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185-005
Originated:Delivered to:9-Nov-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 2N-345A 50-103-20264-01 906623204 Tarn Perforation Record Field- Final 25-Jul-20 0 1 2 2U-02 50-029-21268-00 906648446 Kuparuk River Packer Setting Record Field- Final 11-Aug-20 0 1 3 CPF-1A 50-029-21243-00 n/a Shallow Sands Leak Detect Log Field- Final 26-Aug-20 0 1 4 2G-08 50-029-21125-00 906640095 Kuparuk River Leak Detect Log and Plug Setting RecordField- Final 4-Aug-20 0 1 5 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 7-Aug-20 6 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 8-Aug-20 7 2M-33 50-103-20240-00 906598622 Kuparuk River Multi Finger Caliper Field- Processed 9-Aug-20 0 1 8 1A-23 50-029-22131-00 n/a Kuparuk River Leak Detect Log Field- Final 11-Aug-20 0 1 9 2B-02A 50-029-21154-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Aug-20 0 1 10 2M-10 50-103-20157-00 906659029 Kuparuk River Multi Finger Caliper Field- Processed 15-Aug-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: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 1850050 E-Set: 34236 Originated:Delivered to:1-Oct-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 #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 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: 0 1 0 1 PTD: 1850050 E-Set: 34061 Received by the AOGCC 10/05/2020 10/07/2020 Abby Bell Originated:Delivered to:1-Oct-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 #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 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: 0 1 0 1 Received by the AOGCC 10/05/2020 PTD: 1850050 E-Set: 34060 10/07/2020 Abby Bell 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing patch ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8698 feet None feet true vertical 6208 feet None feet Effective Depth measured 8356 feet 7874 feet true vertical 5972 feet 5645 feet Perforation depth Measured depth 8060 - 8363 feet True Vertical depth 5770 - 5967 feet Tubing (size, grade, measured and true vertical depth)3.5 L-80 7939 5688 Packers and SSSV (type, measured and true vertical depth)Baker FHL 7874 MD 5645 TVD NO SSSV 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 8/16/2020 Contact Phone: Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist ----- ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Conductor 67 16 105 105 N/A N/A N/A Production 8531 7 8564 6115 N/A N/A Surface 3918 9.625 3955 3079 N/A Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/ Kuparuk River Oil Plugs measured Junk measured Burst Collapse 185-005 50029212680000' ADL0025644 KRU 2U-02 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: t Fra O 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:25 am, Aug 17, 2020 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-16 18:25:10 Foxit PhantomPDF Version: 10.0.0 jan.byrne@cono cophillips.com , ADL0025643 X VTL 11/03/20 SFD 8/17/2020 SFD 8/17/2020 DSR-8/17/2020 RBDMS HEW 8/17/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 16, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 for Sundry well operations from ConocoPhillips Alaska, Inc. for installation of two retrievable tubing patches set across known tubing leaks in producer KRU 2U-02 (PTD 185-005). Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-16 18:23:47 Foxit PhantomPDF Version: 10.0.0 jan.byrne@c onocophillips. com Event Summary Executive Summary 2U-02 On 6/26/20 the well failed a TIFL. Slickline replaced a faulty GLV and the well was brought online to be tested, but the follow up TIFL failed and indicated that the leak was below the existing patch (Installed in 2015 over the known leak at 5399'). The patch was pulled and an LDL located new tubing leaks at 6550' & 6555'. A new 3.5", 26' OAL, retrievable Paragon 2 Packer patch was installed over the new tubing leaks and a new 3.5", 35' OAL, retrievable Paragon 2 Packer patch was installed over the old known leak depth. The well passed all testing subsequent installing the patches. Pertinent well work is copied below. 07/29/20 SET DV @ 7808' RKB; LOG TEMPERATURE SPINNER LDL FROM 7900' RKB TO SURFACE (IDENTIFY LEAKS @ 5400', 5412', 6550' & 6555' RKB); LOG 24 ARM CALIPER FROM 7900' RKB TO SURFACE. JOB COMPLETE. 08/11/20 DRIFT TBG W/ 2.72" 31' DUMMY PATCH TO 6600' RKB, SET LOWER 2.72" P2P @ 6562' RKB (ME) (OAL 4.01' / SN: CPP35270), CMIT TBG x IA LOWER PACKER 2500 PSI PASS, SET UPPER 2.72" P2P SPACER & ANCHOR LATCH @ 6540' RKB (OAL 22.88' / SN:CPP35251 / CPAL35156), CMIT UPPER PACKER 2500 PASS. PRE CMIT T/I/O= 225/225/540, PRESSURE UP (3.8 BBLS) T/I/O= 2550/2550/540, 15 MIN T/I/O= 2475/2475/540, 30 MIN T/I/O= 2475/2475/540 08/12/20 RAN 3 1/2 SHF GOOD COMBO TEST @ 5418' RKB, SET LOWER 2.72" P2P @ 5418' RKB (ME) (OAL 4.01' / SN: CPP35266), CMIT TBG x IA W/ TEST TOOL IN LOWER PACKER @ 5418' RKB 2500 PSI PASS, SET UPPER 2.72" P2P SPACER & ANCHOR ASSEMBLY @ 5387' RKB (ME) (OAL 31.85' / SN:CPP35271 / CPAL35126), MIT TBG 2500 PASS W/ TEST TOOL IN UPPER PACKER @ 65387' RKB, CMIT TBG x IA 2500 PASS. COMPLETE. PRE MIT TBG T/I/ 325/300/540, PRESSURE UP T/I/O= 2575/325/540, 15 MIN T/I/O= 2450/350/540, 30 MIN T/I/O= 2400/350/540, ****PASS*** LRS RIG OFF TBG & RIG UP TO IA PRE CMIT TBG x IA T/I/O= 2350/325/540, PRESSURE UP T/I/O= 2525/2550/540, 15 MIN T/I/O= 2550/2475/540, 30 MIN T/I/O= 2550/2450/540, Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,356.0 8/10/2017 2U-02 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install Dual Patches 8/12/2020 2U-02 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 105.0 Set Depth (TVD) … 105.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,954.6 Set Depth (TVD) … 3,078.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,563.9 Set Depth (TVD) … 6,115.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.3 Set Depth (ft… 7,938.7 Set Depth (TVD) (… 5,688.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.3 32.3 0.00 HANGER McEVOY TUBING HANGER 2.910 521.8 521.8 0.23 NIPPLE CAMCO DS LANDING NIPPLE 2.875 7,858.1 5,634.7 48.16 LOCATOR BAKER LOCATOR SUB 2.992 7,860.4 5,636.2 48.19 PBR BAKER 80-40 PBR 4.000 7,873.7 5,645.1 48.36 PACKER BAKER FHL PACKER 2.910 7,922.9 5,677.9 48.08 NIPPLE CAMCO DS NO GO NIPPLE 2.813 7,930.0 5,682.6 48.06 SBR BARREL OTIS SBR BARREL 4.800 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,938.2 Set Depth (ft… 8,239.6 Set Depth (TVD) (… 5,891.9 Wt (lb/ft) Grade Top Connection FL4S Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,938.2 5,688.0 48.05 SLICK STICK SBR SLICK STICK 2.810 7,950.3 5,696.2 48.03 PACKER OTIS 'RRH' PACKER 2.970 8,097.7 5,795.2 47.34 BLAST JT CARBIDE BLAST JOINT (3) 2.992 8,212.9 5,873.7 46.89 LOCATOR OTIS COLLAR LOCATOR 2.970 8,213.5 5,874.1 46.89 PACKER OTIS 'HD' PACKER 2.970 8,216.5 5,876.1 46.88 SBE OTIS SEAL BORE EXTENSION 4.000 8,229.5 5,885.0 46.84 NIPPLE CAMCO 'D' NIPPLE 2.750 8,237.9 5,890.8 46.81 SOS OTIS SHEAROUT SUB 2.992 8,238.7 5,891.3 46.81 WLEG OITS WIRELINE RE-ENTRY GUIDE 2.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,387.0 4,038.2 47.05 PATCH - PACKER 2.72" P2P PACKER, SPACER PIPE, ANCHOR LATCH, 31.85' OAL 8/12/2020 1.610 CPP35271 5,391.5 4,041.2 47.05 SPACER PIPE 2-1/16" P110 SPACER PIPE. Attached to upper packer & is included in the 31.85 OAL. 8/12/2020 1.600 CPAI 5,400.0 4,047.0 47.06 Tubing Leak HES LDL LOG SHOWED TBG LEAKS @ 5400 & 5412' RKB 7/29/2020 2.900 5,418.0 4,059.3 47.21 PATCH - PACKER 2.72" P2P PACKER, 4.01' OAL 8/12/2020 1.625 CPP35266 6,540.0 4,793.3 51.19 PATCH - PACKER 2.72" P2P PACKER, SPACER PIPE, ANCHOR LATCH, 22' OAL 8/11/2020 1.625 CPP35251 6,544.0 4,795.8 51.15 SPACER PIPE 2-1/16" P110 SPACER PIPE 8/11/2020 1.600 CPAI 6,550.0 4,799.6 51.09 Tubing Leak HES LDL LOG SHOWED TBG LEAKS @ 6550 & 6555' RKB 7/29/2020 2.900 6,562.0 4,807.1 51.24 PATCH - PACKER 2.72" P2P PACKER, 4.01' OAL 8/11/2020 1.625 CPP35270 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,060.0 8,062.0 5,769.8 5,771.1 3/30/1985 4.0 IPERF Squeezed, 4" Casing Guns 8,100.0 8,147.0 5,796.8 5,828.7 C-4, UNIT B, 2U -02 4/3/1985 12.0 IPERF Baker TCPF 8,150.0 8,154.0 5,830.8 5,833.5 UNIT B, 2U-02 4/3/1985 12.0 IPERF Baker TCPF 8,159.0 8,165.0 5,836.9 5,841.0 UNIT B, 2U-02 4/3/1985 12.0 IPERF Baker TCPF 8,286.0 8,299.0 5,923.7 5,932.6 A-4, 2U-02 4/3/1985 4.0 IPERF Baker TCPF 8,308.0 8,363.0 5,938.8 5,976.6 A-3, 2U-02 4/3/1985 4.0 IPERF Baker TCPF Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 8,060.0 8,062.0 5,769.8 5,771.1 Cement 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 3,062.4 2,491.5 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,259.0 7/20/2020 3:00 2 4,579.3 3,493.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,291.0 7/20/2020 7:00 3 5,284.2 3,968.0 CAMCO KBUG 1 GAS LIFT OV BK 0.313 0.0 7/20/2020 5:00 4 6,397.7 4,704.9 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 8/31/2003 9:00 5 7,225.7 5,224.3 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 8/31/2003 7:00 6 7,808.0 5,601.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/29/2020 2:00 7 7,986.0 5,720.0 MERLA TPDX 1 1/2 PROD DMY RM 0.000 0.0 3/29/2000 11:00 8 8,056.9 5,767.7 MERLA TPDX 1 1/2 PROD DMY RM 0.000 0.0 3/30/2000 6:00 2U-02, 8/13/2020 9:18:02 AM Vertical schematic (actual) PRODUCTION; 33.0-8,563.9 IPERF; 8,308.0-8,363.0 IPERF; 8,286.0-8,299.0 WLEG; 8,238.7 SOS; 8,237.9 NIPPLE; 8,229.5 TUBING ADAPTER; 8,220.9 SBE; 8,216.5 TUBING CONNECTOR; 8,216.0 PACKER; 8,213.5 LOCATOR; 8,212.9 PRODUCTION; 8,193.3 IPERF; 8,159.0-8,165.0 IPERF; 8,150.0-8,154.0 IPERF; 8,100.0-8,147.0 PRODUCTION; 8,056.9 Cement; 8,060.0 ftKB IPERF; 8,060.0-8,062.0 PRODUCTION; 7,986.0 PACKER; 7,950.3 SLICK STICK; 7,938.2 SBR BARREL; 7,930.0 NIPPLE; 7,922.9 PACKER; 7,873.7 PBR; 7,860.4 LOCATOR; 7,858.1 GAS LIFT; 7,808.0 GAS LIFT; 7,225.7 PATCH - PACKER; 6,562.0 SPACER PIPE; 6,544.0 Tubing Leak; 6,550.0 PATCH - PACKER; 6,540.0 GAS LIFT; 6,397.7 PATCH - PACKER; 5,418.0 Tubing Leak; 5,400.0 SPACER PIPE; 5,391.5 PATCH - PACKER; 5,387.0 GAS LIFT; 5,284.2 GAS LIFT; 4,579.3 SURFACE; 37.0-3,954.6 GAS LIFT; 3,062.4 NIPPLE; 521.8 CONDUCTOR; 38.0-105.0 HANGER; 32.3 KUP PROD KB-Grd (ft) 40.89 Rig Release Date 2/14/1985 2U-02 ... TD Act Btm (ftKB) 8,698.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292126800 Wellbore Status PROD Max Angle & MD Incl (°) 52.15 MD (ftKB) 6,300.00 WELLNAME WELLBORE2U-02 Annotation Last WO: End Date 8/25/2003 H2S (ppm) 40 Date 12/3/2016 Comment SSSV: NIPPLE 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 9 8,193.3 5,860.3 MERLA TPDX 1 1/2 PROD OPEN RM 9/13/2006 OPEN POCK ET Notes: General & Safety End Date Annotation 6/7/2014 NOTE: Mandrel Orientation notes at 8175', mandrel noted as pump01 has an orientation of 4:00 1/30/2012 NOTE: VIEW WELL w/ALASKA SCHEMATIC9.0 3/31/2000 NOTE: CONFIRMED DAMAGED/LEAKING CSM @8192 RKB 2U-02, 8/13/2020 9:18:03 AM Vertical schematic (actual) PRODUCTION; 33.0-8,563.9 IPERF; 8,308.0-8,363.0 IPERF; 8,286.0-8,299.0 WLEG; 8,238.7 SOS; 8,237.9 NIPPLE; 8,229.5 TUBING ADAPTER; 8,220.9 SBE; 8,216.5 TUBING CONNECTOR; 8,216.0 PACKER; 8,213.5 LOCATOR; 8,212.9 PRODUCTION; 8,193.3 IPERF; 8,159.0-8,165.0 IPERF; 8,150.0-8,154.0 IPERF; 8,100.0-8,147.0 PRODUCTION; 8,056.9 Cement; 8,060.0 ftKB IPERF; 8,060.0-8,062.0 PRODUCTION; 7,986.0 PACKER; 7,950.3 SLICK STICK; 7,938.2 SBR BARREL; 7,930.0 NIPPLE; 7,922.9 PACKER; 7,873.7 PBR; 7,860.4 LOCATOR; 7,858.1 GAS LIFT; 7,808.0 GAS LIFT; 7,225.7 PATCH - PACKER; 6,562.0 SPACER PIPE; 6,544.0 Tubing Leak; 6,550.0 PATCH - PACKER; 6,540.0 GAS LIFT; 6,397.7 PATCH - PACKER; 5,418.0 Tubing Leak; 5,400.0 SPACER PIPE; 5,391.5 PATCH - PACKER; 5,387.0 GAS LIFT; 5,284.2 GAS LIFT; 4,579.3 SURFACE; 37.0-3,954.6 GAS LIFT; 3,062.4 NIPPLE; 521.8 CONDUCTOR; 38.0-105.0 HANGER; 32.3 KUP PROD 2U-02 ... 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Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2U-02 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21268-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: A ��:+N� STATE OF ALASKA • r _,SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Ferforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Poolr Repair Well r Re-enter Susp Well r Other: 1�flTGttt 017 2.Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185-005 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21268-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL0025644 Y_'.v 2U-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8698 feet Plugs(measured) None true vertical 6208 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 5390,7860,7874 true vertical 0 feet (true vertical) 4040,5636,5645 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 105 SURFACE 3918 12 3955 PRODUCTION 8531 7 8564 SCANNEDy! ;; R E C E V h D illi_ 2 9 2015 Perforation depth: Measured depth: 8100'-8147',8150'-8154',8159'-8165',8286'-8299',8308'-8363'. IDG/'� True Vertical Depth: 5797'-5823', 5831'-5834', 5837'-5841',5924'-5933',5939'-5977'. :� CO Tubing(size,grade,MD,and TVD) 3.5,J-55,8238 MD, 5891 TVD Packers&SSSV(type,MD,and ND) PATCH-WFT WIDEPAK PACKER AND SPACER PIPE @ 5390 MD and 4040 TVD PBR-BAKER 80-40 PBR @ 7860 MD and 5636 ND PACKER-BAKER FHL PACKER @ 7874 MD and 5645 ND NIPPLE-CAMCO DS LANDING NIPPLE @ 522 MD and 522 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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 Daily Report of Well Operations Copies of Logs and Surveys Run Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25 071,&25 283) 15.Well Class after work. Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt N/A Contact Jan Byrne Email n1617(aconocophillips Printed Name Jan Byrne Title Problem Wells Supervisor Signature ?c"-- Vi/i Phone:659-7126 Date 7/24/2015 s `c\ AUG - 2 ZO1§Submit Original Only Form 10-404 Revised 5/2015 RBDM ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 24th, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2U-02 (PTD 185-005) tubing patch repair. Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659- 7224 if you have any questions. Sincerely, o.. Jan me Problem Wells Supervisor Attachments Name of Recipient Page 2 of 2 07/24/15 Delete the section break above to remove the second page 2U-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/21/15 A diagnostic TIFL failed demonstrating loss of integrity in the tubing. 06/09/15 Slickline diagnostics indicated a leak in the tubing between 5393' and 5398'. 07/03/15 Digital Slickline ran a leak detect log and confirmed the leak point at 5399'. 07/10/15 Eline ran a 24 multifinger caliper survey to assess tubing quality. 07/15/15 Digital Slickline installed a patch from 5357'to 5404' repairing the tubing leak. Attached below is the work performed to install the patch. SET WFT WIDEPAK LE LOWER PACKER @ 5,403.5' RKB SET ER TEST TOOL IN LOWER PACKER @ 5,357' SLM LRS PERFROMED PASSIN CMIT TxIA TO 2,500 PSI SET WFT WIDEPAK LE UPPER PACKER AND SPACER PIPE @ 5,388.5' RKB SET ER TEST TOOL IN UPPER PACKER @ 5,340' SLM LRS PERFORMED PASSING MIT-T TO 2,500 PSI. **CMIT pass: preTIO=445/475/460, initial=2510/2524/480, 15min=2465/2475/480, 30min=2445/2455/480 MITT initial attempt: preTIO=376/654/460, initial=2500/666/460, 15min=2250/689/460 MITT pass: preTIO=2250/689/460, initial=2525/693/460, 15min=2400/714/460, 30min=2350/736/460** 2U-02 DESCRIPTION OF WORK COMPLETED SUMMARY KUP PROD 2U-02 w ConocoPhillips ,3s F Well Attributes Max Angle&MD TD Alaska,Inc. ' # i Wellbore APIIUWI Field Name Wetmore Status t ncl(") MD(ftKD) Act Btm(ftKB)tcmaoral,aIips° 500292126800 KUPARUK RIVER UNIT PROD 52.15 6,300.00 8,698.0 ••• - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) --Rig Release Date 2U-02,7/2320159:14:16 AM -SSSV:NIPPLE 40 10/30/2014 Last WO 8/25/2003 40.89 2/14/1985 Vert cat schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,32.3 --= r- Last Tag: 8,315.0 6/4/2014 Rev Reason'.PATCH,Mandrel Orientations lehallf 7/23/2015 Casing Strings Casing Description OD(in) ID(m) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread • / CONDUCTOR 16 15.062 38.0 105.0 105.0 62.50 440 WELDED { ECasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread uut/SURFACE 95/8 8.921 37.0 3,954.6 3,078.9 36.00 J-55 BTC Ii Cas Description Descripon OD(in) ID(In) Top(kKB) Set Depth(kKB) Set Depth(ND)... WtlLen(I...Grade Top Thread I PRODUCTION Tubing Strings 7 6.776 33.0 8,563.9 6,115.2 26.00 J-55 BTC .A.A.,.A.A.,CONDUCTOR;380-105.0 s�Tubing Description String Ma .ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection TUBING WO 3 12 2.992 32.3 7,938.7 5.6884 9.30 L-80 ABM FUF NIPPLE;521.6 ... Completion Details Nominal ID Top(ftKB) Top(ND)(kKB) Top Incl(°) Item Des Com (in) GAS LIFT,3,062.4 32.3 32.3- 0.00 HANGER McEVOY TUBING HANGER 2.910 521.8 521.8 0.23 NIPPLE CAMCO DS LANDING NIPPLE 2.875 7,858.1 5,634.7 48.16 LOCATOR BAKER LOCATOR SUB 2.992 7,860.4 5,636.2 48.19 PBR BAKER 80-40 PBR 4.000 SURFACE.37.0-3,954.6--a 7,873.7 5,645.1 48.36 PACKER BAKER FHL PACKER 2.910 7,922.0 5,677.9 48.08 NIPPLE CAMCO DS NO GO NIPPLE 2.813 GAS LIFT,4,579.3 I7,930.0 5,682.6 48.06 SBR BARREL OTIS SBR BARREL 4.800 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Origin al 312 2.992 7,938.2 8239.6 5,891.9 FL4S GAS LIFT 6,294.2 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) a.. 7,938.2 5,688.0 48.05 SLICK STICK SBR SLICK STICK 2.810 PATCH',5,389 5 ' - 7,950.3 5,696.2 48.03 PACKER OTIS'RRH'PACKER 2.970 1. 8,097.7 5,795.2 47.34 BLAST JT CARBIDE BLAST JOINT(3) 2.992 GAS LIFT,6,397.7 - 1 8,212.9 5,873.7 46.89 LOCATOR OTIS COLLAR LOCATOR 2.970 8,213.5 5,874.1 46.89 PACKER OTIS'HD'PACKER 2.970 8,216.5 5,876.1 46.88 SBE OTIS SEAL BORE EXTENSION 4.000 GAS LIFT;7,225.7 1. 8,229.5 5,885.0 46.84 NIPPLE CAMCO D'NIPPLE 2.750 8,237.9 5,890.8 46.81 SOS OTIS SHEAROUT SUB 2.992 8238.7 5,891.3 46.81 WLEG OITS WIRELINE RE-ENTRY GUIDE 2.950 GAS LIFT,7,808.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) I°) Des Com Run Date ID(in) 5,389.5 4,039.9 47.05 PATCH WFT WIDEPAK PACKER AND SPACER PIPE 7/15/2015 1.750 LOCATOR',7858.1 Perforations&Slots PBR;7,860.4 5, *' o Shot PACKER;7,873.7 _ Dens (ftKB) Btm(ftKB) Top(ftKB)D) Btm(TVD) (shots/f Top( (ftKB) Zone Date q Type Com 8,060.0 8,062.0 5,769.8 5,771.1 3/30/1985 4.0 IPERF Squeezed,4"Casing I Guns NIPPLE;79226 8,100.08,147.0' 5,796.8 5,828.7 C-4,UNIT B, 4/3/1985 12.0 IPERF Baker TCPF 2U-02 SBR BARREL;7,9300 8,150.0 8,154.0 5,830.8 5,833.5 UNIT B,2U- 4/3/1985 12.0 IPERF Baker TCPF • 02 SLICK STICK,7938.2 8,159.0 8,165.0 5,836.9 5,841.0 UNIT B,2U- 4/3/1985 12.0 IPERF Baker TCPF PACKER,7,950.3 - •' 02 8,286.0 8,299.05,923.7 5,932.6 A-4,2U-02 4/3/1985 4.0 IPERF Baker TCPF PRODUCTION;7,986.0 , 8,308.0 8,363.0 5,938.8 5,976.6 A-3,2U-02 4/3/1985 4.0 IPERF Baker TCPF Cement Squeezes (PERF;8,0600.8,062.01 VD Top(TVD) Btm(T ) PRODUCTION,8,056.9 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com I: 8,060.0 8,062.0 5,769.8 5,771.1 Cement Squeeze 3/31/1985 IPERF;8,100.0-8,147.0- I Mandrel Inserts SI ati IPERF;8,150.0-8,154.0- on N Top(ND) Valve Latch Pori Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn IPERF,8,159 is { 3,0624 2,491.5 CAMCO KBUG 1 GAS LIFT GLV BK-5 0.156 1,266.0 8/31/2003 3:00 I 2 4,579.3- 3,493.1 CAMCO KBUG 1 GAS LIFT GLV BK-5 0.188 1,301.0 8/31/2003 7:00 1 3 5,284.2 3,968.0 CAMCO KBUG 1 GAS LIFT OV BK-5 0.250 0.0 8/31/2003 5:00 PRODUCTION,8,193.3 1r 4 6,397.7 4,704.9 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 8/31/2003 9:00 5 7,225.7 5,224.3 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 8/31/2003 7:00 LOCATOR 9212.9 6 7,808.0' 5,601.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/31/2003 2:00 PACKER,8,213.5 7 7,986.0- 5,720.0 MERLA TPDX 11/2 PROD DMY RM 0.000 0.0 3/29/2000 11:00 TUBING CONNECTOR,8,216o_ii, �A 8 8,056.9 5,767.7 MERLA TPDX 11/2 PROD DMY RM 0.000 0.0 3/30/2000 6:00 SBE;8.216.5IHr 9 8,193.3 5,860.3 MERLA TPDX 11/2 PROD OPEN RM 9/13/2006 OPEN TUBING ADAPTER;8,220.9 p t POCK ET Notes:General&Safety NIPPLE;8,229.5 _ End Date Annotation 3/31/2000 NOTE:CONFIRMED DAMAGED/LEAKING CSM @8192 RKB 606,8,237.9 y 1/30/2012 NOTE:VIEW WELL w/ALASKA SCHEMATIC9.0 WLEG:8.238.7 6/7/2014 NOTE: Mandrel Orientation notes at 8175',mandrel noted as pump0l has an orientation of 4:00 IPERF,B286.0-8,299.0- r IPERF;8,308.0-8,363.0 PRODUCTION;33.0-8,583.9 Ima~Project Well History File' C( ge 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. / ~_~- ~L~~ell History File Identifier Organizing (done) V Color items: DIGITAL DATA [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other://-~. ~, ~ , ~r NOTES: BY: BEVERLY BRF~~ SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other Project Proofing BY: (~~BREN VINCENT SHERYL MARIA LOWELl. Scanning Preparation ~,~ x 30 = BY: BEVERLY BREN VINCE~ARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: -- ~ ~""g~'/~' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND' YES NO BEVERLY BREN VINCENT SHERYL MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALrrY, GRAYSCALE OR COLOR IMAGES) DATE: ISl RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or COmments about this file: Quality Checked (done) 10125/02Rev3NOTSca n ned .wpd Page l of 3 • Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Thursday, January 27, 2011 9:09 AM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Field - Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval , Attachments: Kuparuk Gas Injector Flow back Volumes.xls 00 Attached you will find the Kuparuk Gas Injector Flowback information per your, request. Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7535 CVk og tL I C E 8 201 g Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e -mail in error, lease notify the sender and delete this email immediately. Lci From: Maunder, Thomas E (DOA) [ mailto:tom.maunder@alaska.goi Sent: Tuesday, January 25, 2011 9:09 AM To: NSK Prod Engr & Optimization Supv Subject: RE: Request for Approval Gary/Denise, Following up on my brief conversation with Gary the other day, could one of you provide some information with regard to the flowback of these WAG injectors while TAPS was unavailable. Please copy everyoned as before with your response. Thanks in advance, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. 1/27/2011 • Page 2 of 3 410 Tom Maunder, PE AOGCC I i From: NSK Prod Engr & Optimization Supv [ mailto :n2046(&conocophillips.comj Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto_tom.maunder@alaska govt Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv jmaiito;n2046 conocophills.coml Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D 1/27/2011 • Page 3 of 3 Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. lowback Adjacent Estimated Prod ;as Injector PTD# SI Producer PTD# (Mscfd) o2P -420 201 -182 2P -422A 202 -067 4,500 aP -447 203 -154 2P -448A 202 -005 2,000 aU -03 185 -006 �, 2U-02 185 -00D 3,500 0 .; 202 -205 " IS-08C 207 -163 7,500 3S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/27/2011 Page 2 of Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. 1 have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval JAN X01 n Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ■lowback Adjacent Estimated Prod ;as Injector PTD# SI Producer PTD# (Mscfd) ;P -420 201 -182 2P -422A 202 -067 4,500 ;P -447 203 -154 2P -, 02 -005 2,000 ;U -03 185 -006 2U- I 185- 005.; 3,500 IS -09 202 -205 3S -08C 207 -163 7,500 IS -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/11/2011 Page 1 of • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 ©conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval 1/11/2011 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 rY. ~ ~ .,. March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 d~~~~~~ ~ ~~ ~E Dear Mr. Maunder: ~' ')~±~; ~~~~ ° ~,w ~° ~ r, ~' " ~'~~ ~ ~ ~ .~ Q ~- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23`d , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ a~~~ C M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2!22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1 /18/2009 15.1 2/21 /2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21 " 1 /24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1!24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 12/30/08 ~Cf ~- .,,~~5. k ~, ~ ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2U-03 12080460 INJECTION PROFILE ~}+ 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE 'j - 12/07/08 1 1 iC-11 12114998 PRODUCTION PROFILE a 12/14/08 1 1 i D-07 12114999 USIT ._ a 12!15/08 1 1 1 B-09 12115001 INJECTION PROFILE ~ (- ~ 12/18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP 12/19/08 1 1 1C-18 12100472 INJECTION PROFILE ~' 12/21/08 1 1 1 E-21 12115005 INJECTION PROFILE p 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE 3 12/24/08 1 1 1 ~ ~~I,s, Fpy LF .'~~,+ i .~~`d;;..~ L~~f !. ~. 'ate Log Description NO. 5024 Company: Alaska'Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r-] suspend ~] operation Shutdown [] Perforate [~ Variance ~-] Annular Disp. [] Alter Casing [~ Repair Well [-~ Plug Perforations Change Approved Program E~ Pull Tubing E~ Perforate New Pool E~] Re-enter Suspended Well [] ' 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~] Exploratory [~ 185-005 ! 3. Address: Stratigraphic [~ Service [] 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21268-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105', 32' to tubinghead 2U-02 8. Property Designation: 10. Field/Pool(s): ADL 25644, ALK 2575 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8698' feet true vertical 6211' feet Plugs (measured) Effective Depth measured 8330' feet Junk (measured) true vertical 5957' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 105' 105' SUR. CASING 3923' 9-5/8" 3955' 3081' PROD. CASING 8532' 7" 8564' 6118' Perforation depth: Measured depth: 8100'-8147', 8150'-8154', 8159'-8165', 8286'-8299', 8308'-8363' true vertical depth: 5800'-5832', 5834'-5836', 5840'-5844', 5927'-5935', 5942'-5979' Tubing (size, grade, and measured depth) 3-1/2", L-80/J-55, 8240' MD. Packers & SSSV (type & measured depth) pkr= OTIS 'RRH'; OTIS 'WD', Baker FHL pkr= 7949'; 8214', 7874' SSSV= NIP SSSV= 522' 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 Casin,q Pressure Tubin,q Pressure Prior to well operation shut in since 12/02 - Subsequent to operation 2974 2902 1877 230 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory ~ Development [] Service r--] Daily Report of Well Operations _X 16. Well Status after proposed work: Oil ~-~ Gas r-'] WAG n-'~ GINJ[~] WINJ ~ WDSPLr~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.C. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike ,Mooney Title Wells Group Team Leader / Signature .. //~/~~,¢~. Phone Date /~/~/~_~, .............. .~. Prepared biz $1~aron AIIsup~Drake 263-4612 Form 10-404 Revised 2/2003 BFL SUBMIT IN DUPLICATE ConocoPhillips Alaska Page 1 of 4 Operations Summar Report Legal Well Name: 2U-02 Common Well Name: 2U-02 Spud Date: 2/6/1985 'Event Name: WORKOVER/RECOMP Start: 8/21/2003 End: 8/25/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 8/25/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From - To Hours Code Code 8/21/2003 06:30 - 11:30 5.00 MOVE RURD MOVE Rig released from 3J-19 at 0630. RD mast. Separate Pipe shed module and pit module. Ready to move carrier sub away from well at 1130. 11:30 - 14:30 3.00 MOVE OTHR MOVE Drive to KOC for meeting with CPAI personnel on Workover program to date. Discuss successes and areas of improvement. 14:30 - 16:00 1.50 MOVE RURD MOVE Arrive location. Pull carrier sub away from well. Prep to leave location. 16:00 - 17:40 1.67 MOVE MOVE MOVE Road rig from 3J to KCS. 17:40 - 19:05 1.42 MOVE MOVE MOVE Wait at KCS for Kuparuk crew change. 19:05 - 21:30 2.42 MOVE MOVE MOVE Move rig from KCS to 2U. Arrive 2U at 2100. 21:30 - 00:00 2.50 MOVE RURD MOVE Set mats around wellhead. Set BOP stack behind well. Spot carrier over well. Pull forward. Lay out herculite. Back carrier sub over well. Tree is leaning to the side and back. Position carrier to center wellhead with floor. Leveling carrier at report time 8/22/2003 100:00 - 05:00 5.00 MOVE RURD MOVE Leveled up carrier sub, mated up the pit module & pipe shed to carrier sub. 05:00 - 07:30 2.50 MOVE RURD MOVE Raised & scoped derrick up. 07:30 - 08:30 1.00 WELCTL SFTY DECOMP Accepted Rig @ 07:30 and held a pre-spud meeting. Evening Rig Crew, Tour Pusher, Cameron Rep, Halliburton Rep, Baker Rep, M-I Rep, Rig Supv's, Eng, & Safety attended Pre-Spud. 08:30 - 10:30 2.00 WELCTL NUND DECOMP Nipple down Tree and marked alignment before removal. 10:30 - 11:30 1.00 WELCTL NUND DECOMP Nippling Up BOP's, shutdown for pre-spud meeting. Day Crew, Tool Pusher, Cameron Rep, & Rig Supv attended meeting. 11:30- 16:00 4.50 WELCTL NUND DECOMP Continued nippling up BOP's 16:00 - 17:30 1.50 WELCTL BOPE DECOMP Started Loading the pipe shed w/275 joints of 3-1/2" L-80 tbg. rabbit the first row 2.91 ". Function tested BOP. 17:30 - 19:10 1.67= WELCTL BOPE DECOMP Pulled BPV and installed Test Plug in Hanger. Begin BOP Test. BOP Test witness waived by Jeff Jones AOGCC. Schlumberger staged E/L unit on location. 19:10 - 19:45 0.58 WELCTL BOPE DECOMP Found Packing glands on tubing hanger to be leaking bled pressure off and tightened packing glands. 19:45 - 23:00 3.25 WELCTL BOPE DECOMP Continue with BOP test. Test annular to 250/3500 psi. Test all other equipment to 250/4000 psi. Hold all tests for 5 min. Perform accumulator test. Blowdown choke and kill lines. LD test joint. Pull test plug. 23:00 - 00:00 1.00 FISH PULL DECOMP RU HES spooling unit on rig floor. PU 3-1/2" 8rd EUE landing joint. screw into hanger. BOLDS. 8/23/2003 00:00 - 00:30 0.50 FISH PULL DECOMP PU on landing joint. Pull up to 124K. Block weight=10K. Max pull of 114K on tubing with no movement. Work pipe to try and free up SBR. No success. Call out Schlumberger E-line crew for chemical cut. 00:30 - 01:00 0.50 FISH JAR DECOMP Pull up to 124K on weight indicator and set brake. Hold tension while crew ate lunch. 01:00 - 01:30 0.50 FISH JAR DECOMP 124K still on weight indicator. Continue to work pipe. 01:30 - 02:00 0.50 FISH PULL DECOMP Pipe came free and started pulling at 75K. Pull hanger past floor. LD hanger and pup joint. Fill stack with brine. Small flow out of tubing. 02:00 - 04:00 2.00 WELCTL ClRC DECOMP RU to reverse circulate. Close annular preventer. Pump 110 bbls at 2.7 bpm. 9.5# brine in. 9.5# brine out. Small amount of solids in returns. Close TIW valve. Open annular preventer. No flow. Mix up 9.8+# dry job. Pump 15 bbl dry job at 1.3 bpm. 04:00 - 04:30 0.50 FISH PULL DECOMP Tubing on a vacuum. Check well for flow. No flow. Pull 1 joint and 1 space out pup. Brine began to burp out of tubing. May have gotten air in tubing during dry job. Still no flow on annulus. 04:30- 06:30 2.00 WELCTI. CIRC DECOMP RU to reverse circulate. Close annular preventer. Pump surface to surface circulation 280 bbls. Printed: 9/5/2003 10:32:27AM ConocoPhillips Alaska Page 2 of 4 Operations Summa Report Legal Well Name: 2U-02 Common Well Name: 2U-02 Spud Date: 2/6/1985 Event Name: WORKOVER/RECOMP Start: 8/21/2003 End: 8/25/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 8/25/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From - To Hours Code Code 8/23/2003 06:30 - 07:00 0.50 WELCTL OBSV DECOMP Open up tubing. No flow. Open annular and observe well. No flow. 07:00 - 11:00 4.00 FISH PULL DECOMP Pull and lay down 3-1/2" J-55 8rd tubing. NORM test tubulars as pull out of hole. Spool up control line and recover bands as tubing is being removed from the well. Tubing was dragging and jerky intially (5-15K overpull) while pulling out and seemed to smooth out some as pipe was removed, but is still jerky. Notified AOGCC (Jeff Jones) at 1000 of upcoming BOP test after packoff change. 11:00 - 13:00 2.00 FISH PULL DECOMP Layed down 56 joints of 3-1/2" J-55 8rd tubing, all looks to be in good shape. SSSV @ the rig floor. All control line came back intact. Recovered 32 SS bands(there were 35 installed in 1992). 3 SS bands left in the hole. Control line had residual pressure in it that had to be bled off, did this and layed down SSSV. RD HES spooling unit and remove from floor. 13:00 - 14:45 1.75 WELLSR PLGM DECOMP Pick-up Baker Storm Packer and tied on to the tubing string. 55K up weight. 14:45 - 15:30 0.75 WELLSR PLGM DECOMP Lowered Storm Packer back into well and set @ 14'. Layed down setting tool. 15:30 - 16:15 0.75 WELLSR DEQT DECOMP . Pressure Test above Storm Packer to 1000 psi for 15 mins. Held Good. Bleed down pressure and evacuate the stack. 16:15 - 17:15 1.00 WELCTL NUND DECOMP ND BOP and Tubinghead. Packoffs inside bottom of tubinghead are in good shape. 17:15 - 17:45 0.50 WELCTL NUND DECOMP CA gauge was reading 0 psi but upon removal had a slight positive pressure. Opened CA to bleed hose and allowed to depressure. 17:45 - 19:30 1.75 WELLSR EQRP DECOMP Back out LDS to change PO's. LDS are tight. Able to back out all LDS. Pull Braidenhead packoffs on 7" casing. Casing stub looks to be in good shape. No apparent problems with packoffs. Replace Braidenhead packoffs. PU new tubing head and set on Braidenhead flange. PU BOP stack and set down on tubing head. NU Tubing head. Begin NU BOP stack 19:30 - 19:45 0.251 WELLSF~ DEQT DECOMP Pressure test casing packoffs to 3000 psi. Held good. 19:45 - 21:30 1.75 WELCTL NUND DECOMP NU BOP stack. MU choke and kill lines. 21:30 - 22:30 1.00 WELCTL BOPE DECOMP Set test plug in tubing head. PU setting tool above blinds. Close blind rams. PT kill line, choke line, and blind rams to 250 psi and 4000 psi. BOP test witness waived by Jeff Jones AOGCC. Bleed off pressure. Blow down choke and kill lines. Pull test plug. 22:30 - 23:45 1.25 WELLSF PLGM DECOMP MU TIW valve on 1 jt of 3-1/2" tubing. Close TIW valve. PU retrieving tool for storm packer and MU to joint. RIH and engage storm packer. Open up equalizing valve. Open TIW valve. No pressure. Release storm packer and POOH. LD storm packer assembly. 23:45 - 00:00 0.25 WELCTL OBSV DECOMP Monitor well for flow. Well is static. 8/24/2003 00:00 - 04:30 4.50 FISH PULL DECOMP Continue pulling and laying down tubing. Tubing in good shape. Internal coating still present and in good shape. No visible sign of a leak around GLM #2. 04:30- 05:00 0.50 FISH PULL DECOMP Unload old pipe out of pipe shed. 05:00 - 07:00 2.00 FISH PULL DECOMP Continue to pull tubing. Found 2 holes in 2nd jt below GLM #3 (5' up from pin end). Scale along 1 side of 2nd, 3rd, and 4th jts below GLM #3. Severe corrosion and pitting on collars on 3rd, 4th, and 5th jts below GLM #3. 07:00 - 12:00 5.00 FISH PULL DECOMP Continue to pull tubing. 253 joints removed from well. SBR at surface looks good. Minimal scale and corrosion seen. Will continue per well plan to run back with the completion. 12:00 - 13:30 1.50 FISH PULL DECOMP Unload old tubing from pipe shed and prep to run the completion. Halliburton hand ground seals out of the SBR and prepped for re-run. Printed: 9/5/2003 10:32:27AM ConocoPhillips Alaska Page 3 of 4 Operations Summa Report Legal Well Name: 2U-02 Common Well Name: 2U-02 Spud Date: 2/6/1985 Event Name: WORKOVER/RECOMP Start: 8/21/2003 End: 8/25/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 8/25/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From - To Hours Code Code 18/24/2003 13:30 - 14:30 1.00 CMPLTN PULD CMPLTN Strapped and Drifted completion equipment. Found the pup joint on top of the 2.875" nipple to be undersized. Had another nipple brought out. (No downtime since 2.875" nipple will be run at +/- 500') 14:30 - 15:00 0.50 CMPLTN PULD CMPLTN Make up SBR and 2.813" nipple assembly (6' pups above and below nipple) on floor. Verify that Lock w/RHC plug is installed in the nipple. 15:00 - 15:30 0.50 CMPLTI~ SFTY CMPLTN Held pre-job safety meeting to go over running the completion. 15:30 - 22:00 6.50 CMPLTI~ RUNT CMPLTN MU Ijt 3-1/2" 8rd EUE AB-Mod tbg. Picked up Baker FHL & 80-40 PBR (40000# shear), ljt 3-1/2" tbg and KBUG w/SOV installed. Make up in completion string. Started running 3-1/2" 8rd EUE AB-Mod tubing and jewelry in the hole. 156 jts and 6 GLM assemblies run. 22:00 - 00:00 2.00 CMPLTI~.OTHR CMPL.rN Discovered hydraulic oil leak on lay down machine. Approx 1/2 gal of hydraulic oil spilled on pad. Report spill to Security. Clean up spill and fix leak on hydraulic hose fitting. 8/25/2003 00:00 - 05:30 5.50 CMPLTI~ RUNT CMPLTN Continue to RIH w/tubing and jewelry. Drag increased as SBR barrel went over slick stick at 7939' RKB. Continue in hole 7' and tag top of slickstick inside SBR. Brine came out of tubing last 2' indicating seals are over the slickstick and they seal somewhat. Set down 10K to confirm tag. PU above slickstick. Start pumping brine. Lower tbg down. Pressure increased to 1000 psi as seals went over slickstick. SD pump. Pressure bled off past seals. Continue down and tag up at same spot. PU above slickstick. 05:30 - 06:30 1.00 CMPLTI~ CIRC CMPLTN Pump 10 bbls 9.6# brine with 5 gal corrosion inhibitor down tubing. Displace with 66 bbls 9.6# brine. 3 bbls in tubing 7 bbls in annulus. 06:30 - 07:45 1.25 CMPLTI~ PCKR CMPLTN PU to next collar. Break out joint. Drop ball and rod. MU joint. RIH and go over slickstick. 'rag down. PU to neutral weight and PU 1' more. Wait for ball and rod to drop. 07:45 - 08:10 0.42 CMPLT~ PCKR CMPLTN Pumped up against ball & rod to 2500 psi. Saw pump pressure and weight indicator fluctuate as packer set. Allow 15 minutes for packer element to conform to the casing. 08:10 - 08:30 0.33 CMPLTI~ PCKR CMPLTN Bleed back pressure on the tubing to 1500 psi. Pipe weight @ 65K, pulled 80K and sheared out PBR. Bled tubing pressure down to 0 psi. Spaced out PBR 2' off of bottoming out. 65K Up weight and 42K down weight. 08:30 - 09:00 0.50 CMPLTI~ SOHO CMPLTN Mark pipe for space out. Fluid U-tubing, waited a few minutes and it did not seem to get any better. It had U-tubed app: 5 bbls. Weighted up 5 bbls of fluid and pumped a dry job. 09:00 - 10:20 1.33 CMPLTI~ SOHO CMPLTN Continued with space out. Re-drifted hanger to 2.91". Drained the BOP stack. Landed Hanger and RILDS. 10:20 - 11:10 0.83 CMPLTr~ DEQT CMPLTN Pressure up on the tubing against the ball and rod to 2500 psi and monitored for 15 minutes (holding good). Bled back the tubing pressure to 1500 psi. 11:10 - 11:35 0.42 CMPLTk DEQT CMPLTN Pressure up on Csg to 2500 psi, the tubing pressure rose to 2100 psi due to expansion. Monitor and chart pressure for 15 minutes (holding good). Bled pressure on tubing down to 0 psi. The DCK SOV did not shear. 11:35 - 12:00 0.42 CMPLTI~ DEQT CMPLTN With the tubing pressure at 0 psi and shut in, pressured up on the Csg to 2750 psi. DCK SOV sheared. Tubing and Csg equalized, bled both to 0 psi. 12:00 - 14:00 2.00 CMPLTi~ NUND CMPLTN Layed down the landing joint and installed BPV in the Hanger. 14:00 - 16:00 2.00 CMPLTN NUND CMPLTN Nipple down the BOP's. Emptied and Washed out Pits. 16:00 - 18:30 2.50 CMPLTN NUND CMPLTN Nipple up Tree. Pull BPV. 18:30 - 19:00 0.50 CMPLTN SEQT CMPLTN Installed 2-way test plug. Test Pack-off to 5000 psi and test Tree to 5000 psi. Pull test plug. Printed: 9/5/2003 10:32:27 AM ConocoPhillips Alaska Page 4 of 4 Operations Summary Report Legal Well Name: 2U-02 Common Well Name: 2U-02 Spud Date: 2/6/1985 Event Name: WORKOVER/RECOMP Start: 8/21/2003 End: 8/25/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 8/25/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Code Code 8/25/2003 19:00- 19:30 0.50 WELLSR PLGM CMPLTN SITP=0 psi. SICP=0 psi. SI outer annulus pressure=200 psi. Set BPV. Release rig at 1930. Printed: 9/5/2003 10:32:27 AM S0S (8238-8239, OD:3.500) Perf (8286-8299) Perf ConocoPhillips Alaska, Inc. KRU 2U-02 ~ 2U-02 APl: 500292126800 SSSV Type: NIP Annular Fluid: Reference Log: Last Tag: Last Taxi Date: 32.3' to TBG head 8330 12/25/2002 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING ,Tubing String- TUBING Size I Top 3.5O0 0 3,500 7939 peHOrations Summary Interval TVD 8060-8062 5773-5774 8100-8147 5800-5832 8150-8154 5834-5836 8159-8165 5840-5844 8286-8299 5927-5935 8308-8363 5942-5979 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: Size I Top 16.000 I 0 9.625 I 0 7.o00 I o PROD 2/14/1985 8/25/2003 1698 ftkB 52 deg(~6300 Bottom TVD 105 105 3955 3081 Angle (~ TS: Angle @ TD: Rev Reason: Last Update: 8564 6118 47 deg@8099 46 deg@8698 WORKOVER, GLV design, pull ball/rod 9/1/2003 Wt Grade 62.5O H-40 36.00 J-55 26.00 J-55 Bottom I TVD Wt Grade I Thread 7939 I 5691 9.30 L-80 I EUE8rdABMOD 8240 5895 9.30 J-55 I EUE8rd Thread Zone Status Ft SPF Date I Type I Comment I c 121013/31/19851 Sqz I UNIT B I I 4 I 12 I 4/3/1985 I IPERF IBakerTOPF UNITB I I ~ I 12 1 4/3/1985 I IPERF ]BakerTCPF A~ I I 13 I 4 14/3/1985[ IPERF IBakerTCPF A-3 I I 55 I 4 I 4/3/1985 I IPERF IBakerTCPF Interval I Date Type 8060-8062I 3/31/1985 Cement Comment Gas Lift Mandrels/Valves St, MD IT"DI ManI Man VMfr IVType VODILatchl Port ITRO Date Vlv I I IMfr I Type I I I I I I I Run I Cmnt 1 I 30621 2"931CAMCOI KBUG I I GLV I 1.0 I BK-5 10.156 1126618/31/20031 2 145791 3,.961CAMCOI KBUG I I GLV I 1.0 I BE-5 10.18811301 18/31/20031 3 152841 3"7110AMCOI KBUG I I OV I 1.0 I BE-5 10.2501 0 18/31/20031 416398l 4I'101CAMCOI KBUG I I DMY I 1.0 I BK-5 10.0001 0 18/31/2003I 5172261 5,:291CAMCOI KBUGI I DMY I 1.0 I BK-5 I0,0001 0 18/31/2003I 6178081 5,;041CAMCOI KBUG I I DMY I 1.0 I BK 10.0001 0 18/31/2003I Other (pluBs~ equip, etc,] - JEWELRY. Depth ITVD I Type Description ID 522 / 522 I NIP CAMCO 2.875'DS' NIPPLE set 8/25/2003 2.875 7858 /5638 I LOCATOR BAKER LOCATOR SUB set8/25/2003 2.992 7860 15639 I PBR BAKER 80-40 PBR set 8/25/2003 2.992 7874 15648 I PACKER BAKER FHL PACKER set 8/25/2003 2.910 7923 15681 I NIP CAMCO NO GO NIPPLE W/2.813" DS set 8/25/2003 2.813 7930 15685 I SBR OTIS SBR BARREL set 8/25/2003 5,000 7938 15691 I SBR Otis SLICK STICK 2,810 7949 15698 I PKR Otis'RRH' 2.970 8214 /5877 I PKR Otis 'WD' 4.000 8230 15888 ~ NIP Camco 'D' Nipple NO GO 2.750 8238 158941 SOS Otis 2.992 8239 15894 ~ WLEG Otis Wireline Re-Entry Guide 2.950 8240 158951 TTL 2.992 ;G~netal::Notes::: :, :;:;: ::; ::;;::;;:::;::;:: :::;::;: : ~;, :: ~ ;::;;::; ';: Date I Note 8/25/2003 TREE: McEvoy Gen III 3 1/8" 5000 psi TREE CAP CONNECT ON: Ots MEMORANDUM TO: Julie Huesser, Commissioner ' State of Alaska Alaska Oil and Gas Conservati°n commisSion · · ~' · DATE: December.2,-2000 THRU: Tom Maunder, P. I. Supervisor. FROM: SUBJECT: Chuck Scheve;, Petroleum Inspector Safety Valve Tests Kuparuk River Unit. 2U Pad ~ Saturday, December 2, 2000:1 traveled to the KuParuk River Field and witnessed the semi annual safety valve system testing on 2U Pad. - , As the attached AoGCc Safety Valve System Test RepOrt indicates I Witnessed the' testing of 11 Wells and'22 components with three failureS observed. The IOw pressure pilots on wells 2U-5, 2U-14 and 2U'16 triPped well below the required set point. These three pilotS Were adjusted and retested at the. time of this test. In addition to the three failed pilotS ·several other pilots tripped very near the minimum pressure, these were reset and operated-properly When retested. . ' The 13.6% failure rate will require a retest of this Pads Safety valve System in 90 days rather than the nOrmal ./1~_0. day cycle. Earnie Barndt conducted the testing today he demonstrated goOd test Procedure and was a pleasure to work with - - - . I witnessed the semi annUal SVS testing at 2U Pad in the KuparUk : Summary: River Field. KRU 2U Pad, 11 wells, 22 compo'nent~, 3 failures 13.6% failure rate Attachment: SVS KRU 2U Pad 12-2-00 CS confidential (Unclassified if d°c~ Removed) X Unclassified SVS KP.U 2U Pad 12-2-00 CS dOc Alaska Oil and Gas ConserVatiOn CommiSsion Safety Valve SYstem Test Report Operator: Phillips Operator Rep: Emie Bamdt AOGCC Rep: Chuck Scheve.. Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk/KRU / 2U Pad Separator psi: LPS 96 HPS 12/2/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code PasSed GAS or 2U-01 1850040 96~ 70 50 P P ' OIL 2U-02 1850050 96 70 60 P P OIL 2U-03 1850060 2U-04 1850070 i 2U-05 1850180 3700 2000 . 500 3 P 12/2/00 _ WAG 2U-06 1850190 96 70 50 P P OIL 2U-07A 1850910 2U-08 1850210 96 70 50 P P - OIL 2U-09 1850380 2U-10 1850390 961 70 60 'P ~ P - OIL 2U-11 1850400 2U-12 1850410 96i 70 55 P P ~ OIL . 2U-13 1842460 96 70 50 P P OIL 2U-14 1842470 3700! 2000 0 1 P 12/2/00 WAG 2U-15 1842480 96! 70 60 P P · . OIL 2U-16 1842490 3700 2000 100 3 P ' 12/2/00 : WAG · Wells: 11 Components: 22 FailUres: .3 Failure Rate: ' · 13.6%[59o Remarks: Three failed pilots repaired and retested Pad on 90 day test cycle : 12/4/00 Page 1 of 1 SVS KRu 2U Pad 12.2-00 CS,xls Memory Multi-Finger Caliper Log Results Summary Company: ARCO Alaska, Inc. Well: 2U-02 Log Date: April 24, 2000 Field: KUPARAK Log No.: 4071 State: Alaska Run No.: 1 APl No.: 50-029-21268-00 Pipe Desc.: 3.5" 9.3 lb. J-55 EUE Top Log Intvl: Surface Pipe Use: Tubing Bot. Log Intvl: 8240 Ft. (MD) Inspection Type' Obstruction Evaluation COMMENTS · This survey was run to assess the condition of the tubing with respect to restriction evaluation. The caliper recordings indicate that buckling in the ranges from moderate to severe exist through out the logged interval. The buckling first appears moderate beginning at 3,900' increasing to severe from 6,450' to 7,380'. The buckling at 6452', 6608', 7048', and 7380' all appear to be so severe that the tubing may have been deformed in respect to ovality. Cross sections of these areas are included in the report. Scattered light deposits were recorded but no indication of substantial scale build-up was indicated. No penetrations were recorded in the logged interval in excess of 15%. The tubing appears to be in good condition in respect to corrosive damage. MAXIMUM RECORDED WALL PENETRATIONS · No significant penetrations (in excess of 15%) were recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No area of significant cross-sectional wall loss (in excess of 10%) was recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS · No area of significant ID restriction (in excess of 0.10 in.) was recorded throughout the interval logged as a result of scale deposits. The following restrictions appear to be the result of ovality changes. 6452.04' 2.80 in. 206 Ovality change. 6607.90' 2.79 in. 211 Ovality change. 7048.83' 2.81 in. 225 Ovality change. 7380.20' 2.83 in. 236 Ovality change. ]Field Engineer' R. Liddelow Analyst: S. Adcock Witness: Keith Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ?DS Caliper Overview Body Region Analysis Well: 2U 02 SulYey Date: APRI[ 24, 2000 Field: KUPARAK Toot fype: MFC24 812 Company: ARCO ALASKA, [NC. Tool Size: 1 11/16" ins Country: USA No. of Fingers: 24 Analysed: Steve Adcock Tubing: Size Weight Grade & Thread Nora. OD Nora. ID Nom. Upset 53.5 ins 9.3 ppf EUE 8RD L5 ins 2.992 ins 3.756 ins Penelrafion and Melal Loss (% wall) penetration body ~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to above 1% 10% 20% 40% 85% 8594, Number of joints analysed (total: 267) Pene 70 179 18 0 0 loss 248 19 0 0 0 Damage Configuration ( body ) 10[ 0 Number of joints damaged (total = 7) 5 2 0 0 0 Damage ProfiJe (",4,, wall) penetration body ~ metal loss body 0 50 0 49 GLM 11 96 GLM I0 145 GLM 9 GLM 8 193 GIM 7 GLM 6 GLM 5 240 GLM 1 Bottom of Survey = 256 100 Analysis Overview page 2 Pipe: ~.~ ins 9.] ppf EUE 8RD Well: 2U4)2 qombml iD: 2992 ins ( omp my: ARCO Al ASK,% COLlrl~ry; U SA Date: APRIl 2¢, 2000 ]c}~ht Penemdkm tvte~Jd i Projection /Vfinin~um i Damage profile .00 inches i inches inches 0 2.90 ~ PUP Shallow pitting. .00 0i 0 0 0 0 o i o o % o l .00 6 0 7 0 8 0 0 9 0 0 !3 0 14 0 .0 I 15 0 .00 >7 ' (7) 2r~! o 29 i 0 ~o i o 3 ~ i 0 2.96 ! PUP 288 2.90 35 o 36 0 37' 0 40 0 43 0 o I o [ .od, l 28~) o l o o L o [ o [ ~:i 2.88 .06l 2.89 .06! 2.90 2.87 2.;39 287 o i o6i 0 i 06' 288 0 j l) 289 290 2 89 289 2.;39 2.91 2;39 29 I 2.;37 2.$6 2.;38 288 28;3 07] 287 289 02 1 j 0 ,-i ..... .05i, 2.90 d o o I (}(,i 288 .01 [ ~ o 0 [ 05i o i )6 0 [ 03i o[ q o o [ .o7i o d o o :u .o61 ~ o j o i .01[ ZJ 0 0 i .07 o o [ lO7 .00 I~ 21 ) 0 00i .02 ~! , i 0 ,061 02 ~J! 2 ~ q 0 I -) [ / 6 28q .02 i 7! 0 h .o¢~ I .oeq 2.;3~; o~[ ~j o h o i .osi 289 288[ Pipe Tabulatio!~s page penetration body metal loss body RECEIVED Iv~AY 1 2 RO0(} (% wall) 50 100 c ER IO XT T^BUL, mO, Pipe: 3.5 ins 9.3 ppt EUE 8RD Wall ~hi(kness. Body: 0.254ins Upset - 0.382ins Nominal ID: !992 ins Metali Proj~!ction loss ~Upsel iBody % [illches inches Well: Field: ( onlparw: Country: Date: Miifimum [ ID Commen nches 2U~)2 KUPARAK ARC() Al ASKA, IN(. t/SA APRIl 24, 2000 0 2.89 2.87 2.88 60 0 .06 0 0 PUP SSSV 2.89 2.88 2,88 2.85 GLM (Latch ~ 5:30) 78 89 I 92 ~ 0 0 0 0 h o i o J .O2 .O2 .00 .02 0 07 0 .00 0 0 0 0 0 0 0 0 0 0 1 0 1 0 0 2 .05 .081 0 0 0 0 0 0 0 0 08 I 0 2.88 2.87 2.85 Pipe labulations page 2 penetration body metal loss body Damage orofiie 50 i O0 Ancho~'ag8 ?DS C~ER IOINT TABULATION S Pipe: 3.5 ir~s 9.3 ppf EUE 8RD Welt: 2U~32 Wall thi(kness. Body: 0.254ins Upset = 0.382ins Field: KUPARAK Nominal ID: 2.992 ins Company: ARCO ALASKA, INC. 112 i 0 0 129 [ 0 ~30 [ 0 CotIrltw: USA Date: APRIL 24, 2000 ection ] Minimuml Body I ID [ Commen~s inches] inches [ Shallow pitti~_..2~ .05 2.90 ] 2.89 I Shallow 0 .07 0 0 0 .06L 2.89 4 0 .08[ 2.87 .08[ 2.84 0 0 .o8[ .131 2.84 2.85 Shallow corrosion. Gl M (Latch @ 8:30) 2.74 ~ 09 i 2.83 0 .~. 0 0 i 08[ 2.85[ 2.88 Pipe Tabulations page 3 penetration body metal loss body Damage profile (% wall) 50 1 O0 ?DS CQ ER JO!NT TABULATION Pipe: 3.5 ins 9.3 ppf EUE 8RD Well: 2U~02 Wall thickness. Body: 0,254ins Upset = 0.382ins Field: I<UPARAK Nominal ID: 2.992 ins Company: ARCO Al ASKA, INC. Countw: USA Date; APRIL 24, 2000 Pro ection Upset Body o i 162 0 163 0 t67 0 o o i .00 .02 .07i o ~ o I .o~ 0 .01 .02 0 0 .00 0 .05 .O9[ 2.87 2.85 GLM j_Ls~tch @ 2:3~ 2.82 penetration body metal loss body Damage profile (% wa 50 100 Pipe Tabulations })age 4 ?DS C~ ER IOINT TABULAT!ON $~T Pipe: 3.5 ins 9.3 ppf EUE 8RD Well: 2U~32 WaJ} thickness. Body 0.2~4ins Upset = 0.382]ns Fid& KUP/~RAK Nominal ID: 2.992 ins Company: ARCO ALASKA, INC. Joint Penetration No. Upset Body inches [inches % 193 0 ! .01 5 u~s $_.o I .00[ 2 797 [ 0 ] .02 I 9 199 J 0 ] .00 ~ 2 o j 201 0 .00 [ 2 toss ]Upset % I inches 0 ] 0 0 0 Country: [)ale: ction Body [ ID Comments Itlches inches .07 2.87 .071 2.87I .061 2.88[ .o9J 2.877 .071 2.88[ ...... 2.86 ' 2.87 [ USA APRIL 24, 2000 2.89! 2.79 I GtM(latch@9:00) 2.86 2.83 Latch @ 8:30) 2.85 penetration body metal toss body Shallow corrosion. Deposits. Damage profile (% wa ) 50 100 g~AY 1 ~ SOO© ?DS C~ ER IOINT TABU1.ATION S T Pipe: 3.5 ins 9.3 ppf EUE 8RD Wa[J thickness. Body: 0.2B4ins Upsel: l).382ins Nominal ID: 2.992 ins ection Body inches Well: 2U4)2 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 PACKI R GLM (Latch @ t 1:00) 2.87 2.80 I GLM (Latch @ 6:00) 2.83 ] Shallow corrosion. ?£j]osits. P U P PUP PACKER PUP XN PUP Damage Classifications Penetration / projection class, in order of damage severity ltote - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 60% of circumference, but depth range does not exceed 2 * pipe ID Line - clarnage depth range exceeds 4 * pipe ID, bnt extends less fl~an 30% of circumference Genera[ - damage depth range exceeds 2 * pipe ID and/or extends more than 30% of circumference Isolated - damage depth range does not exceed 4 * pipe ID or extend more than 30% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.305 feet. penetration body metal loss body Damage profile % wa ) 50 100 Pipe labulations page 6 Well: Field: Comparly: Country: 7ub~nB: 2U-02 KUPARAK ARCO ALASKA, INC. USA 3.5 ins 9.3~ EUE8RD PDS Caliper Sections Survey Date: APRIl 24, 2000 Tool Type: MFC24 812 Too[ Size; 1 11/16" iris No. of Fingers: 24 Anal),sed: Steve Adcock Cross section for }oint 206 at depth Tool speed = 61 Nominal ID = 2.992 Nonlinal OD = 3.500 Remaining wall area = 100 % Tool deviation = 67 ° 6452.01 ft Finger 13 Radius= 1.396 ins Ovatity Due To Bending Min. ID=2.80in. HIGH SIDE=UP Cross-Sectionspage 1 Well Field: Company: Country: 2U~02 KUPARAK ARCO ALASKA, INC, USA 3.5 ins 9.3~ EUE8RD PDS CaJiper Sections Survey Date: APRIL 24, 2000 Tool ~ype: MFC24 812 Tool Size: 1 11/16" ills No. of Fingers: 24 Anal~/sed: Steve Adcock Cross section for Joint 21 t Taol speed = 57 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 60 ° at depth 6607.9 ft Finger 13 Radius= 1.392 ins Ovality Due To Bending Min, JD=2.79in. HiGH SID=UP Cross-Sections page 2 Well: Field: Company: Couutry: Tubing: 2U-02 KUPARAK ARCO Al ASKA, INC. USA 3.5 ins 9.3 ppf EUESRD PDS Caliper Sections Survey Date: APRIL 24, 2000 Tool Type: MFC24 812 Fool Size: 1 11/16'~ ins No. of Fingers: 24 Analysed: Steve Adcock Cross section for Joint 225 at depth Tool speed = 66 Nomiual ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 45 ° 7049.83 ft Finger 13 Radius= l.394 ins Ovality Due To Bending Min. ID=2.81 in. HIGH SIDE=UP CrossGectionspage 3 Well: Field: Company: Country: 2U-02 KUPARAK ARCO ALASKA, INC, USA ~. EUE 8RD PDS Caliper Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Analysed: APRIL 24, 2000 MFC24 812 1 11/16" ins 24 Steve Adcocl~ Cross section for Joint 236 at depth Tool speed = 65 Nominal ID = 2,992 Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 56 ° 7380.2 ft Fingerl3 Radius= 1.392ins Ovality Due To Bending Min. tD=2.83in. HIGH SIDE=UP Cross-Sections page 4 W,-fii fifickness. Bc:,civ: ().v'::,~irm i.;nset: 0.382ins I I fcc[ f'ec'l inches i .... ' , .] , 3/.6 ] 4.2 . !tOrN.FIL!. PUD t / ] J I,Y~, J _$,U'I I/~_/l//ll/¢ll I ......... , ! .... I .? ........... 9 ¢-_b t? ......... i!..._¢.~ ....!] Pill! 0 %" .... j .._ F_up_ ...... i .-, "," c "~ ~ -'-'~ .... : .-. ~ I ~ O£).~ J _)0. I £.,t iOI I-III I ~:'ll t. 3i.50 nominalJ]-------'--t t 3 t .65 nominal ..,(,.~8 p, orru[-m[ 30.36 nnmina! 30.02 nominal '10 I 3'15.00 j 30.69 11 I 345.('.,9 30.43 r'K:m'tinal t '2 376.1 '2 3 'I .3 7 ............. , i 3 ,t07.49 30.99 nominal ] 4 ' "' .... '~ 3 lao.,lo _ 1... '1 nominal ~ 15 q69.79 31.5:4 nominaj i6 50!.33 30.62 nominal L._. ! ~ 5 ;:~. 'h }! 5 3 2..~N...J... n0.m! n 0! ......... ~ t 8 563.97 3t..)6 nominal i .,~ -~. i 20 626.61 30.76 nominal 21 6~7.37 3i .S3 rom M'~'~ 688.90 I _~ 1.0-a b' :24--~ 750.2_____~7 3 i. :3___.~ j 2:)" I 781.60 ~ 31.51 , i'iomJnal ................................ I % 8 ! 3. t I '~ '! .6'! nomir:a, ,~7 84,~..75 :.~0..'~ 7 i~,:,.~i~-;°! ' __::..~;.: ................................................... ;:i'c: I ....... .'+_..Z ............................. ?...O_.!Z::'_!.Z ................. ;!..!..:~! .............. !.).g~..4.!.~.:~! ....... ~ .................................... ')' C : ' C~ '~') r~, .- '. I ..,1 t .)69. i ......... , F-'-'i--2 .... I' ............ T -Z- L~'-'i--7' -I ............. Z~'i-" 2'i-""T ................. ' ...... : ...... i .......................... t ~'.' / Iii, Ill.24 I ..~(I.(~/ I nommat I I Y-'~.---Y-~~...., I ..... .-,~; 1 ....... i, i I ....... L.!:..... I~._'_'_~_~J ...... I ......................... 35 J !Ot:LS/23 28.~9 r~orr:ir~a! I I 36 1 t 23.62 ]~ ~n~.~[ ~---1 I.-----[ -=-- .... =-:"- --' -. 1 ! 40 I '!246.'I9 '-,',0.76 nomirwd I'-%-: ..... I ........... 'x::PP-z-P"'-i ............ ffL'::"-;i%'-'l ............... : ........ ; ...... t ........................ ['--'; ;; ............ ~ :;';~'i;' ';::,'Z 't ......... :;'; "7,:'2'"- i'" 21 ] '"' · '"'"" .... t ......"-"~ · t'~'"',t~'~t t 44 t 136c,'.40 i ']0.77 I rmrr~inai t ! ............... : .............................. :'7-:'-T¥'"" I ............. :'7-:':'--~r ........ 7¥~-'"7 ......... l ............................ I 4(:, J ~.,i.':,r~ ~u'; I :',(') ~"> [ ,m--;r~fir;;:[' l ~' i r,.-~, ~,;, .:, [ ,"~7 146! ~':' I 3-~ ':z'~ -t- ..... ~'~""~:"!t -- ' '---s- ...... t. ' .... -- ....... -i..:L=.O3 I 32.03 t .nominal I I ,:it~ I 'l.'Cv . 3 1.75 3 '!. 19 nam, ina[ '28.3 i nomina! 30.9i .nominal -' I '-' '''~ ,n,:;.,,nfii~al . ,~ ...; IL; t .9.91 n<':,n'final ',--~ ....... J 57 I '! 770.95 3'i.04 nornirm[ L._~.5_,I:.~_[ ~807.90 9.70 'nominal i Sssv 59 't 847.81 .3 't .29 nominal .... ~..._.~ ',87tL'lO 3t.50 r,ominal ~'"~ I ~-).~Iz.'~9 so.,18 n°minal 63 ' 1972.67 31.03 nominal ~--67 2(:~] 5.59 29.6;' I nominal I %1, 2'64 ;2' h' 67.'t~ ~'[25.87 ~.47 t~omfnai ~ GIm'l p._69 .... j 2! G,-t75 31.79 ,x.,,nh,al ,v -~ -"~ ( ~' c ') ] '~ ~ "'1 'T :" "' I / I ZZZI.)t 51.J .)/ I I ........ .~.~.e:.::~.~ .............. .:~s:2..L_,__./:~2E~LL)9.~_ ........ ~ .............................. _~] .... 24. f2.72 t 3 t.28 m'm'~irmf j ,7°~ ,.'~ 444 00 3,n 5',' m') mirm ~' ' .... ::-~----[ .......... ~"Tr'":'::f-'-J' ......... :7":":-:1-7'-'-'"'~ ............... :---7'--J I o-~ t '",~:,o -~ .> I [35 I Z,)JLI,,).] I ,.5 I.~U rtOl'l'lll'll]l I ~" ~ m~:n''~*'l~ 3~.t7 nominal I o6 , ...... '"' i * I o -;~ , ) v, ) '..~ ,.~ ~ -~ l ~ ,'- ' i ' 71o Z' '}~.DO/ 5 .3 "}OtY 'N-t 1 i ............................... Z_:.: ................................ : ........ :...=: .................... = .............. = ........ , ........................ .................... ~ ............ ~ .............................. r .............................. 1 ................................ ~ ........................ ~ ,:~ '~a{-~ 701 i ........... ~--.-I ........ z= ........ rz_...q ........ ::~'~z'--t'"~"~:=" "~-' ~:--d ............... I ~)5 J ~0.'1~ j 30.64 t r~ominat t RECEiV[D It, lAy t 2 ' 000 Arm,',o~aga FL.'~ "* '" ~PF2 i(3,1b-JT TAi I y 'qHFF Pipe: 3.5 ins 9.3 ppf k',..ii:: 8RD Wall thickness. ,., ,.., ,_,. . 0.254ins ' ~-, " . ,,use, = 0.382ins ............. IL.'. ..... .~ ,,,.. Jnin! l-)eplh ! length I Mo¢.sured No. ] I ID feet feet inches 96 3000.76 I 31.47 j nominal on~n n~ '~n 9~ nominal .~ b' ~ z... ~. _,1 ~' ,../. _ '1- -9'~' 3062.17 31.94 nominal 99 3094. I1 30.69 nominal 1 O0 3124.80 31..41 nominal I 01 3156.'2 t 31.93 nominal 102 3 'I 88.'I 4 29.14 nominal 103 3217.28 31.13 nominal 105 3277.97 31.35 nominal 106 3309.32 31.22 nominal 107 3340.54 31.58 ~ominal 108 3372.i 2 30.71 nominal -109 3402.83 3126 nominal 110 3434.09 3'I .04 nominal 111 3465.13 30.96 nominal 113 3525.'I 4 31.15 nominal 115 3 a87..):, 31.12 nominal I 'I 6 3618.65 30.02 nominal 1 t 7 3648.67 32.38 nominal '1 't 8 3681.05 30,67 nominal 119 3711.72 31.61 nominal 120 3743.33 30.83 nominal 12 t 3774.16 30.73 nominal 122 3804.89 32.11 nominal ................................................................................................................................................................. 123 3837.00 27.41 nominal 124 3864.41 30.72 nominal !.~5. ~.~.? ~:.!. e ................ 2_.L.e.2 ............ u.2,_d~,.~J,. ........ i ............................. I26 3926.79 ! 29.25 nominal ] 128 ~ 3988.78 I 29.49 , nomh'~a! "'1' 29,'t ' 4048.57 5,.fi9 nominal Giro2 '130 j 4054.26 3'1.58 nominal 1" 9 '~ 1 ' Q ' 'I ')" ' ( ' "~ I' i,.3~ ~ ~,, i,A), I .:,f.4~)I no,l~, ~i '''~''~'" I' ,'.,:1-.~.~,~ I ~0 .... 4i / :).07 3 t.76 non, ina! I '135 ,12'I '1.63 30.33 nominal 42 9 .......... ..... ................. [138 t 4303.99 ............. .g.~.,.g..~ ............... t40 I 4363.77 _3i.30 ~.-5--41":i'"2:i ........... ' ............... _=~__5.2'~;:~-'~5'5 ..................... -"'=~::'::i ....... ................. \'V l:ie!d: ( Country': ] joint No. 145 146 147 148 -- 149 -- 150 -- 15t 152 'I 7f~, 2U O2 KL, I ,-,RA,,, , , ~,% ~., ,'.,%, USA l-)eplh feet I englh feel Moae. t red ID inches Tyl)e 4519.13 29.87 nominal 4549.00 '~ ~ nn nominal 4581.09 30.'18 nominal I 4611.27 3 '1.98 aominal 4643.25 3 ~.00 nominal -- 4674.25 31.05 nominal -- 4705.30 30.86 nominal 4736.16 30.19 nominal 4766.35 30.90 nominal 4797.25 30.5'1 nominal 4827.76 30.86 norninal 4858.62 4890.18 31.65 nomi~al 492 '1.u..,° ,~ 31.62 nominal 4953.45 31.07 nominal 4984.52 30.96 nominal 50't 5.48 3 't .22 nominal 50,46.7() 30.02 nominal 5076.72 32.28 nominal 5109.00 32.45 nombat 5t 41.45 30.32 nolitinal 5171.77 30.69 nominal 5202.46 3 t.'l 7 nomina 5233.63 31,48 nc)minal 5265.11 6.94 nominal 5272.05 30.72 nominal 5302.77 .31.36 nominal 5334. '13 30.92 norninat ..~ao.xu:~ 31.90 norninal 5396.95 3 ! .08 5428 03 .-~o ~"~. nominal ..... z_ _,,./ ~ 5,457.75 ;' ° ~ t .4,.., nominal 4on 9-~ -~ w,.,-, .... , ,~0., 5 non'~inal 5519,68 29 65 rmminal 5549.33 31,68 nominal 558'1.0'1 3'~ .90 nominal 56 '[ 2.9 t 3 (t. 70 n O I nit ~ al :~o,..,.~,~ 31.~... nominal 5704.72 3 ~ .88 nominal 5736.60 29.28 nominal } 186 } 5798.5'! 28.44. nomi.-.,a! I .]:.8.'...7., [ ...... ........ ~.~.~...6,, ['>.._5_ ........... .':3...~.'I...7.. ~, JLo..nmal [ . - ¢c E''O,/' It"'A / I-Q ,.~.,._. ' .. ti:?.) .,~.~,:..:,~- ~0..:,,:, ~.o,,~na! I 1'I 9t 5958,76 3C43 ~c,l'~i~ai [- RECEiVEI) 1 2 2000 PD.,I" 'AL!PER !N1N T TAllY Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0.254ins Upset = 0.382ins Nam[ha! ID: 2.992 ins Join I. Depth I.ength Measured Type No. ID feet feet inches 193 6018.94 30.42 nominal 194 6049.36 29.42 nominal 195 6078.78 32.94 nominal 196 6111.72 30.37 nominal 197 6142.09 30.95 nominal 198 6173.04 30.78 nominal 199 6203.82 30.29 nominal 200 6234.11 31.47 nominal 201 6265.58 32.12 nominal 202 6297.70 30.01 nominal 203 6327.7'1 31.39 nominal 203.1 6359.10 6.83 nominal Giro5 204 6365.93 30.50 nominal 205 6396.43 32.05 nominal '2-0--6-- -- 6428.48 31.18 norninal 207 6459.66 30.98 nominal 208 6490.64 30.59 nominal 209 6521.23 31.65 nominal 210 6552.88 31.45 nominal 2'! t 6584.33 31.06 nominal 212 6615.39 31.38 nominal 2"[ 3 664.6.77 28.75 nominal 214 6675.52 30.62 nominal 215 6706.14 31.6I nominal 216 6737.75 30.28 nominal 217 6768.03 32,58 nominal 218 6800.6'I 30.93 nominal 218.1 6831.54 7.20 nominal Giro6 2'i 9 6838.74 31.20 nominal 220 6869.94 29.80 nominal 221 6899.74 31.78 nominal 222 6931.52 31.23 nominal 223 6962.75 30.70 nominal 224 6993.45 30.10 nominal 225 7023.55 31.35 nominal 226 7'054,90 31.77 nominal 227 7086.67 29.69 nominal 228 7'116.36 30.94 nominal 229 7147.30 31.69 nominal 230 7I 78.99 30.35 nominal 231 7209.34. 30.4.3 nominal 234.1 7333.83 5.29 nominal GIm7 .~35 4 7339.12 ,32.61 nominal 236 [ 7371.73 ,31.49 nominal ._~_37__] 7403,,22: ,31.98 nominal 238 ---~435.20 30.62 nominal 239~' - 7465.82 30.62 nominal Joint Depth Length Measured Type No. ID feet feet inches 240 7496.44 31.99 nominal 241 7528.43 30.99 nominal 242 7559.42 30.94 nominal 243 7590.36 29.92 nominal 244 7620.28 31.91 nominal 245 7652.19 31.56 nominal 246 7683.75 31.52 nominal 247 7715.27 31.03 nominal 248 7746.30 31.31 nominal 249 7777.61 31.55 nominal 250 7809.'16 30.82 nominal 251 7839.98 30,82 nominal 252 7870.80 29.49 nominal 252.1 7900.29 9.30 nominal Giro8 -- 253 7909.59 30.99 nominal 253.1 794,0.58 18.77 nominal Packer 254 7959.35 32.17 nominal 254.1 7991.52 9.36 nominal GIm9 255 8000.88 31.65 nominal 256 8032.53 27.89 nominal 256.1 8060.42 9.71 nominal Glml0 257 8070.'13 26.04 nominal 258 8096,17 30.57 nominal 259 8126.74 3t.10 nominal 260 8157.84 30.58 nominal 260.1 8188.42 4.85 nominal Pup 260.2 8193.27 6.76 nominal Glml 1 260.4i o210.% 9.95 nominal Packer 260.5 8220.88 8.68 nominal Pup 260.6 8229.56 1. [ 5 nominal Xn 260.7' 8230.71 unknown nominal Pup ,, .... --. R El) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed- Operation Shutdown __ Pull tubing x Alter casing Stimulate __ Plugging __ Perforate Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 517' FSL,1081' FWL, SEC 32, T12N, RgE, UM At top of productive interval 1337' FSL, 1474' FEL, SEC 5 , T11N, R9E, UM At effective depth 1089' FSL, 1339' FEL, SEC 5, TllN, R9E, UM At total depth 955' FSL, 1265' FEL, SEC 5, TllN, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8698' 6209' 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 105' 7. Unit or Property name Kuparuk River Unit 8. Well number 2U-02 9. Permit number/approval number ~"'~B"-05/ Conserv Order ~261 10. APl number 50-029-21268 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8486' true vertical 6063' feet Junk (measured) feet Casing Length Size Structural 8 0' 1 6" Conductor Sudace 3923' 9- 5/8" Intermediate Production 8 5 3 2' 7" Liner Perforation depth: measured Cemented Measured depth 230 SX CS II 105' 785 PF E 3955' & 875 SX PF C,50 SX PFC TOP JOB 350 SX CLASS G 8564' &250 SX PFC True vertical depth 105' 3081' 6118' 7560'-7566', 7578'-7602', 7619'-7658', 8100'-8147', 8150'-8154', 8159'-8165', 8286'-8299', 8308'-8363' MD true vertical 5441'-5445', 5433'-5468', 5479'-5505', 5800'-5832', 5834'-5836', 5840'-5844', 5927'-5935', 5942'-5979' TVD Tubing (size, grade, and measured depth) '3-1/2" 9.3# J-55 @ 8226' Packers and SSSV (type and measured depth) OTIS RETR PKR @ 7935' MD,OTIS WD PKR @8200' MD, CAMCO TRDP-1A SSSV @ 1793' J~D_ ,,~ _, · ~ r" r~ 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) J u L - ? 199 - Treatment description including volumes used and final pressure ~oo~.o ni~ ~ c.~.~ Cons, Co~tSS[0t~ Representative Daily Average Production or Injection 'l~'a"'t~. ........ A~h0ra_~e Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~Si~lne"~+7/~~~"~-~~,,-, ~-.(,~' Title Area Drillin~l Engineer Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE DAILY OPERATION~~' ARCO ALASKA INC. PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: 2U-02 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-21268 APPROVAL: 88-05 ACCEPT: 02/19/92 10:02 SPUD: RELEASE: 02/20/92 11:02 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 02/20/92 (1) TD: 0 PB: 8486 02/21/92 (2) TD: 0 PB: 8486 RU SLICKLINE MW:ll.8 NaCl/Br CONT MOVE RIG F/3Q-01 TO 2U-02,ACCEPT RIG AT 10:00 HRS 19-FEB-92,RU HARDLINE TO FLOW TANK AND PROD LINE,RU PUMP LINES TO TREE,OPEN SSSV, INSTALL LOCKOPEN CAP,RU SLICKLINE, TEST LUBR TO 1500 PSI,OK, RIH PULL DV F/GLM AT 7894',RIH SET CV W/O CHECK IN SAME, RD SLICKLINE,GEAR DRIVE ON PIT VALVE CRACKED,RERUN LINES TO DISPLACE INTO UPRIGHT TANK INSTEAD OF DN PROD LINE,CIRC 11.8 PPG BRINE, SET BPV, BLOW DN AND VAC OUT LINE TO TANK, HAUL CRUDE AND DIESEL TO 2Z RECYCLE,ND TREE,NU BOPE,TEST SAME TO 3000 PSI,OK, MU LANDING JT,BOLDS, PU TO ll5K#,SBR NOT SHEARED,RELEASE AND PU TO ll5K#,SBR SHEARED, PULL HGR TO FLOOR, CIRC, LD/REDRESS TBG HGR, LD 1 JT TBG, SPACE OUT PUPS,POH TO SSSV STD BK TBG, STRAP,DRIFT TALLY TBG, LD SSSV, RECOVERED 37 C-LINE BANDS,MU REDRESSED SSSV, TEST C-LINE TO 5K, OK, RBIH W/COMP STRING, TAG SLICK STICK W/SBR, SPACE OUT,MU REDRESSED HGR, TEST CLINE TO 5K, OK, LAND HGR, RILDS,RAN 35 SS C-LINE BANDS,69K# UP WT,38K# DN WT,RU SLICK LINE TO PULL CV RIG RELEASED MW:ll.8 NaCl/Br RU SLICKLINE, TEST LUBR TO 1500 PSI,OK, RIH/PULL DV F/BTM GLM @ 7894',RIH/SET CV W/CHECK IN GLM, POH W/SLICKLINE, TEST TBG TO 2500 PSI F/15 MIN, OK, HOLD TBG PRESS PRESS ANN TO 2500 PSI,HOLD F/15 MIN, OK, BLEED PRESS TO 1000 PSI,TEST SSSV W/ 500 PSI DIFF,OK, BLEED PRESS,CLOSE SSSV, LDLJ, SET BPV, ND BOPE, NU TREE, TEST PO TO 5000 PSI,OK, TEST TREE TO 250/5000 PSI,OK, PULL TP,OPEN SSSV, RU LINES,REV CIRC 70 BBLS WATER FOLLOWED BY DIESEL, TAKE RETURNS THRU CHOKE TILL CLEAN DIESEL RETURNS, RU SLICKLINE,TEST LUBR TO 1500 PSI,RIH/PULL CV F/BTM GLM, RIH/SET DV IN SAME, RIH/PULL PLUG F/'D'NIPPLE AT 8230',RD SLICKLINE, SITP=ll50 PSI,SICP=0 PSI, SECURE WELL, RELEASE RIG, MOVE TO 2M-03 DATE: RECEIVED J U L - Alaska Oil a Gas Cons. CommissioD Anchorage STATE OF ALASKA AI..A,~ OIL AND GAS CONSERVATION ~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate _ Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 517' FSL, 1081' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1337' FSL, 1474' FEL, Sec. 5, T11N, R9E, UM At effective depth 1089' FSL, 1339' FEL, Sec. 5, T11N, R9E, UM At total depth 955' FSL, 1265' FEL, Sec. 5, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8698' 6209' Effective depth: measured 8486' true vertical 6063' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size feet Plugs (measured) feet None feet feet 6. Datum elevation (DF or KB) 105' RKB. 7. Unit or Property name Kuparuk River Unit 8. Well number 2U-02 9. Permit number/approval number 88-5/9-124 10. APl number 5o-029-212§8 11. Field/Pool Kuparuk River Oil Pool RECEI. VED JAN 1 4 1991 JUnkNone(measured) ~iaska- _.0iT'. _~, (~a$ C0Jl$, ~.--~[sj~13' Cemented Measured depth ~J{~rurac:~e:~tical depth 68' 16" 3918' 9 5/8" 8531' 7" measured 230 Sx CS II 1 0 5' 1 0 5' 785 Sx PF "E"& 3955' 3081' 875 Sx PF "C" & 50 Sx PF "C" TOP JOB 350 Sx Class G 8 5 6 4' 61 1 8' 250 Sx PF "C" feet 8100'-8147', 8150'-8154', 8159'-8165', 12 SPF 120 degree phasing 8286'-8299', 8308'-8363', 4 SPF 120 degree phasing true vertical 5800'-5832', 5834'-5836', 5840'-5844', 5927'-5935', 5942'-5979' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55 set at 8240' Packers and SSSV (type and measured depth) Otis RRH at 7935', OTIS WD @ 8200', Camco TRDP-1A @ 1793' (locked out)~, OTIS FXE WRDP @ 1793' 13. Well Operation Install "K" valve, Set at 540 psi 60 degrees F 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 2100 2200 I 6 1300 2100 1540 17 1400 Tubing Pressure 25O 539 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~C~ &. ~ Title ~ni~ Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inci~ - Subsidiary of Atlantic Richfield Company~ WELL ONTRACTOR · WELL SERVICE REPORT FIELD- DISTRICT - STATE YS _ IOPERATION AT REtoRT TIME ~ /- '~''g -- _1~ ? I-'l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BAcK ~ OIL AND GAS ~SERVATION COMN,,..~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate __ Pull tubing _ Variance _ Perforate _ Other X 2, Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development .X__ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 517' FSL, 1081' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1337' FSL, 1474' FEL, Sec. 5, T11N, R9E, UM At effective depth 1089' FSL, 1339' FEL, Sec.5, T11N, R9E, UM At total depth 955' FSL, 1265' FEL, Sec. 5, T11N, R9E, UM Present well condition summary Total Depth: measured true vertical 8698' 6209' 6. Datum elevation (DF or KB) RKB 105 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2U-2 9. Permit number 88-5 10. APl number 5o-029-21 268 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool · _1 ,- - . ] i ' ' 12, Effective depth: measured 8 4 8 6' true vertical 6 0 6 3' Casing Length Size Structural N/A Conductor 6 8' 1 6" Surface 3918' 9 5/8" Intermediate N/A Production 8 5 3 1 ' 7" Liner N/A Perforation depth: measured feet Plugs (measured) feet None feet Junk (measured) feet None Cemented · .~,' ~ >..i _ Measur~ depth True ve~ical depth 230 Sx CS II 105' 785 Sx PF "E" & 3955' 875 Sx PF "C" & 50 Sx PF "C" TOP JOB 350 Sx Class G & 8 5 6 4' 250 Sx PF "C" 105' 3081 ' 6118' 8100'-8147', 8150'-8154', 8159-8165 12 SPF 120 degree phasing 8286'-8299', 8308-8363 4 SPF 120 degree phasing true vertical 5800'-5832', 5834'-5836', 5840'-5844', 5927'-5935', 5942'-5979' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.3 #/ft J-55 set at 8240' Packers and SSSV (type and measured depth) OTIS RRH @ 7935', OTIS WD @ 8200', Camco TRDP-1A @ 1793' (locked out), OTIS FXE WRDP @1793' 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ Install storm choke to replace failed closed WRDP @ 1793. 14. Estimated date for commencing operation January 18, 1~8~ 16. If proposal was verbally approved /--,/~ Name of approver ~ -.~' ~,t ! //'~ Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSlONC0SE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require ORIGINAL SIGNED BY ~,pproved by the order of the Commission LONN!E C..SMITH 10-///*~Z~ Commissioner Date (~r._./?..~/~ Form 10-403 Rev 06/15/88 ,~p',>*oved Copy Returned SUBMIT IN TRIPLICATE Kuparuk River Unit Well 2U-2 Install Storm Choke The WRDP in the subject well has failed closed. In order to restore the well to a producible condition, it is proposed that a storm choke be installed. The Well is currently shut in. The maximum anticipated SIWHP is 1800 psi. The storm choke will be an ambient type that will be set to close if the flowing tubing pressure drops to within 100 psi of he anticipated minimum flowing tubing pressure. This should adequately compensate for the loss of normal surface control typically afforded by a WRDP. The proposed procedure will entail pulling the OTIS FXE WRDP currently in the well and running an OTIS Type K storm choke using wireline. All necessary equipment to maintain control of the well will be installed and both pressure and function tested prior to commencing any operations. No workover fluids will be required to perfrom this operation. ARCO Alaska, Ir ~ Post Offic,= t~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE:10-22-85 TRANSMITTAL NO:5410 RETURN TO: TRANSMITTED HEREWITH RECEIPT AND RETURN ONE SI FINAL PRINTS/ SCHL/ ONE * CEMENT BOND LOG/ VAKIABLE ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115b, . -- P.O. POX 100360 . ANCHORAGE, AK 99510 TdE FOLLOWING ITEMS. GNED COPY OF THIS TRANSMITTAL. OF EACH DENSITY " ~3B-8 ' 06-06-85 ~ 42X-15 11-07-.84 "¢2X-13 11-17-84 *~ 2X-12 12-08-84 ~2X-ll 12-08-84 -~gX-10 12-21-84 '~ 2X-9 12-20-84 '~ 2W-6 11-25-85 '~'2V-16 06-06-85 '~2V-15 ' 06-07-85 ~'2V-13 06-03-85 -~2U-8''~'' '~ 04-02-85 ~'-2U- 7? ~-!~ 04- 01- ~ 5 '~2U-6 '--'-/ 03-31-85 ~,,,2u_41~..-. · 03_02_85 ~2D-16 12-19-84 2D-15 ..~i 12-18-84 ~"~2D-1.. 11-03-84 "~ 1R-8 06-17-85 - "'iR- 7 ~ 06-08-~5 "~JIR- 5 06-08-85 :'~iL- 15 . 11-05-84 "~ lQ-15 05-27-85 '~ lQ-3 04-17- ~ %CPF-1A 12-21- CEMENT EVALUAT ~.~F~r~16 -~:~- 03-12- . · %'*iR' 5 .... 06-26- '~ ~iR-5" 06-27- RUN #1 RUN RUN RUN HUN RUN RUN RUN .' RUN RUN RUN RUN #1 ~UN ~1' RUN RUN. RUN RUN RUN RUN RUN ~UN RUN RUN RUN LoGS / . ~ ~'2U-2- ' '"-':" 03-25- -~2U-15-. 03-07- '~3B-9 -.>.~' 06-30- .. -~'3C-111~--i 06-29-. ~-i,~3C~12:06-29- 8 5 RUN 84 RUN ION TOOL 85 RUN 85 RUN 85 · RUN 85 i~UN 85 RUN 85 RUN 85 RUN 85. RUN PLEASE ACKNOWLEDGE 5850-8369 5900-8258 5896-8410 3050-7215 3100-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 6590-8553 4970-693~ 0070-~122 . . 5600-8107.~ . '-' . 5994-9161 -. - :- ..'i~..;: 6284-7850 5200-7469 3285-6454 ' 5693-6652 5987-~324 4302-7028 6950-8628 4883-6600 ' 6490-7566 897~-10744 2200-3856 CEMENT ~VALUATION LOGS 8269-8712 6974-8644 8254-8532 5790-9450' " 6400-7002 6O00-8246 6500-8726 540O-7457 W. PASHER EXXON PHILLIPS OIL J. RATHmELL- RECEIPT ACKNOWLEDGED: BPAE '" " DRILLIN~*BL B. CURRIER L. JOHNSTON CHEVRON- mOBIL D-& M .-' '" NSK CLE~K*oL ' UNION VAUL~/~O*FIL~ ARCO Alaska. Inc. Is a Subsidiary of AllanticRichfieldCompan¥ ~ ,,.,, ARCO Alaska, ' Post Of~'Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-1 8-85 TRANSMITTAL NO: 5219 RETURN TO: ., FINAL PRINTS CBL ' S ( ONE ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 AI~I-IOR~GE, AK 99510 }IER~I~H ARE TIlE FOLLOWING IT~qS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF TIIIS TRANSMITTAL. / SCHL * OF EACH ) _./ 1E-15 11-01-84 1L-16J 11-05-84 2D-2-/ 11-03-84 2D-4 j' 11-04-84 2U-1-/' 03-01-S5 2U-2 -/ 03-01-85 2U-13 ~ 02-05-85 2U-14-'~ 02-09-85 2U-16 -~ 02-10-85 2W-5 -- 11-25-84 2W-7-~' 11-27-84 2W-8 /' 11-27-84 2X-16 / 11-07-84 RUN #2 69 94-7 910 RUN ~1 56 93-7620 RUN #1 6760-7663 RUN #1 6987-8492 RUN #1 4550-7316 RUN #1 5850-8446 RUN #1 4600-7786 RUN Itl -4900-6991 RUN ~.1 4600-6070 RUN ~1 5750-8059 RUN ~1 4530-6241 RUN #1 5140-7702 RUN #1 7900-9568 RECEIPT ACKNOWLEDGED: B PAE B. CURRIER C HE VRON D & M DISTRIBUTION: DRILLING*BL W. PASttER L. JOttNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL DATE Ala:k~ 0~ ~ ~ - ,~. Commissio~ STATE OF ALASKA*BL / SOHIO SE UNION K.~ULIN/VAULT~FZLMS ARCO Alaska, Inc. Post Office"~'~x 100360 Anchorage. AI3ska 99510-0360 Telephone 907 276 1215 DATE: 05-2 9-$5 TRANSMITTAL NO: 5199 RETURN TO: T ]L%N SM ITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK A TO- 1115B P.O. BOX 100360 AI'~HORAGE, AK 99510 HEREA~ITIi ARE TIIE FOLLOWING ITEMS. PLEASE AcKNO~WLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK ~;ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-8 03-21-85 2G-12 03-23-85 2H-13 04-26-85 2i~-14 04-28-85 2H-15 04-29-85 2U-1 04-11-85 2U-2 04-11-85 2U-3 04-11-S5 2U-4 04-11-85 2U-5 05-02-85 2U-6 05-03-85 2U-7 05-04-D5 2U-8 05-04-85 2U-13 03-09-85 2U-14 03-21-85 2U-15 03-20-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 2W-4 04 -13-85 2X-1 · 04-14-85 2X-3 04-13-85 2X-13 03-30-85 STATIC-'C' SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ST%"~!C-'A' SAND STATIC-'A' SAND STATIC STATIC-'A' &'C' SAND c~ I ! ! ~TATIC- A & C SAND STATIC-'A'&'C' SAND CTATiC-'C' SAND STATIC-'C' SAND STATIC-'A'&'C' SAND c,~-,,~IC , , ~ ~ - A SAND .A~IC- A & C SAND STATIC-'A'&'C' SAND 2GU-'A' SAND :'.ECEIPT ACKNOWLEDGE D: ;PAE* CURRIER* VIX. X._t L". ) f M* DRILLING L. JOHNSTON MOB I L * NSK CLERK DISTRIBUTION: W ~ASq~' R EXXON PHILLIPS OIL'~ J. RATHMELL* DAT.E,j~.sK~: 0i~ & 6~,s Cur, s. (;ummission STATE OF SOiiiO* UNION* K.TULiH/VAULT ARCO Alaska, Inc. Post Office B. 00360 Anchorage, A'l~ska 99510-0360 Telephone 907 276 1215 June 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells: 1Q-6 2U-2 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L34 Enclosures RECEIVED JUN 0 4 ]985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA ALASKA'--..~ AND GAS CONSERVATION C(,..~MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] '2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-5 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 ~ 50- ~'029-21268 4. Location of well at surface 9. Unit or Lease Name 517' FSL, 1081' FWL, Sec.32, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1:~37' FSL, 1474' FEL, Sec.5, TllN, RgE, UM 2U-2 At Total Depth 11. Field and Pool 955' FSL, 1265' FEL, Sec.5, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 105' RKB ADL 25644 ALI( 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/06/85 02/11/85 02/14/85*I N/A feet MSLt 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set ! 21. Thickness of Permafrost 8698'MD,6209'TVD 8486'MD,6063'TVD YES I-~]X NO [] 1807 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/Cal/FDC/CNL, Gyro (GCT), CCL/Temp, CBL/VDL/GR, CET 23. CASING, LINER AND CEMENTING RECORD .. SE~I-ING DEPTH MD CASING SIZE' WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 230 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3955' 12-1/4" 785 sx Permafrost E & ~.75 sx Permafrost C .. 7" 26.0# J-55 Surf 8564' 8-1/2" 350 sx Class G & 250 s~ Permafrost C 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) 8100' - 8147', 8150' - 8154', 8159' - 8165' 3-1/2" 8240' 8214' & 7949' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8286' - 8299', 8286' - 8299', 8308' - 8363' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED w/4 spf, 120° phasing 8060' - 8062' 100 sx Class G (See Well History for frae info,) 7658' - 7619', 7602' - 7578', 7566' - 7560' w/ 4 spf, 90° phasing 27. N/A PRODUCTION TEST ,,, Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow 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. None ~lasl(a Oil & Gas Cons, ComrnlSsio~ Form 10-407 * NOTE: Tubing was run & the well perforated 4/5/85. GRU9/WC13 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - . . .. .. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEP_-FH GOR, and time of each phase. .:. - . . . Top Upper Sand 8098'-'~ · 5797'' N/A : Base Upper Sand 8140" 5825, Top Lower Sand 8264' 5910' ; - ":'.' ':-' ". !!.; '~ Base Lower Sand 8447' 6036' .,, . ,. - , ,~ ' . _. ~! : ~ : ;-_ : : _ . ' - i .; ,:; ~ .~ .; , . - '.. ~. . , t . . · · . 31. LIST OF ATTACHMENTS , .. ; .- ;. Addendum : 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed,~ ~..~LJ~C. JL~ Title Associat;e Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well. completion report and Iog'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 combustiom 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". I~nrrn I n.~¢l? ADDENDUM WELL: 2/20/85 3/04/85 3/27/85 4/25/85 2U-2 Arctic Pak w/250 sx PF "C", followed by 59 bbls Arctic Pak. 8486' PBTD Rn CBL/VDL/GR f/8446'-5850'. Rn gyro f/8406' - surf. Log w/CET f/8450'-5790'. RU Schl, perf 7658'-7619', 7602'-7578' & 7566'-7560' w/thru tbg 2-1/8" Enerjets @ 90° p~asing, 4 SPF, 283 shots. Rn BHP/BHT: 7610' MD, 6096' TVD: BHP = 3041.56 psi BHT = 159.45° F 7540' MD, 6044' TVD: BHP = 3014.64 psi BHT = 158.28° F Dr ill~g ~u~e-r int end ent dUNO *,¢,, . AlaSka Oit & Gas Cons / Anchorage' Commission ' / Date ARCO Alaska, Inc. Post Office B~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 24, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-2 Dear Mr. Chatterton: Enclosed is a Well Completion Report for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L06 Enclosure RECEIVED MAY 2 9 ]985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA'~,_ AND GAS CONSERVATION CC~_.,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-5 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21268 4. Location of well at surface 9. Unit or Lease Name 517' FSL, 1081' FWL, Sec.32, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1337' FSL, 1474' FEL, Sec.5, TllN, RgE, UM 2U-2 At Total Depth 11. Field and Pool 955' FSL, 1265' FEL, Sec.5, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' EKBI ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/06/85 02/11/85 02/14/85'J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set ! 21. Thickness of Permafrost 8698'MD,6209'TVD 8486'MD,6063'TVD YES I-)IX NO [] 1807 feet MDt 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/Cal/FDC/CNL, Gyro (GCT)~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 230 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3955' 12-1/4" 785 sx Permafrost E & ~75 sx Permafrost C 7" 26.0# J-55 Surf 8564' 8-1/2" 350 sx Class G & 250 s; Permafrost C 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) 8100' - 8147' 3-1/2" 8240' 8214' & 7949' 8150' - 8154' w/12 spf, 120° phasing 8159' - 8165' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8286' - 8299' 8060' - 8062' 100 sx Class G 8308' - 8363' w/4 spf, 120° phasing (See attached Wel History for frac info.) 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDal~ 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. NoneRECEIVED IAY 2 9 A~aska 0{! & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run & the well perforated 4/5/85. CRU9/WC03 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... : . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH - .GOR, and time of each phase. - ..... . Top Upper Sand 8098~ 5797' N/A -~ . ~se Upper Sand 81~0~ 5825~ lop ko.er Sand -.82~~ 5~10~ - -~ ~ .:: : :- . .: ~ Base ko.er Sand 8~7' ~03~~ . .. .: · ~ :- '~. - . ~ ' ~ - , '.' . . , . .... . ~. _ . . . . . . . . . ..... 31. ~IST OF ATTACHMenTS - . We!! History (Completion Details) .. ........ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . . -- 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". l~nrm I n.4n? AtlanticRichfieldCompanyv~' Daily Well Hist°ry- Initiai'ReP°rt Inetrucflons: Prepare and submit the "Initial Report" on the first Wednesday after a well fs spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District [ County orPerish IState Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River ADL #25644 I 2U-2 I Title Auth. or W.O. no. AFE 603597 Completion WWS #1 API 50-029-21268 Operator ARCO Alaska, Inc. Complete 3/30/85 Date and depth aa of 8:00 a.m. 3/30/85 thru 4101185 4/02/85 4/04/85 Complete record for each day reported 0515 Hrs. A.R.Co's W.I. 56.24% Prior status if a W.O. 7" @ 8564' 8486' PBTD, Drlg cmt Wt. 10.1 ppg Accept ri~ @ 0515 hrs, 3/30/85. ND tree, NU & tst BOPE. RU WL, RIH w/4" csg guns, 4 SPF, 120°phasing. Shoot sqz perfs @ 8060'-8062' RIH w/RTTS, set @ 7805'. Est IR of 2 BPM @ 4500 psi. Pmp 160 sx cmt, stage in. POH w/RTTS. Set pkr @ 7805'. Sqz well w/100 sx Cl "G" blend. Final sqz press of 2500 psi. Rel'd pkr. Rev out. POOH, WOC. RIH, tag cml @ 7862'. Drl cml. 7" @ 8564' 8486' PBTD, Prep to perf Wt. 10.1 ppg Drl cmt f/7900'-8092' 7" , tst csg to 2000 psi. CBU to cln brine. PU TCP guns & 3½" tbg. 7" @ 8564' ~-:' 8486' PBTD, LD perf guns Wt. 10.1 ppg RIH w/TCP guns & 3½" tbg. Tie in guns, set pkr. Drop bar, fire guns & flow well to tst tank. Kill well. POH w/perf guns. 7" @ 8564' 8486' PBTD, RIH w/pkr Wt. 10.1+ ppg RIH w'/bit & scrprs. Tag fill @ 8444', wsh to 8472'. RIH w/Otis WD pkr on WL. Rn JB/GR. The above is correct For form preparation and dlstribu~an, see Procedures Manual, Section ~), Drilling, Pages 86 and 87. 5/01/85 Drilling 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 uoon 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 cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit Well no. Kuparuk River ADL #25644 20-2 Auth. or W.O. no. T fie AFE 603597 Completion Operator Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. WWS #1 API 50-029-21268 A.R.Co. W.I. [Total number of wells (active or inactive) on this, Icost center prier to plugging and I ARCO Alaska, Inc. 56.24% labandonment of this well Date IHour I Prior status if a W.O. 3/30/85 / 0515 Hrs. Complete record for each day reported Old TD Released rig 0400 Hrs. 4/05/85 4/15/85 Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 7" @ 8564' 8486' PBTD, RR Crude/Diesel Set perm pkr @ 8200' WLM. RIH w/257 jts, 3½", 9.3#, J-55 EUE 8RD, IPC tbg & ind. Shear SBR. Set BPV, ND BOPE, NU & tst tree. Pull BPV. Displ well to crude. Tst SSSV. RR @ 0400 hfs, 4/5/85. SSSV @ 1807' - Pkr @ 7949' - Tailpipe @ 8240' WD Pkr @ 8214' - "D" Nipple @ 8230' Frac'd "A" sand w/700# 100 mesh sand, 15,100# 20/40 mesh sand & 337 bbls diesel. RU Otis, RIH w/CCL &temp tl, tag PBTD @ 8430'. Release to Production. New TD Date I PB Depth 8698' (2/12/85) 8486' I Kind of rig 4/05/85 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 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 % GOR Gravity Allowable Effective date corrected lV£b The above is correct I Date ITitle Signature /~,~,~ ~~,~_~_~_.~j 5/01/85 Drilling Superintendent ~~$'~e Co~]~ For form prepa~atio~ a~d dist~i;u~io~ -- see Procedures Manual, Section 10,- Drilling, Pages 86 and 87. ARCO Alaska. Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO' T I:;: A N,S' M ]' T T I::: I) I:::ECE I F']' AND I::' I ?,/Al._ F'R [)PEN I-I CJ I._ ARCO ~-~I...A,..,I',A, INC. A'l'Tiq: RI:-:iCOI:;:I),.? CI...li:_'l:;:l< A-f'CJ-'i '1 '/ I::',0, I'-'(OX t003/.)0 ANCI'~OI',:AC,-I!i:, Al< 9:?5 t 0 I'-I I-7 I:;t [[ W ]i T H A R Ii"' 1' H Ii.--. I::' 0 [.. I... 0 W I N G R E '~' U R N I) N ti! J'i' I G N [" D C 0 I:' Y 0 F I N -r ,_, L=.. / X C I..I L.'U H B E I:;: {; Ii. R I) A '1' E ' O .5 - 07 -',., ::) ..,': TI:;:ANSMITTAL N. 0'5'i78 lq-5 · -') · '.5' I "f Iii. M 2. /__.~J~... I:!] A .'i' I::'] ~ C I( N 0 W L EZ ]) G EZ T I--I I S T I:;.' A N S i"11 T T A 1_. F;: E C E I I::'T A C I< N .. }'3 F' A Iii: I::, C U I:;: R I Ii: I:;~ C I--I Ii'- V I::: 0 N ]) & N~,:.B[.. I) ]] I_ /,?,.'1:' L.-[; R D :[ L / 2 F I...-- [; I::: I) E N / N I:_.' L.I-.-. (; I:-;'. I) Ii: N ,/?4 IE t_l--(; l) I.-'.] N / N I!i] I.J -' [; [;,'. DIE N/N IZ t.J -" (; R C '( B I;: R L 00 ( r:' 0 I:;.' 0 ) ( I::' 0 R 0 ) ( RAW ) ( RAW ) 02 -' 2 8 - ,<ii '_"~ 02-28-85 02 --' 2 ,<ii -. 85; 0 '') '- '') ("'') -- ~''') ()2-'28-8!~ 02 -' 28-- 85 02-28-85 RUN ~:i S2'"57- 7,187 RUN $:1 3257-7'1137 R t.J i"4 ~: 1 3; 8'50 -' 7,190 RU?'4 '"-1 '" ..... , ,Jdo~--Tqga -~- RUN.,-1 3850-7490 R U N -,,-t 6750--7,1S~ D I I... / £ F' I_'-- [4 I::: I" ]. !.. ," .Y I:-I...-- 6 ['~'. I) Ii.-: N / i'4 Ii::. t.l -F' [1 I:,.: I) I:-." N / N Ii.'-. t.l '-r:' 0 I::: [} I) Iii N ../N Ii-.-I.J -I::: ,'h Id. I) El N ;" N E LJ -. R A U (7) ") ._ ") z~ -- C.) i:,: %, ..:_ ,..; -%- ~..! ~/ 0 '.."! - 2,1 '-' 8 _"5 O2-.24-85 0 2 -' 24 -. 85 02 '-. 24 - 85 O 2 -' 2! -1 --85 02-24-85 ( I::' [)I:;: 0 ) ( F:' 0 I:;; 0 ) ( RAW ) ( RAW ) 02- t 2-85 02- t 2-S5 02- i 2-8"5 02-t 2-85 02 '-' t 2! --8 5 02-t2--85 0 2 - i... ''~ -' 8 5 I:;,' [_l N :'..': t gS:'5=-S&T7 I-?UN :lb1 3?54 F;~ I_J ?4 :',',' 1 ,:5-' c'/._,,,: ,.: - I:;: I. J N .... " - :::' 6 -,,- '~ .~9r''; ~' ,:5 ...... I:-?.UN -'Il: t :5':?'"5,: -8653 I:;,'1J N ..... ' - - · ,.t 3:?~':~ So53 - . _2 , I:;: U N -11:1 395.4 --S 640 I) I L/Si---I_ 03--07-"-'-d I5. I I._ /,5' F: I... 03 - 07 -- 8 .;'::' F D f: ...... ,/[; N I._ / (; I:;: ,' F' (:)I:;t (:1 ') 0 S - 0 '7 -o..>'"' ':" I-;.: IIN 0t- F !) C; ../C: N L. / G R ( F:' 0 F;: 0 ) (-;' .-.:, - (-) 7-- 8 _5 I:;: U N :~: t I:- I) r} ,/C i'-,! I.~ / C-, I::: ( I::: A W. ) 0 FDC/CNI...,/GI:;: ( I:~AW ) 0S--~07.. _,:~c,,:--..¢ I:;:UN -,,- .... t C Y B [:: I:;: 1_ 00 I,~ 03 ,-, o ,',,: .... -- ,:, ,:> - o .., I;: LJ N t · _ , '11' ARCO Alaska, Inc. Post Offi¢ ,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TL')' AF.:CO ALA,~I<A, IN.C,. ,....t., T'¥ ?-? - R E C [) FL: D 5' C; L_ E R I< r:',TO-, i i t 5B F'.O. BOX i0:336,3 r:', ~-.! C I'-I O F-,.: A G E,_ A I< 9 o,...,':': i 0 DAI'E' AF'RIL i°,, i98_' TI--<ANSMITTAL NO' _,,~i4'Z f:' A G E r,-.:.-~,,?rl]: ......... -I--IFI::FhlITH ................. AR.r:.. THE F[.II._L_P,I.,I]:NG ]:I'IEM:', F'I.__,::r--,..:.E ACI<t~riI,,JL.ET~F'-, ._ ...._,,:. F:..'FC['-TII--'T Ai,.'D RETURN ON.E SIC-NED COF'Y OF THIS 'I'RANSHITTAL, $-' F': (;! U E i'-.'. C E 0 F E "..: E N T ~-' ' i F--3 'A' - ...,,:D FRAC-'dELLED WATEF,~: -'i "~.- o. ..'?T?~T T C i Y-- i i F'B IJ i Y.- i i F'BU o p,-.. i F'F:I I ......... 2X- i G F'B~J · 1 r.a -- ~ F' B ti t~--2 CELl. ED WATEF.! FRAC IL-t6 POST FRAC TEHP LOGS ,-,r .... i ~ F'DLJ .: _ ,'.., ~r,- i -'=' F'R!I ~-"- ~: ~TAT ,'[. ~ .~Sz- -,'-' ~ , _ i,_~--.i . '~ F'E:U '~'- --' F'~',I I --'.. '..¥ I' ~£'-27 ~ ~ .r. ~ H Grl_,_.'"[ ATER F:ATCH FRAC ~"---"-~m:,._ ~-_, PhST_. , FF.:AC TEMF' LOG ,~l,,J ..... I .,~'Ti'%TIC BHF'. -~ v._. -z °TATIC r:HF' .-:.., .., .._, .', ._ IE-i6 INJ,:%CTEVZTY TEST ISZF' '~U ..... ~ STATIC BHP 2 U - 3 .F..,' t--I F' ~ i--~ BHF.' 2 U- t B i-I F' '"": .... I,_,z- pr;il II:T.-i5 F'OST FRAC TEMF' LOG · -) v _ 1 F: I--I ,r.:, ~-.....-,, _ · - ' T,-_~-~,- LOG · ~ I--- I ,-, F'OS.T FF-.'AC r::,.'.r-, iF .... i'6 I-1YT), FRACTURE 2 F-- 9 I'-" B U 2F-7 F'BU 413/8_5 '~'/ -'/'DJ 4/~ -2/85 5/-5 t ,/85 'I;'t 185 4/I/85 4/2/8: 4/9- t 0/85 4/7-8/8~ A /c,_/o~- 4/t ~ -13'/85 4/t t -i 4/t 2/85 4/I '~ ':-~ 4/f3/85 4/i ~/85 4/i S/8_5 4/i t/85 4/i 2/85 4/i 2/85 4/i 2/8_5 ' 4/i 0--i i/8_5 4/i 4-- i a/i 4/8~- , · 4/i 5;'85 4/i 5/85 4/i S-i 4/8~-_:- 4/i4-i5/85 RECEIPT A CI< i-.!OI.JLED C., E D ' BF'AE B., CUF:RIER CHEVRON DISTRI[:UTION ' DRII_L ! N(.i W, F'ASFIER I ..... IOHNSTON EXXON HOE:IL F'HILL I F',~ OIL NSK CLERK J, RAI'I-IMELL ARCO Alaska, Inc. II a Subsidiary of AllanlicRichfieldCompany APR 2 Alaska Oil & I)A'FE · Cons. C~TATE OF ALA.",'I<A'") SOHIO UNION K ,"'r U L_ I N/VALII_T ARCO Alaska~ Inc.~' .... Post Office .~,, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 . .. I-- I_ I::. ,'-i ,:.:. F. A C K iq iJ W I... E I) R r:'r: E I F' T t.~i,.. ¢' I'..'. ~' o, ~l . r:'l"rr; IE D · .. L:, ;i: ,:; T I::: I JB Ll'f I 0 i'~.:. ]E-.'F'AE DI:;.' I I...!... I H('; I,,.I., F:'A,S:HI]EF;; !!~ ... C, URR I E;i'::I ........ I01 li',~,?'l'ON , C I lIE V RtEll-'~ i"l 0 B I L F'I..I I ~ I... T ':" ':" ..... ,' ,.~. 01 I.. ..,I~ & i'4 N,.:.'~I/', CI..'EF::I( ' · . ~ ,", ', ',r .... ,'..; ~ ARCO Alaska. Inc. ts a *ubsidlary of AllanticRichfieldCompany ARCO Alaska, Inc. Post Office B"~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-2 Dear Mr. Chatterton: Enclosed is a copy of the 2U-2 Well History (including Addendum) to include with the Well Completion Report dated 03/14/85. If you have any questions, please call me at 263-4944. Sincerely, ' C~..~%QL.' ~'1 ~ O. Gruber Associate Engineer JG/tw GRU5/L69 Enclosures RECEIVED 3 I B5 Alaska Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARco Oil and Gas Company,~,'~' Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily wot1< prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty. parish or borough North Slope Borough Lease or Unit Tree ADL 25644 Drill, Complete & Perforate Kuparuk River Auth. or W.O. no. AFE 603597 IState Alaska IWell no. 2U-2 Doyon #9 API 50-029-21268 Operator I.ARCO w.I. ARCO Alaska, Inc. SpuddedorW.O. begUnspudded Io~e' 2/6/85 IH°ur 1900 hrs. Priorstatusifaw.o. Date and depth as of 8:00 a.m. 2/07/85 2108185 2/09/85 thru 2111185 2/12/85 iComplete record for each day reported 56.24% 16"'@ 105' 1138', (1033'), DD Wt. 9.8, PV 22, YP 24, PH 8.5, WL 14.4, Sol 10 NU diverter sys. Accept rig @ 1600 hrs, 2/6/85. Spud well @ 1900 hrs, 2/6/85. Drl 12¼" hole to 541', DD & surv f/541'-1138'. 541', Assumed vertical 693', 4.7°, S41.7E, 693 TVD, 6 VS, 5, 4 843', 11.3°, S36.9E, 841TVD, 27 VS, 21, 17 16" @ 105' 3981', (2843'), POH Wt. 9.8, PV 16, YP 20, PH 9.0, WL 12.8, Sol 10 DD & surv 12¼" hole to 3981'. 992', 17°, S37.5E, 986 TVD, 63 VS, 50S, 40E 1328', 28.8°, S36.5E, 1295 TVD, 194 VS, 159S, lllE 1843', 45.3°, S36.2E, 1700 TVD, 504 VS, 405S, 308E 9-5/8" @ 3955' 8490', (4509'), Drlg ahead Wt. 10.2, PV 12, YP 11, PH 9.5, WL 5.6, Sol 11 Fin cond hole f/9-5/8". RU & rn 99 jts, 9-5/8", 36#, J-55 csg to 3955', FC @ 3872' (top). Cmt w/785 sx PF "E" + 875 sx PF "C". Displ using rig pmps, bump plug. CIP @ 2215 hrs, 2/8/85. ND diverter. Perform top job w/50 sx PF "C". NU BOPE & tst; OK. TIH, tst csg, DO flts. Perform leak-off tst to 11.5 EMW. Drl & surv 8½" hole to 8490'. 3947', 48.3°, S34.5E, 3089 TVD, 2085 VS, 1687S, 1233E 4608', 48.6° 5155', 47°, 5785', 48.2° 6415', 51.7° 7045', 50.7° 7676', 49.4° 8105', 47.0° , S31.7E, 3528 TVD, 2580 VS, 2101S, 1503E S31.0E, 3894 TVD, 2985 VS, 2447S, 1714E , S29.2E, 4319 TVD, 3450 VS, 2850S, 1947E , S28.7E, 4725 TVD, 3931VS, 3271S, 2180E , S28.7E, 5119 TVD, 4420 VS, 3702S, 2416E , S30.4E, 5525 TVD, 4903 VS, 4123S, 2655E , S29.7E, 5811 TVD, 5223 VS, 4400S, 2815E 9-5/8" @ 3955' 8698', (208'), RIH Wt. 10.2+, PV 13, YP 12, PH 9.0, WL 5.2, Sol 12 Drl 8½" hole to 8698', CBU, spot pill on btm, POH f/logs. Schl, RIH, hit bridge @ 4494', RD loggers. RIH, rm 4458'-4626', RIH. 8698', 43.7°, S25.7E, 6228 TVD, 5643 VS, 4773S, 3011E RECEIVED ~Jaska 0ii & Gas 00,% ' ..... m-'.. ..... Anchorage RU The above Is correct For form preparation and distribution, see Procedures Manual, Section 10,' Drilling, Pages 86 and 87. Date 3/14/85 ITM Drillin~ 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 Rep@ri" 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 ~vailable. Oistrict JCounty or Parish I Alaska Field ~Lease or Unit Kuparuk River I ADL 25644 Auth. or W.O. no. ~Title I AFE 603597 North Slope Borough Accounting cost center code State Alaska JWell no. 2U-2 Drill, Complete & Perforate Doyon #9 API 50-029-21268 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 2 / 6/85 Date and depth Complete record for each day reported as of 8:00 a.m. Iotalnumber of wells (active or inactive) 'on this @st center prior to plugging and -I bandonment of this well I our J Prior status if a W.O, I 1900 hrs. 2/13/85 2/14/85 9-5/8" @ 3955' 8698', (0'), POH, LD DP Wt. 10.2+, PV 14, YP 11, PH 9.0, WL 5.0, Sol 12 RIH, rm 8445'-8698', circ & spot pill. RU Schl, rn DIL/SFL/SP/GR/CAL/FDC/CNL f/8679'-3954', RD Schl. TIH, C&C mud, POH, LD DP. 7"0 8564' 8486' PBTD, R.RI3 /O. Wt. 10.2, PV~, YP~, PH 9.0, WL 5.0, Sol 12 RU & rn 213 jts, 7", 26#, J-55 BTC csg w/FC @ 8486', FS @ 8564'. Cmt w/350 sx C1 "G". Displ using rig pmps, bump plug. CI? @ 2100 hrs, 2/13/85. ND BOPE, set slips, instl pack@ff. RR @ 0300 hrs, 2/14/85. Old TO I New TD PB Depth 8486 , PBTD Released rig J Date Kind ut rig 0300 hrs. J 2/14/85 Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) 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 % GOR Gravity Allowable Effective date corrected The above is correct Signature Date Title ~.~_Z ,/~.L,.,~ J 3/14/85 For form preparation and distribution, ~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling Superintendent ADDENDUM WELL: 2/20/85 2U-2 Arctic Pak w/250 sx PF "C", Pak. followed by 59 bbls Arctic D~i~ 1 {~j- ~p er int end en t 'Date ARCO Alaska, Inc. Post Office B-'o'x~ 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 ~larch 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2U-2 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the 2U-2 Well History. When I do, I will forward a copy to you. Also, tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L42 Enclosures RECEIVED kl~s~a Oii & G~s Cons. commisslo~ At~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA ALASKAr.~- AND GAS CONSERVATION C(_.~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska· Inc. 85-5 3. Address 8. APl Number P. 0. Box 100360, Anchorage· AK 99510 50- 029-21268 4. Location of well at surface 9. Unit or Lease Name 517' ESL, 1081' FWL, See.32 T12N, R9E, UM · --- .... ,, ~'-'. Kuparuk River Unit At Top Producing Interval i VE~iFi:_--D ! 10. Well Number 1337' FSL, 1474' FEL, Sec.5, TllN, RgE, UM tSu.~. ~-~ i 2U-2 At Total Depth H __~/ J 11. Field and Pool 955' FSL, 1265' FEL, Sec.5, T11N, RgE~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' RKBJ ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/06/85 02/11/85 02/14/85 N/A feet MSLI N/A 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+'rVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8698'MD,6209'TVD 8486'MD,6063'TVD YES [~X NO [] N/A feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/Cal/FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 1~' ?b.,, 3~(~ ~v Pnl~l c;~t- II 9-5/8" 36.0# .I-q~ S,,rf ~q:,c,, 17-!/~," 785 _~× Perm_~frost E & !75 sz Perm_=frest C 7" 26.0# J-55 Surf R=;¢,/~' R-l/p,, 350 s× r~l_ass G & 250 s:. Perm_=frost C 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) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=k 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. None RECEIVED IAR 2 6 1985 A!aska 0ii & G~s C0ns~ Commission Anchorage Form 10-407 GRUS/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29..,. .. o. ., ,..:.... .:~ -...'-- .,,, .-, .,,,: ..:r~: : ,, ..~:...: ,: ?.;:~.., ~.;.~.~ ~ · ,,... ,... :..": Gi:OE_OG[E~.i~IA.RKER~i ",:'.; :~.. ~.:; ::':-~: :~;:':::~.' ~.-'-~'~{~:i:~u:~:~:~!: -~::' ..~ , · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of:e~ch phase. . . Top Upper Sand 8098.' 5797' N/A Base Upper Sand 8140' 5825' Top Lower Sand 8264' 5910' Base Lower Sand 8447' 60~,6' , · 31. LIST OF ATTACHMENTS Cvrn.~r. nnir..~,,rv~_v (?. 32. I hereby certify~that the' foregoing is true and correct' to the best of my knowledge Signed ~ ~ ~b~ Title Associate Engineer' Date ~.~' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ARCO Alaska, Inc. Post Office B'c'~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-2 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2U-2. I have not yet received a copy of the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/L26 Enclosure RECEIVED 1 8 Alaska 0ii & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CQ._~vllSSiON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-*AX ABANDONED [] SERVICE [] ,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-5 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21268 4. Location of well at surface 9. Unit or Lease Name 517' FSL, 1081' FWL, Sec.32, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2U-2 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 02/06/85 02/11/85 02/14/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8698'MD 8486'MD YES [] NO []X N/A feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/Ca 1/FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 230 sx C°ld Set II 9-5/8" 36.0# J-55 Surf 3955' 12-1/4" 785 sx Permafrost E & I~75 sx Permafrost C 7" 26.0# J-55 Surf 8564' 8-1/2" 350 sx Class G & 250 s Permafrost C 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) None N/A 2'6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,, N/A · 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow 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. None ' R C IVF_D · ,laSka 0ii & Form 10-407 GRU5/WC10 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . ..: -. :.. NAME Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . . . _ Top Upper Sand 8098~ N/A N/A Base Upper Sand 8140' N/A Top Lower Sand -8264' N/A ~ -- Base Lower Sand 8447' N/A . . . 31. LIST OF ATTACHMENTS Nnn~ 32. I h~r~b~ certif~ that th~ foragoing is true nnd corr~at to th~ best of m~ Eno~l~dg" ' Signed ~ ~ ~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other'spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for Only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 $ UB-$ URFA CE DIRECTIONAL SURVEY ~ UIDANCE [~ONTINUOUS ~']OOL Company_ ATLANTIC RICHFIELD COMPANY RECEIVED Alaska 0il & Gas Carls. C0mrn/ssion Well Name 2U-2 (517' FSL~ 1081' FWL, $32~ T12N. R9E. UM) Field/Location ~~u~, FORTH ST,O?E, ALASKA Job Reference No. · 70168 LocJ~ed By: [OZUSKA Date 12-MARCH- 1985 Computed By; STEVENS SCHLUMBERGER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC NELL 2U-2 FIELO KUPARUK COUNTRY USA RUN ONE DATE LOOOED 1-MAR-SS REFERENCE OO0O70:168 ARCU A[,,ASt~.A, INC, ? U -2 K lJ P A !~ Li K NOP,'I'H 8LOPI:?, ALASK~ $t. JRYEY DATE: 1-MAR-85 EN(;£~,]EFR: K{'IZUSKA ~ETHO[)?, OF COMPUTATION TUoI.,, LnC~,TTO!~': TA~rGFi~T,[.SL- averaged dev~,ation and azimuth VF~m.,I, CAI, fi~C~,,~IC,~: ~I[~RT~. D1ST, P~OJ~CTi~;h ONTO A TARGE]T AZIt4[JTH OF' SOUTH 32 DEG 45 MIN EAST ARCO 21]-2 KTIp.~RITK NORTh ~LDPF',~ ~L,~KA Cnf,iPOTAT./r',I'~ DAI'E: 12-MAR-R5 DATE OF SURVEYt 1-MAR-85 ENGINFER; KOZUSKA INTF. I{PUf,ATED VA[,LiWS .FRR EVEN 100 FEF'F OF ~EAfiURED DEPTH PAGE 1 TPUF SUR-$E~ CO~.iPSF ~EaSI~RFD VFRTI. CAI, VEPTTCAL DEVIATIOI~ DEPTH D~P~H DEPTH DEG M'Ih DFG .~1~.~ 105,00 FT 0 O0 '~ O0 -105.o0 0 0 N 0 0 F lOO:Oo ~o~:oo -~.00 o lo ~ 5s 3~ ~ 200.00 2nO,O0 95.00 0 o h 39 50 F 300.0o 3ho.On 195.00 0 17 N 7 3! ~ 400.00 400.00 295,n0 0 16 ~? ~6 50 w 500.00 500.00 395.00 0 14 N 63 16 w 600,~0 509.99 494.99 1 43 S 29 23 F 700 O0 699.76 ~94,76 5 16 $ 40 26 F ~O0~OU 798.94 ~93.04 9 lq S 3b 50 F qO0.O0 Bq6,Sg 791,89 13 40 S 38 5 ~ VErTICaL DOCLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEC/lO0 FEET FEET FEET DEG MIN 1000.o(3 903,2~ RBR,?2 17 1100.00 1087 oB 1200.00 1.179~B0 1074.R0 ~4 1~00,00 1.269 36 1.104,36 1400 O0 1355~91 1~b0,91 ~1 40 1500'00 1439~23 1~34 23 35 45 1600~00 1.517 9~ 1417~98 39 3o 1700.00 ~594~17 148~.17 41 1900,00 166'7.42 15o2o42~ 44 lqO0,O0 1'737.29 0.00 0,00 0,00 N 0.00 E 0.09 1,80 0,06 S 0,07 E -0.03 0,90 0,04 N 0.01 E -0.29 0,72 0,30 N 0,08 W -0.62 0,71 0,56 N 0,27 W -0.91 0,98 0,7] N 0,54 W -0.16 4,46 0,01N 0.27 W 6.30 2,44 5 04 S 3 B2 E 1~.~6 4,0~ 14~97 S 11~60 F 3~.R2 3,83 30'86 S 23,70 E $ 35 57 E 65.49 $ 30 30 F 9R.24 g 29 51 F 137,05 g 34 ~ ~ 181,46 S 37 17 E ~31,,43 S 39 1R F 786,43 $ 38 ~5 F 347,60 5 37 1,6 E 417.07 ~ 36 47 F 479.96 S 3'/ n ~ 551.30 2000 O0 1603 4t 169P,.43 ~9 14 2100~00 ,!86 B; t;'? 1763.6'7 49 2~ 300,'00 !9q8:3' IR93,17 49 5~ 2400"00 2062,79 i057,72 49 47 2500.00 ~197,3 ~. 202~, t.~ 50 13 260o.00 ~190,94 2o85.~ 49 b3 2700,00 ~255,9J 2~5~,91 49 25 2800,00 2.3~0,96 2~15,96 09 20 2900,00 23~6,03 2~81,03 m. 9 23 3000,00 2451,27 2346,27 49 14 3100.00 7510,55 2411,55 49 13 3700,00 ~5~1 °97 2476,97 49 6 3300 o0 ~47.44 2542,.4,4 49 4 3400 ~ oO 7712.97 2607. q7 49 0 3500.00 ~'178. bO 2673,59 48 57 3600 O0 ~844'42 27~9.42 48 4! 3~00~0 ~910 5~ 2~0~,53 48 30 3800,00 2976~6 2RTl,~o 48 33 3900.00 3043,0~ 2O3R.Ot~ 48 2O S 33 7 E 1387 03 R 32 48 F 1462:78 S 32 37 E 1538,41 S 32 31 ~ 1614.00 $ 32 34 E 1689,54 S 32 28 E 1764,99 $ 32 16 E 1040,27 S 32 2 E 1015.~9 8 31 54 E 1990,13 ~ 31 50 E 2065,05 0,00 N 0 0 g 0,09 $ 49 38 E 0,04 N 18 54 E 0,31 N 15 46 W 0,62 N 26 14 W 0,91 N 36 26 W 0,27 N 86 5~~ 18, $ 37 46'~ 38,96 $ 37 36 E 4,04 4,~6 2, 0 5,03 3 25 :o4 ,00 3,37 2,41 3,12 52 04 S 79 5~ $ 5 7 1~3 30 S 77 151 21S 100 lO1 59 S 129 235 01S 164 2~2 54 $ 203 333 53 S 243 38794. S 284 445:15 $ 327 40 15 P 98 E 98 20 E 137 36 E 93 E 231 11 E 286 29 E 348 19 E 412 OO E 480 03 E 65,73 S 37 38 g ~ E 48 $ 33 34 E 4g S 34 8 E 64 ~ 34 55 E 07 S 35 44 E 78 S 36 5 E 84 S 36 12 E 552,37 S 36 ~8 E 0 20 0 90 0 73 0 61 0 43 0 96 41 0,71 0,40 504 91 S 372 32 E 627,34 $ 36 24 E 565 44 S 41.7 93 E 703 13 8 36 28 E 626 45 S 463 687 79 $ 508 749 82 S 553 8t2 27 S 597 875 54 S 641 938 74 1002 21S 725 1065,87 S 766 3~ E 779 20 S 36 29 g 54 E 855 37 ~ 36 28 g 38 E 931 91 $ 36 ~5. E 57 E 1008 41 S 36 20 E 43 E 1085,36 8 36 13" 66 E 1161,30 S 36 3 ( 39 E 1237,17 $ 35 5~ ~ 77 E 131,3,01 $ 35 43 ~ 0,30 0,20 0,48 0,1~ 0,28 0,22 0,55 0,48 1129 1192 1,256 1320 13~3 1447 1511 1574 1.638 1.701 39 S 808 12 E 1388,73 S 35 35 g 94 S B49:35 E 1464,41. S 35 27 E 53 S 890,28 E 1539,96 S 35 19 E 28 S 930,91 E ~615.46S 35 11 E 94 S 971,57 E 1690,93 S 35 4 E 54 S 1012,16 E 1766,31 S 34 57 E 14 S 1.052,45 E 1841,52 $ 34 51E 63 S 1092,41 E 1916,46 $ 34 45 E 12 S 1132,04 E 1991,22 $ 34 38 E 7.3 S 1171,64 E 2066,06 8 34 32 E PAGE 2 A~C~ AL, AbKA, 2!t-'2 Kt~P~R~)K DA?B OF SURVEY: 1-MAR-R5 KELb¥ BUSHING EBgVATION: ENGTNEER: KOZUSKA ~EA$1~RFD VFRTICA.[. VEPTTCA[, DEVIATIRi~ AZI~UTti DEPTH D~BT~.i DEPTH DEG ~.lTi~ DFG i~TN 105,00 FT 4000,00 31n9.~5 3n04,95 47 56 41o0.ou 317~.59 3n71.59 ~8 1~ 4?00.00 ]243,1o 313R,10 48 24 4300.no 3309.41 3~04.41 48 27 4400.O0 3375.70 3970.70 48 2~ 4500,OU qq42.06 3337.06 48 2~ 4600 00 3508 36 3403.36 48 27 4700:00 3574~G5 3460,85 48 12 4800,O0 3041. 5~ 3536.59 47 57 4900.O0 l'/OB:7? 3603,72 47 37 5000.0,0 3776.30 3671.30 4.7 20 5100 O0 ~844 ~4 :.~730 1~ ~7 16 5200:00 3912:1~ 3~07:10 47 5]00 00 3990:27 3;'~75.?7 46 57 5400:00 4.048 52 3o.%3,~2 46 5q 550~.O0 4116,05 401],05 48 35 5600,00 ~1~1,'79 4~76,79 4S 51 5700,00 4247,7~ 41. 49,78 4~J 3! 5900.00 43~1.~7 4276.~7 47 5~ 6000 O0 4448.b~ 6100~00 4516.27 4411.27 47 17 6200.00 45R4,0~ 447q.n8 48 6300.00 4647,95 4542,95 ~1 57 6500.00 4771,51 4&hS,ql 5J .i~ ~6o0.00 4~33.83 972~.R~ gl 20 6700,00 4896,35 4791,~5 51 6800,o0 4958 9R 4853,08 51, 20 6900,00 50~1:67 4916,67 51 7000.0(3 50Rq "14 6970.7~j 50 58 7100.00 5147~72 5047.72 5U 53 7200.00 52~0, Uq 5105.~9 50 7300 Oo 5274.34. 516<) 34 50 7400:00 533B.21 5733:9J 50 10 7500 Ob 5402,4~ 5~97,45 4.9 47 7600:00 5467,09 5367"09 49 7700.00 5532.u~) 5427,09 49 15 7800,00 55q7,'/O 549~.79 ~8 40 7~00,00 5664,10 6550,~0 A8 ].5 g 31 33 E 213q.47 S 31 36 F 2213,93 $ Il. 39 F 2288.59 S 31 39 R 2363,43 A 31 2~ F 2439,28 S 31 16 F 2513.07 S 31 10 ~ 2587,91 $ ~1 1~ ~ 2662.57 S 31 ~3 F 2737.02 $ ~1 n F 28i1.10 S 31 17 F' 2884.79 $ 31 1~ F 2..q59.23 S 31 3 F 3031,56 $ 31 2 !;7 3104,69 c 30 5t F 3177,75 $ 29 47 E 3251..44 S ~9 2 F :3326.65 ~ 29 1 E 3401.62 $ 78 53 F 3476.15 S ~8 gO F 3550,31 :-~ ?~ 50 F 3624 02 $ ?i~ 2~ F 3770.74 S ~8 3~] F', 3R47,46 S ~8 1 F 3025,97 S P7 56 F 4004,21 S 2'1 46 R ~237.58 S ~7 40 F 4315.1.9 2'7 45 F 4392.49 97 b0 E 4469,87 27 5q E 4547,12 ~7 5] E 4624.15 ?7 54 ? 4700,81 2't 48 F. 47'77.1.7 77 45 E 4B53.18 27 55 ~ 4928.~9 2~ 12 ~ 5004.03 gB 15 E 5o7~.64 0,84 0,47 0,50 0,26 0 1~ 0:32 0,12 0.05 0.12 0,60 0,23 0,40 0,26 0,25 0,15 3,00 0,40 0 6~ 0:30 0,46 0,30 0,27 3,97 1,98 0,66 0,97 0,19 0,12 1 00 0:96 0,45 0,42 0,44 0,85 0,35 0,79 0,63 0,32 0,15 1765.09 S 1210,71 F 2140 41 6 34 26 E 1.828,54 S 1249,70 E ~214 79 S 34 21E 1892,15 $ 1288.83 F 2289 39 8 34 15 E 1955,85 S 1328,13 ~ 2364 16 S 34 10 E 62 S 1367,35 E 2438 96 $ 34 5 E 201.9 2083:48 S 1406,33 ~ 25~3 ~9 S 34 1E 2147.4g S 1445,13 E 2588 46 ~ 33 5~ 51 2275 O~ S 1522.41E 2737,47 S 33 47 E 2338~49 S 1560,78 E ~811,51 6 33 43 E 24Ol,51 s 1599 oo E 2885 15 $ 33 39 E 2464,31S 1637 14 E ~958~56 $ 33 35 E ~527,13 S 1675 02 E 3031'84 $ 33 32 E 25~9,80 S 1712 78 E 3104 94 $ 33 28 E ,46 S S 33 25 E 2652 1750 2715,95 S 178'! 2781,73 $ 1824 2847,4] S 1.861 291.2,79 S 1897 2977,88 S 1933 3042 62 S 1968.7R g 3624 3107 12 S 2004'21 E 3697 3171 60 S 2039 48 E 3770 3239 3308 3377 3446 3516 3584 3653 04 S 2076,~4 F 3847 44 S 211..3,67 E 3925 76 $ 2150,52 g 4004 85 $ 21R7,20 E 4082 84 S 2223,67 E 4160 80 $ 9260,04 E 4237 75 S 22q6,30 E 4315 3722,44 S 2332 41. ~; 4392 379~,17 S 2368 60 E 447 0 3859,65 $ 2404 3927,90 $ 2441 3995,92 S 2477 4063 66 $ 2513 4131 ~7 S 2548 4198 40 S 2583 4264 92 S 2619 4330 86 S 2654 93 E 4547 21 ~ 4624 18 E 4701 O0 £ 4777 41. F 3177 96 92 ~ 3251 62 $ 33 21 g 67 ~ 3326 7R S 33 15 E 14 E ~401. 72 S 33 10 g 28 g 3476 20 $ 33 4 E 18 E 3550,34 S 32 59 E 32 49 E 74 S 32 44 E 46 $ 32 39 E 99 S 32 34 E 25 ~ 32 29 E 23 S 32 2 03 $ 32 18~' 75 S 32 13 ~ 42 S 32 8 E 80 S 32 4 E 26 ~ 3i 59 E 59 $ 3i 55 g 71 S 31 51E 47 ~ 31 47 g 92 $ 31 43 E 56 F 4854,05 $ 31 40 E 98 E 4929,86 $ 31 3b E 46 E 5005,11 S 31 33 E 87 E 5079,83 S 31 30 E VbJRT?CAL DOGbFG kFCTANGIILAR cnORDINATES HORIZ, DEPARTURE 6ECTIn[,{ SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUIH FRET PEG/1. O0 FEET FEET FEET. DEG MZN COHPuTAT]OI~ [3ATE: 12-MAR-~t5 PATE OF SURVEY: 1'-MAR-B5 KELLY BUSHING ELEVATION: ENGINEER: KOZUMKA PAGE 105,00 FT IN'I'~:RPO[,AT~iD VAr,LiVS FOR EVEN lO0 FEET OF MEASUREO DF..PTH '.['RUE SUR-SE~a CnURSK ~E~6IIRRI) VRRmICAI, V'LRTICAG DF, VIA?IO~ AZIMt3TH PkP'.L'H DF. PTH DEPTH I)EG b'l.TN I.)EG tqlN VERTICAL DOGLEG RECTANGULAR COORDINATES HOEIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FFET PEG/100 FEET FEET FEET PEG 8000.00 5730 U5 5625.R5 47 5& 8!0o,n0 5708:29 b~9~.29 47 20 820o.ou 5866,31 57b~.31 46 56 830n. Ou 5934.8q 5R2g.89 40 37 8500~00 6072,50 bq07.59 4b 2P 8600,00 614i,57 o03~.57 46 22 869~.00 6209.17 6!04.~7 4b 22 $ 2u 24 F S ?8 ~2 ~ 5226'.53 S 78 46 ~ 5299.64 S 2b 37 F 5372,25 $ ?~ 4.4 F 5444'71 $ 28 ~3 ~ bS1R,93 S 28 43 F 55~g.15 $ 2~ ~3 ~ 565~.g2 0.91 0.13 0.77 0.17 5,86 0,00 0,00 0,00 43qb 44 $ 2690 14 ~ 5154,18 $ 31 27 g 4461:27 S 2'125 49 E 5227,93 S 31 25 g 4.525,58 S 2760 66 E 5301,15 $ 3~ 23 E 45~9,41S 2795 64 F 5373,86 $ 3~ 20 E 4653,15 S 2830 5~ E 5446'43 $ 31 ~8 E 47!b,6] S 2865 30.F 5518,75 S 31. 16 E 4780,1~ S 2900,09 E 5591,08 $ 31. X~ ..... 4842,34 S ~9]~,19 E 5661,96 ARC{n ALA~SKA ~ 21J-? KIIPARIIK NORTH DATE OF SURVEYt 1-MAR-R5 KELbY BUSHING EbEVATIGNc gNGINEER: KOZUSKA I~,~TF..RPOT,ATED VALUES E'O~ r:VE~' 1000 FEET OF MEASURED DEPT ~EA$I]RFTb VRRTIPAI, V£RTTCAL DEVI,~TZO:'~ A2i~UTh 0 ou 0 On -10~o00 0 0 lO00:nO 993:22 R88,22 17 1R 2000.00 1803,43 169~.43 49 14 3~00.00 7451.27 2346.27 4.9 14 4a00 OU ~109.8K 3004.85 47 56 5OU0[nO ~77~.30 367~.~0 47 20 6~()0.O0 4448.5K 4343.55 47 2~ 7000 ~(') 50R~.')4 ~070.74 50 58 800~00 5730°85 5625,~5 47 56 869R.OU 6209.17 ~ (.)4.17 40 2~ PAGE 105,00 VERTTCA[., DOGL.F.G RFCTANGULAR COORDINATES HORIZ, DEPARTURE SECTIDN SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/1.00 FEET FE~T FEET M 0 0 E ~.~0 $ 35 52 E 65.49 S ~7 9 E 626,O6 S 33 7 E 1387,03 $ 31 33 F 2139.47 S 31 17 W 2R84,79 $ ~8 50 ~ 3624,02 S 28 24 ~: 515P,88 S 28 ~3 E 5659.g2 0.00 4,04 0,20 0,30 0.84 0,23 0,30 0,91 0,00 0.00 N 0,00 E 0 52,04 S 4'0,15 E 65 504,9] S 372,3~ E 627 1129,39 S 808 12 E ]388 1765,09 S 12~0:7~ E ~140 ~401,5~ S ~5~9,00 E ~042.62 S ~968,78 E 36~4 ~722 44 S ~332,41 E 4392 4396:44 S 2690 14 K 5154 4842~ 34 S 2934:19 E 5661 KUP~RI1K PAGE 5 DATE OF SURVEY: 1-MA~-fl5 KELbY BUSHING ~DEVATXON$ 105,00 FT ENGINEEP: KDZUSKA FOR EVE~I 100 FEFT OF SUB-SEA DEPTH VKFTICA]. VER'rTC~L DEVIATIf);~ ~ZIFI~ITn DEPTH DEPTq DEG MtN DFG t,~TN o.nO O.OO -luS.00 0 0 N 0 0 ~ 5.00 5,00 -100,00 0 5 ~ 22 26 ~ 10~.00 lOb. On 0.00 0 10 S 83 15 ~ ~05 nO 205,00 100.00 0 I~. N 30 10 ~ ~05~00 3n5.00 ~()0,00 0 14 N I 23 E 405.00 4nS,On ~0o.00 0 16 N 34 1~ W ~05.00 505,00 4o0,00 0 13 N 74 lq W 605.01 605,00 500,00 1 56 S 30 5~ E 70~.26 705.00 600,00 5 24. S 40 14 E P06,14 805,00 700,00 9 34 S 36 ~8 E V~R'rTCAI. 0 DOGbEG RFCTANG[IbA~ COORDINATES MOR!Z, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0,00 N 0.00 0.00 0,00 0,00 g 0,00 0.10 1,95 0,07 S 0,08 -0.03 0,79 0,05 g 0,02 -0,31 0,77 0,32 N 0,08 -fl,64 0,88 0,58 N 0 29 -O,q3 1,17 0,74 M 0:56 0,02 4,34 0,14 $ 0,18 6,78 2,81 5,40 S 4.13 10.87 4,14 15,'78 S 12,21 S 38 O F 40.79 S 35 8 ~ 69,22 S 99 50 E 105.02 $ 30 22 F 148.84 $ 3b 5 ~ 201.,~6 S 38 19 E 262'79 S ]9 14 E ~36'99 $ 37 7 F 421.71 S 36 5~ F 517,~1 S i]7 ~ E 627,~7 ~08.35 90b.O0 ROn.nc) 1] bg lO1Q,t6 1005,00 qO0,O0 1'1 45 1227,~3 1205'0~ 110~.00 ~5 32 1~40.7~ 1.305,00 1200,00 ~9 43 145~,32 1405,00 1300,00 33 50 1583,?0 1505,00 14On,O{) 39 13 1714,51 lb05.00 1500,a(; 4,1, 50 1~52,98 1705.00 160¢).00 4,5 50 2002.a0 ~805.00 1700.00 49 1~ 2156,n7 1.9Ob,On 1.900,00 49 33 2310.32 2005'00 lqOO,O0 2465.~4 2105.0o 2nOn,O0 49 5~ 262~ ,7~ ~2n5,00 2775 4'1 2305,00 2~00.00 49 25 292q~11 2405,00 2t00,00 4,9 lq 308?~ 32 ~505. O0 3235 I 8 2bOb,On 25UO,O0 4.9 7 3387:Rb ~705.0~ 26(.)0.00 49 0 3540,17 2805,00 2700.00 48 51 369~,66 2905.00 280o.n0 48 31. 384~ K4 3005,00 2900.00 4.8 31 399:77 3105.00 3000,00 47 53 414~ 67 ')205,U0 3100,00 4.!~ 17 4~931~4 ~305,0o ..~p()O. OO 4,8 2~ 4444.~5 ~05,00 3300.00 a8 26 4~94 ~3 3505.00 340~,~0 48 2a 4745:P3 3605,90 3500. 0 48 1o 5042.31 3805,00 370o.00 47 16 S 3b 41 F 744.26 $ 36 13 E R61, 45 S 35 i4 E 980:01, g ~3 5q F; 1090'96 S 33 15 F 1.216 69 $ 33 2 E 133,3132 S 32 50 E 14,49,39 S 32 31 E 1565,00 S 32 34 E 1680,~8 $ 32 '~1 E 1795,~ S 32 4 E lgOq.04 S 31 55 F 2022 02 $ 31 33 E 2134,:1,1 $ 31 33 E 2245,76 S 31 40 ~ 2358,44 $ 31 26 E 247~.,30 R 31 10 E 2584,!1 S 31 12 E 2696.28 $ 31 g ~ 2807,03 S 31 15 E 2915,87 3,78 4,16 3,84 3,78 3,44' 4,58 2,36 3,27 4,13 0,18 0 75 0 55 0 95 1 58 0 25 0 23 0 28 0,29 0,25 0,37 0,41 0.33 0,76 0,36 0,27 0,19 0,09 0,46 0,78 0,09 0,00 h 0 0 E 0.00 N 90 0 E 0,11 $ 50 49 E 0.06 N 23 35 E 0,33 N 14 3~ ~ 0 65 N 26 1.9 W 093 N 36 51" 023 853 ~ 6 80 $ 37 ~ 19 95 S 37 43 E 32 42 $ 25 O0 55:09 $ 42 31 85,40 S 61 37 123,51 S 83 11 167,3~ S 111 81 21,6,49 S 149,21, 274,25 S 196,57 341,23 S 249,03 417,84 S 306,46 506,35 S 373.4~ 40,94 S 37 38 E 69,46 S 37 31 E 105,16 $ 35 42 E 148,87 $ 33 56 E 20~,29 S 33 44 E 262,93 S 34 34 E 337,42 S 35 37 E 422,44 $ 36 7 E 518,18 $ 36 15 E 629,16 S 36 ~4 E 599,66 S 443,50 F 745,84 $ 36 29 E 694,16 S 513,22 K 863,28 S 36 ~8 E 790,~5 $ 582,36 E 981,97 S 36 22 E 889,28 S 650,75 K 1101,95 S 36 11E 986 63 S 715,17 K 1218 57 S 35 56 E 1.084 37 S 778,81 E 1,335 07 8,35 41E 1.181 68 S 842,09 E 1451 1.278 95 S 904,59 ~: 1566 52 $ 35 16 1]76 22 S 966 64 ~ 1681 78 1473 08 S 1028~40K 1.796'55 S 34 55 E 1569, 1665, 1760, 1.855, 1,951, 2047. 33 $ 1,089 10 K 1,910 22 S 34 45 E 19 S 114,8 91 ~ 2023 08 $ 34 36 E 51 S 1207 b5 S 1266 60 S 1.325 79 S 1384 91 K 2135 39 ~ 2246 51 K 2359 5q E 2471 05 S 34 27 E 59 $ 34 18 E 18 S 34 1.1 E 95 S 34 3 E 214:4,25 S 1443 17 E 2584 67 $ 33 5.6 E 2240,22 $ 1.501 30 F 2696 76 S 33 49 E ~335,01S 1558 67 K ~807 44 S 33 43 E 2428,09 S 1615,14 E 2916,22 S 33 37 E ARCO /~LASKA, 21~-2 NORTH s~r,oPL· Tr,iC. AIjA,SK A i NTF, R Pl,.)~,ATED VAI,UE5 '£RUF SUR-SkA 5189.57 ~905,U0 3ROO.O0 5336.92 4005.00 3900.00 5483.~6 4105.00 400n,O0 5635,~4 420'5,0~ 57~6,10 4305,00 4700,00 5935.53 4406.00 4300.00 608~ 38 4505,00 q400.00 ~231~78 4605.0~ 4500.00 6392.61 4706,00 6553,79 48o5,0~ 4700.00 6713.~1 m705,On 6~7~.46 50n5 00 4000,00 7037.~} 51n5~00 boon.00 7190.~9 52o5.0o 510o.o0 7348.07 53O5,0~ 7503.95 5405,00 5300,00 · , 7658 40 5505~o0 5400. , 810.02 5605,00 SlOg. Q0 5805.00 5700.00 825~,47 5905.00 5~00.00 840...03 6005.00 5900.n0 8546,99 6105,00 6000.00 8691,'~5 6205.0~. 869~.00 62~9,1 6104,17 DATE: FOR EVEN 100 COURSE EVIAmlOi'i AZi~IiTH EG NTN OEG ~,ilN 2 I~ 0 E 3 ~ ~4 K 46 F': 43 F, 39 E 59 E, q9 E 42 E .~4 F 51, E 46 E 1,5 E 47 3 S 31 46 57 S 31 4, 11 S ~0 48 46 S 29 47 41 ~ 2~ 47 1~ S 28 49 29 S ?~ 51 46 S ?8 51 26 S ~7 51 1~ S 27 ~1 5 S ?7 50 5~ S 27 50 45 S ?7 5() 16 S 2'1 ~9 46 $ 97 ~9 26 S 27 48 5 S 2~ ~,7 17 $ 2~ PAGE 6 DATE OF SURVEY: 1-~AR-85 KELLY BUSHING EbEVATION: 105,O0 FI ENGINEER: KOgUSKA 4,0 30 $ 28 43 E 4o 24 $ 28 44 F., 40 22 $ 28 43 E 40 22 $ 78 4't E 46 2~ S PU 43 E VERTICAl., 5ECTInN FEET 3023.03 3131.1,4 3239.02 3353.11 3465.82 ,35'16.60 368~.94 3794.59 392~.19 4046.1,6 41'10.63 4294.61 ~417,44, 4530.94 4661,04 4780.~8 ~897,44 501~ ~u 5~24:22 5233.79 53]40.67 5446.18 5550.86 5655 55 5659:92 rEFT OF SUB-SEA DEPTH DL]GLEG RECTANGULAR SEVERITY NORTH/SOUTH DEG/IO0 FEET 0 23 2520,59 $ 0:08 2612.47 S 3 07 2705,1q S 0:14 2804.92 S 0,48 2903,72 S ~.17 3000.97 S 0,14, 3096,40 S 4,52 3192,61 S 0 '17 3303.32 S 0~43 3414,95 S 0.15 3525, 0'2~ 3635, 0,46 3744 0,65 3853: 0,48 3960. 0,28 4066, 0,44 4170. 0,44 4272 0,44 4371! 0,46 4467 1671, 1726, 1781, 1837. 1892, 1945, 1908, 2050. 21i0, 2170. 0,14 4561 6,55 4654 0,00 4746 0,00 4838 0,00 4842 COORDINATE15 HORIZ. EAST/WEST DIST. FEET FEET og E 3024 22 2 E 3131 38 ~9 E 3239 21 54 E 3353 23 27E 3465 88 87 E 3576 62 33 E 3685 25 89 E 3794 59 94 g 3920 20 26 E 4046 22 76 83 78 4O 64 41 93 24 36 33 E 5013 29 51E 5125 48 99 E 5235,20 44 F 5'342,23 22 E 5447.90 65 E 5552 73 09 E 5657i58 19 E 5661 96 36 S 2228,69 E 4170 46 S 2286.70 E 4294 61 S 2344,07 E 4417 29 S 2401,55 E 4540 63 S 2458.53 F 4661 33 S 25i. 4, E 4780 49 S 2569. F 4898 14 S 2623, 13 S 267~, 66 S 2728. 64 S 2780. 44 S 2831, 47 S 2881, 50 S 2932, 34 S 2934. DEPARTURE AZIMUTH DEG MIN S 33 32 E S 33 27 g S 33 22 g 15 33 13 g S 33 5 E 15 32 57 g IS 32 5;~' S 32 4 S 32 34 ~d $ 32 26 E Ii 32 18 E S 32 10 E S 32 2 g S 31 55 E S 31 49 E S 31 43 g 15 31 38 E 1531 33 E S 31 28 E 631 25 E 1 E S 31 128 E S 31 $ 31 15 E S 31 12 E 15 31 12. g ~ARKF~ DATE: 12-~AR-85 IiUTF..kPO[,ATED VA[.,uF',5 I~rIR CHOSEN ~lF A S U R [-.;P nEPTH R Ef.,Ow Ki.; gOoS.UO 5796,93 8]40.00 5~25.4~ ~26g,00 5010.1'1 ~44'1'U0 b036.02 8~6,00 6062,g~ 8OgS,uO 020g,17 PA~E DATE OF SUR'V~¥: i,-NAR-85 KE[,6Y BOSHINa ~6EVATION: ENGTNEER; KOZIISKA 105,00 SURFACE LOCATION AT ORIGIN= 517' FSL, ~081' F~L. SEC 32. T~2N R~9E, U~ TVD RECTANGU6AR COORDINATE SUB-SEA NORTH/$OIJTH EAST/WEST 5691 93 4459.98 $ 2724.79 ~ 5720:44 4487.05 S 2739.5U E 5805 17 4566.45 S 2783.08 E 59tli02 4682.99 6 2846,8b ~ 5957 93 4707.75 S 2860 43 "' 6104 ~7 %842.]4 $ 2934~9 C{'!MPuTATI!71,~ DA't'FT; I~-MAR-R5 PAGE 8~ DATE UF SURVF¥: 1-MAR-R5 KELLY RUSHTNG EbEVATION~ 105,00 F'T ENGTNEER; KOZII~KA STi{a'I'TG~ADHIC SPM~ARY *~***~*~*~** TOP Ln;..~FR S~ND b~SF' I,OWEP ,qANO P R Tn '/'R 3.' 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L.L.4..4...i..~..4...~...~......4..4..4...~.. L4..-i.4-.4..[-4..4...~.-.~...L-..L4..4.. ;--. L4..4...L.~. L4-.-~- .~.-4. -.~-..~...~.--~..44-..~.--~..-~ ....... ~...~...~...L..~...~...~ 4-.-~---'.-.~---~ 4---~.-.{--&-~.-.~----~-.. r"~'-'~'"~'-'~"+"~' ~---~'--~ ..... ~---;--~---~---~---~-.-~.--~---~---. - ~---~.--~---~4--.~-.-~---~---~---t--.~-.-~- ~--~---{--;--~-4-~--,--.~---~---~---;---~.--~----~---~---~--.{ ..4...~...~...~-., :...~...~...~..4 ...... ~...~..4. ~ ...... ~.-.~-.4..4..-~ ...~..-~.~,4... '.4-~-~-~-....4-4 ...... ~..-'...~..4...~...~... -4... ~..4-i .. '..4-.~-~...~.......~..4-L.4... L..~...i..4...i ...... ~...~..i.-4.-. 4.-. ~.- ~ ........ ;..4-- .~. L. '.-4... i...;--.~..- -9000 -2000 -1000 0 1000 2000 9000 4000 5000 EF~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: ~2~~/~ ~i~ Date Required Date Received Remarks C°mpleti°n Rep°rt Well History'. - ~_ ~. ~_-' -_ ~ :-~ SampZe8 . ~- -,~ ~ore Ch~ps ~ore Description Registered Suy~ey Plat 'InClinatiOn Survey ectsonal Survey Ye~ ..'~'~.. S,,m~e,~ ~,,or,, Production Test Reports , Log Run ~g~t~zea Data ARCO Alaska, Inc,~_.. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~-!arch 13, 1985 Mr. C. V. Chatterton Commissioner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells' 17-11 2C-11 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2w-1 2w-2 2w-3 2w-4 If you have any Sincerely, Gruber Associate Engineer JG/tw GRU5/L18 Enclosures questions, please call me at 263-4944. RECEIVED ,AR 1 4 1985 A}aska 0{{ & Gas Coils. Gommission Anchorage ARCO Alaska, Inc. is a Subsidiary of AflanlicRichfieldCompany "'" ' STATE OF ALASKA ALASKA O,_,, AND GAS CONSERVATION COri...,__~lSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well E~ × Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-5 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21268 517' 4. Location of Well at surface FSL, 1081' FWL, Sec.32, T12N, R9E, UM 6. Lease Designation and Serial No. ADL 25644 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2U-2 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool For the Month of. February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1900 hfs, 02/06/85. Drld 12-1/4" to 3981'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8698'TD as of 02/11/85, Run OH logs. Ran, cmtd & tstd 7" csg. PBTD = 8486'. Displ to brine. Secured well & RR @ 0300 hfs, 02/14/85. Arctic packed 02/19/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 105' Cmtd w/230 sx Ca II (approx) 9-5/8", 36.0#/ft, J-55, BTC csg w/FS @ 3955'. Cmtd w/785 sx PF "E" & 875 sx PF "C" & 50 sx PF "C" top job. 7" 26 O#/ft, J-55, BTC csg w/FS ~ 8564' Cmtd w/350 sx Class "G" cmt & 250 sx PF "C" 14. Coring resume and brief description NONE 15. Logs run and depth where run D IL/SFL/SP/GR/Cal/FDC/CNL f/8679' - 3954' 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED {~__~~/~~ TITLE Associate Engineer DATE ~'4-~' NOZE--Repor~on 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 JMM/MR63 Submit in duplicate ARCO Alaska, Inc Post Office""b~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 25, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' COnductor As-Built Location Plats - 2U Pad Wells 1-8, 9-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L77 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL 1 Y = 5,975,841.16 LAT. 70°20'42.7599'' X = 509,642.25 LONG. 149°55'18.2508'' PAD ELEV. 68.4 O.G. ELEV. 6~,.Z FSL 575 FWL 1,096 i WELL 2 Y = 5,975,782.54 LAT. 70°20'42.1835'' X = 509,627.77 LONG. 149°55' 18.6762" , PAD ELEV. 68.4 C.G. ELEV. 64.1 FSL 517 FWL 1,081 WELL 3 Y = 5,975,724.43 LAT. 70°20'41.6122'' X = 509,613.34 LONG. 149°55' !9.0999" PAD ELEV. 68.3 C.G. ELEV. 64.0 ?SL 458 FWL 1,O66 WELL 4 Y = 5,975,666.21 hAT. 70°20'41.0397,' X = 509,599.09 LONG. !49o55'19.5187'' PAD ELEV. 68.4 C.G. ELEV. 63.9 FSL 400 FWL 1,052 WELL 5 Y = 5,975,753.43 LAT. 70020' 41.902'~ X = 509,249.86 LONG. 149055, 29. 720" PAD ELEV. 68.6 C.G. ELEV. 64. FSL 488 FWL 703 WELL 6 Y = 5,975,811.41 LAT. 70°20' 42.472" I ~ X = 509,264. 30 LONG. 149055' 29.296" ~ ~ PAD ELEV. 68.6 C.G. ELEV. 64.4 ~ ~ FSL 546 FWL 716 WELL 7 Y = 5,975,869.59 LAT. 70020, 43.044" X = 509,278.75 LONG. l~9°55' 28.871" PAD ELEV. 68.6 C.G. ELEV. 64.3 FSL 604 FWL 732 WELL 8 Y = 5,975,927.80 LAT. 70°20' 43.616" X = 509,293.26 LONG. !~°55' '2~.445 ~l ~ PAD ELEV. 68.5 C.G. ELEV. 64.2 FSL 662 FWL LOCATED IN PROTRACTED SECTION 32 TOWNSHIP 12 N, RANGE 9 E, UMIAT MER. ,/ '.~ . ~ , / .. NOTE: BASIS OF BEARING IS PAD PILING CONTROL . . - NI3~55, E8+30 AND NI3+55~ Eli+70 AND ' ' ;,~.: ~,~ BASIS OF ELEVATION IS 2U-5AND 2U-4 PER LHD ~ ASSOCIATES. ..... · :~: . , I HEREBY CERTIFY THAT~ I AM PROPERLY REGISTERED AND , LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF .'-~/~ ARCO Alaska, Inc. ,,~~~V~ ~;: ~N ~ ~ ]"1~;~ - Kuporuk Project~R,bb S'TEN°rth Slope Ori,ling~U .~ ~ /~SCALE: ~ I--= I Mile~ Drewn By' ~ Dwg. No. NsKg.05.221d I January 16, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2U-2 ARCO Alaska, Inc. Permit No. 85-5 Sur. Loc, 517'FSL, 1081'F~.~, Sec. 32, T12N, R9E, UM. Btmhole Loc. 1059'FSL, l152'FEL, Sec. 5, TllN, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. 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 16.05.870 and the regulations promulgated thereunder (Title 5, 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 prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation Mr. Jeffrey B. Kew~. Kuparuk River Unit 2U-2 -2- -~-January 16, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. P~here a diverter system is required, please also notify this office 24 hours prior to commaencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~y~t~ly yours, C. V. Charge,r/ton~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 8, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2U-2 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2U-2, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 11, 1985. If you have any questions, please call me at 263-4970. Sincerely, !~~~gineer JBK/HRE/tw PD/L20 Attachments & ~ Oo~.~ A?Ci~ore~oe°' Oo/7/nT/SS/o# ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA Om'AND GAS CONSERVATION COIt~r~lSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~x DEVELOPMENT GAS [] SERVICE [] STRATIGRAP. HIC SINGLE ZO N E~I--I MULTIPLE Z~ I~]X 9. Unit or lease name Kuparuk River 10. Well number 2U-2 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0, Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 517' FSL, 1081' FWL, Sec.32, T12N, RgE, UM At top of proposed producing interval 1320' FSL, 1320' FEL, Sec. 5, TllN, RgE, UM At total depth 1059' F.~L, 1152' FEL, Sec. 5, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 106' , PAD 69' 6. Lease designation and serial no. ADL 25644 ALK 2575 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500~000 t15. Distance to nearest drilling or completed U-1 well 60' (~ surface feet 18. Approximate spud date 02/11/85 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 517' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8689' MD, 6209' TVD feet 2560 19. If deviated (see 20 AAC 25.050) I20.Anticipated pressures 2~_9 psig@ 80OF Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 49 oI (see 20 AAC 25.035 (c) (2) 30F;O psig@ 5943 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing Weight j24" 16" 62.5# !12-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# I 22. Describe proposeO program: CASING AND LINER Grade Couplin.[ H-40 Wel J-55 BTC HF-ERW J-55 BTC HF-ERW Length MD 80' 35' 3764' 35' MD BOTTOM TVD 115' 3799' 13026' I TOP TVD 135' 115' I 135' I I 134' I I (include stage data) ± 200 cf Poleset 785 sx Permafrost "E" 875 sx Permafrost "C" 8655' 34' 8689' 16209' 270 sx Class G neat I i ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8689'MD (6209'TVD). ! A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The i 9-5/8" casing will be set through the West Sak Sands at approximately 3799'MD (3026'TVD). A 13-5/8", 5000 psi, 'i RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly ! thereafter. Test pressure will be 3000 psig (3000 psi for annular) Expected maximum surface pressure is 2649 ! · i psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an ~ unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 3-1/2", 9.2#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer ~yo ~7~is~ u~e The spac ~v fl~/ '" CONDITIONS OF APPROVAL Samples required Mud log required ~]YES ~NO I--lYES ..I~N O Permit number /'.. ~ , Approval date Form 10-401 (HRE) PD/PD20 R,=u 7-1-Rfl Directional Survey required I APl number j~YES I--]NO I 50-- ~L~-'L / SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE 5anuary 16: 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2U-2 installed and tested upon completion of the job. 2U-2 will be the sixth well drilled on the pad. It is 60' away from 2U-1 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7070'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. RECEIVED 4 Alaska Oil & Gas Cons, Commission ~L Anu.orage · ' I ~ . -.t#C.. . ~ ' liIO~ 2 AL~ ~SK^ .... ASTPI~N WHi,PSTOI~K, ]: lC, I ...................................... ~ .............. q~ES-T--- EAOT-L ...... ; ........... 000 :) 000 ~000 ~000 i , SUR£AC:E LI:~,,AT Z OK, ~ $17! FSL. tlOIl' FI,IL [ .............. -8~o~--a~-..!~-,-qt~. ! . · ~ .......... ~. .. ¢000 5000 T AROET ~ CENTER THD-8~itO l~R~e~', T LOCATION: 1320 FSL. 1320 FEL, ~ SOUTH ~477 SEC. $. T! IN. !R gE ~ EAST ~87g ~ ~.TD : ~', ~ ...... ~ ........................ ..................... ........................ .............. .~.~..~_.~_. ........... ', ,~; ?L~''~ S 32'D.EO. 45 ;g-.I.~ .E ~ 5323~ (TO T~RGET) ; AlasKa Oil & Gas Cons. AQc}~or~g~ · . · . 100 500 · . . 600i 7OO 800 9O · i Surface Oivelt. r~- Svst~ i. 16"-2000 psi Tankco starting heaO. i 2. Tankco quicZ connect ass7, 3. 16" X 20" 2000 psi double stu~(se~ ac~aoter. i i I ~. 20" 2000 ~si drilling sDOOl w/lO" sloe outlets. I 5. 10" ball valves~ hyc)rauiically actuated, w/lO" lines to reserve ~it. Valves to omen auton~ticaily umon c)osure of annular preventer. · 20 2000 psi annular preven',e 7, 20" bell nipple. ~ ~ -- il -. m Maintenance & Operation i. Upon initial installation close 8nnular oreveeter 8nd verify that ~ali valves nave opened ~r~oer!y. 2. Close annular Dreve~ter and ~io~ air through civet.er lines every !2 hours. Close annular preventer in the event t~a: Gas or f~id ~tow :o surface is OetecteC. i~ necessary, manually overrioe ano close bail valve to ~owinc Civerter line. Dc not ShUt in well unoer any c~-cumstances. '. 6" Conouctor Alaska Oil & G;~s Cons, T 3. ~' - ~P~I x 13-5/8' - 5CO0 ~I ~x:)~;) Si:K33. 4. 13-5/8' - ~ ~I ~I~ ~ KILL ~I~ 1~/8' - ~ ~I ~E ~ ~I~ ~ ~ T~, 7. 1~5/B' - ~ ~I ~~ > DIAGI~ #~ 5000 ,~! Ex:J~RA BOP STAO,i AC'O.IVU~ATC~ CAPAC~'~ .-EST I. Q-~CX ~ FILL LEVEL WITH NYICP~IC ~..UICX 2. ~ TMAT ~ATIiiI~ ~:m~L~___~ IS ~ ~I ~FITI~ ALL LI~TS N;~ CLOSED IS 45 5E~ C3.0Slh[~ TIIW~ AhD t2(1:1 I:~jI ~i)W~klhll~ · I~'-5/8' 50~ STACK ~$T m i. FILL ~ ST,/~4X AN:) ~ NI~INrlFCI.~ ~iCZT!-I. AI4Cg'.!C DIESI[L. 2. C-.ECl< Tl-ii' ~4_L LOtSX ~ 50:2E~5 IN ~L~ ~ F~LY ~~. ~T TEST ~ IN ~~ ~TH ~I~ JT ~ ~ !N L~ ~~ 3. ~ ~ ~~ ~ ~ KILL ~ ~ ~ KI~ ~ ~ -~. 8. ~N T~ ~!~ ~ ~ ~ ~ mI~ ~. ~T ~PI~ a~ TO ~ ~I ~ ~ ~I. 9, ~N ~TT~ ~i~ ~ ~ ~ ~~ ~ ~ lO. ~ ~I~ ~ ~ T~T TO ~ ~ ~ ~I. II. ~N ~I~ ~ ~ ~~ ~T ~ ~ ~ 12. ~ST ~I~ v~ ~Y, ~Y ~ ~!~ PI~ ~E~ v~ ~ l~i~ ~ TO ~ ~i ~ ~ ~I. CHECK LIST FOR NE~ WELL PEI~flTS Company ~c~ ITEH APPROVE DATE (1) Fee , · (2) Loc (/thru 8) Lease & Well No. YES NO 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ...... 4. IS well located proper distance from other wells ..::...: : ii i!!:::'~ " 5. Is sufficient undedicated acreage available in this pool ~.i : .. 6. Is well to be deviated and is wellbore plat included~ ~ ~ ..... ii~ ..... 8. Can permit be approved before ten-day wait ~ ............ e 10. 11. 12. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed e..®,..e®,.®..®.ee.e..e®eeeeee.®..® Is the lease number appropriate ..................................... (s) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. Geology:z,~Engineerin~: HWK ~ LCS '7_~','~ BEW J ' ,z.F .-UTu rev: 10/29/84 6. CKLT Is conductor string provided .............. 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 gi~e adequate safety in collapse, tension and burst'"~-~ Is this well to be kicked off from an existing wellbore ........... .. - Is oldwellbore abandonment procedure included..°n.10-403' Is a diverter system required ...................................... ~.,,~ A~.e:me~s.~a~.y..d~~.,'of~.~div~r~er'.~and BOP.'..~qutpmen~"at~ached ,,... Does BOPE have sufficient pressure rating - Test to ~'~ psig :~ ~ Does the choke nmnifold comply w/API RP-53 (Feb 78) Is the presence of H2S gas probable ee.elel®e.eee..e®.ee®eeee.eee.®~e REMARKS Additional requirements //~J~ , eeeeee~e.e.eee, ce. e~eeeeeeeeeee®eeee e.®.®..®® POOL CLASS STATUS AREA NO. SHORE ,. 27. [ o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. .. No special 'effort has been made to chronologically organize this category of information. LVP 010.wO~ VE~IFICAq"IDN LIS~ING PAGE, ** RFEt, NEADFR ** SERVTC~ NA~E I~D~T DATE ~9510~/~1 ORTG~N : REMb N~F .. : CONTiNUAtION # PREVIO~S R~EL ** TAPE MEADMR ** SERVICE NA~E :EDIT ORIGIN :0000 TAPE N~M~ :~094 COMT~N~!A~I~N # :01 ~R~VTOUS TAP~ ** FILM HEADER ** $£~VICM NA~E VER$IO~ # DATE : MA×IMU~ LENGTH : lO~m, PREVIOUS FILM : ** INFORMATION RECORDS TYPE CATE SIZE CODE CN .~ AR~O ALASKA INC 000 000 016 065 W'N : ~U 2 000 000 004 0,65 ~N :i~: ~, ,U.,P A R u',< ooo ooo 0o8 065 ~AN'G~ 9~,' 000 000 002 065 TOWN' ~ 000 000 004 065 SECT: 000 000 002 0:65 COUN: N,SbOP~ 0O0 000 010 065 ST~. ~L~$~A 000 O0 006 06:5 000 O0 O03 065 ** · $CHLUWMERGER LVP Ol.n.MO~ VE~IF'ICATION LISTING PAGE 2 * ~L~S~A CO~PUTI~G COMPANY : ATLANTIC RICHFI~bD COMP&NY WELL = 2U-2 FIELD = KUPARtIK COUNTy = NORTH SLOPE BOROUGH STATE = ALASK~ JOB NUMB~R~AT ~CC: 70094 RUN #ONE, DATE LOGGED: l~-FER-85 LDP: CO~ENTS: SFL ~ND ILF CURVES INVALID DUE TO TOOL ~LFUNCTION ILD CU~V~ ACCEPTED, NO BACKUP RUN AT CUST, CASING = 9~675" ~ 36.00' - RIT SIZE x 8,5" TO 8698' ~E FLUID = XoC- POLY SITY = ~..~ LB/G DM VISCOSITY = 39.0 S RM' = ~.~0 @ ~0.0 DF PH = 0,~ ~MC =~ ~-, 0 ~-0,0 DF FLUID LOSS : 5.P C3 RM AT BMT = 1.752 ~ 138,0 DF MATRIX SANDSTONE ******************************************************************************* LVp OiO,HO~ VERIFICATION b~STIMG PAGE 3 * * * DUAL INDUCTION SPHER~CAbI,Y FOCJMED bOG (DIb) * * FORMATYON DENSITY COmPeNSATED LOG (FDN) * * COMPENSATED NEHTRON LOG , , * · , · , , * * , , , ~ , * , * * , , ,. , , * · , * , * * ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 6~ 8 4 7] 60 9 4 65 ,lin 16 1 66 1 0 1 66 0 DATU~ SPECIFICATION.BLOCKS ' W' ~ ~NMM SFRVICE SERVICE UNIT APl AP! APl API ILE SIZE SPL REPR ID DEPT Sp DIL ~R ~R FDN CALl, FDN RHOB FD~ DRHO FDN NRAT FDN RNRA FDN ~P~I FDN ORDER # FT 4 O0 , 0 0 OH~t O0 '{200 460 44 10 Ol 0 ~V ~AP! O0 310 O1 0 0 4 ~API O0 310 01 0 :0 4 IN O0 280 O1 0 0 4 ~/C3 O0 350 02 0 0 4 420 :0! 0 4 DO 000 O0 0 0 4 PU O0 890 O0 0 0 4 CPS O0 ~30 31 0 0 4 PROCESS CODE '1 68 68 00000000000000 68 00000000000000 1 68 00000000000000 I 6B 000~0000:0~0000 I 68 000 00000 0090 i 68 000000000000:00 1 68 00000000000000 bVP ol.O,W02 VERIFICATION bTS~IMG PA~E 4 wCNL FDN CPS O0 330 3O 0 ** DATA DEDT GR DEPT ~R NR~T DEPT ~R NRAT PCNL DEPT GR MR~T FCNL DEDT 'NRA2 FCNL EDT ~R NRAT FCNL DEDT ~R NR~T N~AT FC N'I,,, DEDT ~R FCNL DEP! NRAT FCNL 8717 0000 .TbP 2 . 0 PN~A -~ 83 8750 8700 0000 TLD -14!2031 CAT,I ~ 4160 DNRA -183 ~750 8aoo.oooo Ibm ~02.3750 CALI 3.2363 RN~A 584.00n0 8500 384 750 CAbi 7 01 ~ RNRA 00 8~00.0000 9].1250 CALl ...0234 RNRA 686.5000 8300 88 72:'~' 8200 ,0000 TLD .6875 CALI ,~555 RNRA .5000 ,0000 ILD ,0625 CALl .8574 RNRA i0000 8100.0000 78'2500 CALl 1t4~.351.6 DNRA .0000 SO00.0000 ~bD J6~ ~ ALI . NRA 0000 7900.0000 .IbD 116.1250 CAi.,! 3.5105 RN~A 417;0000 2 8809 SP 8:5000 RHOB 2.6270 ~.PH! 7266 RHOB 216270 NPHI 2 89~6 SP O:0000 RHOB 3.4473 NPH! 2.5957 SP 9,2656 RHOB 4.=1914 NPHI 5.5469 SP ~.2500 ~H. OB ...2441 PHI 3.2168 NPHI 1'72 0.1094 SP 9.5547 RHOB 2.4883 NPHI 3.67'38 SP 9.4.453 RHO 3.3848 NPH~ 2,6270 BP g.,~2:66 RHOB ].g180 MPg1 0 4 I 68 '89.31~5' GR -32768,0000 DRBO 25.1465 NCNb -85'.8750 ~R -32768.0000 DRHO 24.8535 NCNb -63..8750 GR 2 4766 DRHO 37:5977 NcNb -52,~375 ~R 754 DRHO .47.3145 NCNb -49.03.t, 3 GR 3],3945 DRHO .3496 NCNL · 4:7 DRHO 30.9570 ~CNL -44.0938 GR 2,4160 DRHO 30.3711 NCN5 -52,0625 GR 2.,8613 DRHO 22.R51.6 NCNL GR DRHO NCNb -4q, 656 GR 9;~,326:1~ DRHO 41 ,6992 MCN[~ 00000000000000 -14.2031 -32768,~000 -483. 500 -14 ~031 -32768! 000 -483 2500 102:3750 0:1421 2014.0000 97.8750 92.1250 222~ '031'7 .0000 8~,6875 2334 ,0098 .0000 81,0625 0,0303 2520'~0000 2R5~'0:48'8 .0000 162.';500 , · 0,06 4 9 2021,0000 I, 160, 1250 .02:05 1634.0000 5VP 010.~02 VEPI?ICA?ION LISTING PA~E 5 ~gEPT 7700,n000 YLD GR 234'6250 CALI NRAT -999 2500 ~NPA DEPT 7600.0000 ILD GR 207 0000 CALl URaT -990]~500 ~N~ ~CNL -999.2500 DEPT 7500 aO00 GR 1.25:6875 CAY, I NRAT -~9~.~500 WCN'L -990.~500 DEPT 7400 0000 ~R .116156~5 ChL! NR~T ~99 ~500 FCNL -999 ~500 DEPT 7300.0000 ILD GR 113.4375 CALl R~ ,,999 2500 RNRA FCN~ .~90'.2500 DEPT 7~00.0000 I[~D GR 11~.,3125 CALl WRAT -999.2'500 RN~A ~CN[~ -999.~500 DEPT 7100.0000 ILD GR 1,21..31~5 CALI ~RAT -999,2500 RNRA ~C~b -~9~.~500 DEPT 7000 0000 IbP GR 1,45~6250 CALl NRAT -o99.9500 RNgA FCNL -999.~500 NRbT DEPT ~[RAT 6800.0000 -999.2500 CALl ~NRA 4.30~6 SP 9.35e4 RHOB -99g.~500 ,P~! 9...5498 SP 9 42~9 RHOB -99~:2500 ~-'P}qI 3.8691 9 8359 RHOB ,=, ~ p. 5oo ~.7051 SP 9.8594 ~HDB -099.~500 NP}{I 4.6875 SP 9,7656 RHOB -99q,.~500 NPHI 5977 SP ~0000 ~HOB -099.~500 NP~I 3.~793. SP, g,q6B7 RHOB '~99"~500 NPHI 3.1719 SP 9.4609 RHOB -090.,~500 NPMI 5808 SP ,-990..~500 NPHI 3.86~3 SP. 3.941,~4 SP -999 2500 ~H~B -990~500 NPHI -50.0938 ~R -999.2500 DRHO -099.~500 NCN5 -53 9687 GE -999:~500 DRHO -999.2500 ~C~b -66.3125 GR -999.2500 OReO -999.2500 NCNb -63.6563 GR -999.~500 DRHO -990.2500 NCN~ -60.1. 250 GR -999.~5500 DRXO -099. O0 NCNb .-66,4375 GR 999.2500 DRHO -990.2500 NCNb -6:7, .-999.2500 DRHO qg~.~:500 NCN.[~ -60.3125 GR -099..~500 DRHO -099.2500 NCNb -65.~500 GE -999,2500 DRHO -999-~500 NCNb -69 .'3!50 GR ,ago · '2500 DRH:O -999o2500 NCNb -69.7500 ~R -990,2500 DR~O -~9'2500 ~45.~500 -990.2500 -999.2500 -9 9.~500 -999.~500 207.0000 -999,2500 -999'2500 125,6875 -999,2500 '999.2500 116.5625 -999,2500 -999,.9500 113,4375 -099'2500 -999.2500 112, -999 O0 -999 1.21,3125 -999,2500: -999.2500 .1.: 45, 999 , 117,437 ,'999,950~ -o99,2500 121. =5000 -099,2500 '999,2500 LVP 010.!402 VEPIFICATION L.TSTING PAGE 6 FCNL -499,2500 DEPT ~700.0000 lbD qR 999.~500 CALl NRAT -999.2500 RNRA FCND -99g.~500 _n~,p? 66oo o0o0 TUn C,R -099:9.500 CALl ~RAT -999,2500 ~NRA FCNb -o99,~.500 DEPT ~00 0000 T. bD C,,R -,.. 99: 9~500 CALl NRAT -999.2500 RNRA ~'CNI~ -999.9.500 DEPT 6300.0000 GR -999..9500 CALl NRAT -999,~'5~0 ~N~A FCIC5 -999'~5 0 DEPT 6100.0000 R -990.2500 RAT -999.~500 ~CNL -999.~500 DEDT 6000 000~ ILD GR -999~50v NRAT -999..2.500 RNRA FCNL -99~.~500 DEDT 5800. 0000 TLD ~R -999,~500 CALl FC'NL -q99.2500 DEPT 570 0000 IL, D C A L 1 ~500 3.9941 SP -090.2500 ~HOB -099.2500 NPHI 4,5000 SP '999.2500 RHOB -Qgo.25no NPHI 3965 SP -990:~500 RHOB ..~500 NPHI 1.9834 SP -999.2500 RHOB -999.~500 NPHI t..8428 SP ~q99.,,~500 q9g.~500 NPH][ 2.i1211 =99~,2500 RHOB -99 .~500 '2 5137 SP -999:9500 RHOB -qgg, 2500 NPH1 2,9941 SP .-99,9.25o0 RHOB 999.9,500 NPHI -,.999: ~5~,~ -999. ~500 ~PMI 2:7832 SP -999 :~500 RHOB -999,.~500 NPHI 8340 -81.3125 GR -990.9500 DRRO -99~.2500 NCNb -74.8750 ~R -999.2500 DRHO -qgq.2'500 ~CNL -6~ 6875 GR -99 ~2500 DRHO -990.2500 NCNb -65.1875 OR -,999,~500 DRMO -999.~.500 NCNL -64,4375 GR '999.~500 DRMO '999.~500 NCNb -67.31,~5 GR -099,2500 DRHO -999~500 NCN'~ -68,4375 g'~HO -999-~'500 999.2500 N C N b -64,5000 GR -999,.2500 DR.O 'ggq,~500NC, N~ '7..,.~,1250 ~.R -999,2500] DRHO -999,2500 NCNb -70,0000 GR -999,2500 DRHO "999,~500 NCN.b -70,6.250 gRRH0 '999 ' ~500 145,1250 --~99.,.9500 -999.2500 158.3790 -999 2500 -999:9500 146 3750 -999..2500 135.7500 -.999,2500 099.~500 1.2~,2500 .2500 -999,2500 107' -999 -099 ,149,8750 999,2500 -09q.2500 1.03, ~0 -999, '999. ~0 .141,,~500 999,2500 -999,2500 113:' :8125 ~99~,2500 -99~ "2500 .122,1875 999.2500 LVP OiO,MO~ VERIFICATION LTSTING PA~E 7 NRAT -~99.2500 RNRA FC~L -999.7500 600 0000 TLD soo FC~L -999.2500 DEPT 5500 0000 T.LD GR -99~500 CAt,! NRAT -999 2500 FCNL -~99~500 DEPT 5400'0000 TLD. GR -999 2500 ~R~T -99~500 WCNL -999.~500 DEPT 5300.0000 ~R :o9o.~500 OALI NR~T 999.~5o0 ~N~A FCNL -q99.~500 GR -999 2500 CALl ~RAT -~99~500 ~CNL -999.~500 EPT 5~.00,0000 R -999,~50'0 NRAT -999,~500 FCN5 '999°~500 D~:PT ~000.0:000 ~R .99~,~500 CALI gRAT 999°~500 FCNL -999.~500 DEPT ~900.,0000 ~R 999,~50() CALI NRAT -999.~500 FCNL -999.~500 DE ~ 4~00 0000 GR -999i2500 CALI NRAT -~99 ~500 wC~L -999.~500 DEPT 4700. O0 ~R -999.~ CAL O0 NRAT -999.~5~ RNRA FC.b -999.~5 oo.oooo -99q.2500 2,~672 ~P. -999 ~5nO ~HOB 3.7480 SP.. -99~o9500 RHOB ~°9375 -999,~500 RHOB -99q.~500 3 1172 SP -q9q:~500 RHOB -~99.:~5~0 NPH1 ~.37R9 -999,~500 -999,}500 NPHI 3,609~ SP -999,.~§0 -999o~500 NPHI 3,1855 999,~500 . 3,.5~76 SP 999,<~500 -999.'~500 NPHI 'soo 4.0664 -999.2500 -99~.2500 NPHI ~.6094 -999°2500 NCNL -78.:3750 GR -999. 2500 DRH0 -99~. ~.500 NCNL '74.8125 GR -999,2500 DRHO -999.2500 NCNL -73.6250 GR -999,}500 DRHO -990,2500 ~]CNb .~'11 3750 GR 99:.2500 DRHO -999.2500 NCNb '73.06~5 GR 999,2500 DRHO :999,2500 NCNL -999' ~500 -q99.~500 NCNX~ -7~..~250 GR -999,2500 DR~O -q99.~:500 NCNL -70.~750 ,~ -999,2500 ~HO '999.2500 NCNI~ '69.56~5 ~R -99~o~500 DRHO '99~.~500 -76,9375 GR -999-~500 DRHO -99q.2500 NCN~ -71.1250 GR -999,2500 120.,2500 -999.2500 -q99,2500 93,9375 -999..2500 -999,2500 ~1'13 1250 12~. 125 -99 , 500 -999. 500 I02,~250 '999, 500 -999'2500 999.~500 ~1~,3125 ,.999,2500 -P:9'9, ~500 91:, 0000 "999, ~.50~ -999,~.50 101,0625 -999,2500 'q99,~500 ~07.3i25 LVP O10,W02 VERIFICA~ImN L'T$?ING PA~E 8 GR -999.2500 CALI MR~T -990.2500 RNPA FCNL -990.2500 -999.2500 RHOB -o99'2500 NP~! DEPT 4500.0000 TbD GR -999.~500 CALl MRAT -999.~500 RNRA wCML -999.~500 8.5547 SP 4.~188 -999.2500 -999.~500 DEPT 4300 0000 IUD GR -~99i~500 CALl NRAT -999 ~500 RN~A WCNL -o9~ ~500 3,6621 SP -999.~500 RHOB '999.~500 ~'P~I D.EPT 4~00. 0000 Yb.O GR -o99.~g0 CALl ~iR~T -~99, 0 RNRA FCNL -999. ~500 5,9258 SP -99g,~500 RHOB -999..~500 NPHI DEPT 4100 ~R -999 MR~T -999 FCNL -999 OOnO TLD 2500 CALI 2500 RNP~ 2500 4.0664 SP -999.~500 RMOB -999.2500 NP~I DEOT 4000.0000 TLD GR -999.2500 CAbI WRiT -~99,~500 RN~A FCNL -999.~500 5.2031 SP -999.2500 RHOB -999.7500 NP~i DEPT 3940 5000 ILD MR~T -.999,~500 RNRA FCNL ~99..2500 12 ..1016 SP -999:~500 RHOB -999.95n0 NPHI ** FIbE TRAILER * ~ILE NAME :E[)~'~ .001 SER'VICE NA~E : VERSION# : ~ATE ~ WILE TYP~ : NEXT FTL~ MA~E : EOF ** TAP~ TRAILER ** SERVICE NAME :EDIT -~99.2500 DRHO -999.2500 NCNb -84.31~5 GR -999.2500 DR~O -990,2500 UCNb -71,0000 GR -999.2500 DRHO -990.2500 ~CNb · .70 0625 -999:~500 -999, ~500 NCNb -69,5000 GR -999,2~.g0 DRHO ..999.~ O NCNL -69 9625 -§99. 500 -999 2500 -71,0625 .999. oo ,,999.~500 -57 .i 875 -999,2500 -99Q .~500 ~R ~RHO ~ICN L DRHO ~R D.:RHO NCNb -999 2500 107 1875 .999:2500 -999,2500 92 2500 -999!2500 -999 ~500 113,~1~5 -999, 500 -999,2500 .93 .2500 :999.25oo ,8750 ,2500 'ggg,2500 . 60,1875 9gg. '2500 L'~m'l lml ii1 ii:-] l_,_' [:.] ~ bVP 010,~0~ VERIFICATION LIS?I~!G ~AGE 9. DATE :R51021~1 ORIGIN :0000 ?APE NAME :0094 CONTINUATION # :01 NEXT TAP~ ~TAWE : COMMENTS : ** RME[, TRAILER ** SERVICE NAME :EDIT DATE RIGIN CONTINUATION # :01 ~EXT EOF EOF
