb 3.25 8 77 F 3.3? 2.24 ~ 77F t.832 MATRIX SANDSTONE PAGE bVP 009,H05 VERIFICATION LISTING PAGE *~ DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE 4 1 66 8 4 73 9 4 65 0 1 66 DATUM MNEM SPECIFICATION BLOCKS SERVICE SERVICE UNIT API ID ORDER DEPT SFLU ISM ILL ISM IbM SP DT ISM GR LOG FT 0 OHMM 0 OHMM 0 OHMM 0 MV 0 U$/F 0 GAPI 7 ** DATA DEPT DEPT SP DEPT DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP DEPT DEPT DEPT SP 96 500 SFLU oo.ooos [u -26,906 DT 8500,000 SFDU -26,375 DT 8400,000 SFLU '36,906 DT 8300,000 SFLU -42,625 DT 8200,000 SFLO -44,750 DT 8100,000 SFLU -27,391 DT 8000,000 SFLU -21,922 DT 7900 000 SFbU -20:516 mT 7800 ooo s 'Lu -18:875 DT 7700,000 SFLU -26,219 DT API API API FILE TYPE CLA~S M~D N~. 0 o o o o 12 46 0 0 0 0 0 0 1 0 0 0 52 32 0 0 3! 32 0 0 2,590 ILD 93,750 GR 2,605 108,563 GR 4 645 89:375 GR 4,184 96,188 GR 92. 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GR -999,250 DEPT 6100.000 NPHi ~999 5O -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 ~999 50 '999,250 '999.250 ~999 250 9992250 '999,250 '999,250 '999 250 '999,250 '999'250 '999,250 RHOB FCNL RHOB FCNb RHOB FCNG RHOB FCNb RHOB FCNb RHOB ~CNb RHOB FCNb RHOB FCNb RHOB FCNb CNb RHOB FCNb RHOB FCNL RHOB ~999,250 DRHO 999.250 NCNb -999,250 DRHO '999.250 NCNb -999 50 DRHO '999",2250 NCNb -999 50 DRHO ~999.250 DRHO 999.250 NCNb ~9999,2250 DRHO 99 . 50 NCNb -999,250 DRHO -999'250 NCNb ~999.250 DRHO 999.250 NCNb -999,250 DRHO -999.250 NCNb ~999,250 DRHO ~ 999.250 NCNb -999.250 DRHO '999,250 NCNb 999,250 DRHO 9991250 NCNb ~999.250 DRHO 999.250 NCNb -999.250 DRHO -999 250 -999:250 -999,2~0 -999,2 0 -999 50 -999 50 -999.~50 -999, 50 ~999,250 999 ' 250 999.~50 999. 50 -999,~50 '999, 50 ~999.2250 999, 50 -999 250 '999:250 -999,~50 -999. 50 '999,250 '999.250 -999.250 LVP OOg. H05 VERIFICATION RNRA -999.250 CALf GR -999.250 DEPT ~000 000 NPHI RNRA -999:250 CAb! GR -999.250 DEPT 5900..000 GR -999.250 DEPT 5800.000 NPHI RNRA -999.250 CALf GR -999.250 DEPT 5700.000 NPHI RNRA -999*250 CALI GR -999.250 DEPT 5600.000 NPHI RNRa -999,250 CALI GR -999.250 DEPT 5500 °°so GR -999.250 DEPT 54~.000 NPH, I RNRA -9 '250 CALI GR -999,250 DEPT !300.000 NPH~ RNRA 999,250 CALl GR 999.250 GR -999,2~0 DEPT .51~0 000 NPHi RNRA 9 9 ~ 250 CALl GR -999.250 DEPT 5000 NPHII 2 CAb GR 88.875 DEPT 4900.000 NPH~ RNRA 3.703 CAb GR 69.375 DEPT 4800.00 NP RNRA 3,69~ CA GR 68.563 blSTING -999.250 2999 250 999:250 -999. 50 -999,2250 -99 50 999 50 ' 50 ~999.250 999.250 999.250 999.250 .-999.250 999~250 -99 250 -999 250 I0.7'1 39 355 11:578 12 78 RHOB FCNb RHOB rCNb RHOB RHOB RHOB RHOB FCNb RHOB FCNb RHOB FCNb RHOB FCNb FCNb '0 RH B FCNb RH00 rCNb FCNb -999.250 99. 50 -99 2250 -999.250 -999.250 .-999 2250 -999,250 -999.250 -999. 50 -999.~50 -999.250 -999,250 -999.250 -999,250 2.227 535.000 z NCNb DRHO NCNb DRHO NCNb DR. HO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb RHO PAGE 10 -99g.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999".250 -99~9.250 -999.250 ~999 250 5O ~999 250 ~99.250 99.250 999.250 -'999.250 ~999 250 0.074 ~922.0'00 0.079 1836.000 LVP 009.M05 VERIFfCATfON bISTING PAGE DEPT 4700.000 NPHI RNRA 3 777 CALI D~P~ 4600~000 RNRA 3.258 CALI GE 63.688 DEPT 4500 000 NPHI RNRA 3:449 CALf GR 53,594 DEPT 4400.000 NPHI RNRA 3,773 CALl GR 51.625 DEPT 4300,000 NPHI RNRA 3,480 CALf GR 79.938 DEPT 4200 000 NPHI RNRA 3:408 CALf GR 76.000 RNRA 369 CAbI GR 57.188 DEPT 4000,0~0 NPHI RNRA 3,5 7 CALl GR 45,813 DEPT 3900,000 NPHI RNRA 3.936 CALl GR 63,063 DEPT 3800,000 NPHI DEPT 3700 000 RNRA 4:145 CALl GR 75.563 DEPT 3600.000 NPHI RNRA 4.457 CALl DEPT 3500,000 NPHI RNRA 3.916 CALI GE 56.563 DEPT 3400.000 NPHI 41.992 12.352 12. 41.943 10.305 47 46 42,67~ 14.97 41.211 14,695 42 18 41 53 46 19 44,336 10.063 5 51 807 12:086 45 264 45,312 RHDB FCNb RHOB FCNb RH00 FCNL RHOB FCNb RHOB FCNb HOB CNb RHOB FCNb RHOB FCNb RHOB FCNb RHOB FCNb RHOB FCNb RHOB FCNb HOB . CNb RHOB 2.28~ DRHQ 498.75 NCNb 314 DRHO 2,307 DRHD 558.500 NCNb ,129 DRHO 48~.500 NCNb ,283 DRHO 55~.500 NCNb 291 DRHO 2.121 DRHO 474.750 NCNb 2 27! DRHO 428:000 NCNb ,273 DRHO 37 .250 NCNb 2,289 DRHO 321.250 NCNb 2,205 DRHO 429.500 NCNb 2,191 DRHO 0,080 1884'000 0 099 1872:000 0,064 1927,000 0.047 t814.000 0.135 1882.000 0,056 1884.000 0.074 I679.000 -0 001 I6.9:ooo 0.052 1685i000 0.009 1879,000 0.071 15561000 0.078 1432.000 0,057 1682,000 0.043 LVP 009.H05 VERIFICATION LISTING RNRA 4.188 CAGI GR 59.031 DEPT 3300.000 NPHI RNRA 3.727 CALI GR 54,000 DEPT 3200,000 NPHI RNRA 3,488 CALl GR 47,063 DEPT 3100.000 NPHI RNRA 3,611 CALI GR 71.500 DEPT 3000,000 NPHI RNRA 3.814 CALI GR 66,563 DEPT 290D,0~0 NPHI RNRA 3.6 B CALI 49.688 DEPT 2800.000 NPHI RNRA 4.391 CAbi GR 51.063 DEPT 2700,000 NPHI RNRA 4.094 CALI GR 64,563 DEPT 2600.000 NPHi RNRA 3.570 CALI GR 42,438 DEPT 2500 000 NPHI RNR~ 3:490 CALI GR 72,500 DEPT ~419,000 NPHI RNRA 999.250 CALl GR -999.250 10.078 45,557 10,203 44 141 44.775 12.617 38.916 11.602 50 49 40 46 338 -999. FCNb RHOB FCN6 RHOB FCNb RHOB FCNb RHOB ?CNb RHOB FCN6 HOB CNb RHOB FCNb RHO8 FCNb RHOB FCNL RHOB FCNL ** FILE TRAILER FILE NAME :$ERVIC.O02 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FIhE NA~E 427.750 471 '135 .250 2.148 491.750 2.158 557.000 2 58 4 441 '092 .250 '999,2 0 '999,2~0 NCNb DRHO NCNL DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNL DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb PAGE 1792.000 0.032 1876,000 0.041 1655.000 0 042 165B~000 162~ '°96 .000 0.016 t809.000 0 011 2446.'000 0.037 1568.000 -0.000 1903,000 0.030 155B.000 -999.250 -999.250 12 LVP 009.H05 'VERIFICATION LISTING *~ TAPE TRAILER SERVICE NAME :$ERVIC DATE :81/i0/14 ORIGIN :FS1A TAPE NAME : CONTINUATION # NEXT TAPE NAME COMMENTS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :$ERVIC DATE :81/10/14 ORIGIN : REEL NAM~ :REEL ID CONTINUATION # :02 NEXT REEL NA~E : COMMENTS :REEL COMMENTS ***~****** EOF ********** EOF