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183-020
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 183-020/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1G-05 KUPARUK RIV UNIT 1G-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1G-05 50-029-20908-00-00 183-020-0 W SPT 6115 1830200 1529 2400 2400 2400 2400 100 110 110 110 4YRTST P Sully Sullivan 7/1/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1G-05 Inspection Date: Tubing OA Packer Depth 350 1860 1820 1815IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230704051755 BBL Pumped:1.5 BBL Returned:1.5 Friday, September 1, 2023 Page 1 of 1 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: 1830200 E-Set: 34054 10/07/2020 Abby Bell MEMORANDUM TO: Jim Regg P.I. Supervisor��%�' FROM: Bob Noble Petroleum Inspector I Well Name KUPARUK R1V UNIT IG -05 Insp Num: mitRCN200811135309 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1G-05 KUPARUKRIV UNIT IG -05 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-20908-00-00 Inspector Name: Bob Noble Permit Number: 183-020-0 Inspection Date: 8/9/2020 Packer Well 1G-05 Type Inj W TVD PTD 1830200 Type Test' SPT iTest psi BBL Pumped: 1.1 iBBL Returned: Interval l OTHER --- - -,P/F Notes' MIT -IA post patch, Sundry #320-284 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6115 Tubing � 2300 2300 2300 2300 " -- _ — 1529 IA 625 1720 1680 1680 ' 0.7 OA 300 - 305 305 305 Monday, August 17, 2020 Page 1 of I 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 10071 feet N/A feet true vertical 7056 feet N/A feet Effective Depth measured 9244 feet 8810 feet true vertical 6442 feet 6115 feet Perforation depth Measured depth 8976 - 9378 feet True Vertical depth 6234 - 6532 feet Tubing (size, grade, measured and true vertical depth)3.5 L-80 9189 6392 Packers and SSSV (type, measured and true vertical depth)FHL Retrievable 8810 MD 6615 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: 8/11/2020 Contact Phone: 183-020 5002920908000' ADL0025640 KRU 1G-05 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: Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk/ Kuparuk River Oil Plugs measured Junk measured Burst Collapse Conductor 50 16 80 80 N/A N/A N/A Production 10041 7 10071 7056 N/A N/A Surface 2494 10.75 2523 2278 N/A ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 320-284 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 ----- 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 10:00 am, Aug 11, 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: 2020-08-11 09:26:33 Foxit PhantomPDF Version: 10.0.0 jan.byrne@cono cophillips.com SFD 8/12/2020 RBDMS HEW 8/11/2020 10,086 7,067 DSR-8/11/2020 SFD 8/12/2020VTL 8/12/20 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 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 report for Sundry 320-284 well operations from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 1G-05 (PTD 183-020). 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: 2020-08-11 09:26:02 Foxit PhantomPDF Version: 10.0.0 jan.byrne@c onocophillips .com Submit to: OOPERATOR: FIELD /UNIT /PA D: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1830200 Type Inj W Tubing 2300 2300 2300 2300 Type Test P Packer TVD 6115 BBL Pump 1.1 IA 625 1720 1680 1680 Interval O Test psi 1529 BBL Return 0.7 OA 300 305 305 305 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al Int egr i t y Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MIT-IA post patch per Sundry # 320-284 Notes: 1G-05 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1G Pad Bob Noble Hembree / Hills 08/09/20 Form 10-426 (Revised 01/2017)MIT KRU 1G-05 08-09-20.xlsx Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,412.0 6/6/2015 1G-05 lehallf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced DV, Pulled Plug, and installed Tbg Patch 7/27/2020 1G-05 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 29.7 Set Depth (ftKB) 2,523.9 Set Depth (TVD) … 2,278.4 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description L1-02 WINDOW OD (in) 7 ID (in) 6.28 Top (ftKB) 9,254.0 Set Depth (ftKB) 9,261.0 Set Depth (TVD) … 6,445.2 Wt/Len (l…Grade Top Thread Casing Description L1 WINDOW OD (in) 7 ID (in) 6.28 Top (ftKB) 9,280.0 Set Depth (ftKB) 9,285.0 Set Depth (TVD) … 6,463.0 Wt/Len (l…Grade Top Thread Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 29.9 Set Depth (ftKB) 10,071.0 Set Depth (TVD) … 7,055.9 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING - 2015 WO - UPPER String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.4 Set Depth (ft… 9,189.3 Set Depth (TVD) (… 6,392.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.4 26.4 0.10 HANGER McENVOY TUBING HANGER 2.992 8,778.9 6,093.3 45.96 LOCATOR LOCATOR 2.970 8,779.3 6,093.6 45.96 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 8,809.6 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 8,831.8 6,130.4 45.13 NIPPLE OTIS X NIPPLE 2.812 8,966.6 6,227.0 43.34 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 8,971-ft 2.992 8,986.3 6,241.3 43.06 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 9,045.5 6,284.8 42.27 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 8rd 9,055-ft 2.992 9,061.4 6,296.6 42.06 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 9,086.8 6,315.6 41.72 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 9,090-ft 2.992 9,106.6 6,330.3 41.58 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 9,182.3 6,386.8 41.90 LOCATOR LOCATOR 2.990 9,183.1 6,387.4 41.90 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 Tubing Description TUBING - 2015 WO - LOWER - 3 1/2" x 5 1/2" @9222 String Ma… 5 1/2 ID (in) 4.95 Top (ftKB) 9,183.0 Set Depth (ft… 9,312.0 Set Depth (TVD) (… 6,482.9 Wt (lb/ft) 14.00 Grade H-40 Top Connection STC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,183.0 6,387.3 41.90 PACKER BAKER 85-40 F1 PERMANENT PRODUCTION PACKER 4.000 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 9,191.3 6,393.5 41.93 XO Reducing Crossover sub 2.990 9,210.2 6,407.6 42.03 NIPPLE OTIS X NIPPLE 2.812 9,222.1 6,416.4 42.09 XO Enlarging Vented/Ported Cross-over 3-1/2 EUE 8rd x 5-1/2" STC BxP 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,630.0 5,370.1 49.81 P2P UPPER PACKER (PATCH) P2P (UPPER) 2.72" OD (4.01' OAL) 7/27/2020 1.620 CPP35252 7,634.5 5,372.9 49.85 SPACER/ANCH OR LATCH 2 1/16" P-110 Spacer Pipe and Anchor Latch Assembly (15.55' OAL) 7/27/2020 1.590 CPAL35143 7,644.0 5,379.1 49.93 TUBING LEAK TUBING LEAK AT 7644' 5/9/2020 2.992 7,650.0 5,383.0 49.99 P2P LOWER PACKER (PATCH) 2P2 (LOWER) 2.72" OD 4.01' OAL 7/27/2020 1.620 CPP35206 9,250.0 6,437.1 42.25 WHIPSTOCK Baker Gen II Whipstock, TOWS at 9,250', BOWS at 9,262.97', Set 30° ROHS, RA tags 7.35' down from TOWS 10/3/2015 9,277.0 6,457.0 42.40 WHIPSTOCK 3 1/2 " X 5 1/2" GEN II WHIPSTOCK 6/6/2015 9,509.0 6,628.6 41.65 FISH 1.5" CV Empty Pocket; Fell to Rathole 8/7/1987 8/7/1997 9,520.0 6,636.8 41.62 FISH 1.5" OV Lost in Hole 1/25/1994 1/25/1994 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,976.0 9,050.0 6,233.8 6,288.2 C-3, C-4, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 9,095.0 9,131.0 6,321.7 6,348.6 C-1, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 9,332.0 9,336.0 6,497.6 6,500.5 A-5, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 9,348.0 9,378.0 6,509.4 6,531.5 A-4, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,843.2 2,490.3 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2015 1G-05, 7/28/2020 9:39:14 AM Vertical schematic (actual) PRODUCTION; 29.9-10,071.0 FISH; 9,520.0 FISH; 9,509.0 IPERF; 9,348.0-9,378.0 IPERF; 9,332.0-9,336.0 L1 WINDOW; 9,280.0-9,285.0 WHIPSTOCK; 9,277.0 L1 LINER; 9,275.8-12,534.0 L1-02 WINDOW; 9,254.0- 9,261.0 WHIPSTOCK; 9,250.0 L1-02 LINER; 9,244.7-10,649.0 SLOTS; 9,245.5-10,649.0 NIPPLE; 9,210.2 SBE; 9,186.3 SEAL ASSY; 9,183.1 PACKER; 9,183.0 LOCATOR; 9,182.3 GAS LIFT; 9,145.9 IPERF; 9,095.0-9,131.0 GAS LIFT; 9,073.0 PACKER; 9,061.4 IPERF; 8,976.0-9,050.0 GAS LIFT; 8,946.8 GAS LIFT; 8,885.3 NIPPLE; 8,831.7 PACKER; 8,809.6 PBR; 8,786.3 SEAL ASSY; 8,779.3 LOCATOR; 8,778.9 GAS LIFT; 8,722.3 GAS LIFT; 7,828.9 P2P LOWER PACKER (PATCH); 7,650.0 TUBING LEAK; 7,644.0 SPACER/ANCHOR LATCH; 7,634.5 P2P UPPER PACKER (PATCH); 7,630.0 GAS LIFT; 6,629.5 GAS LIFT; 4,963.2 GAS LIFT; 2,843.2 SURFACE; 29.7-2,523.9 CONDUCTOR; 30.0-80.0 HANGER; 26.4 KUP INJ KB-Grd (ft) 29.99 Rig Release Date 2/17/1983 1G-05 ... TD Act Btm (ftKB) 10,086.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292090800 Wellbore Status INJ Max Angle & MD Incl (°) 56.37 MD (ftKB) 4,600.00 WELLNAME WELLBORE1G-05 Annotation Last WO: End Date 3/24/2015 H2S (ppm) DateComment SSSV: NONE 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 2 4,963.2 3,737.0 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2015 3 6,629.5 4,739.9 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/27/2015 4 7,828.9 5,496.1 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/27/2015 5 8,722.3 6,054.4 CAMCO RDO-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/26/2020 6 8,885.3 6,168.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 7 8,946.8 6,212.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 8 9,073.0 6,305.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/8/2015 9 9,146.0 6,359.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 1G-05, 7/28/2020 9:39:15 AM Vertical schematic (actual) PRODUCTION; 29.9-10,071.0 FISH; 9,520.0 FISH; 9,509.0 IPERF; 9,348.0-9,378.0 IPERF; 9,332.0-9,336.0 L1 WINDOW; 9,280.0-9,285.0 WHIPSTOCK; 9,277.0 L1 LINER; 9,275.8-12,534.0 L1-02 WINDOW; 9,254.0- 9,261.0 WHIPSTOCK; 9,250.0 L1-02 LINER; 9,244.7-10,649.0 SLOTS; 9,245.5-10,649.0 NIPPLE; 9,210.2 SBE; 9,186.3 SEAL ASSY; 9,183.1 PACKER; 9,183.0 LOCATOR; 9,182.3 GAS LIFT; 9,145.9 IPERF; 9,095.0-9,131.0 GAS LIFT; 9,073.0 PACKER; 9,061.4 IPERF; 8,976.0-9,050.0 GAS LIFT; 8,946.8 GAS LIFT; 8,885.3 NIPPLE; 8,831.7 PACKER; 8,809.6 PBR; 8,786.3 SEAL ASSY; 8,779.3 LOCATOR; 8,778.9 GAS LIFT; 8,722.3 GAS LIFT; 7,828.9 P2P LOWER PACKER (PATCH); 7,650.0 TUBING LEAK; 7,644.0 SPACER/ANCHOR LATCH; 7,634.5 P2P UPPER PACKER (PATCH); 7,630.0 GAS LIFT; 6,629.5 GAS LIFT; 4,963.2 GAS LIFT; 2,843.2 SURFACE; 29.7-2,523.9 CONDUCTOR; 30.0-80.0 HANGER; 26.4 KUP INJ 1G-05 ... WELLNAME WELLBORE1G-05 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7.If perforating:8.W ell Name and Number: W hat Regulation or Conservation Order governs well spacing in this pool?N/A W ill planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10071'2978'N/A Casing Collapse Conductor Surface Production Packers and SSSV Type: PKR:PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/5/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity & Compliance Specialist Jan Byrne / Dusty Freeborn n1617@conocophillips.com Packers and SSSV MD (ft) and TVD (ft): 10041' 80'80' 10071' 50'16" 10.75" 7" 2494' Length TVD Burst 9189' MD 2278' 7056' 2523' 7056 9244' PRESENT WELL CONDITION SUMMARY 6442'8832' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025640 183-020 P.O. Box 100630, Anchorage, Alaska 99508 50029209080000 ConocoPhillips Alaska, Inc. KRU 1G-05 Kuparuk River/Kuparuk River Oil COMMISSION USE ONLY Authorized Name: N/A Tubing Grade:Tubing MD (ft): 6234-6288, 6322-6349, 6498- 6501, 6509-6532 Perforation Depth TVD (ft):Tubing Size: 8976-9050, 9095-9131, 9332- 9336, 9348-9378 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7224 Baker FHL, Baker FHL, Baker 85- 40 F1 N/A 8810 MD & 6115 TVD, 9061MD & 6297 TVD, 9183 MD & 6387 TVD N/A Size Authorized Signature: Jul-20 3.5" Perforation Depth MD (ft): L-80 mmm wnnns 1 66 t t chhhhhhhhh c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:53 am, Jul 06, 2020 320-284 Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.07.05 16:11:54 -08'00' SFD 7/6/2020 SFD 7/6/2020 X , ADL 0025647 10-404 X DSR-7/6/2020 10,086' SFD 7/6/2020 7,067' VTL 7/13/20 Comm 7/13/2020 dts 7/13/2020 JLC 7/13/2020 RBDMS HEW 7/16/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 5 July 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1G-05 (PTD 183-020) to install a retrievable tubing patch over a known tubing leak. Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.07.05 16:08:49 -08'00' KRU 1G-05 (PTD# 183-020) Description Summary of Proposal Well Work Justification & Objectives (and date required if appropriate): A LDL was performed on 1G-05, which identified a tubing leak at 7638'. A tubing patch needs to be installed in order to regain TxIA integrity and return the well to injection. DO NOT PERFORM WORK UNTIL APPROVED 10-403 HAS BEEN AQUIRED Steps: 1. Have jumper line hooked from IA to available flow line. 2. Set catcher on XX plug at 8832'. 3. Pull DMY valve from station #5 (8722'). 4. Pump 240 bbls inhibited SW and 75 bbls diesel down tubing taking returns off the IA. U-Tube to freeze protect T & IA. 5. Reset DMY valve in station #5 (8722') 6. Pull catcher and XX plug from 8832'. 7. Set lower 3.5" P2P mid-element at 7650' 8. Set test tool in 3.5" P2P at 7650' and perform CMIT-TxIA to 2500 psi. Record initial, 15 min and 30 min pressures. A. If CMIT-TxIA passes, pull test tool and proceed to step 9. B. If CMIT-TxIA fails, troubleshoot failure mechanism. 9. Set anchor latch, spacer pipe and upper 3.5" P2P mid element at 7630' (ensure elements and slips are above collar at 7633') and perfrom MIT-IA to 2500 psi. Record initial, 15 and 30 min pressures. A. If MIT-IA passes, rig down and turn well over to operations. SW MIT-IA will be required when returned to injection. B. If MIT-IA fails trouble shoot failure mechanism. Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag:smsmith 1G-05L1-02 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Set Tubing Plug & Identified Tbg Leak 5/6/2020 zembaej 1G-05 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 30.0 80.0 80.0 65.00 H-40 WELDED 1G-05 SURFACE 10 3/4 9.95 29.7 2,523.9 2,278.4 45.50 K-55 BTC 1G-05 L1-02 WINDOW 7 6.28 9,254.0 9,261.0 6,445.2 1G-05 L1 WINDOW 7 6.28 9,280.0 9,285.0 6,463.0 1G-05 PRODUCTION 7 6.28 29.9 10,071.0 7,055.9 26.00 K-55 BTC 1G-05 L1-02 LINER 2 3/8 1.99 9,244.7 10,649.0 6,424.6 4.60 L-80 ST-L 1G-05L1-02 L1 LINER 2 3/8 1.99 9,275.8 12,534.0 4.60 L-80 ST-L 1G-05L1 L1-01 LINER 2 3/8 1.99 9,700.7 11,451.0 4.60 L-80 ST-L 1G-05L1-01 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING - 2015 WO - UPPER 3 1/2 2.99 26.4 9,189.3 6,392.1 9.30 L-80 EUE 8rd AB Mod 1G-05 TUBING - 2015 WO - LOWER - 3 1/2" x 5 1/2" @9222 5 1/2 4.95 9,183.0 9,312.0 6,482.9 14.00 H-40 STC 1G-05 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 26.4 26.4 0.10 HANGER McENVOY TUBING HANGER 2.992 1G-05 8,778.9 6,093.3 45.96 LOCATOR LOCATOR 2.970 1G-05 8,779.3 6,093.6 45.96 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 1G-05 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 1G-05 8,809.6 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 1G-05 8,831.8 6,130.4 45.13 NIPPLE OTIS X NIPPLE 2.812 1G-05 8,966.6 6,227.0 43.34 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 8,971-ft 2.992 1G-05 8,986.3 6,241.3 43.06 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 1G-05 9,045.5 6,284.8 42.27 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 8rd 9,055-ft 2.992 1G-05 9,061.4 6,296.6 42.06 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 1G-05 9,086.8 6,315.6 41.72 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 9,090-ft 2.992 1G-05 9,106.6 6,330.3 41.58 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 1G-05 9,182.3 6,386.8 41.90 LOCATOR LOCATOR 2.990 1G-05 9,183.0 6,387.3 41.90 PACKER BAKER 85-40 F1 PERMANENT PRODUCTION PACKER 4.000 1G-05 9,183.1 6,387.4 41.90 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 1G-05 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 1G-05 9,191.3 6,393.5 41.93 XO Reducing Crossover sub 2.990 1G-05 9,210.2 6,407.6 42.03 NIPPLE OTIS X NIPPLE 2.812 1G-05 9,222.1 6,416.4 42.09 XO Enlarging Vented/Ported Cross-over 3-1/2 EUE 8rd x 5-1/2" STC BxP 2.990 1G-05 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 7,644.0 5,379.1 49.93 TUBING LEAK TUBING LEAK AT 7644' 5/9/2020 2.992 1G-05 8,832.0 6,130.6 45.12 2.81" XX Plug 2.813" XX Plug with fill extension(4' 1" OAL) 5/5/2020 0.000 1G-05 9,250.0 6,437.1 42.25 WHIPSTOCK Baker Gen II Whipstock, TOWS at 9,250', BOWS at 9,262.97', Set 30° ROHS, RA tags 7.35' down from TOWS 10/3/2015 1G-05 9,277.0 6,457.0 42.40 WHIPSTOCK 3 1/2 " X 5 1/2" GEN II WHIPSTOCK 6/6/2015 1G-05 9,509.0 6,628.6 41.65 FISH 1.5" CV Empty Pocket; Fell to Rathole 8/7/1987 8/7/1997 1G-05 9,520.0 6,636.8 41.62 FISH 1.5" OV Lost in Hole 1/25/1994 1/25/1994 1G-05 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 29.7 29.7 0.11 HANGER 9.950 1G-05 30.0 30.0 0.11 CONDUCTOR 15.060 1G-05 9,244.7 6,433.2 42.22 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 1G-05L1-02 9,254.0 6,440.0 42.27 Window 6.276 1G-05 9,275.8 6,456.1 42.52 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 1G-05L1 9,280.0 6,459.3 42.42 Window 6.276 1G-05 9,700.7 6,510.8 90.66 BILLET BAKER OPEN HOLE ANCHORED BILLET 1.000 1G-05L1-01 9,722.6 6,510.6 90.56 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.920 1G-05L1-01 10,746.7 6,545.2 88.53 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 1G-05L1 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 9,245.5 10,649.0 6,433.8 6,424.6 10/12/2015 SLOTS Slotted Liner 1G-05L1- 02 9,723.5 11,450.6 6,510.6 6,356.3 A-4, 1G-05L1-01 10/8/2015 SLOTS Slotted Liner 1G-05L1- 01 9,287.1 10,746.3 6,464.3 6,545.2 UNIT B, 1G-05L1 10/2/2015 SLOTS Slotted Liner 1G-05L1 10,747.6 12,533.6 6,545.2 6,688.6 A-4, 1G-05L1 10/2/2015 SLOTS Slotted Liner 1G-05L1 Comment SSSV: NONE 1G-05, 5/10/2020 7:06:03 AM Vertical schematic (actual) PRODUCTION; 29.9- 10,071.0 FISH; 9,520.0 FISH; 9,509.0 IPERF; 9,348.0-9,378.0 IPERF; 9,332.0-9,336.0 L1 WINDOW; 9,280.0- 9,285.0 WHIPSTOCK; 9,277.0 L1 LINER; 9,275.8- 12,534.0 L1-02 WINDOW; 9,254.0- 9,261.0 WHIPSTOCK; 9,250.0 L1-02 LINER; 9,244.7- 10,649.0 SLOTS; 9,245.5-10,649.0 NIPPLE; 9,210.2 SBE; 9,186.3 SEAL ASSY; 9,183.1 PACKER; 9,183.0 LOCATOR; 9,182.3 GAS LIFT; 9,145.9 IPERF; 9,095.0-9,131.0 GAS LIFT; 9,073.0 PACKER; 9,061.4 IPERF; 8,976.0-9,050.0 GAS LIFT; 8,946.8 GAS LIFT; 8,885.3 2.81" XX Plug; 8,832.0 NIPPLE; 8,831.7 PACKER; 8,809.6 PBR; 8,786.3 SEAL ASSY; 8,779.3 LOCATOR; 8,778.9 GAS LIFT; 8,722.3 GAS LIFT; 7,828.9 TUBING LEAK; 7,644.0 GAS LIFT; 6,629.5 GAS LIFT; 4,963.2 GAS LIFT; 2,843.2 SURFACE; 29.7-2,523.9 CONDUCTOR; 30.0-80.0 HANGER; 26.4 KUP INJ KB-Grd (ft) 29.99 Rig Release Date 2/17/1983 Annotation Last WO: End Date 3/24/2015 H2S (ppm) Date... TD Act Btm (ftKB) 10,086.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292090800 Wellbore Status INJ Max Angle & MD Incl (°) 56.37 MD (ftKB) 4,600.00 Legal Wellname 1G-05 Common Wellname1G-05 AK All Wellbores Schem Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 8,976.0 9,050.0 6,233.8 6,288.2 C-3, C-4, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 1G-05 9,095.0 9,131.0 6,321.7 6,348.6 C-1, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 1G-05 9,332.0 9,336.0 6,497.6 6,500.5 A-5, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 1G-05 9,348.0 9,378.0 6,509.4 6,531.5 A-4, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 1G-05 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 2,843.2 2,490.3 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2015 1G-05 2 4,963.2 3,737.0 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2015 1G-05 3 6,629.5 4,739.9 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/27/2015 1G-05 4 7,828.9 5,496.1 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/27/2015 1G-05 5 8,722.3 6,054.4 CAMCO RDO-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/28/2015 DCR 1 1G-05 6 8,885.3 6,168.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 1G-05 7 8,946.8 6,212.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 1G-05 8 9,073.0 6,305.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/8/2015 1G-05 9 9,146.0 6,359.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 1G-05 1G-05, 5/10/2020 7:06:04 AM Vertical schematic (actual) PRODUCTION; 29.9- 10,071.0 FISH; 9,520.0 FISH; 9,509.0 IPERF; 9,348.0-9,378.0 IPERF; 9,332.0-9,336.0 L1 WINDOW; 9,280.0- 9,285.0 WHIPSTOCK; 9,277.0 L1 LINER; 9,275.8- 12,534.0 L1-02 WINDOW; 9,254.0- 9,261.0 WHIPSTOCK; 9,250.0 L1-02 LINER; 9,244.7- 10,649.0 SLOTS; 9,245.5-10,649.0 NIPPLE; 9,210.2 SBE; 9,186.3 SEAL ASSY; 9,183.1 PACKER; 9,183.0 LOCATOR; 9,182.3 GAS LIFT; 9,145.9 IPERF; 9,095.0-9,131.0 GAS LIFT; 9,073.0 PACKER; 9,061.4 IPERF; 8,976.0-9,050.0 GAS LIFT; 8,946.8 GAS LIFT; 8,885.3 2.81" XX Plug; 8,832.0 NIPPLE; 8,831.7 PACKER; 8,809.6 PBR; 8,786.3 SEAL ASSY; 8,779.3 LOCATOR; 8,778.9 GAS LIFT; 8,722.3 GAS LIFT; 7,828.9 TUBING LEAK; 7,644.0 GAS LIFT; 6,629.5 GAS LIFT; 4,963.2 GAS LIFT; 2,843.2 SURFACE; 29.7-2,523.9 CONDUCTOR; 30.0-80.0 HANGER; 26.4 KUP INJ ... Legal Wellname 1G-05 Common Wellname1G-05 AK All Wellbores Schem Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, May 3, 2020 11:28 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1G-05 (PTD 183-020) Report of annular communication Attachments: 1 G-05.pdf, 1 G-05 90 day TIO trend 5.3.20.pdf Chris, KRU injection well 1G-05 (PTD 183-020) was shut in this morning after exhibiting suspected TxIA communication. The current plan is to secure the well with a tubing plug and begin diagnostics to locate and repair the source of communication. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Cell phone: (808) 345-6886 Office phone: (907) 659-7224 WELLS TEAM cor oc;'%Mps WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Sharefile CD's 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL LDL FINAL FIELD 9-May-20 1 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL Caliper FINAL FIELD 9-May-20 1 1C-27 50-029-22943-00 1005117.1S11 KUPARUK RIVER WL Caliper FINAL FIELD 10-May-20 1 1C-27 50-029-22943-00 1005117.1S12 KUPARUK RIVER WL LDL FINAL FIELD 11-May-20 1 4 Delivery Receipt ________________________________X____________________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. AlaskaPTSPrintCenter@slb.com SLB Auditor - A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Abby Bell Abby Bell 05/18/2020 Received by the AOGCC 05/14/2020 PTD: 1830200 E-Set: 33088 WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Sharefile CD's 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL LDL FINAL FIELD 9-May-20 1 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL Caliper FINAL FIELD 9-May-20 1 1C-27 50-029-22943-00 1005117.1S11 KUPARUK RIVER WL Caliper FINAL FIELD 10-May-20 1 1C-27 50-029-22943-00 1005117.1S12 KUPARUK RIVER WL LDL FINAL FIELD 11-May-20 1 4 Delivery Receipt ________________________________X____________________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. AlaskaPTSPrintCenter@slb.com SLB Auditor - A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Received by the AOGCC 05/14/2020 PTD: 1830200 E-Set: 33087 Abby Bell Abby Bell 05/18/2020 MEMORANDUM TO: Jim Regg 7 P.1. Supervisor �Pj/' �S FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT IG -05 Insp Num: mi[BDB190708071741 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 15, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IG -05 KUPARUK RIV UNIT IG -05 Sre: Inspector Reviewed By: P.1. Supryj7F— Comm API Well Number 50-029-20908-00-00 Inspector Name: Brian Bixby Permit Number: 183-020-0 Inspection Date: 7/7/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IG -05 - Type Inj TVD 0i15 Tubing 1;10 180 'ao 180 . PTD 1830200 ' Type Test I SPT Test psi 1 i' -'I IA i05o 7000 ",a1, 1910. BBL Pumped: 2.2 ' BBL Returned: - OA 000 Tao -40 780 - Interval I 4YRTST P/F i> Notes: Monday, July 15, 2019 Page 1 of I I O a . . a, N J o 1- O co ? Vt o ? u o N. . r v ° f` NO U J 0.0 YCo (13 �fo w- O co N o UO 4 > f co co O In a) L o �i5 a ' c o Q 0 u E a o CO p 007 r_-Z L.9.9 r• r• ti f` n t Q) J ° +-+ L O N Q O N W O U U U U U U U L - �'' In C� -' m w p O O O O O O O c co c L s v G VRA' d O YL'j N M u) O o0 ° O LA Z Z 0J` 0 .� E — v a) o c 0 aCu 0 0 Co a) 10 N U c ,_ Q i w 00000000 •tip C u ° a w w w w w w w w o a) C. 1- LL LL LL LL U. U. U. L. -, > L v o 1- Q Q Q Q Q Q Q Q v c Z 0) < Z Z Z Z Z Z Z Z U0 a) CO 0 > LL LL LL LL LL LL LL LL c riiiYi - (.3 ,1" C N E 4�-, Q) , O Q) a E a v u v O z iii C O ; ZZ Co O -c C i., 0 t, CL ~ C (U0 a O 0 UV 2 Q a) a Ln c a (d Q W LL LL LL LL LL F o .E O 0 O ct 0 , N ty TS 4) mf'- aaaco oa. u) d w U S W W a V > o o o t0 1. M ar all a0N z dIx w 5 uo > m 0 n. J J J> J J J> J J p , F ZM ‘o ,e) w ar p A IIYCLW Cr Cert Cr C j W w w w w w w W W > > > > > > > > U z Y Y Y Y Y Y Y Y o o C4CereCr CLtYCr a) Q LA., Q Q Q Q Q Q Q Qa w Q. d Q. d d Q. d d •.t Y W > > > > > > > > Co u ti ' ` Y Y Y Y Y Y v co 0 ce Lit , t0 N M .0 N CD C- 0 X Coco _ U ce , CO M M M M M M M E W C Od40Ooo0O0OOO coo N V u�t r, N- r r C r N c V coocococococo co co WQx ppppppp CO V-. CC 0 0 0 0 0 0 0 0 0 C In 9 0 0 0 0 0 0 0 c00 v U) co D o ' 0 Co o .y E N O N U) M '0 r CO 0 R) g g 0) N. 0 0 N O N o U 1a, Se- 0 0 0 M M 4 N E. N N N N N N N N I- R Q O)NT T T M O do 0) a) EO O O O O O O O 7 0 0 0 0 0 0 O O +' 0 a) Eim 000 C U) If) U) U) U) U) U) U) 0. 0 -' so W Co a) ES Cal F- m l0 u 5 U Lu cc c 3 a` • UJ • ~ r CO N .+ E ar `i' CO uToa) • z i) (IT '� Q co 0 0 0 0 0 !' 1 0 O VY) g N z a a 2 = > 2 2 E cz z ar Co 10 = d N W N N N N i In Y Ca -_1_', '-I c E f6 .� CU r6 -C• COD 8 4 �) F- a G, Q • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,February 03,2016 P.I.Supervisor ' '�� 4,611‘, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1G-05 FROM: Jeff Jones KUPARUK RIV UNIT IG-05 Petroleum Inspector Src: Inspector Reviewed By P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1G-05 API Well Number 50-029-20908-00-00 Inspector Name: Jeff Jones Permit Number: 183-020-0 Inspection Date: 1/29/2016 Insp Num: mitJJ160129155425 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IG-05 - Type Inj w, TVD 6115 ' Tubing 1940 . 1940. (1940• 1940 PTD 1830200 , Type Test SPT Test psi 1529 IA 440 2820 2820 - 2820 Interval VITAL P/F P ✓ OA 500 560 . 580 - 580 Notes: Post rig W/O MIT-IA.2.1 BBLS diesel pumped,one well inspected,one exception noted:there is bubbling and water moving in the cellar. Mr.Mouser will initiate samples and investigate to determine the source/cause of this condition. Wednesday,February 03,2016 Page 1 of 1 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG Flo 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-020 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20908-00 7.Property Designation(Lease Number): ' 8.Well Name and Number: ADL025640 KRU 1G-05 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 10086 feet Plugs(measured) None true vertical 7068 feet Junk(measured) None Effective Depth measured 9975 feet Packer(measured) 8810, 9061, 9183 true vertical 6982 feet (true vertical) 6115,6297,6387 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80' SURFACE 2494 12 2524 2278' L1-02 WINDOW 7 7 9261 6445' L1 WINDOW 5 7 9285 6463' PRODUCTION 10041 7 10071 7056' 1te` . ,. .mow . v't Perforation depth: Measured depth: 7986-9050; 9095-9131; 9332-9336; 9348-9378 True Vertical Depth: 6234-6288;6322-6349;6496-6501;6509-6532 JAN 20 ,n t is Tubing(size,grade,MD,and ND) 3.5 x 5.5 @ 9222', L-80/H-40, 9312 MD,6483 TVD C '' Packers&SSSV(type,MD,and TVD) TRDP-CAMCO TRDP-1A SSA @ 1831 MD and 1757 ND PACKER-BAKER FHL RETRIEVABLE PACKER @ 8810 MD and 6115 TVD PACKER-BAKER FHL RETRIEVABLE PACKER @ 9061 MD and 6297 TVD PACKER-BAKER 85-40 Fl PERMANENT PRODUCTION PACKER @ 9183 MD and 6387 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): " i' "' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation 2345 800 1305 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Rectronic Fracture Stimulation Data r GSTOR r WINJ 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: 315-755 Contact Bob Christensen/Darrell Humphrey Email: n1139(C7conocophillips.com Printed Name Robert D. Christensen Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date ' /0 Form 10-404 Revised 5/2015 V71- 7t -2////I tBDMS LL- JAN 2 1 2016 Submit Original Only • • ,G-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/26/15 BRUSHED & FLUSHED/ DRIFTED TBG 2.80"TO X-NIPPLE @ 9210' RKB. SET 2.81"XX PLUG WITH GAUGES @ SAME (GOOD PT ON TBG). DEPLOYED 2.79"AVA CATCHER. PULLED GLVs @ 7830', 6629', 4963' &2843' RKB. SET DVs @ 2843' &4963' RKB. IN PROGRESS. 12/27/15 SET DVs @ 6629' &7830' RKB (GOOD DDT ON TBG). PULLED OV @ 8722' RKB. LOADED TBG x IA WITH 270 BBLS CRW SW& 85 BBLS DIESEL, U-TUBE FREEZE PROTECT. (FLOWLINE FREEZE PROTECTED WITH 19 BBLS MEOH). IN PROGRESS. 12/28/15 SET DV @ 8722' RKB. MIT-IA 3000 PSI; PASS. PULLED CATCHER, EQUALIZED & PULLED 2.81"XX PLUG WITH GAUGES @ 9210' RKB (2247 PSI). JOB COMPLETE. 01/15/16 Well put on injection service z KUP INJ , 1G-05 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,(r1C. Wellbore API/MI Field Name Wellbore Status 'nein MD(ftKB) Act Btm(ftKB) . ce .4,..lkps 500292090800 KUPARUK RIVER UNIT INJ 56.37 4,600.00 10,086.0 A... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date I 0-05,12/30/201521729 PM SSSV:NONE Last WO 3/24/2015 29.99 2/17/1983 Venal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER'264 OW/ Last Tag SLM 9,412.0 6/6/2015 Rev Reason:GLV C/O lehallf 12/30/2015 1muly�r1���e8 as Casing Strings I'.` f 71 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread e. T CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread €- SURFACE 103/4 9.950 29.7 2,523.9 2,278.4 45.50 K-55 BTC .A.A.A CONDUCTOR;30.0-80.0A.41,n.a/,4 r4,4,..1.4,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread L1-02 WINDOW 7 6276 9,254.0 9,261.0 6,445.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread L1 WINDOW 7 6.276 9,280.0 9,285.0 6,463.0 SURFACE;29.7-2,523.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread __ PRODUCTION 7 6.276 29.9 10,071.0 7,055.9 26.00 K-55 BTC GAS LIFT;2,843.2 .Tubing Strings Tubing Description String Ma...ID(in) !Top(ftKB) !Set Depth(ft..f Set Depth(ND)(...I Wt(Ib/ft) (Grade Top Connection TUBING-2015 WO- 31/2 2.992 26.4 9,189.31 6,392.1 9.30 L-80 EUE 8rd AB Mod UPPER GAS LIFT;4,963.2 Completion Details , Nominal ID Mk Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Corn (in) ill 26.4 26.4 0.10 HANGER McENVOY TUBING HANGER 2.992 GAS LIFT;6,629.5 8,778.9 6,093.3 45.96 LOCATOR LOCATOR 2.970 8,779.3 6,093.6 45.96 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 GAS LIFT;7,828.9 8,809.6 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 8,831.8 6,130.4 45.13 NIPPLE OTIS X NIPPLE 2.812 8,966.6 6,227.0 43.34 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 2.992 GAS LIFT;8,722.3 8'971-k 8,986.3 6,241.3 43.06 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 _ 9,045.5 6,284.8 42.27 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 8rd 2.992 9,055-k LOCATOR; 9,061.4 6,296.6 ' 42.06 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 SEALALASSY;SSY;8,7799.33 PBR;8786.3 9,086.8 6,315.6 41.72 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 2.992 PACKER,8,809.6 9,090-ft 9,106.6 6,3303 41.58 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 NIPPLE;8,8317 a 9,182.3 6,386.8 41.90 LOCATOR LOCATOR 2.990 • 9,183.1 6,387.4 41.90 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 GAS LIFT;8,885.3 It Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-2015 WO- 51/2 4.950 9,183.0 9,312.0 6,482.9 14.00 H-40 STC LOWER-31/2"x5 1/2"C7a 9222 Completion Details GAS LIFT;8.946.8 �` Nominal ID :. Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Com (in) _ 9,183.0 6,387.3 41.90 PACKER BAKER 85-40 Fl PERMANENT PRODUCTION PACKER 4.000 (PERF;8,976.0.9,050.0 z. 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 9,191.3 6,393.5 41.93 X0 Reducing Crossover sub 2.990 9,210.2 6,407.6 42.03 NIPPLE OTIS X NIPPLE 2.812 PACKER;9,061.4 ..-.- 9.222.1 6,416 4 42.09 XO Enlarging Vented/Ported Cross-over 3-1/2 EUE 8rd x 5-1/2"STC 2.990 GAS LIFT;9,073.0 BxP Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) _ Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Corn Run Date ID tin) (PERF;9,095.0.9,131.0 IM, 9,250.0 6,437.1 42.25 WHIPSTOCK Baker Gen II Whipstock,TOWS at 9,250',BOWS at 10/3/2015 9262.97',Set 30°ROHS,RA tags 7.35'down from TOWS GAS LIFT;9,145.9 9,277.0 6,457.0 42.40 WHIPSTOCK 31/2"X51/2"GEN II WHIPSTOCK 6/6/2015 LOCATOR,9,1823 - 9,509.0 6,628.6 41.65 FISH 1.5"CV Empty Pocket;Fell to Rathole 8/7/1987 8/7/1997 PACKER;9,183.0, _:fir'• 9,520.0 6,636.8 41.62 FISH 1.5"OV Lost in Hole 1/25/1994 1/25/1994 SEAL ASSY;9,183.1 SBE;9,1e6.3 iiPerforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com NIPPLE;9.210.2 :: 8,976.0 9,050.0 6,233.8 6,288.2 C-3,C-4,1G- 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann a 05 TCP A 9,095.0 9,131.0 6,321.7 6,348.6 C-1,1G-05 2/17/1983 - 12.0 IPERF 120 deg Ph;GeoVann TCP SLOTS;9,2455-1.064,30301_ 9,332.0 9,336.0 6,497.6 6,500.5 A-5,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann L1-02 LINER;9244.7,10,649.0 TCP WHIPSTOCK 9,2500, Li-02 WINDOW,92540- 9,348.0 9,378.0 6,509.4 6,531.5 A-4,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann 9.261.0 i.'. - TCP LI LINER;9.275.8-12,534.0 Mandrel Inserts St ati WHIPSTOCK;9,277.0 on Top(ND) Valve Latch Port Size TRO Run LI WINDOW;9,2800-9.285.0 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,843.2 2,490.3 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2015 it 2 4,963.2 3,737.0 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2015 (PERF;9,332.0.9,336.0 _ _ _ 3 6,629.5 4,739.9 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/27/2015 IPERF;9.348.0-9,378.0 4 7,828.9 5,496.1 CAMCO R-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/27/2015 FISH;9.509.00 5 8,722.3 6,054.4 CAMCO RDO-20 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/28/2015 DCR 1 FISH;9.520.0 0 6 8,885.3 6,168.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 PRODUCTION;29.318071.0 ,a 4, 7 8,946.8 6,212.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 KUP INJ 110 1G-05 ConocoPhillips Alaska Inc. • 1G-05,12/30/2015 2:17:30 PM Vertical schematic(actual) HANGER,26.4 + ' I Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ROB) (kK8) Make Model OD(in) Sore Type Type (in) (p6) Run Date Com .`).AA CONDUCTOR,300-80.0 - g 9,073.0 6,305.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/8/2015 9 9,146.0 6,359.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/10/2015 Notes:General&Safety End Date Annotation SURFACE;29.7-2,523.9 9/16/2010 NOTE:Mandrel @ 8924-Leak found 6/21/2006 @ C-sand;lbg lest failed 2/9/08 confirmed C3/C4 leak 10/27/2015 NOTE:ADDED LATERALS L1(off main wellbore),L1-01,L1-02(off main wellbore) GAS LIFT,2,843.2 GAS LIFT,4.963.2 GAS LIFT,6.6295 GAS LIFT;7.828.9 GAS LIFT;8,722.3 LOCATOR;8,778.9 SEAL ASSY;8,776.3 PBR;8,786.3 PACKER;8,809.6 NIPPLE;8,831.7 Ame GAS LIFT;8,885.3 B GAS LIFT;8,9468 B. IPERF;8,976.0-9,050.0 PACKER;9.061,4 - - GAS LIFT;9,073.0 IPERF;9,095.0-9,131.0 1 GAS LIFT;9,145.9 LOCATOR;9,182.3 111 PACKER;9,183.0- SEAL ASSY;9,183.1 SBE;9,186.3 V NIPPLE;9,210.2 SLOTS;9,245,51,064,303,0—_ �. L1-02 LINER;9244.7-10,649.0 I ': WHIPSTOCK;9,250.0 L1-02 WINDOW;9,254.0- 9,261.0 ,254.09,261.0 L1 LINER;9,275.9-12,534.0 WHIPSTOCK;9,277.0 L1 WINDOW;9,280.0-9,285.0 IPERF;9,332.0-9,336.0 IPERF;9,348.09,378.0 FISH;9,509.0 FISH;9,520.0 PRODUCTION;29.9.10,071.0 - OF Th, • • ,,,\1//77;:s,,„ THE STATE Alaska Oil and Gas �-` - of/ j /� Conservation Commission 'wet' = _= 333 West Seventh Avenue Xw if GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 907.279.1433 OFALAS P Main: Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen Engineering Specialist q3 ' 63' 92 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-05 Sundry Number: 315-755 Dear Mr. Christensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 2) day of December, 2015 Encl. RBDMS tDEr 2 4 2015 STATE OF ALASKA 0SKA OIL AND GAS CONSERVATION COM SION , APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Oil to WAG Conversion❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc., Exploratory ❑ Development Q. 181 0 I$3 Dap 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20908-00- 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? KRU 1 G-05 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025640 . Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10086• 7068 ' 9975 • 6982.. Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80 SURFACE 2494 12 2524 2278 RECEIVED L1-02 WINDOW 7 7 9254 6445 L1 WINDOW 5 7 9285 6463 DEC 16 ZU15 PRODUCTION 10041 7 10071 7056 Tode6 4-5 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(1t): 8976-9050;9095-9131; 6234-6288;6322-6349; 9332-9336;9348-9378 . 6498-6501;6509-6532 3.5 x 5.5 @ 9222' L-80/H-40 9312 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PKR=BAKER FHL RETRIEVABLE PACKER . MD=8810 TVD=6115 PKR=BAKER FHL RETRIEVABLE PACKER • MD=9061 TVD=6297 PKR=BAKER 85-40 Fl PERMANENT PRODUCTION PACKER . MD=9183 TVD=6387 SSSV=CAMCO X NIPPLE . MD=8832 TVD=6130 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑ Service Q• 14.Estimated Date for 15.Well Status after proposed work: 12/20/2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ ' GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Bob Christensen/Darrell Humphrey Email n1139@conocophillips.com Printed Name Robert D.Christensen( Title Engineering Specialist Signature "a4,6 -141474 ��� L j`� Phone:659-7535 Date ti COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 --755 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ]� Location Clearance ❑ / Other: 1a/-C l� r v f 6-/ 1 r'34.,di .'r,,)�C �Yw, dam✓ �Y?fSS�G� /lnfT—/�4 r---e-1 �ti{�fC a U ✓ Post Initial Injection MIT Req'd? Yes 2/No ❑ Spacing Exception Required? Yes ❑ No 27 Subsequent Form Required: /r - !/O 4 APPROVED BY �✓ Approved by: COMMISSIONER �RnT■H,E�CCOOMMMIIS�SION q 1Date: /z - Z1--LJ Form 10-403 evised-11167/7- �7/20� IR rw�p�l O .i lid for 12 monRISDNISlat�'b�d '��'))of 1 141 Submit Form and.Ari ply I Attachments in Duplicate �j� • • 1 G-05 DESCRIPTION SUMMARY OF PROPOSAL 13 O. -O ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 1G-05 (PTD# 1433-200) from Oil Production service to Water Alternating Gas Injection service as the well has completed the, post CTD operations, pre-production period. Area of Review: Kuparuk well 1 G-05 was drilled in 1983 to exploit A and C-Sand targets in the central part of the field. The well was originally completed as a Kuparuk"A/C' Sand producer and was converted to injection in 1988 and has injected water and gas into the A and C-Sands in perforated intervals from 8976' to 9378' MD. CTD operations to add laterals L1, L1-01, & L1-02 were completed in September, 2015. Pre-production began on 10/25/2015 and will continue until the well can be converted back to injection'Wells 1G-05, 1G-05L1, 1G- 05L1-01, and 1G-05L1-02 will provide injection support nearby area wells including 1A-03, 1G-12 and 1G- 11A. The top of the Kuparuk C sand was found at 8975' and /6233' tvd The top of the Kuparuk A sand was found at 9319' and /6488' tvd Area Map with 1/4 mile radius around target injection zone (see attached): Tha map attached shows that there are 6 production/injection wells located within a 1/4 mile radiurs of the 1G-05, 05L1, 05L1-01, & 05L1-02 penetrations of the Kuparuk A sands. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1 G-05 is good and classified as a "Triple Selective Well". A State- witnessed MIT-IA will be performed once well 1 G-05 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker FHL Packer located at 8810' and (6115' tvd). The 10-3/4" Surface casing was cemented with 1300 sx AS III, followed by 250 sx AS I, followed by 60 sx AS I (top job). The 7-5/8" Production casing was cemented with 1000 sx Class 'G' followed by 250 sx AS I. CBL and interpretation of the cement quality: The CBL interpretation was completed on the PTD's. KUP PROD 0 IG-05 ConocoPhillips °- Well Attributes Max Angle&MD TD AlitSk' Inc, Wellbore API/UWI Field Name Wellbore Status eel 7) MD(ftKB) Act Btm(ftKB) CmocoPHpR 500292090800 KUPARUK RIVER UNIT PROD 56.37 4,600.00 10,086.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 1G-05,11/23/2015 2.55:31 PM SSSV:NONE Last WO: 3/24/2015 29.99 2/17/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- - - ---- --•--------- -- / - - Last Tag:SLM 9,412.0 6/6/2015 Rev Reason:GLV C/O pproven 11/23/2015 HANGER;26A Il 1:it „pan,.,...,.....,,.,......man�auua.anw pL.an . Casing Strings I`Qtl i Casing Descr pbon OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 10 3/4 9.950 29.7 2,523.9 2,278.4 45.50 K-55 BTC .AAACONDUCTOR;30.0-80.0.4.4tAw/J4 iY - Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1-02 WINDOW 7 6.276 9,254.0 9,261.0 6,445.2 Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread L1 WINDOW 7 6.276 9,280.0 9,285.0 6,463.0 SURFACE;29.7-2,523.9-s i - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.9 10,071.0 7,055.9 26.00 K-55 BTC GAS uFr;z,843z _ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-2015 WO- 31/2 2.992 26.4 9,1893 6,392.1 9.30 L-80 EUE Ord AB Mod UPPER GAS UFT;4,963.2 _ Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Mel(°) Item Des Com (in) 26.4 26.4 0.10 HANGER McENVOY TUBING HANGER 2.992 GAS LIFT;6,629.5 8,778.9 6,093.3 45.96 LOCATOR LOCATOR 2.970 8,779.3 6,093.6 45.96 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 GAS LIFT;7,828.9 8,809.6 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 8,831.8 6,130.4 45.13 NIPPLE CAMCO X NIPPLE W/PXX PLUG 2.812 8,966.6 6,227.0 43.34 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 2.992 GAS LIFT;8,722.3 _ 8'971 ft 8,986.3 6,241.3 43.06 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 9,045.5 6,284.8 42.27 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 8rd 2.992 9,055-ft EALSLOCATOR;8270.3 { ,3; 9,061.4 6,296.6 42.06 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 SEAL ASSY;8,]79.3 PBR;8,786.3 ' 9,086.8 6,315.6 41.72 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 2.992 PACKER;8,809.6 .- ' - 9,090-ft 9,106.6 6,330.3 41.58 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 NIPPLE;8,831.7 9,182.3 6,386.8 41.90 LOCATOR LOCATOR 2.990 9,183.1 6,387.4 41.90 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 EP Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;8,885.3 TUBING-2015 W0- 51/2 4.950 9,183.0 9,312.01 6,482.9 14.00 H-40 STC aLOWER-31/2"x5 It: 1/2"@9222 GAS LIFT;8,946.8 a.. Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) t 9,183.0 6,387.3 41.90 PACKER BAKER 85-40 Fl PERMANENT PRODUCTION PACKER 4.000 � (PERF;8,976.0-9,050.0y ■i 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 9,191.3 6,393.5 41.93 XO Reducing Crossover sub 2.990 .. 9,210.2 6,407.6 42.03 NIPPLE CAMCOX NIPPLE 2.812 PACKER;9,061.4 '- 9,222.1 6,416.4 42.09 XO Enlarging Vented/Ported Crossover 3-1/2 EUE 8rd x 5-1/2"STC 2.990 GAS LIFT;9,073.0 BXP Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl .'Y Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) (PERF;9,095.0-9,131 0 , j 9,250.0 6,437.1 42.25 WHIPSTOCK Baker Gen II Whipstock,TOWS at 9,250',BOWS at 10/3/2015 - I 9,262.97',Set 30'ROHS,RA tags 7.35'down from in TOWS GAS LIFT;9,145.9 9,277.0 6,457.0 42.40 WHIPSTOCK 31/2"X51/2"GEN II WHIPSTOCK 6/6/2015 LOCATOR;9,182 3 9,509.0 6,628.6 41.65 FISH 1.5"CV Empty Pocket;Fell to Rathole 8/7/1987 8/7/1997 PACKER;9,183.0 - 9,520.0 6,636.8 41.621 FISH 1.5"OV Lost in Hole 1/25/1994 1/25/1994 SEAL ASSY;9,183.1 SEE;9,186.3 Perforations&Slots Shot Dens Top(ND) Btu(TVD) (shots/f Top(ftKB) BM(ftKB) (ftKB) (ftKB) Zone Dale t) Type Com NIPPLE;9,2102 , 8,976.0 9,050.0 6,233.8 6,288.2 C-3,C-4,1G- 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann in 05 TCP 9,095.0 9,131.0 6,321.7 6,348.6 C-1,1G-05 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann TCP SLOTS;9,24551,0043030L_ ' 1 9,332.0 9,336.0 6,497.6 6,500.5 A-5,10-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann L1-02 LINER;9,244.7-10,649.0 TCP WHIPSTOCK;9,250.0-, L1-O2 WINDOW;9,254.0- 9,348.0 9,378.0 6,509.4 6,531.5 A-4,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann 9,261.0 iTCP L1 LINER;9,275.8-12,534.0 Mandrel Inserts Sl ati WHIPSTOCK;9,277.0, N Top(TVD) Valve Latch Port Size TRO Run LI WINDOW;9,280.0-9,285.0 . Top(ftKB) (ftKB) Make Model OD(in) Ser/ Type Type (in) (psi) Run Date Com 1 2,843.2 2,490.3 CAMCO R-20 5.968 GAS LIFT GLV RK 0.188 1,306.0 11/19/2015 I 2 4,963.2 3,737.0 CAMCO R-20 5.968 GAS LIFT GLV RK 0.188 1,309.0 11/19/2015 IPERF;9,332.0-9,336.0 _ 3 6,629.5 4,739.9 CAMCO R-20 5.968 GAS LIFT GLV RK 0.188 1,292.0 11/18/2015 IPERF;9,348.0-9,378.0 4 7,828.9 5,496.1 CAMCO R-20 5.968 GAS LIFT GLV RK 0.250 1,312.0 11/18/2015 FISH;9,509.0 5 8,722.3 6,054.4 CAMCO RDO-20 5.968 GAS LIFT OV RK 0.313 0.0 11/18/2019 DCR 1 FISH;9,520.0 6 8,885.3 6,168.4 CAMCO MMG 5.968 GAS LIFT -DMY RK 1.500 0.0 4/10/2015 PRODUCTION;29.9-10,071.0 a 7 8,946.8 6,212.5 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 • KUP PROD • 1G-05 ConocoPhillips Ori Alaska,IGO. cvaceotampc 10-05,11/23/2015 2'.55:34 PM Vertical schematic(actual) HANGER;28.4 f4°.'fat Mandrel Inserts sr - - on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com .AAA CONDUCTOR;30.0-80.0 - 9,073.0 6,3052 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 3/8/2015 9 9,146.0 6,359.7 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 Notes:General&Safety End Date Annotation SURFACE;29.7-2,523.9 9/16/2010 NOTE:Mandrel @ 8924-Leak found 6/21/2006 @ C-sand;tbg test failed 2/9/08 confirmed C3/C4 leak 10/27/2015 NOTE:ADDED LATERALS L1(off main wellbore),L1-01,L1-02(off main wellbore) GAS LIFT;2,843.2 GAS LIFT;4,963.2 GAS LIFT;6,629.5 GAS LIFT;7,828.9 GAS LIFT;8,722.3 LOCATOR;8,778.9 1 I SEAL ASSY;8,779.3 14, FOR;8,708 6 t ,, PACKER;8,809.6 S('�✓-�S�IF NIPPLE;8,831.7 GAS LIFT;8,885 31. GAS LIFT;8,9468 IPERF;8,976.0-9,050.0 .� } PACKER;9,061A GAS LIFT;9,073 0 _ (PERF;9,095.0-9,131.0 I ' GAS LIFT;9,145.9 LOCATOR;9,182.3 PACKER;9,183.0, . SEAL ASSY;9,183.1 SBE;9,186.3 NIPPLE;9,210 2 Ir I SLOTS;9,245.5-1,064,303.0L_ "4I L1-02 LINER;9,244.7-10,649.0 WHIPSTOCK;9,250.0 L1-02 WINDOW;9,254.0- I 9,261.0 L1 LINER;9,275.8-12,534.0 �. WHIPSTOCK;9,277.0 L1 WINDOW;9,280.0-9,285.0 4 IPERF;9,332.0-9,336.0 (PERF;9,348.0-9,378.0 FISH;9,509.0 FISH;9,520.0 PRODUCTION;29.9.10,071.0 • • ConocoPhillips 1G-05 Well Alaska 14Dec15 ADL025640 ADL025639 oAG- AAP 0 -.1. • I 0 et 0 Q L.0 p 4„. ,\P=16 ADL025647 Well Pad ADL025648 1G-05 Open Interval 1 G-05 Trajectory -- 1G-05L1 Open Interval �, m 1G-05L1-01 Open Interval ®1 G-05L1-02 Open Interval Well Within 1G-05L1 Radius Well Within 1G-05L1-01 Radius E 1/4 Mi. 1G-05 Open Section Radius References: 1/4 Mi. 1G-05L1 Open Section Radius Well Data: ConocoPhillips Alaska Well Database(ATDB) Surface Facilities:ATDB 1/4 Mi. 1G-05L1-01 Open Section Radius N ❑1/4 Mi. 1G-05L1-02 Open Section Radius Pad Outline 0 0.1 0.2 0.3 0.4 I I CPAI Lease Miles • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Wednesday,May 13,2015 TO: Jim Regg �(4I ��j I S P.I.Supervisor l SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1G-05 FROM: Lou Grimaldi KUPARUK RIV UNIT IG-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1G-05 API Well Number 50-029-20908-00-00 Inspector Name: Lou Grimaldi Permit Number: 183-020-0 Inspection Date: 5/8/2015 Insp Num: mitLG150508083009 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1G-05 Type Inj w- TVD 6114 - Tubing 2210 2210 2210 2210 • PTD 1830200 " Type Test SPT Test psi 1528 • IA 170 3030 2960 • 2950 - Interval INITAL P/F P / OA 115 , 135 - 135 139 - Notes: 2.8 bbl's diesel pumped,2.1 bbl's returned(bled only to 500 psi).Good solid test.All pertinent paperwork supplied prior to test. d A-A4rtaget : `) cum ' SSItie PI Qt z) ekr`re41- t tie 5C 41,C_ SCANNED JUL 1 0 2015 Wednesday,May 13,2015 Page 1 of 1 • , dUielie IQgI3 10 CD CD CD 1-0 CD A— c CD ` .J " 1 �4 11 11 , I , li f1, I d iI i I , II I, h i 'I II 111 I, ifs V '--'_ 1 . -7_1-":7---7_ : . '").''t 1(Li • - ...)."' t --2- —71 • t. • • • • s.t c� • . : ta• } •• V : : r • A-- • 4-6• • I - • • • T CU - a) - • I— • • - 2 • • • , : W r 1' I' 1 ' 1 11 '1 I 1' 1' I 1 ' I 11 11 I f 1 I ' I ' r 'I .I la) U- J 0_ o 0 o (N r f I I ISd 1 • • KUP INJ 1 G-05 N ConocoPhillips 2Well Attributes Max Angle&MD TD Al'sk,1,ht.:. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(MB) Act Blm(ftKB) r nmxrivhdivw 500292090800 KUPARUK RIVER UNIT INJ • 56.37 4,600.00 10,086.0 ••• Comment H2S(ppm) 'Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-05,5/7801512:21:39 PM SSSV:Flapper Locked Out Last WO: 3/24/2015 29-99 2/17/1983 Verxal schematic(actual) Annotation Depth(ftKB) End Data Annotation Last Mod By End Date Last Tag'SLM 9,379.0 3/8/2015 Rev Reason:WORKOVER smsmith 4/28/2015 HANGER;204 ls'I,'1I Casing Strings `I� , Casing Description OD(in) ID(in) Top(ft(B) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grads Top Thread CONDUCTOR 16 15060 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 29.7 2,523.9 2,278.4 45.50 K-55 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade 'Top Thread CONDUCTOR,30.0-80 own PRODUCTION 7 6.276 29.9 10,071.0 7,055.9 26.00 K-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD),...rt(Ibdt) Grade Top Connection TUBING-2015 WO- I 31/2 2.9921 26.4 9,189.3 6.39211 9.301 L-80 I EUE 8rd AB Mod UPPER SURFACE;207-2,5239 • Completion Details III Nominal ID Top(ftKB) Top(TIMI)(RKB) Top Ind(°) Item Des Com (in) GAS LIFT Z803 2 .' 26.4 26.4 0.10 HANGER "MCENVOY TUBING HANGER 2.992 ':I 8,778.9 6,093.3 45.96 LOCATOR 'LOCATOR 2.970 8,779.3 6,093.6 45,96 SEAL ASSEMBLY BAKER 8040 SEAL ASSEMBLY 3000 GAS LIFT;4.983.2 E; • • 11 I 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 8,809.6 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 8,831.8 6,130.4 45.13 NIPPLE 'CAMCO X NIPPLE W/PXX PLUG 2.812 GAS LIFT 6 829 5 i' 8,966.6 6,227.0 43.34 BLAST JTS 'Crossover 4-12 OD Blast Joints 3-1/2 8rd x 3-12 TCII 2.992 8,971-ft I •� 8,986.3 6,241.3 43.06 BLAST JTS "4-12 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII ' 2.992' 9,045.5 6,284.8 42.27 BLAST JTS Crossover 4-12 OD Blast Joints 3-1/2 TCII x 3-1/2 8rd 2.992 GAS LIFT;7,8280 ., 9,055-ft III 9,061.4 6,296.6 4206 PACKER "BAKER FHL RETRIEVABLE PACKER 2.900 MI 9,086.8 6,315.6 41.72 BLAST JTS Crossover 4-12 OD Blast Joints 3-1/2 8rd x 3-12 TCII 2.992 9,090-ft GAS LIFT;8,722.3 9,106.6 6,330.3 41.58 BLAST JTS '4-12 OD Blast Joints 3-12 TCII x 3-12 TCII 2992 9,182.3 6,386.8 41.90 LOCATOR LOCATOR 2.990 9,183.1 6.3874 41.90 SEAL BAKER 80-40 SEAL ASSEMBLY 2.990 ASSEMBLY LOCATOR;8,778.9 SEAL ASSEMBLY;8,779.9 1ir - Tubing Description String Ma...ID(in) -Tap(RKB) Set Depth(R..Set Depth(1VD)I...I WI(1b/ft) Grads Top Connection • PBR;8,786.3 F TUBING-2015 W0- 5 1/2 4.950 9,183 0 9.312 0 6,482.9 14.00 H-40 STC LOWER-31/2"x5 PACKER;8,8090. 1/2"@9222 Completion Details NIPPLE;8,831.7 .4. Nominal ID ■ Top(ftKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (in) 9,1830 6,387.3 41.90 PACKER BAKER 85-40 Fl PERMANENT PRODUCTION PACKER 4.000 GAS LIFT e ass 3 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 P 1 9,191.3 6,393.5 41.93 XO Redudng Crossover sub 2.990 9210.2 6,407.6 42.03 NIPPLE CAMCO X NIPPLE W/PXX PLUG 2.812 9,222.1 6,416.4 42.09 XO Enlarging Vented/Ported Cross-over 3-12 EUE 8rd x 5-1/2"STC 2.990 GAS LIFT;8,946 8 .4 BxP Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) III Top(TVD) Top Incl Top(ftKB) fm 11 Des Com Run Date ID(in) (PERF,8,0780-9,0500-1 1.119,509.0 6,628.6 41.65 FISH 1.5'CV Empty Pocket;Fell to Rathole 8/7/1987 8/7/1997 4%1 9,520.0 6,636.8 41.62 FISH 1.5"OV Lost in Hole 125/1994 1/25/1994 Perforations&Slots PACKER;9.081A -' Sha Dens tm GAS LIFT;0,073.0 ° Top(ftKB) Ben(ftKB) T)ARKB( B(1KEI D) Zone Data (shtt( Type Can 8,976.0 9,050.0 6,233.8 6,288.2 C-3,C-4,1G- 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann 05 TCP 9,095.0 9,131.0 6,321.7 6,348.6'C-1,1G-05 2/17/1983 12.0 IPERF "120 deg Ph;GeoVann I TCP (PERF,9,095.0-0,131,0 a I 9,332.0 9,336.0 6,497.6 6,500.5 A-5,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann TCP 9,348.0 9,378.0 6,509.4 6,531.5 A-4,1G-05 2/17/1983 12.0 IPERF •120 deg Ph;GeoVann GAS LIFT;9,1450 TCP • LOCATOR;9,182.3 1 Mandrel Inserts PACKER;9,183.0.. St ali SEAL ASSEMBLY;9,183.1 en - - on Top(TVD) Valve Latch Port SW TRO Run SBE;9,788.3 IVr N Top(RKB( (KB) Make Model OD(in) Sent Type Type n (psi) Run Data Com f 2,843.2 2,490.3 CAMCO MMG 5.968 GAS LIFT DMY 'RK 1.500 0.0 4/102015 2 4,963.2 3,737.0 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 3 6,629.5 4,739.9 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 4 7,828.9 5,496.1'CAMCO MMG 5.968 GAS LIFT DMY 'RK 1.500 0.0 4/102015 NIPPLE;9,2102 5 8,722.3 6,054.4 CAMCO MMG 5.968 GAS LIFT DMY RKP 1.500 0.0 4/16/2015 OCR 1 l 6 8,885.3 6,168.4 CAMCO MMG 5968 GAS LIFT DMY RK - 1.500 0.0 4/102015 • 7 8,946.8 6,212.5 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 8 9,073.0 6,3052 CAMCO MMG 5968 GAS LIFT DMY RK 1.500 0.0 3/8/2015 1PERF;9,392.0-9.336.0 I 9 9,146.0 6,359.7 CAMCO MMG 5968 GAS LIFT DMY "RK 1.500 0.0 4/10/2015 Notes:General&Safety (PERF;9,348.0-9,378.0.-4End Date Annotation 9/16/2010 NOTE:Mandrel @ 8924-Leak found 6/21/2006 @ C-sand;(59 test failed 2/9/08 confirmed C3/C4 leak FISH;9,609.09/16/2010 NOTE:View Schematic w/Alaska Schematic9.0 FISH;9,520.0 PRODUCTION;29.9-10,071.0 STATE OF ALASKA AL ..A OIL AND GAS CONSERVATION COI. .SIGN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r Pull patch,CTD Alter Casing r Pull Tubing r Stimulate-Frac Waiverr Set-Up r r Time Extension Change Approved Program r'Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-020 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20908-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25640 KRU 1G-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10086 feet Plugs(measured) 9210 true vertical 7068 feet Junk(measured) 9509, 9520 Effective Depth measured 9975 feet Packer(measured) 8810, 9061, 9183 true vertical 6982 feet (true vertical) 6115,6297,6387 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80 SURFACE 2494 10.75 2524 2278 PRODUCTION 10041 7 10071 7056 sCANNEU M,.', 8 2a15 RECEIVED MAY 0 h 2015 Perforation depth: Measured depth' 8976-9050,9095-9131,9332-9336, 9348-9378 ����� True Vertical Depth: 6234-6288, 6322-6349,6398-6501,6509-6532 Tubing(size,grade,MD,and TVD) 3 5", L-80 @ 9222' MD/6416'TVD and 5.5", J-55 @ 9312' MD/6483'TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 8810 MD and 6115 TVD PACKER-BAKER FHL PACKER @ 9061 MD and 6297 TVD PACKER-BAKER F-1 PACKER @ 9183 MD and 6387 No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ 171 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 315-050 Contact Brett Packer(c,265-6845 Email J.Brett. Packer@conocophillips.com Printed Name Brett Packer Title Supervising Workover Engineer Signature —7?., v 7e76.1 Phone.265-6845 Date 577 :5._..._ V ri- 5-ill/IC RBDMSAA MAY 1 1 2015 11 Form 10-404 Revised 10/2012 /0 ffi,/__ Submit Original Only 1.-, E • KUP INJ 1G-05 ConocoPhillips a Well Attributes Max Angle&MD TD Alaska.Ina WetmoreAPI/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act BM,(ttKB) cmoznn-imp, 500292090800 KUPARUK RIVER UNIT INJ . 56.37 4,600.00 10,086.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1G-0s,D7/2915 12 21 39 Pm SSSV:Flapper Locked Out Last WO: 3/24/2015 29.99 2/17/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -.... __..__Last Tag:SLM 9,379.0 3/8/2015 Rev Reason:WORKOVER smsmith 4/28/2015 HANGER;26.4 I'.tyl Cai k(� I., Casing DsingescStrriptionngs OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread III 1CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread ill SURFACE 10 3/4 9.950 29.7 2,523.9 2,278.4 45.50 K-55 BTC Casing Description •OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread -AAA.CONDUCTOR;30.080.0. PRODUCTION 7 6.276 29.9 10,0710 7,055.9 26.00 K-55 BTC Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(166t) Grade Top Connection TUBING-2015 WO- 31/2 2.992 26.4 9,189.3 6,392.1 9.30 L-80 EUE 8rd AB Mod UPPER SURFACE;29.7-2,523.9 Completion Details El Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;2,843.226.4' 26.4 0.10 HANGER McENVOY TUBING HANGER 2.992 I 8,778.9' 6,093.3 45.96 LOCATOR LOCATOR 2.970' 8,779.3 6,093.6 45.96 SEAL 'BAKER 80-40 SEAL ASSEMBLY 3.000 ASSEMBLY GAS LIFT;4,963.2 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 8,809.6' 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 8,831.8 6,130.4 45.13 NIPPLE 'CAMCO X NIPPLE W/PXX PLUG 2.812 GAS LIFT;6,619.5 8,966.6 6,227.0 43.34 BLAST JTS 'Crossover 4-12 OD Blast Joints 3-1/2 8rd x3-1/2 TCII 2.992 11. 8,986.3 6,2413 43.06 BLAST JTS 14-12 OD Blast Joints 3-12 TCII x 3-1/2 TCII 2.992 9,045.5 6,284.8 42.27'BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 TCII x 3.12 8rd 2.992 GAS LIFT;7,828.9 1 9,055-ft 9,061.4 6,296.6 42.06 PACKER 'BAKER FHL RETRIEVABLE PACKER 2.900 9,086.8 6,315.6 41.72 BLAST JTS 'Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 2.992 9,090-ft GAS LIFT;8,722.3 IS 9,106.6 6,330.3 41.58 BLAST JTS 4.1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 ■ 9,182.3 6,386.8 41.90 LOCATOR -LOCATOR 2.990 9,183.1 6,387.4 41.90 SEAL BAKER 80-40 SEAL ASSEMBLY 2.990 LOCATOR;8,78.9 ASSEMBLY SEAL ASSEMBLY;8,779.3 Tubing Description String Ma,..ID(in) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(lb/ft) Grade Top Connection PBR;8,786.3 TUBING-2015 WO- WLOWER-312"x5 5 12 4.950 9,183.0 9,312.0 6,482.9 14.00 H-40 STC PACKER;8.809.6 1/2"@9222 Completion Details NIPPLE;8,837.7 Nominal ID Top(ft613) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 9,183.0 6,387.3 41.90 PACKER BAKER 85-40 Fl PERMANENT PRODUCTION PACKER 4.000 GAS LIFT;8,885.3 1,1 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 9,191.3 6,393.5 41.93 XO Reducing Crossover sub 2.990 9,210.2 6,407.6 42.03 NIPPLE CAMCO X NIPPLE W/PXX PLUG 2.812 9,222.1 6 416.4 42.09 XO Enlarging Vented/Ported Cross-over 3-1/2 EUE 8rd x 5-1/2"STC 2.990 GAS LIFT;8,946.8 BvP Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ttKB) (") Des Corn Run Date ID(in) (PERF;8,976.09,0500 1 1117 I 9.509.0 6,628.6 41.65 FISH 1.5"CV Empty Pocket;Fell to Rathole 8/7/1987 8/7/1997 II 9.520.0 6,636.8 41.62 FISH 1.5"OV Lost in Hole 1/25/1994 1/25/1994 al Perforations&Slots PACKER;9,061.4 -'' Shot Dens Top(TVD) Btm(ND) (shots/f GAS LIFT;9,073.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,976.0 9,050.0 6,233.8 6,288.2 C-3,C-4,1G- 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann al 05 TCP g 9,095.0 9,131.0 6,321.7 6,348.6'C-1,1G-05 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann TCP IPERF;9,095.0-9,131.0 11. 9,332.0 9,336.0 6,497.6 6,500.5 A-5,1G-05 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann TCP 9,348.0 9,378.0 6,509.4 6,531.5 A-4,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann GAS LIFT;9,145.9 TCP Mandrel Inserts LOCATOR;9,182.3 PACKER;9.183.0 Strt::: SEAL ASSEMBLY;9,183.1 at1 BBE;9,18fi.3 onTop(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com at i 2,843.2 2,490.3 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 2 4,963.2 3,737.0'CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0-4/10/2015 3 6,629.5 4,739.9 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/1012015 NIPPLE;9,210.2 4 7,828.9 5,496.1 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 5 8,722.3 6,054.4 CAMCO MMG 5.968 GAS LIFT DMY RKP 1.500 0.0 4/16/2015 DCR 1 AIlr y 6 8,885.3 6,168.4 CAMCO MMG '5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 7 8,946.8 6,212.5 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 8 9,073.0 6,305.2-CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0.3/82015 (PERF;9,332.0-9,336.0 9 9,146.0 6,359.7 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 I&Safety (PERF;9.348.0-9,378.0-. End Date Annotation 9/16/2010 NOTE:Mandrel @ 8924-Leak found 6/21/2006 @ C-sand;tbg test failed 2/9/08 confirmed C3/C4 leak FISH;9,509.0 9/162010 NOTE:View Schematic w/Alaska Schematic9.0 FISH;9,520.0 PRODUCTION;29.9-10,071.0 - a 1G-05 PRE-RIG WELL WORK SUMMARY DATE SUMMARY 3/2/2015 STAND BY FOR SNOW REMOVAL. GAUGED TBG TO 2.77"TO 8916' RKB. IN PROGRESS. 3/3/2015 ATTEMPT TO PULL PATCH @ 8918' RKB (ER PULLING TOOL NO EN GAUGING); SET 3.5"RELEASABLE SPEAR IN PATCH @ 8918' RKB &JARRED UP FOR 1.25 HOURS W/ NO 3/5/2015 W/ .160 WIRE JAR UP ON PATCH @ 8916' RKB FOR 1.5 HRS WITH NO MOVEMENT. IN 3/6/2015 W/.160" WIRE PULLED ER PATCH ASSEMBLY @ 8916'-8938' RKB (LOST ELEMENTS OFF ER PACKERS). IN PROGRESS. 3/7/2015 GAUGED TBG. TO 2.80"AND SET BAIT SUB CATCHER @ 9207' RKB; PULLED CV @ 9072' RKB; ATTEMPTED TO PULL CV @ 9152' RKB. IN PROGRESS. 3/8/2015 PULLED CV @ 9152' RKB; SET DV'S @ 9072' & 9152' RKB; TAG FILL @ 9379' SLM EST. 12' RAT HOLE; MEASURED SBHPS @ 9339' RKB (3509 PSI) SET 2.75" CA-2 PLUG @ 9207' RKB; SET 2.74" x 124" CATCHER @ 9197' RKB. READY FOR COIL 3/17/2015 SET CT PACKER @ 9045',9050',9180',9183', COULD NOT GET A PT ON THE SELECTIVE. IT APPEARS THAT THE CA-2 PLUG IS LEAKING. @ 9183' CT PACKER WOULD NOT RELEASE, HAD TO PUMP 3/4" DISCONNECT BALL TO DISCONNECT. RETURN IN THE MORNING TO RETRIEVE CT PACKER WITH FISHING TOOLS. ****JOB IN PROGRESS**** 3/18/2015 RIH, LATCH UP TO CT PACKER @ 9181' CTMD, 7 JAR LICKS CAME FREE, WELL FREEZE PROTECTED ****READY FOR DSL**** 3/20/2015 PULLED ST# 1 DMY @ 8,767' RKB, PULLED CATCHER FROM TOP OF CA-2 @ 9,207' RKB. PULLED CA-2 PLUG FROM D NIP @ 9,207' RKB. FIRED STRING SHOTS OVER INTERVALS @ 9052'-9060' RKB & 8786'-8794' RKB. *JOB IN PROGRESS. 3/21/2015 RAN 3 1/2" BRUSH & 2.70" G.RING TO D NIP @ 9207' RKB, BRUSHED AREAS FROM 8770'-8810' RKB & 9036'-9076' RKB WHILE LRS PUMPED 50 BBL HOT WATER THEN 50 BBL HOT DIESEL. SET CA-2 PLUG @ 9,207' RKB SET CATCHER SUB @ 9,207' RKB CUT TBG W/CHEM CUTTER @ 9,056' RKB ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 1G-05 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 3/24/2015 10:30:00 AM Rig Release: 4/11/2015 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/24/2015 24 hr Summary Move Rig Sub to 1G-05 and spot over well. Spot Pits to sub. Spot Cuttings bin. Berm Up.Accept Rig. Rig Up to kill well. Kill Well. Set BPV. Nipple Down Tree. Daily Losses: 194 bbls RIG ACCEPTED @ 10:30 RIG on HIGHLINE @ 16:00 00:00 08:30 8.50 0 0 MIRU MOVE MOB P Pull Pits off of Rig. Pull Rig Sub off of 1G-11. Move Sub to 1 G-05. Move Sub over well. Spot Pits up to Rig Sub. Spot Cutting Bin. 08:30 10:30 2.00 0 0 MIRU MOVE RURD P Berm up around rig, pits and cutting bin.Work on rig acceptance checklist. RIG ACCEPTED @ 10:30 10:30 11:30 1.00 0 0 MIRU WELCTL RURD P Rig Up Hardline and Choke shack. SIMOPS: Pick Up lubricator, Take on 10.7 ppg Brine to the pits. 11:30 12:30 1.00 0 0 MIRU WELCTL MPSP P Install lubricator,test to 3000 psi, pull BPV.Tubing 250 psi, OA 60 psi, IA 50 psi. Rig down lubricator and Blow down test equipment. 12:30 14:00 1.50 0 0 MIRU WELCTL RURD P Rig Up circulation lines for well kill. Test hardline with air and steam. SIMOPS: Continue to take on 10.7 ppg Brine to the pits.. 14:00 14:30 0.50 0 0 MIRU WELCTL SFTY P PJSM for well kill with all crew members. 14:30 17:30 3.00 0 0 MIRU WELCTL KLWL P Kill well with 10.7 ppg Brine. Lines tested to 3000 psi.vent tubing(240 psi)to tiger tank for 10 minutes and shut in(still 240 psi). Pump down tubing taking returns to tiger tank 3 bpm; ICP 305 psi, FCP 363 psi. RIG on HIGHLINE @ 16:00 17:30 18:30 1.00 0 0 MIRU WELCTL KLWL P Well Kill stopped after pumping 325 bbls to suck out tiger tank.280 bbls removed from Tiger Tank. 18:30 20:00 1.50 0 0 MIRU WELCTL KLWL P Continue pumping 10.7 ppg Brine 4 bpm 350 psi. FCP 450 psi. Returns cleaned up to 10.7 ppg. Slow to 1.5 bpm and close choke to bullhead 10 bbls 150 psi. Route returns into pits and then shut down. Loss rate pumping at 4 bpm is—1 bpm. Total of 501 bbls pumped during entire well kill operation. Page 1 of 17 r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 0 0 MIRU WELCTL OWFF P Monitor well 30 minutes.Well is dead(actually on a vacuum) 20:30 21:00 0.50 0 0 MIRU WHDBO MPSP P Set BPV. SIMOPS: Fill IA with Brine. 21:00 00:00 3.00 0 0 MIRU WHDBO NUND P Nipple Down tree. Pull tree of wellhead with top drive, 7k overpull to get free. Remove tree with Bridge Crane and lifting cap. 33/25/2015 Nipple Up BOPE.Test BOPE. Pull 3.5"completion free. Circulate well clean. Lay Down 3.5"completion. Daily Losses: 317 bbls 00:00 03:00 3.00 0 0 MIRU WHDBO NUND P Function LDS and install test dart. Install DSA, Nipple Up BOPE. Tighten turnbuckles. 03:00 04:00 1.00 0 0 MIRU WHDBO RURD P Rig Up to test BOPE. Make up test joint,fill stack and lines with water. 04:00 10:30 6.50 0 0 MIRU WHDBO BOPE P Test BOPE. Perform initial BOPE test per ConocoPhillips/AOGCC requirements at 250/3000 psi (Annular at 250/2500 psi)with 3 1/2"Test Joint. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector, Lou Grimaldi. All pressure tests PASS except for Upper VBR (after functioning the Upper VBR PASS).All tests recorded on a chart. Koomey draw test,good. 5 bottle avg 1990 psi.Accum Pressure 2975 psi, Manifold Pressure 1360 psi,Annular Pressure 860 psi. Pressure after all rams functioned 1700 psi. 200 psi recovery in 18 sec, full system pressure 94 sec. 10:30 11:00 0.50 0 0 MIRU WHDBO RURD P Rig down and blow down test lines and equipment. 11:00 11:30 0.50 0 0 MIRU WHDBO MPSP P Pull test Dart/BPV 11:30 12:00 0.50 0 0 COMPZ RPCOM RURD P Rig Up power tongs and equipment to pull completion. 12:00 12:30 0.50 0 8,760 COMPZ RPCOM PULL P Pull hanger free at 100k indicated. Pull cut apart at 115k indicated. Up Wt after free 88k. Terminate control line. 12:30 15:00 2.50 8,760 8,760 COMPZ RPCOM CIRC P Circulate 1.5 hole volumes. Returns after 70 bbls pumped. ICP 5 bpm 680 psi, FCP 4 bpm 480 psi. Pumped 578 bbls to get 1.5 hole volumes (with losses calculated in). 15:00 17:15 2.25 8,760 7,251 COMPZ RPCOM PULL P Lay Down 3.5 IBTM completion with control line. 17:15 17:30 0.25 7,251 7,251 COMPZ RPCOM SFTY P Kick while tripping drill. Shut in 49 sec.All crew in position 92 sec. AAR. 17:30 18:00 0.50 7,251 7,251 COMPZ RPCOM SVRG P Service Rig,Top Drive Inspection 18:00 18:45 0.75 7,251 6,949 COMPZ RPCOM PULL P Continue Lay Down 3.5 IBTM completion with control line. Page 2 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:00 0.25 6,949 6,949 COMPZ RPCOM SFTY P Kick while tripping drill. Shut in 25 sec.All crew in position 69 sec. AAR. 19:00 19:30 0.50 6,949 6,949 COMPZ RPCOM RURD P Rig Down SLB spooling unit. 32 SS bands recovered. 19:30 00:00 4.50 6,949 810 COMPZ RPCOM PULL P Continue Lay Down 3.5 IBTM completion. 33/26/2015 Continue Laying Down 3.5"completion. Set test plug.Test Valve#14. Pick Up BHA#1 (3.5"overshot). SIH Picking Up Drill Pipe. Fish Seal Assembly. Circulate hole. TOOH and LD BHA#1 and fish. PU and RIH with BHA#2(PBR spear). Daily losses: 317 bbls 00:00 01:00 1.00 810 0 COMPZ RPCOM PULL P Continue Lay Down 3.5 IBTM completion. 01:00 02:00 1.00 0 0 COMPZ RPCOM RURD P Rig Down GBR equipment. Mobilize BHA#1 components to rig floor. Clean and Clear Rig Floor. SIMOPS: Set test plug and Rig Up test equipment. Contact AOGCC Rep Chuck Scheve inform that Valve#14 was tested to 2500 psi on high test instead of 3000 psi on high test. Permission given to test valve to full pressure and proceed with well work. 02:00 02:30 0.50 0 0 COMPZ RPCOM BOPE T Test Choke valve#14 to 250/3000 psi. Charted. 02:30 03:00 0.50 0 0 COMPZ RPCOM RURD P Set Wear Ring. 6-5/16"ID. Rig Up to Pick Up BHA#1. 03:00 03:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for Picking Up BHA#1. 03:15 05:00 1.75 0 301 COMPZ RPCOM BHAH P Pick Up BHA#1. 05:00 12:30 7.50 301 8,785 COMPZ RPCOM PULD P RIH w/BHA#1 from 301-ft, picking up Drill Pipe from pipe shed to 8785'. Up Wt= 165k, Dn Wt=90k, Rot Wt = 110k, 10 rpm, 7600 ftlbs. 12:30 13:30 1.00 8,785 8,785 COMPZ RPCOM CIRC P Circulate BU 4bpm @ 790 psi. 232 bbls pumped. SPRs taken. SPRs: 8785'MD; 6108'TVD Pump 1:2 bpm =245 psi;3 bpm= 490 psi Pump 2: 2 bpm =240 psi;3 bpm = 450 psi 13:30 15:00 1.50 8,785 8,725 COMPZ RPCOM FISH P Engage fish @ 8790' lbpm 110 psi, set down 8k and then pulled off. Rotated Down onto fish.Attempted to spud fish. Fish engaged. Hit Jars 4 times @ 85k over circ 1 bpm 194 psi. Pulled free seals after 12'of travel. Up wt= 175k. 15:00 15:15 0.25 8,725 8,725 COMPZ RPCOM OWFF P Monitor well. Dead and Losing fluid. 15:15 17:30 2.25 8,725 3,896 COMPZ RPCOM TRIP P TOOH with BHA#1 and fish. 17:30 18:00 0.50 3,896 3,896 COMPZ RPCOM SVRG P Service Rig. Daily inspection of Top Drive. Service blocks. 18:00 20:00 2.00 3,896 331 COMPZ RPCOM TRIP P TOOH with BHA#1 and fish. 20:00 21:30 1.50 331 0 COMPZ RPCOM BHAH P Lay Down BHA#1 and fish. 15.17' cut joint and 12.85'seal assembly. Page 3 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:00 0.50 0 0 COMPZ RPCOM RURD P Clean and Clear Rig Floor. 22:00 22:30 0.50 0 0 COMPZ RPCOM SVRG P Service Rig. Top Drive Inspection. 22:30 22:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM for Picking Up BHA#2. 22:45 23:30 0.75 0 303 COMPZ RPCOM BHAH P Pick Up BHA#2. Spear for PBR. 23:30 00:00 0.50 303 776 COMPZ RPCOM PULD P RIH Picking Up Drill Pipe from shed. 03/27/2015 Continue to RIH with BHA#2. Circulate BU. Spear PBR and fish packer and tailpipe.TOOH and LD BHA#2. PU and RIH with BHA#3(PBR spear with rattler). Slip and Cut Drill Line. Engage PBR and fish. Daily losses:237 bbls 00:00 02:30 2.50 776 8,785 COMPZ RPCOM TRIP P Trip in Hole with BHA#2 to 8785'. 02:30 03:45 1.25 8,785 8,785 COMPZ RPCOM CIRC P Circulate BU(accounting for losses) 260 bbls. lost—30 bbls during BU.4 bpm @ 1050 psi. Up Wt= 168k, Dn Wt=94k, 1 bpm 90 psi. SPRs taken. SPRs:8785'MD;6098'TVD #1: 2 bpm =340 psi; 3 bpm =620 psi #2:2 bpm =330 psi;3 bpm=610 psi 03:45 08:30 4.75 8,785 8,785 COMPZ RPCOM JAR P Spear the PBR. Straight pull to 132k over. No release. Start using jars, 82k over hits, followed by 132k straight pull. Continue to roll pumps at 1 bpm every 5-10 min. Pump 4 bpm @ 1,050 psi in attempt to equalize hydrostatic pressure across packer. Attempt to rotate and release-No luck, Release spear grapple, PU off of fish. 08:30 09:30 1.00 8,785 8,785 COMPZ RPCOM SFTY T Conduct Post jarring inspection on derrick and top drive 09:30 13:30 4.00 8,785 500 COMPZ RPCOM TRIP T POOH from 8,727-ft w/170k Up Wt, 96K Dn Wt to 500-ft. 13:30 13:45 0.25 500 500 COMPZ RPCOM OWFF T Monitor well for flow,well still taking fluid. 13:45 14:45 1.00 500 0 COMPZ RPCOM BHAH T POOH from 500-ft and stand back drill collars, Lay down BS and Jar, lay down Spear-Grapple in good condition. 14:45 15:15 0.50 0 0 COMPZ RPCOM RURD T Clean and Clear work area, prep tools to RIH. 15:15 16:15 1.00 0 338 COMPZ RPCOM BHAH T PU, MU and RIH w/BHA#3 Spear assy w/rattler tool to catch 4" ID on PBR to 338-ft 16:15 22:00 5.75 338 8,762 COMPZ RPCOM TRIP T RIH w/BHA#3 to 8762'. Fill string every 5 stands. 22:00 23:00 1.00 8,762 8,762 COMPZ RPCOM SLPC T Slip and cut 112'of drilling line. SIMOPS: Service Drawworks. 23:00 00:00 1.00 8,762 8,815 COMPZ RPCOM JAR T Obtain parameters. Up Wt= 170k, Dn Wt=90k. Begin Rattling increasing overpull from 20k over to 100k over pull. Hit jars once at beginning. Page 4 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/28/2015 24 hr summary Continue Fish PBR and tailpipe. Fish comes free. Circulate BU.TOOH with BHA#3 and fish. Pick Up and TIH with BHA#4(3.5"Overshot) Daily Losses: 193 bbls 00:00 01:30 1.50 8,815 8,974 COMPZ RPCOM JAR P Continue Rattling continuing overpull 100k over pull. Begin Jarring. Move from 50k jar hits and 130k straight pull to 90k jar hits and 130k overpull. Continue rattling at max rate(3bpm 1710 psi).After—20 full jar hits and rattler tool operating at maximum setting held 130 over for a few min and observed weight slacking slowly. Continued to pull and continued to see very slight and slow movement. Tested down movement by slacking off,we could move down slowly.drag was 50-80k over. 01:30 02:00 0.50 8,974 8,974 COMPZ RPCOM SFTY P Post jarring derrick and top drive inspection. Fluid level observed to be dropping. 02:00 02:15 0.25 8,974 8,881 COMPZ RPCOM JAR P Pull 1 more stand with rattler tool operating.test pull without rattler tool and can pull with—10-20 overpull. 02:15 04:30 2.25 8,881 8,881 COMPZ RPCOM CIRC P Drop dart and open circulation sub at 2300 psi.Circulate Bottoms Up 3.5 bpm 650 psi.Take SPR Pump#1,2 bpm=260 psi, 3 bpm= 520 psi. 04:30 05:00 0.50 8,881 8,881 COMPZ RPCOM OWFF P Monitor Well.Well taking fluid. 05:00 11:15 6.25 8,881 500 COMPZ RPCOM TRIP P POOH to BHA#3 and Fish @ 500-ft± 11:15 11:45 0.50 500 500 COMPZ RPCOM OWFF P MOnitor well for flow w/2 stands before BHA-No flow-well taking fluid. Held PJSM with crew and 3rd party venders on pulling BHA and laying down fish. 11:45 12:45 1.00 500 249 COMPZ RPCOM BHAH P POOH w/BHA#3 12:45 15:45 3.00 249 0 COMPZ RPCOM PULL P Lay Down fish. PBR/Packer,joint, GLM, 2 joints, GLM,joint,4 blast joints, cut pup joint(3.57').Total Length 251.2'. 15:45 16:45 1.00 0 0 COMPZ RPCOM RURD P Rig Down GBR tong and equipment. Clean and clear rig floor. move used Baker Tools from floor. 16:45 17:15 0.50 0 0 COMPZ RPCOM SVRG P Service Rig. Service Top Drive. Daily Top Drive Inspection. 17:15 19:00 1.75 0 336 COMPZ RPCOM BHAH P Pick Up BHA#4(3.5"Overshot). 19:00 00:00 5.00 336 9,030 COMPZ RPCOM TRIP P Trip in hole with BHA#4 filling every 5 stands. Page 5 of 17 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 33/29/2015 24 hr Summary Fish 2nd packer and tailpipe.While fishing string parted(likely above Drill Collars). Circulate 1.5 x BU. Indications 2nd packer released due to gas during circulation. TOOH checking every connection. String parted at bottom of Inesifier above threads. PU and RIH with BHA#5(String recovery Overshot). Engage String and release at safety joint.TOOH and LD BHA#5 and fish(entire rest of string and cut joint stuck in Overshot/Grapple). Daily Losses: 199 bbls 00:00 00:15 0.25 9,030 9,055 COMPZ RPCOM FISH P Establish parameters. Up Wt= 170k, Dn Wt= 100k. Engage Grapple on cut joint. Confirm latched onto fish. Straight pull to 100 over. 00:15 01:00 0.75 9,055 8,719 COMPZ RPCOM JAR P Fire Jars at 20k overpull. Bring up pumps to run rattler tool 3 bpm 1880 psi. Straight pull to 50 over, 75 over, 100 over.After—2min at 100 over with rattler tool running string jumped and pump pressure went to 3 bpm 470 psi. Up Wt 150k. String parted likely above Drill Collars. 01:00 02:30 1.50 8,719 8,719 COMPZ RPCOM CIRC T Circulate 1.5 Bottoms Up. Observed some gas prior to and at BU indicating packer could have released prior to parting of string. SIMOPS: Inspect Derrick. 02:30 02:45 0.25 8,719 8,719 COMPZ RPCOM OWFF T Monitor Well.Well taking fluid. 02:45 03:00 0.25 8,719 8,609 COMPZ RPCOM TRIP T Trip out of the hole to 8609'. 03:00 03:30 0.50 8,609 8,609 COMPZ RPCOM SVRG T Service Top Drive and Inspect Top Drive and continue to inspect Derrick after fishing ops and string parting. 03:30 10:00 6.50 8,609 0 COMPZ RPCOM TRIP T Trip out of the hole checking all joint connections, found3-1/2 IF pin connection on 4-3/4"OD Bowen Intensifier to be parted. 10:00 10:30 0.50 0 0 COMPZ RPCOM RURD T Clean and clear work area, prep for BHA#5 10:30 11:00 0.50 0 0 COMPZ RPCOM SVRG T Daily inspection of Top drive 11:00 11:30 0.50 0 0 COMPZ RPCOM SFTY T Held PJSM with rig crew on PU, MU and RIH w/BHA#5 11:30 12:15 0.75 0 13 COMPZ RPCOM BHAH T PU, MU BHA#5 5-3/4 OS dressed for 4-3/4"catch and Lubricated bumper sub. 12:15 15:30 3.25 13 8,732 COMPZ RPCOM TRIP T PU, MU and RIH w/5-3/4 OS dressed for 4-3/4"catch and Lubricated bumper sub on 92 1/3 stds of HT 38 S-135 Drill pipe to 8,731-ft tag up,work overshot over fish,to 8,732-ft, PU and seen 12k wt increase. 15:30 16:00 0.50 8,732 9,050 COMPZ RPCOM FISH T Engage fish and PU to original string of 175k and insert 13 rds of LH torque while working string to break safety joint. PU and recovered an extra 13k in string. 16:00 20:30 4.50 9,050 318 COMPZ RPCOM TRIP T Lay down working jt, and POOH standing back 92 std's to 318-ft of fish. Page 6 of 17 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 23:00 2.50 318 0 COMPZ RPCOM BHAH T Lay Down BHA#5, BHA#4 and cut joint in Overshot. 23:00 23:30 0.50 0 0 COMPZ RPCOM SVRG P Service Rig.Top Drive Inspection. 33/30/2015 PU and RIH with BHA#6(Pup for wireline guide). RU and RIH with SLB Digital Slickline. Cutter and Drift will not go past-87'. RD SLB Digital Slickline. TOOH with BHA#6. 00:00 01:30 1.50 0 8 COMPZ RPCOM BHAH P Pick Up BHA#6. Cut joint in Overshot, Safety Joint,2 crossovers to Drill Pipe. Double check on ID, all 2-9/16 or greater. 01:30 05:45 4.25 8 8,998 COMPZ RPCOM TRIP P RIH w/BHA#6 to 8,998-ft 95K SOW 05:45 07:00 1.25 8,998 8,998 COMPZ RPCOM SLPC P Slip and Cut 58-ft of 1-1/8"Drill line 07:00 08:00 1.00 8,998 8,998 COMPZ RPCOM RURD P Locate,drift and RU equipment for Jet cut conducted on Digital Slick line. MU and tag TOF. 140K up wt, 100k Dn wt. 08:00 09:00 1.00 8,998 9,055 COMPZ RPCOM RURD P RIH w/X-O, and 3-1/2 8RD pup joints, and 1 full joint of 3-1/2 L-80 8rd to 9,055-ft 09:00 09:30 0.50 9,055 9,055 COMPZ RPCOM ELNE P Spot E-line unit, 09:30 16:30 7.00 9,055 9,055 COMPZ RPCOM ELNE P RU E-line equipment, lubricator, Sinker bars, and 2.5"Jet cutter,set down @ 89-ft, attempt to work through,turn on charge pump and attempt to pump in hole-No Luck, POOH and RD 2.5"OD Jet Cutter. 16:30 21:00 4.50 9,055 9,055 COMPZ RPCOM ELNE P PU and RIH w/2.5"OD gage ring to -90'. Set down. POOH and LD tools. Rig Down Lubricator and line. 21:00 00:00 3.00 9,055 4,027 COMPZ RPCOM TRIP T Trip out of hole. 03/31/2015 Continue to TOOH with BHA#6. LD BHA#6. PU and RIH with BHA#7(Overshot for wireline guide)on 3.5" EUE8rd work string. 00:00 02:00 2.00 4,027 8 COMPZ RPCOM TRIP T Trip out of hole. 02:00 02:45 0.75 8 0 COMPZ RPCOM BHAH T Lay Down BHA#6 and space out pups from top of string. 02:45 03:45 1.00 0 0 COMPZ RPCOM RURD T Clean and Clear Rig Floor. Rig Up to run 3.5"EUE 8rd work string. 03:45 04:00 0.25 0 3 COMPZ RPCOM BHAH T Pick Up BHA#7(SSHort Catch Overshot without grapple)and crossover. 04:00 15:00 11.00 3 9,059 COMPZ RPCOM PUTB T RIH with BHA#7 on 3.5"EUE8rd tubing. Pick up 3.5"EUE8rd tubing form pipe shed.Space out tubing for Eline 15:00 20:00 5.00 9,059 9,059 COMPZ RPCOM ELNE T PJSM, RU DSL to make dummy run,&Jet cutter. unable to get into packer with 2.5 gauge tagging @ 9030'WLM. Packer top corrected to ORKB. POOH with gauge run. Hang back tools. 20:00 20:30 0.50 9,059 9,021 COMPZ RPCOM ELNE T Pull Tbg. up 40 ft.from TOF. . Page 7of17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 9,021 9,021 COMPZ RPCOM ELNE T Run back in hole with 2.5 gauge unable to get past 9030'WLM. correct back ORKB packer top 9060 ft. POOH with tools. RD 04/01/2015 POOH with BHA#7 RIH with BHA#8 to 2779 ft Picked up storm packer&set.Test BOPE.W/Johnnie Hill AOGCC. Pull Storm packer. 00:00 00:30 0.50 COMPZ RPCOM ELNE T Continue to RD DSL. 00:30 03:30 3.00 COMPZ RPCOM WAIT T Wait on road to be cleared to get in 3rd party 03:30 11:00 7.50 9,021 0 COMPZ RPCOM TRIP T PJSM. POOH with completion string. 11:00 13:30 2.50 0 2,778 COMPZ RPCOM TRIP T RIH with BHA#8.5 7/8"Bowen over shot with 2.5 ft X 3.5 EUE 8rd stump. Up Wt=47K, Dwn Wt=45K 13:30 15:00 1.50 2,778 2,778 COMPZ RPCOM MPSP T PJSM. Installed storm packer @ 95.5 ft&test to 1000 psi. for 10 min's. Good test. 15:00 15:30 0.50 2,778 2,778 COMPZ WHDBO RURD T Pull wear bushing. bushing showed damage. 15:30 16:30 1.00 2,778 2,778 COMPZ WHDBO RURD T RU Testing equipment&prep for weekly BOPE test. 16:30 21:30 5.00 2,778 2,778 COMPZ WHDBO BOPE T Test BOPE 250/3000 psi.Johnnie Hill AOGCC witnessed test. Test: #1)BR,Choke 1,2,3,16, KM Demco, 3.5 HT 39 Dart valve. passed #2)HCR kill, Choke 4,5,6 Passed #3)Man kill, Choke 7,8,9 Passed #4)Flow check Super choke, man choke Pass. #5)HT 38 FOSV, Choke 10,11 passed #6)Choke 12,13,15 passed #7)Annular W/3.5 TJ, 3.5"EUE 8rd FOSV, Choke 14. Passed #8)TD HCR, UPR W 3.5 TJ passed #9)TD manual passed #10) Lower PR,W 3.5 TJ, Passed. Accumulator build up/fuction test. passed. Nitrogen bottles 1 @ 1950 psi. 5@ 2050 psi. 21:30 22:00 0.50 2,778 2,778 COMPZ WHDBO RURD T RD testing equipment. 22:00 00:00 2.00 2,778 2,778 COMPZ RPCOM MPSP T Released test packer. Flow check 15 min's lay down packer. Page 8 of 17 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 34/02/2015 24 hr Summary RIH with BHA#8 5 7/8 over shot with 3.5"tubing stump as guide. RIH W/DSL to make Jet cut in lower completion. Unable to get past 9039 ft. RD DSL. POOH with BHA#8 00:00 05:00 5.00 2,789 9,060 COMPZ RPCOM TRIP T Continue to RIH with BHA#8. Tag up and set down at 9060' DPM. Repeat to verify set down and alignment correct. 05:00 08:00 3.00 9,060 9,060 COMPZ RPCOM RURD T PJSM RU Schlumberger DSL PT lubicator to 2500 psi. 08:00 13:00 5.00 9,060 9,060 COMPZ RPCOM ELNE T RIH with 2.5 gauge rig enable to get past 9039'. POOH with gauge run ., RIH with Blind box. Unable to get down 9029'. RIH with Stren swedge unable to get past 9029' . 13:00 13:30 0.50 9,060 9,060 COMPZ RPCOM CIRC T Attempted to circulate possible fill out @ 2BP @ 165 psi. unable to get down. POOH . . 13:30 18:00 4.50 9,060 9,060 COMPZ RPCOM ELNE T RIH with IBP tagged. POOH. No real indication of fill or junk. RD DSL 18:00 00:00 6.00 9,060 900 COMPZ RPCOM TRIP T POOH with BHA#8 04/03/2015 RIH with BHA#9:5 7/8 over shot fishing assembly. Engaed packer at 9060 ft attempted to jar packer free working jarring up to 100 K over W/200 K direct pull.with out success. attempted to right hand release without success. POOH with BHA#9. RIH with 6 1/8"X 4 3/4"Burn shoe assembly to 5608 ft. Total fluid losses for the day-140 BBLS. Total Fluid losses for well to date-2294 BBLS. 00:00 01:00 1.00 900 0 COMPZ RPCOM TRIP T Continue to POOH with BHA#8 01:00 01:30 0.50 COMPZ RPCOM RURD T Change over handling equipment to DP&RD GBR tongs. 01:30 02:00 0.50 COMPZ RPCOM SVRG T Sevice and inspect Top drive unit. 02:00 04:30 2.50 0 406 COMPZ RPCOM BHAH T Picked up BHA#9 Jarring assembly. 04:30 08:30 4.00 406 9,048 COMPZ RPCOM TRIP T RIH with BHA#9&Drill pipe Up wt = 145 K, Dwn wt= 110 K, Rotaion wt = 123 K,Torque @ 10 RPM's= 5200. 08:30 14:00 5.50 9,048 9,060 COMPZ RPCOM JAR T Engaged packer Warmed up jars with 30K pull.worked jars up to 100 K over pull.&&200 K straight pull. worked jars for 4 hrs, 165 hits without success.Attempted to right hand release packer with out success. Release over shot. 14:00 14:30 0.50 9,060 9,048 COMPZ RPCOM SFTY T Complete post jarring inspection 14:30 16:00 1.50 9,048 9,048 COMPZ RPCOM CIRC T Condition brine @ 5 BPM @ 1250 psi. 16:00 16:30 0.50 9,048 9,048 COMPZ RPCOM OWFF T Monitor well&blow down TD. 16:30 20:00 3.50 9,048 403 COMPZ RPCOM TRIP T POOH with BHA#9 20:00 21:30 1.50 403 0 COMPZ RPCOM BHAH T Lay down BHA#9 21:30 22:30 1.00 0 403 COMPZ RPCOM BHAH T Pick up BHA# 10 6 1/8 Burn showe assembly 22:30 00:00 1.50 403 5,608 COMPZ RPCOM TRIP T RIH with BHA#10 on drill pipe Page 9 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/04/2015 24 hr Summary Milled on HB packer @ 9060 ft. Milled off a foot. Body of packer is rotating. Unable to make any hole. POOH with BHA#10. Make up&RIH with BHA# 11. Jarring assembly. Slip&cut DL Total fluid losses for the day-234 BBLS. Total Fluid losses for well to date-2528 BBLS. 00:00 02:00 2.00 5,608 9,060 COMPZ RPCOM TRIP T Continue to RIH with BHA#10. 02:00 12:00 10.00 9,060 9,061 COMPZ RPCOM MILL T Begin Milling on Packer. Up Wt. = 145K.Dwn Wt=110K. Rotation 130K. Est circulation @ 5 BPM @ 1180 PSI. F/T=5.5. @ 50 RPM's. 7.5-9 K W/5-7K on mill. 12:00 12:30 0.50 COMPZ RPCOM OWFF T Flow check 30 min's: loss=7 BPH 12:30 16:30 4.00 9,061 403 COMPZ RPCOM TRIP T POOH with BHA#10 16:30 18:00 1.50 403 0 COMPZ RPCOM BHAH T Laid down mill assembly and inspected. Minor wear on lower mill. Discuss options with engineer.Top one foot of the packer is milled off including the set screws. Suspect packer will come free with pull on inner sleeve. 18:00 19:30 1.50 0 402 COMPZ RPCOM BHAH T Pick up 5 7/8"Overshot assembly with 4 5/8"grapple. BHA#11. 19:30 23:30 4.00 402 8,920 COMPZ RPCOM TRIP T RIH with Drill pipe&BHA#11. Observed proper displacement. 23:30 00:00 0.50 8,920 8,920 COMPZ RPCOM SLPC T Held PJSM. Slip&cut 90'of Drilling line. 04/05/2015 Jar HB packer free, Circulated BU. POOH lay down HB packer assembly 121 ft recovered. RIH with 6 1/8 X 2 3/8 Packer mill assembly. Total fluid losses for the day-345 BBLS. Total Fluid losses for well to date-2873 BBLS. 00:00 01:00 1.00 8,920 8,920 COMPZ RPCOM SLPC T Continue to Slip&cut DL. 01:00 05:00 4.00 8,920 9,060 COMPZ RPCOM JAR P Engage packer @ 9060.0 ft. begin jarring operations. Up Wt= 150K Dwn Wt=105K.Warm up jars @ 45K Over.Worked jars @ 100 K over and pulled 215K over after impact.Worked 3 rounds into string got back 2. Continue jarring. Pulled free, observed 2K extra wt. 112 total jar hits. 05:00 06:30 1.50 9,060 9,050 COMPZ RPCOM CIRC P Circulated Bottoms up @ 4 BPM @ 1100 psi. Observed champagne gas breaking out at surface. Circulate, Monitor well until)static. • 06:30 14:30 8.00 9,050 403 COMPZ RPCOM TRIP P POOH with BHA#11 14:30 17:30 3.00 403 0 COMPZ RPCOM BHAH P Laid down121 ft of fish&BHA#11. 2 Slip segments missing off of E-22 Latch assembly 17:30 19:00 1.50 0 404 COMPZ RPCOM BHAH P PJSM Pick up BHA#12. Packer milling assembly. 19:00 00:00 5.00 404 9,181 COMPZ RPCOM TRIP P RIH with DP&BHA#12 Page 10 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/06/2015 24 hr Summary Milled up 3H packer @ 91814 ft chased packer to 9374 ft. POOH with Mil assembly. RIH with Spear assembly fished packer 10-25 K drag up. Fluid lost for the day=298 BBIs.Total fluid losses to the well=3171 BBLs. To date. 00:00 05:30 5.50 9,181 9,181 COMPZ RPCOM MILL P Est circulation @ 4 BPM @ 850 PSI. Up wt.=160K Dwn wt= 105K. F/T= 8 K @ 40 RPM's. Tagged packer and begin milling process. Sat 3K on mill TD RPM's @ 80 Torque @ 9 K.Wt to mill 5-10 K torque 10.5- 12 K. Upper Slip bonnet is rotating. Dry milled for 15 min's Continue milling ops. 05:30 06:45 1.25 9,181 9,181 COMPZ RPCOM CIRC P Packer fell, circulate bottoms up. Observed gas breaking out at surface, continue circulating until well dead and static. 06:45 07:45 1.00 9,181 9,347 COMPZ RPCOM PULD P Trip in hole with singles of drill pipe to chase packer down to 9374'DPM. Push weight 5-10 K. 07:45 12:45 5.00 9,347 403 COMPZ RPCOM TRIP P Well static. POOH with milling BHA to surface. Observed proper displacement.Well taking fluid. 12:45 13:30 0.75 403 0 COMPZ RPCOM BHAH P Lay down BHA# 12 13:30 14:00 0.50 0 395 COMPZ RPCOM BHAH P Pick up BHA# 13 14:00 17:00 3.00 395 9,355 COMPZ RPCOM TRIP P RIH with BHA#13 spear assembly. 17:00 18:00 1.00 9,355 9,291 COMPZ RPCOM FISH P Engaged fish Up wt= 167K Dwn wt.= 100K.set graple pulled up to 275K straight pull worked fis up/ down twice fish free.dragging 10-25 K ove string wt. 18:00 19:00 1.00 9,291 9,221 COMPZ RPCOM CIRC P Circulated BU @ 4BPM @ 2000 psi. well stactic.taking fluid. 19:00 00:00 5.00 9,221 395 COMPZ RPCOM TRIP P POOH with BHA#13&fish 04/07/2015 Lay down fished packer. Pick up BHA#14 clean out assembly. Run in hole and clean out to 9,417'. Circulate hole clean. POOH with cleanout assembly. Lay down BHA#14. Wash out stack and rig up and test BOPE's. Daily fluid lost to the formation: 238 bbls, Total lost: 3409 bbls 00:00 02:30 2.50 395 0 COMPZ RPCOM BHAH P Lay down BHA/fish recovered 39.71 ft of fish. Had to work grapple out of fish due to junk. 02:30 04:00 1.50 0 425 COMPZ WELLPF BHAH P PJSM pick up BHA#14 Clean out assembly. 04:00 08:00 4.00 425 9,227 COMPZ WELLPF TRIP P RIH with drill pipe&BHA#14 to 9,227'. 08:00 09:00 1.00 9,227 9,417 COMPZ WELLPF REAM P Establish parameters; PUW 175K, SOW 98K. Free torque 9640 ft-lbs at 40 rmps. Establish circulation at 5 bpm 1250 psi. Wash and ream down from 9,227 to 9,417'. Observe increase in torque at 9,385', to 10,500- 11,000 ft-lbs, Slow string speed to allow torque to burn off. Page 11 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:30 1.50 9,417 9,322 COMPZ WELLPF CIRC P Circulate hole clean, pumping 20 bbls of high viscosity pill. Rotating and reciprocating pipe. Monitor well, loss rate 11 bph. 10:30 11:00 0.50 9,322 9,322 COMPZ WELLPF SVRG P Inspect and service top drive. 11:00 13:30 2.50 9,322 5,156 COMPZ WELLPF TRIP P POOH with cleanout assembly from 9322 to 5156'. 13:30 14:15 0.75 5,156 5,156 COMPZ WELLPFOTHR P Pick up Camco D nipple from decompletion and break out to allow HES to retrieve CA-2 plug. 14:15 16:30 2.25 5,156 525 COMPZ WELLPF TRIP P Continue to POOH from 5,156 to 525' 16:30 19:00 2.50 525 0 COMPZ WELLPF BHAH P Lay down drill collars and BHA, clean out junk baskets and magnet. 19:00 21:30 2.50 0 0 COMPZ WHDBO RURD P Pull wear bushing. Rig up and flush BOP Stack. 21:30 22:30 1.00 COMPZ WHDBO RURD P Install test plug Rig up to test BOPE's. 22:30 00:00 1.50 COMPZ WHDBO BOPE P Weekly BOPE test with 3-1/2"test joint to 250/3000 psi. Right to witness waived by Bob Noble. 1. Blind rams; Rig floor kill; Outer test spool; IBOP; Chokes 1, 2, 3, 16 -pass. 2. Bline rams; HCR kill; inner test spool; manual IBOP; Chokes 4, 5, 6 -pass. 04/08/2015 Continue with BOPE test with 3-1/2"TJ 250/3000 psi. Right to witness waived by Bob Noble. Accumulator test: starting pressure 2980 psi, final 1700 psi. First 200 psi recharge 18 seconds,total recharge 93 seconds. 5N2 bottles at 2000 psi. Rig up and run in hole with Lower Completion on drill pipe. Space out. Spot E-line Unit. Daily fluid lost to the formation 240 bbls. Total lost 3649 bbls. Page 12of17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:45 4.75 0 0 COMPZ WHDBO BOPE P Continue to test BOPE with 3-1/2" test joint to 250/3000 psi. Right to witness waived by Bob Noble. 3. Blind rams; Manual kill; inner test spool; HT 38 TIW; Chokes 7, 8, 9 -pass 4. Blind rams; Manual kill; Inner test spool; HT38 Dart; Chokes 10,11 - pass 5. Blind rams; Manual kill; chokes 12, 13, 15 -pass 6.Annular with 3-1/2"TJ; Manual kill; 8rd TIW; Choke 14-pass 7. Upper pipe rams with 3-1/2"TJ; Choke HCR; Manual Kill; 8rd TIW- pass 8. Upper pipe rams with 3-1/2"TJ; Manual Choke, Manual Kill; 8rd TIW -pass 9. Lower pipe rams with 3-1/2"TJ; 8rd TIW-pass. Koomey test-starting pressure 2980 psi,final 1700 psi. First 200 psi recharge 18 seconds,total 93 seconds. 5 N2 bottles at 2000 psi 04:45 06:00 1.25 0 0 COMPZ WHDBO RURD P Rig down testing equipment 06:00 09:45 3.75 0 0 COMPZ RPCOM RURD P Pep to run the Lower Completion. Change Bails. Rig up fill-up line. Rig up GBR equipment. Review Lower Completion running order. 09:45 10:00 0.25 0 0 COMPZ RPCOM SFTY P Safety meeting with all. 10:00 13:45 3.75 0 0 COMPZ RPCOM PUTB T Pick-up the Mule Shoe Wearsox Joint. Attempt to run in the hole...however,the joint stacked out at 12-ft below the wellhead. Pulled the joint and noticed that one of the Wearsox bands had"scuff mark"on it. Measured the OD and found out to be 6.250"(drift OD=6.151"). Measured the remaining bands and found them to be closer to spec (6.00"OD). Report finding to the Anchorage Engineer. Lay down the joint and dress-off the oversized band with a peanut grinder/gauge ring. Check all of the bands on the second Wearsox joint...ok. Page 13 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 15:30 1.75 0 161 COMPZ RPCOM PUTB P Single in the Lower Completion as follows: 2 ea 5 1/2"Wearsox Joints, XO Ported-Sub,2.813"X-Nipple Assembly w/PXX Plug installed (BakerLoc'd the required connections in the Tailpipe) Baker F-1 Permanent Packer Assembly...Continue to pick-up the following:...Note:the following not part of the Lower Completion...Baker Setting Tool Assembly and the Baker Retrievamatic Test Packer Assembly. 15:30 22:00 6.50 161 9,152 COMPZ RPCOM RCST P Continue to trip in the Lower Completion with 3 1/2"Drill Pipe from the Derrick to 9,152'. SOW 92K. 22:00 23:00 1.00 9,152 9,307 COMPZ RPCOM RCST P Run in hole with lower completon picking up singles from the pipe shed and space out to 9,307'. PUW 174K, SOW 92K. 23:00 00:00 1.00 9,307 9,307 COMPZ RPCOM RURD P Clean and clear rig floor. Sim Ops: Spot Halliburton E-line up to rig. 04/09/2015 Rig up E-Line and coorelate to 1983'CBL. Determine spaceout. Attempt to pick up 5'; unable to move. Set F-1 Packer. Release and set test packer. Test F-1 to 1500 psi Packer,good. Circulate hole clean. POOH laying down drill pipe. Rig up and run in the hole with upper completion as per detail to 84'. Daily fluid lost to formation 240 bbls,total lost 3889 bbls. 00:00 01:00 1.00 9,307 9,307 COMPZ RPCOM ELOG P Rig up E-line. 01:00 03:30 2.50 9,307 9,312 COMPZ RPCOM FLOG P Run in hole with E-line. Coorelate to K-1 Marker at 8,833'to Dresser Atlas Cement Bond Long dated 2-16-83. Determine Space out. POOH with Halliburton E-Line. 03:30 04:30 1.00 9,312 9,312 COMPZ RPCOM ELOG P Rig down E-Line. 04:30 05:00 0.50 9,312 9,312 COMPZ RPCOM SVRG P Inspect and service top drive. Determine space-out-5'low. 05:00 06:00 1.00 9,312 9,312 COMPZ RPCOM HOSO T Attempt to pick up on packer to set on depth. Unable to travel up, Slack off, pick up to 200K no travel. Troubleshoot packer, appear set. Discuss Options with town. 06:00 06:45 0.75 9,312 9,312 COMPZ RPCOM PACK P Rig up to set the Baker F-1 Packer. Rig up test equipment. Page 14of17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:00 1.25 9,183 9,183 COMPZ RPCOM PACK P Set F-1 Packer as follows: Slack off to close the Bumper Sub. Bring Pump on line and pressure up on the Drill Pipe to 2,500 psi(note: observed a pressure bump at 1,700 psi...good indication packer set). Hold the pressure at 2,500 psi x 5 minutes. Continue to hold pressure and pull up to 215K...40K over the string weight and hold x 5 minutes. Bleed off pressure and slack off to neutral weight(175K). Rotate to the right 2 turns and work the torque down to the setting tool. Repeat x 10. Total turns to the right=20. Pick-up...Setting Tool released. Pick-up 10-ft, rotate to the left to set the Retrievamatic Test Packer. Pressure up on the Drill Pipe to 1,500 psi to pressure test the F-1 Pack x 10 minutes. Good test. Breed of pressure and release the test packer. All tests recorded on a chart. Top of the F_1 PAcker at 9182.99-ft 08:00 10:00 2.00 9,183 9,152 COMPZ RPCOM CIRC P Circulate bottoms up at 3.0 bpm/490 psi....(SIMOPS Slip and cut Drilling Line at the same time). 10:00 19:30 9.50 9,152 32 COMPZ RPCOM PULD P Single down the 3 1/2"Drill Pipe to the Pipe shed to 32'. 19:30 20:00 0.50 32 0 COMPZ RPCOM BHAH P Lay down test packer and setting tool 20:00 20:30 0.50 0 0 COMPZ RPCOM RURD P Pull wear bushing. 20:30 21:30 1.00 0 0 COMPZ RPCOM RURD P Rig up GBR,tubing elevaters. Verify running order and prep pipe shed. 21:30 00:00 2.50 0 84 COMPZ RPCOM PUTB P RIH with lower completions as per detail to 84'. Pick up and make up seal assembly, GLM and blast joint. 04/10/2015 Continue to RIH with 3-1/2"completion;tight at 8,801'. Locate lower completion. Spot 20 bbls corrosion inhibited brine from F-1 Packer to 8,600'. No-Go seal assembly and space out 1'. Shear out PBR. Space out. Make up hanger and landing joint. Displace well to 8.6 ppg corrosion inhibited seawater. Daily fluid lost to the formation 243 bbls. Total lost 4132 bbls 00:00 03:00 3.00 84 409 COMPZ RPCOM PUTB P Continue to run in hole with 3-1/2 upper completion to 409'. Picking up completion equipment; blast joints, GLM, FHL packer, Blast Joints, Nipple, GML, FHL Packer. Page 15 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 15:15 12.25 3,600 9,191 COMPZ RPCOM PUTB P Continue to run the Upper Completion on 3 1/2"Tubing from the Derrick to—8,801-ft(packer set down. Work free). Continue in the hole. Bring pump on line at 15 spm/65 psi...continue in and enter the top of the F-1 Packer. Pressure jumped up to 105 psi. End pump and bleed off pressure. Continue in to"No-Go"at 9,185.34'. (Top of the F-1 Packer is at 9,184.24'...Seal Assembly Mule shoe depth is at 9,191.59'). 15:15 15:45 0.50 9,191 9,191 COMPZ RPCOM HOSO P Bring pump on line at 15 spm/65 psi...continue in and enter the top of the F-1 Packer. Pressure jumped up to 105 psi. End pump and bleed off pressure. Continue in to"No-Go"at 9,185.34'. (Top of the F-1 Packer is at 9,184.24'...Seal Assembly Mule shoe depth is at 9,191.59'). 15:45 17:45 2.00 9,191 9,180 COMPZ RPCOM CRIH P Sting back out of the F-1 Packer. Bring pump on line at 2.0 bpm/155 psi. Pump a 10.7 lb/gal, 20 bbls Corrosion Inhibited Pill(Congor 303A(-1.3%concentration with 5 lbs/Sodinm Metabisufite and 1.5 gals of Busan 1060). Chase the Pill in place with 75 bbls 10.7 lb/gal Brine at 3.1 bpm/315 psi. End pump. 17:45 19:15 1.50 9,180 9,184 COMPZ RPCOM PACK P Sting back into the F-1 Packer and leave 1-ft"stick-up"from"No-Go". Pressure up on the tubing to 2,500 psi. Observe tubing bobble, good. Stack 30K down on Packer. Increase pressure to 3,000 psi and hold for 10 minutes. Good. Bleed tubing pressure down to 2,000 psi and block in. Pressure up on the Casing to 2,500 psi x 10 minutes. Good. 19:15 20:30 1.25 9,184 9,184 COMPZ RPCOM HOSO P Shear Seal Assembly free from the PBR. Calculate space out. Make up hanger. Rig up head pin and circulating hoses to landing joint. 20:30 22:00 1.50 9,184 9,184 COMPZ RPCOM PULD P Lay down remaining stands of tubing. Simops: prep pits for displacement. Empty pits of fluid,take on seawater, build spacer. 22:00 22:45 0.75 9,184 9,184 COMPZ RPCOM RURD P Rig down GBR equipment, clean and clear rig floor. Simops: prep pits for displacement. Empty pits of fluid,take on seawater, build spacer. Page 16 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 9,184 9,184 COMPZ RPCOM CRIH P Displace 10.7 ppg brine to 8.6 corrosion inhibted seawater. Pump 40 bbls 10.7 ppg high viscosity spacer, 150 bbls 8.6 ppg neat clean water,290 bbls corrosion inhibted seater, and 20 bbls neat seawater. 2.5 bpm, ICP 580 psi, FCP 210 psi. 04/11/2015 Continue to displace well to corrosion inhibited seawater. Land tubing. RILDS. PT tubing 3500 psi for 10 minutes. PT IA 3000 psi for 30 minutes. Shear out SOV. Install and test TWC. N/D BOPE, N/U tree. Test tree and packoffs 250/5000 psi. Pull TWC. Freeze protect well. Install BPV. 00:00 01:00 1.00 COMPZ RPCOM CRIH P Continue to displace the well to corrosion inhibited seawater. 01:00 01:30 0.50 COMPZ RPCOM THGR P Land tubing. RILDS 01:30 04:00 2.50 COMPZ RPCOM PRTS P Rig up and test the tubing to 3500 psi for 10 minutes-good. Bleed pressure to 2000 psi. PT IA to 3000 psi for 30 minutes-good. Bleed pressure. Shear out SOV at 2700 psi. Rig down testing equipment. 04:00 05:30 1.50 COMPZ WHDBO MPSP P Back out landing joint. Install TWC. Test to 1000 psi from below. 05:30 09:30 4.00 COMPZ WHDBO OTHR P Clean under rotary table, drip pan. Blow down all lines. Off load fluid from pits 09:30 11:00 1.50 COMPZ WHDBO NUND P Nipple down BOPE's 11:00 13:00 2.00 COMPZ WHDBO NUND P Nipple up tree and adapter flange 13:00 14:30 1.50 COMPZ WHDBO PRTS P Test tree and hanger packoffs 250/5000-good. 14:30 17:30 3.00 COMPZ WHDBO FRZP P Free protect well; PT hard lines to2500 psi. Rig up Little Red Services. Reverse circulate 75 bbls of diesel ag 2 bpm ICP 550, FCP 750 psi. Allow diesel to U-tube. 17:30 18:00 0.50 COMPZ WHDBO MPSP P Install BPV. Final pressures Tubing=0, IA=0 psi, OA= 100 psi Rig Released 18:00 Page 17 of 17 1G-05 PRE-RIG WELL WORK SUMMARY DATE SUMMARY POST-RIG WELL WORK SUMMARY 4/16/2015 DRIFTED TBG TO 2.72"TO 9185' SLM. BAILED FILL OFF P-PRONG IN PXX PLUG @ 9210' RKB. REPLACED SOV @ 8722' RKB WITH DV. IN PROGRESS. 4/17/2015 MIT TBG & MIT IA 2500 PSI EACH, PASSED. PULLED 2.81"XX PLUG @ 9210' RKB. DRIFTED 2.72" & 5' x 2.5" BAILER TO TAG © 9410' SLM. DRIFTED TBG WITH 2-5/8" DUMMY WHIPSTOCK TO 9427' RKB. MEASURED A SAND BHP @ 9280' RKB: 3542 PSI. \g 3- 020 2511 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 21, 2015 Attn.: Makana Benderice : ' „4. 333 West 7th Avenue, Suite 100 i.".AY 0 1 NIS DATA LOGGED Anchorage, Alaska 99501 5 .BEND i K.BEND R A0000 RE: Correlation Record: 1G-05 Run Date: 4/9/2015 The technical data listed below is being submitted herewith. 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 1G-05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20908-00 SCANNED MAY 2 7 2015 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: ✓aiz...., OF T�� �w\�\I�j,.. THE STATE Alaska Oil and Gas ofALASIc:A Conservation Commission ___= tlf }�t 333 West Seventh Avenue At, .0 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' F w% Main: 907.279 1433 ALAS- Fax: 907 276.7542 www aogcc alaska gov SCAHNED Brett Packer Supervising Workover Engineer 3 -- O Xb ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 G-05 Sundry Number: 315-050 Dear Mr. Packer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 . Daniel T. Seamount, Jr. Commissioner (1--j DATED this 2 day of February, 2015 Encl. ' STATE OF ALASKA ' A. .KA OIL AND GAS CONSERVATION COMMI. _N • ' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r . Change Approved Program r Suspend r Rug Fbrforations r Perforate r Pull Tubing r 4 Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Pull patch,CTD Set-Up . 17 Operator Name. 4 Current Well Class 5 Permit to Drill Number. ConocoPhillips Alaska, Inc. Exploratory r Development r 183-020 • 3.Address: 6.API Number: Stratigraphic r Service p- . P.O.Box 100360,Anchorage,Alaska 99510 50-029-20908-00 7 If perforating, What 8.Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 KRU 1 G-05 v 9.Property Designation(Lease Number). 10 Field/Pool(s) ADL 25640 ' Kuparuk River Field/Kuparuk River Oil Pool ' 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft)• Plugs(measured) Junk(measured): 10086 7068 9975' ' 6982' • none 9509,9520 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80' 80' SURFACE 2494 10.75 2524' 2278' RECEIVED PRODUCTION 10041 7 10071' 7056' FEB 0 3 Z015 .AOGCC Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size Tubing Grade: Tubing MD(ft) 8976-9050,9095-9131,9332-9336,9348-9378 6234-6288,6322-6349,6398-6501,6509-6532 3.5 J-55 9224 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB RETRIEVABLE PACKER - MD=8820 TVD=6122 PACKER-WEATHERFORD ER PACKER • MD=8916 TVD=6190 PACKER-WEATHERFORD ER PACKER • MD=8938 TVD=6206 PACKER-BROWN HB RETRIEVABLE PACKER ` MD=9060 TVD=6296 PACKER-BROWN 3H PERMANENT PACKER MD=9181 TVD=6386 SSSV-CAMCO TRDP-1A SSA • MD=1831 TVD=1757 12.Attachments: Description Summary of Proposal „ p 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14.Estimated Date for Commencing Operations 15. Well Status after proposed work 4/19/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date VVINJ p u GINJ r WAG r Abandoned r Commission Representative GSTOR r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact. Brett Packer @ 265-6845 Email J Brett.Packer@conocophilliDs corn Printed Name BrettPackerTitle Supervising Workover Engineer Signature 7(/Z ??.,e.,-1_ Phone.265-6845 Date e/i/ Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 3t5 - 0S0 Plug Integrity r BOP Test f Mechanical Integrity Test Location Clearance r CUP f-e-5/- to 3ovv ps1 (Nt r? 5P 1-5 /867 p5', -) Other. /61,vi vi v i cr r /21_2,..v c vi f t tis 1– to Z 5 )b p.5 r i v. G C 17'�+ . �f-ati w,t0r55rd � ! T-/A rrTvirrd a ft-e- 1-.r b� h3�a J. Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required f U — 4 0 if APPROVED BY Z /�7 3 / (5 Approved by: 0 / COMMILSSIONER THEis- COMMISSION Date: G — Appici e�iti n a dlici fur 12 moritlra fru n ire odle u cippruVdl. N,� A ^•,^.z T1s p Form 10-403(Revised 10/2012) KK I `v= A itIi I Submit Form and Attachments in Duplicate fT1- 2/Z4' //5 RBDMFEB 2 4 2015 lipv RECEIVED ConocoPhillips Alaska FEB 0 3 2015 P.O. BOX 100360 /A OGc� ANCHORAGE,ALASKA 99510-0360 !`� February 2, 2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Injection Well 1G-05 (PTD# 183-020). Well 1G-05 was drilled and completed in1983 as an A&C Sand producer. The well was on production until 1988, and then converted to injection service following a rig workover. The well is currently online and has complete mechanical integrity. A coiled-tubing drilling sidetrack is planned for 1G-05,targeting injection into the A-Sand in support of planned CTD sidetrack producer 1G-12. 1G-05 currently has a straddle patch in the tubing across a leaking injection mandrel in the C3/C4 interval. The patch has an ID restriction of 1.58". A rig workover is required to remove the ID restriction and repair the leaking selective in preparation for the CTD sidetrack. The scope of the workover begins with an attempt to pull the patch with slickline pre-rig,then test the integrity of the lower selective across the Cl sand. If both are successful,the scope of the workover would be to simply run new 3-1/2"tubing with a stack packer straddling the C3/C4(proposed schematic WBS Option 1.) Alternatively,the entire completion may need to be pulled,and a triple selective completion will be run,with a large tail pipe below the permanent packer(WBS Option 2.) Stretching (casing growth)of the 7"production casing to proactively address any possible subsidence is also planned. This Sundry application is intended to document and request approval to proceed with the proposed work of pulling the patch pre-rig and the subsequent workover on injection well 1G-05. Due to the pre-rig work required to determine the final scope of the workover, and the need for sundry approval to begin the pre-rig work, a quick turnaround is kindly requested. If you have any questions or require any further information,please contact me at 265-6845. Regards, i Brett Packer Supervising Workover Engineer CPAI Drilling and Wells J.Brett.Packer@conocophillips.com 1G-05 Kuparuk Injector Rig Workover (PTD#: 183-020) Current Status 1G-05 is currently on injection. Scope of Work The goal of the workover is to prepare the well for a coiled-tubing drilling sidetrack. 1G-05 currently has a straddle patch in the tubing across a leaking injection mandrel in the C3/C4 interval. The patch has an ID restriction of 1.58". A rig workover is required to remove the ID restriction and repair the leaking selective in preparation for the CTD sidetrack. The scope of the workover begins with an attempt to pull the patch with slickline pre-rig, then test the integrity of the lower selective across the C 1 sand. If both are successful, the scope of the workover would be to simply run new 3-1/2" tubing with a stack packer straddling the C3/C4 (proposed schematic WBS Option 1.) Alternatively, if the patch does not pull pre-rig or we cannot confirm integrity of the lower selective,the entire completion will need to be pulled, and a triple selective completion will be run, with a large tail pipe below the permanent packer(WBS Option 2.) Stretching(casing growth)of the 7" production casing to proactively address any possible subsidence is also planned. General Well info MPSP: 1807 psi using SBHP from 12/8/2011 with a 0.1 psi/ft gas gradient Reservoir pressure/TVD: 2445 psi at 9,177' MD(6,383' TVD) SBHP taken on 12/8/2011 New SBHP will be requested pre-rig Wellhead type/pressure rating: McEvoy Gen 1 retrofit, 11"3K btm x 7-1/16" 5K top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-OA,to 1800 psi: Passed, 12/20/2014 MIT-IA,to 3000 psi: Passed, 12/19/2014 Tubing and Inner casing pack-offs passed pressure test, 12/19/2014 Well Type: Injector Estimated Start Date: April 19, 2015 (rig ETA in April; pulling patch pre-rig requires sundry approval) Drillsite Production Engineer: John Cookson (265-6547/John.Cookson@conocophillips.com) Workover Engineer: Brett Packer ( 265-6845 /J.Brett.Packer@conocophillips.com) 1G-0S Kuparuk Injector Well Information Sheet Page 1 Pre-Rig Work 1. MIRU Slickline: Obtain SBHP,attempt to pull patch from 8916' MD If Patch Successfully Pulls: a. Continue w/Slickline: Pull CV's from GLM's#4 at 9073' MD and 9152' MD respectively and replace w/DV's. Drift the tubing to 2.80"for CTD clearance. Set a 2.75"plug in the `D' nipple at 9207' MD, set catcher sub on top. RDMO Slickline. b. MIRU CTU: Run an inflatable test packer to test lower the selective(C-1 sand)for integrity. c. MIRU DSL: Pull the DV from GLM#1 at 8767' MD. RIH w/GR/CCL&Chem cutter, cut the tubing at 9055' MD. RIH w/GR/CCL&Chem cutter and cut the tubing at 8790' MD. d. Set BPV. If Patch Cannot be Pulled with Slickline: a. RDMO Slickline. b. MIRU CTU: Attempt to pull patch at 8916' MD. If Patch Successfully Pulls with CTU: a. Continue w/CTU: Run an inflatable test packer to test lower the selective (C-1 sand)for integrity. b. MIRU DSL: Pull the DV from GLM#1 at 8767' MD. RIH w/GR/CCL& Chem cutter,cut the tubing at 9055' MD. RIH w/GR/CCL&Chem cutter and cut the tubing at 8790' MD. c. Set BPV. If Patch Cannot be Pulled with CTU: a. RDMO CTU. b. MIRU DSL: Pull the DV from GLM#1 at 8767' MD. RIH w/GR/CCL& Chem cutter, cut the tubing at 8900'MD. RIH w/GR/CCL&Chem cutter and cut the tubing at 8790' MD. c. Set BPV. 1G-05 Kuparuk Injector Well Information Sheet Page 2 Option#1: Proposed Procedure (If patch successfully pulls and lower selective pressure tests) 1. MIRU. Pull BPV. Circulate kill weight fluid. Verify well is dead. Set BPV. 2. ND tree,NU BOPE&test to 30 p i. Pull test plug and BPV. 3. POOH laying down tubing. a. On TOH(after the SSSV has cleared the rig floor), set a storm packer at.-100' MD w/ remaining completion hanging below. PT storm packer. RU Hydratight equipment if necessary. ND BOP and tbg head,replace tbg head&IC packoffs,NU BOP&test.Pull storm packer. Continue laying down completion. 4. RIH w/overshot& grapple on drillpipe to tubing stub at 8790' MD, engage the tubing stub and jar the seal assembly from the PBR. POOH. 5. MU spear assembly, RIH& spear the PBR,pull upper Brown retrievable packer and blast joints down to tubing cut at 9055' MD. POOH with fish. a. If external tubing condition around cut looks good(no corrosion),continue w/Step#6. b. If external tubing condition around the cut is corroded or pitted, skip to Step#7. 6. RIH with overshot w/seals& stack packer assembly on drillpipe to just above the tubing stub. Spot corrosion inhibited brine in the IA from the PBR down. Engage the tubing stub and pressure test tubing to 500 psi to verify integrity. Drop ball&rod&pressure up to set the FHL packer. PT the IA to verify packer set. Shear the PBR and POOH laying down drillpipe. RIH w/new tubing completion, sting into PBR. Skip to Step#19. 7. RIH w/overshot&grapple,engage tubing stub and pull in tension, set drillpipe in the slips. RU E- line and RIH w/GR/CCL&2"RCT cutter w/EMA's,cut the tubing at 9169' RKB (l Oft above the anchor seal assembly). RDMO E-line. 8. POOH w/the middle Brown retrievable packer and lower selective down to the cut joint at 9169' MD. 9. RIH w/overshot&grapple, engage tubing and rotate to release Brown anchor seal assembly. POOH. 10. RIH w/packer mill and mill up permanent packer,push to bottom. POOH. 11. RIH w/spear and retrieve packer&tailpipe assembly. POOH. (If packer could be pushed below 9400' MD,this step may be eliminated) 12. RIH w/7"casing scraper to—9400' MD,reverse circulate well until clean,POOH. 13. MU Wearsox tailpipe and permanent packer, RIH on drillpipe to approximate setting depth. Set the drillpipe in the slips. 14. RU E-line: RIH with GR/CCL and correlate packer depth. RDMO E-line. 15. Make depth correction,drop a ball,pressure up drillpipe to set the F-1 packer. Release wireline setting tools from packer&POOH laying down drillpipe. 16. MU dual FHL straddle packer assembly and single in on new tubing to just above the F-1 packer. 17. Spot corrosion inhibited brine in the IA below the PBR. 18. Sting into SBE until fully located,pull up 1 ft, drop ball&rod,pressure up to set the FHL's w/2500 psi. While holding pressure on the tubing, PT the IA to 2500 psi. Bleed pressure from the IA& tubing. Shear the PBR. 19. Space out 7 ft from fully located,mark the pipe and pull out of PBR. Space out below hanger. 1G-05 Kuparuk Injector Well Information Sheet Page 3 20. Load the IA w/corrosion inhibited brine and land the hanger. RILDS. 21. PT the tubing&IA, bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear t/ the SOV. 22. Pull the landing joint, install BPV or two-way check. 23. ND BOPE,NU tree&test. Pull test plug or two-way check. 24. Freeze protect well w/diesel. 25. Set BPV. RDMO. 1G-05 Kuparuk Injector Well Information Sheet Page 4 Option#2: Proposed Procedure (If patch cannot be pulled pre-rig) 1. MIRU. Pull BPV. Circulate kill weight fluid. Verify well is dead. Set BPV. 2. ND tree,NU BOPE&test to 3000 psi. Pull test plug and BPV. 3. POOH laying down tubing. a. On TOH(after the SSSV has cleared the rig floor), set a storm packer at—100' MD w/ remaining completion hanging below. PT storm packer. RU Hydratight equipment if necessary. ND BOP and tbg head,replace tbg head&IC packoffs,NU BOP&test.Pull storm packer. Continue laying down completion. 4. RIH w/overshot&grapple on drillpipe to tubing stub at 8790' MD,engage the tubing stub and jar the seal assembly from the PBR. POOH. 5. MU spear assembly,RIH& spear the PBR, pull upper Brown retrievable packer down to tubing cut at 8900' MD. POOH with fish. 6. RIH w/burn shoe and washpipe. Burn over GLM at 8924' MD. Wash down to middle Brown packer at 9060' MD. Circulate well clean. POOH. 7. RIH w/external tubing cutter to tubing stub at 8900' MD, swallow tubing down to middle Brown packer at 9060' MD. Pick up to locate tubing collar at 9054' MD and engage the knives. Cut the tubing. POOH w/fish. 8. RIH w/overshot&grapple, engage tubing stub at 9055' MD. Shear the retrievable Brown packer and attempt to rotate&release the anchor assembly from the lower packer. If successful,POOH w/ middle Brown packer and skip to Step#11. If unable to release anchor assembly,pull in tension and set the drillpipe in the slips. RU E-line and RIH w/GR/CCL&2"RCT cutter w/EMA's,cut the tubing at 9169' RKB(10ft above the anchor seal assembly). RDMO E-line. 9. POOH w/the middle Brown retrievable packer and lower selective down to the cut joint at 9169' MD. 10. RIH w/overshot&grapple, engage tubing and rotate to release Brown anchor seal assembly. POOH. 11. RIH w/packer mill and mill up permanent packer,push to bottom. POOH. 12. RIH w/spear and retrieve packer&tailpipe assembly. POOH. (If packer could be pushed below 9400' MD,this step may be eliminated) 13. RIH w/7"casing scraper to—9400' MD,reverse circulate well until clean,POOH. 14. MU Wearsox tailpipe and permanent packer, RIH on drillpipe to approximate setting depth. Set the drillpipe in the slips. 15. RU E-line: RIH with GR/CCL and correlate packer depth. RDMO E-line. 16. Make depth correction,drop a ball,pressure up drillpipe to set the F-1 packer. Release wireline setting tools from packer&POOH laying down drillpipe. 17. MU dual FHL straddle packer assembly and single in on new tubing to just above the F-1 packer. 18. Spot corrosion inhibited brine in the IA below the PBR. 19. Sting into SBE until fully located,pull up 1 ft, drop ball&rod,pressure up to set the FHL's w/2500 psi. While holding pressure on the tubing,PT the IA to 2500 psi. Bleed pressure from the IA& tubing. Shear the PBR. 20. Space out 7 ft from fully located,mark the pipe and pull out of PBR. Space out below hanger. 1G-05 Kuparuk Injector Well Information Sheet Page 5 21. Load the IA w/corrosion inhibited brine and land the hanger.RILDS. 22. PT the tubing&IA,bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear the SOV. 23. Pull the landing joint, install BPV or two-way check. 24. ND BOPE,NU tree&test. Pull test plug or two-way check. 25. Freeze protect well w/diesel. 26. Set BPV. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull ball&rod. Pull SOV&replace w/new SOV,pull RHC plug,pull plug from `D' nipple. 4. Turn well over to operations. 1G-05 Kuparuk Injector Well Information Sheet Page 6 KUP • 1G-05 ConocoPhillips if Well Attributes Max Angle&MD TD • Afar ca IncWellbore API/UWI Field Name Well Status Incl(") MD(ftKB) Act Btm(ftKB) co„ � 500292090800 KUPARUK RIVER UNIT INJ 56.37 4,600.00 10,086.0 "' Comment- H2S(ppm) Date - Annotation End Date ' •KB-Grd(R) Rig Release Dale ••• Well Confie'-1G.o5.320/201310'27:33AM SSSV:Flapper Locked Out Last WO: 8/2/1988 29.99 2/17/1983 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,416.0 3/12/2013 Rev Reason:TAG,DRILL DATES/DEPTHS osborl 3/20/2013 HANGER,20 "�aa y; 6." Casing Strings _„ Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd I CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H-40 WELDED V Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 10 3/4 9.950 29.9 2,523.9 2,278.4 45.50 K-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 29.9 10,071.0 7,055.9 26.00 K-55 BTC II Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth It...Set Depth(ND)...String Wt..String...String Top Thrd CONDUCTOR, 30-80 TUBING 3 1/2 2.992 20.4 9,224.5 6,418.4 9.30 J-55 BTC AB-MOD Completion Details Top Depth SAFETY VLV, I I (TVD) Top Inel Need... 1,831 Top(ftKB) (RKB) ("1 Item Description Comment ID(in) 20.4 20.4 0.31 HANGER CIW TUBING HANGER 3.500 1 1,830.6 1,756.4 33.85 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE-LOCKED OUT FLAPPER ONLY 2.812 6/24/2008 8,806.1 6,113.2 45.60 PBR BAKER PBR 3.000 8,819.8 6,122.6 45.41 PACKER BROWN HB RETRIEVABLE PACKER 3.000 SURFACE, - ,A l 8,963.9 6,225.1 43.35 BLAST JT STEEL BLAST JOINTS(5) 2.867 342,524 9,060.1 6,295.5 41.38 PACKER BROWN HB RETRIEVABLE PACKER 3.000 '''1 � 9,087.4 6,315.9 41.50 BLAST JT STEEL BLAST JOINTS(3) 2.867 GAS LIFT. _ 9,162.8 6,372.3 41.81 NIPPLE OTIS X NIPPLE 2.813 8,767 9,179.0 6,384.3 41.88 SEAL ASSY BROWN ANCHOR SEAL ASSEMBLY 3.000 lit- 9,181.0 6,385.8 41.89 PACKER BROWN 3H PERMANENT PACKER 3.000 PBR,8,806 9,185.8 6,389.4 41.91 MILL EXT MILL OUT EXTENSION 2.992 PACKER.8.820 9,207.1 6,405.6 42.53 NIPPLE CAMCO D NIPPLE NO GO 2.750 111 9,223.5 6,417.7 42.53 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 9226 during IPROF on 3.015 INJECT8,9.57ION, 9/23/2007 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth PACKER,8,916 ' (TVD) Top Incl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) PATCH,8,918-N 8,916.0 6,190.9 43.98 PACKER WEATHERFORD ER PACKER 9/30/2012 1.750 INJECTION ___ 8,918.0 6,192.3 43.95 PATCH STRADDLE PATCH w/SNAP LATCH ASSEMBLY 9/30/2012 1.580 8,924 l 1 8,938.0 6,206.5 43.69 PACKER WEATHERFORD ER PACKER 9/9/2012 1.750 PACKER,8,938 - - 9,509.0 6,628.6 41.65 FISH 1.5"CV Empty Pocket Fell to Rathole 8/7/1987 8/7/1997 III 9,520.0 6,636.9 41.62 FISH 1.5"OV Lost in Hole 1/25/1994 1/25/1994 Perforations&Slots IPERF. Shot 8.9765,050 Top(ND) Atm(TVD) Dens I- Top(MB)Btm(ftKB) MB) (ftKB) Zone Date (sh... Type Comment ((''''''�� 8,976.0 9,050.0 6,233.8 6,287.9'C-3,C-4,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann TCP LJ 9,095.0 9,131.0 6,321.7 6,348.6 C-1,10-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann TCP PACKER,9,060 __ 9,332.0 9,336.0 6,497.6 6,500.5 A-5,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann TCP -� 9,348.0 9,378.0 6,509.4 6,531.5 A-4,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann TCP INJEC9,073 00 Notes:General&Safety End Date Annotation 9/162010 NOTE:Mandrel @ 8924-Leak found 6/21/2006 @ C-sand;tbg test failed 2/9/08 confirmed C3/C4 leak 9/16/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF._ .: 9.0959.131 t{ 1 [ 1 INJECTION, 9,152 NIPPLE,9,163 - U; SEAL ASSY. _ _ � 9,179 , all PACKER.9,181 MILL EXT, 9,186 B Ail NIPPLE,9,207 - SOS,9,224 M- Mandrel Details � Top Depth Top Port S... (TVD) Incl OD Valve Latch Size TRO Run IPERF, N...Top(ftKB) (ftKB) P) Make Model tint Sery Type Type (in) (psi) Run Date Com... 9,332-9,336 - 1 8,767.2 6,085.4 4621 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 8/9/1988 2 8,857.2 6,148.5 44.88 CAMCO MMG 1 12 INJ DMY RK 0.000 0.0 6252008 !PERE. g 3 8,924.5 6,196.9 43.87 CAMCO MMG 1 12 INJ DMY RK 0.000 0.0 6/252008 9,348-9,378 _-1 4 9,072.7 6,304.9 41.44 CAMCO MMG 1 12 INJ HFCV ROK 0.000 0.0 8/312008 FISH,9,509 5 9,152.4 6,364.5 41.77 CAMCO MMG 1 12 INJ HFCV RK 0.000 0.0 8/302008 FISH,9,520-1 PRODUCTION. 30-10,071 4i ' TD,10,086 1G-05 Proposed RWO Schematic - Option #1 Modified by JGE, 1-14-15 OPTION: 3-1/2" DS-nipple at 500' MD (2.875" min ID) 3-1/2"9.3# L-80 EUE 8rd, AB-Mod tubing to surface 16"62#H-40 shoe 3-1/2"Camco MMG gas lift mandrels 9-5/8"45#K-55 shoe @ 2524' MD _ Baker 3-1/2" PBR at xxxx' MD (3" ID) Baker FHL packer at XXXX' MD (4.0" ID) (Note:Set uppermost packer at 8776'MD or deeper for 200'injection well requirement) ..-. .. ...___. 3-1/2"X-nipple at XXXX' MD (2.812" min ID) 3-1/2" mandrel(s) at xxxx' C-sand pens 3-1/2"overshot with seals C4: 8976-9050' MD ' {` '° Existing Completion Cl: 9095-9131' MD Brown HB packer at 9060' MD 3-1/2" mandrels at 9073'&9152' 3-1/2"X-nipple at 9163' MD (2.812" min ID) Brown 3H packer @ 9181' MD 3-1/2" D-nipple 9207' MD (2.75" min ID) 3-1/2"tubing tail at 9224' MD CTD KOP @ 9280'MD A-sand perfs 9332-9336' MD 9348-9378' MD = - 7"26# K-55 shoe at 10071' MD 1G-05 Proposed RWO Schematic - Option #2 Modified by JGE, 1-14-15 OPTION: 3-1/2" DS-nipple at 500' MD (2.875"min ID) 3-1/2" 9.3#L-80 EUE 8rd, AB-Mod tubing to surface 16"62#H-40 shoe @ 80' MD Camco MMG gas lift mandrels 9-5/8"45#K-55 shoe @ 2524' MD — Baker 3-1/2" PBR at xxxx' MD (3" ID) Baker FHL packer at XXXX' MD (4.0" ID) (Note:Set = uppermost packer at 8776'MD or deeper for 200'injection well requirement) 3-1/2"X-nipple at XXXX' MD (2.812" min ID) C-sand penis 3-1/2" mandrel(s)at xxxx' C4: 8976-9050' MD Cl: 9095-9131' MD .. ... I Baker FHL packer at XXXX' MD (4.0" ID) 3-1/2" mandrel(s) at xxxx' Baker F-1 packer @ XXXX' MD Baker SBE @ XXXX' MD XXXX'MD 3-1/2"X-nipple at XXXX' MD (2.812"min ID) Crossover 3-1/2"to 5-1/2"liner *vented/Ported for installation �� 5-1/2" Big Tail Pipe configuration(see details) CTD KOP @ 9280'MD 7"csg cplgs at 9254',9293',9336' 9220'-9300'MD***Critical Depth!*** 2 Jts 5-1/2", 14#, -(-40,Range 3 *Depth correlated to Dresser CBL of 2/16/83 *6"OD special clearance connections A-sand perfs — — *Bevel/she'on bottom every 2.5 3.0'along the pipe 9332-9336' MD = — *Baker-Lok connections 9348-9378' MD — 7"26#K-55 shoe at 10071' MD Bettis, Patricia K (DOA) From: Packer, J.Brett <J.Brett.Packer@conocophillips.com> Sent: Tuesday, February 03, 2015 3:56 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1G-05 Patricia, Yes, this is going to be a water only injector. They plan to bring it back on injection prior to the CTD drilling. The gas line on this pad has been de-rated and there are no plans to repair it. J.Brett'Pacer �Dri�ng ez Wells Supervising Workaver Engineer Work# (907)265-6845 Celt# (907)980-9467 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, February 03, 2015 12:32 PM To: Packer, J.Brett Subject: [EXTERNAL]KRU 1G-05 Good afternoon Brett, On Form 10-403, Box 15 Well Status after proposed work, the WINJ box is checked. Is this correct? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 STATE OF ALASKA AL& OIL AND GAS CONSERVATION COMAIION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug I:trforations r Perforate r Other Install Tubing P Tubing Patch Alter Casing r g ] ` Stimulate - Fra ]—" Wai r Time Exte �"" Change Approved Rogram r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 183 -020 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service ` 50-029-20908-0V 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25640 ' 1 G -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,- none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10086 feet Plugs (measured) None true vertical 7068 feet Junk (measured) 9509', 9520' Effective Depth measured 9975 feet Packer (measured) 8820, 8916, 8938, 9060, 9181 true vertical 6982 feet (true vertucal) 6123, 6191, 6207, 6296, 6386 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80 SURFACE 2494 10.75 2524 2278 PRODUCTION 10041 7 10071 7056 SCANNED JAN 10 2013 Perforation depth: Measured depth: 8976'- 9050', 9096- 9131', 9332'- 9336', 9348' -9378' True Vertical Depth: 6234'- 6288', 6322'- 6349', 6498'- 6501', 6509' -6532' Tubing (size, grade, MD, and TVD) 3.5, J - 55, 9224 MD, 6418 TVD Packers & SSSV (type, MD, and TVD) PACKER - BROWN HB RETRIEVABLE PACKER © 8820 MD and 6122 TVD PACKER - WEATHERFORD ER PACKER © 8916 MD and 6191 TVD PACKER - 3.5" WEATHERFORD PACKER © 8938 MD and 6206 TVD PACKER - BROWN HB RETRIEVABLE PACKER @ 9060 MD and 6296 TVD PACKER - BROWN 3H PERMANENT PACKER © 9181 MD and 6386 TVD SSSV - CAMCO TRDP -1A SSSV @ 1831 MD and 1756 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 na 3915 Subsequent to operation na 1850 14. Attachments 15. Well Class after work: ...- Copies of Logs and Surveys run Exploratory r Development r Service 1' Stratigraphic r 16. Well Status after work: Oil E Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIN WAG -• 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: 312 - 201 Contact John Peirce @ 265 - 6471 Email: John .W.Peirce @conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 77.,-4,, V: 10 (za/i2_ Form 10 -404 Revised 12 o ftE3Dms OCT 2 3 2Ol / D z , '1 Z Submit Original Only • 1G -05 Well Work Summary DATE SUMMARY 9/1/12 DRIFT DOWN TO AND PULLED ER PKR @ 8938' RKB; BRUSH & FLUSSBG 8800' TO 9100' RKB.' WELL FREEZE PROTECTED ( READY FOR E -LINE ). 9/8/12 ATTEMPTED TO SET 2.74" WEATHERFORD ER PACKER AT 8938' RKB. POOH AND FOUND AN ELECTRICAL SHORT AT THE SWIVEL. FAILED TO GET ENOUGH VOLTAGE TO THE IGNITER. REPLACE SWIVEL. WILL ATTEMPT TOMORROW. 9/9/12 SET 2.74" WEATHERFORD ER PACKER AT 8938'. LOG CORRELATED TO TUBING DETAIL RECORD DATED 02 AUG 1988. WELL LEFT SHUT IN AND TURNED OVER TO DSO. 9/30/12 SET WEATHERFORD 3 1/2 ER STRADDLE PATCH w /SNAP LATCH ASSY' (20.84'OAL) 8938' RKB; RAN TEST TOOL AND MITT ( PASS ) AGAINST ER PACKER @ 8916' RKB; COMPLETE "A -SAND INJECTION ONLY" a KUP 1G -05 Conoc s Well Attributes Max Angle & MD TD • e Aia5ht1, It pi; Wel!bore API /UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) 500292090800 KUPARUK RIVER UNIT INJ 56.37 4,600.00 10,086.0 CommeM H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: Flapper Locked Out Last WO: 8/2/1988 29.99 2/17/1983 Well Conlin'. - 1G -05, 10/6/2012245 49 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,472.0 1/5/2011 Rev Reason: SET PATCH ASSY I ninam 10/6/2012 HANGER,20 ''"". Casing Strings JIM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 29.9 2,523.9 2,278.4 45,50 K - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 29.9 10,071.0 7,055.9 26.00 K -55 BTC MI Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, 30 - 80 TUBING 3 1/2 2.992 20.4 9,224.5 6,418.4 9.30 J -55 BTC AB -MOD Completion Details I. Top Depth SAFETY VLV, (ND) Top Inc! Noml... 1,831 1_44:34m. _ ° I Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 20.4 20.4 0.31 HANGER CIW TUBING HANGER 3.500 1,830.6 1,756.4 33.85 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE - LOCKED OUT FLAPPER ONLY 2.812 6/24/2008 8,806.1 6,113.2 45.60 PBR BAKER PBR 3.000 8,819.8 6,122.6 45.41 PACKER BROWN HB RETRIEVABLE PACKER 3.000 SURFACE. ____Al l 8,963.9 6,225.1 43.35 BLAST JT STEEL BLAST JOINTS (5) 2.867 30 - 2,524 9,060.1 6,295.5 41.38 PACKER BROWN HB RETRIEVABLE PACKER 3.000 9,087.4 6,315.9 41.50 BLAST JT STEEL BLAST JOINTS (3) 2.867 GAS LIFT, 9,162.8 6,372.3 41.81 NIPPLE OTISXNIPPLE 2.813 8,767 9,179.0 6,384.3 41.88 SEAL ASSY BROWN ANCHOR SEAL ASSEMBLY 3.000 9,181.0 6,385.8 41.89 PACKER BROWN 3H PERMANENT PACKER 3.000 PBR 6.e0e -- 9,185.8 6,389.4 41.91 MILL EXT MILL OUT EXTENSION 2.992 PACKER, 6,820 _ -R! 9,207.1 6,405.6 42.53 NIPPLE CAMCO D NIPPLE NO GO 2.750 all 9,223.5 6,417.7 42.53 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 9226 during IPROF on 3.015 INJECTION, 9/23/2007 8,857 III Other In Hole (Wireline retrievable • lu . s valves • um .s, fish, etc. Top Depth PACKER, 8,918 - 9 EA (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) PATCH, 8,918 8,916 6,190.9 43.98 PACKER WEATHERFORD ER PACKER 9/30/2012 1.750 IwEC 8,924 C 8,918 6,192.3 43.95 PATCH STRADDLE PATCH w/ SNAP LATCH ASSEMBLY 9/30/2012 1.580 8,924 8,938 6,206.5 43.69 PACKER WEATHERFORD ER PACKER 9/9/2012 1.750 PACKER, 8,938 9,509 6,628.6 41.65 FISH 1.5" CV Empty Pocket; Fell to Rathole 8/7/1987 8/7/1997 9,520 6,636.9 41.62 FISH 1.5" OV Lost in Hole 1/25/1994 1/25/1994 Perforations & IPERF, Shot 8,976-9,050 1 Top(TVD) Btm(TVD) Dens l Top (ftKB) Btm (ftKB) (ftKB) )ftKB) Zone Date (sh... Type Comment 8,976 9,050 6,233.8 6,287.9 C -3, C-4, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 9,095 9,131 6,321.7 6,348.6 C-1, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP PACKER. 9,060 9,332 9,336 6,497.6 6,500.5 A -5, 1G-05 2/17/1983 12.0 IPERF - 120 deg Ph; GeoVann TCP IF 9,348 9,378 6,509.4 6,531.5 A -4, 10-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP INJECTION, 9.073 ft - Notes: General & Safety End Date Annotation 9 /16/2010 NOTE: Mandrel @ 8924 -Leak found 6/21/2006 @ C -sand; tbg test failed 2/9/08 confirmed C3 /C4 leak 9/16/2010 NOTE View Schematic w/ Alaska Schematic9.0 PERF, • I l i 9,095 -9,131 INJECTION. - r. •^ 9,152 NIPPLE, 9,183 - - -- 2 REAL ASSV, _ 9,179 PACKER.9,181 - /,/`3; MILL EXT, 9,186 - II NIPPLE, 9,207 I I so5, 9,224 { - ....._ Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size 750 Run IPERF, Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 9,332 - 9x36 _ _ _ 1 8,767.2 6,085.4 46.21 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/9/1988 2 8,857.2 6,148.5 44.88 CAMCO MMG 1 12 INJ DMY RK 0.000 0.0 6/25/2008 IPERF, ■ 3 8,924.5 6,196.9 43.87 CAMCO MMG 1 1/2 'INJ DMY RK 0.000 0.0 6/25/2008 9,348 - 9,378 4 9,072.7 6,304.9 41,44 CAMCO MMG 1 12 INJ HFCV ROK 0.000 0.0 8/312008 ft 5 9,152.4 6,364.5 41.77 CAMCO MMG 1 1/2 INJ HFCV RK 0.000 0.0 8/30/2008 FISH, 9,509 FISH. 9.520 II PRODUCTION. 30- 10,071 N • 7D, 10,086 • • 1-'070 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 12, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED FEB 2 2 2013 RE: Plug Setting Record: 1G-05 Run Date: 9/9/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20908 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 -273 -3535 klinton.wood@halliburton.com Signed: l PA) ,� Date: \o 1-1-/Ira � . . r. h SEAN PARNELL, GOVERNOR Lt ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Wells Engineer a 2:() ConocoPhillips Alaska, Inc. qt. �' P.O. Box 100360 \ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1G -05 Sundry Number: 312 -201 Dear Mr. Alvord: SLANNED JUL 3 "LI 1L Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 7 day of June, 2012. Encl. STATE OF ALASKA '" �''' ED A OIL AND GAS CONSERVATION COMMI N + ' • A P ICATION FOR SUNDRY APPR ALS MAY 31 2 012 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Chang Q , • , . m J"' Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdow n j•' Re -enter Susp. well r Stimulate Alter casing g r Other:install Tubing Patch F.: - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183 - 020 • 3. Address: Stratigraphic r Service r • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20908 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes I° No I✓ 1G -05 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25640 • Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10086 . 7068 • 9509', 9520' Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80' 80' SURFACE 2494 10.75 2524' 2278' PRODUCTION 10041 7 10071' 7056' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8976' 9050', 9095 9131', 9332' 9336', 9348' - 9378' 6234 6288', 6322' 6349', 6498' 6501, 6509' - 6532' 3.5 J - 55 _ 9224 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN HB RETRIEVABLE PACKER MD= 8820 TVD= 6122 PACKER - 3.5" WEATHERFORD PACKER MD= 8938 TVD= 6206 PACKER - BROWN HB RETRIEVABLE PACKER MD= 9060 TVD= 6296 PACKER - BROWN 3H PERMANENT PACKER MD= 9181 TVD= 6386 SSSV - CAMCO TRDP -1A SSSV MD =1831 TVD =1756 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program f BOP Sketch r Exploratory Development J! Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/29/2012 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ Fr, • GINJ I WAG f Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature 1 ' t, . Phone: 265 -6471 Date 54/30/12- Commission Use Only Sundry Number 1 2.10 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance E" Other: Subsequent Form Required: i 2 � . APPROVED BY Approved by: " ■ if COMMISSIONER THE COMMISSION Date: 69 ) . I / a Form 10 -403 Revised 1/2010 I / - k RSDAIlS JUNOItIZ ubmit in Duplicate '� r.,:„..„ kt 4 / ':' / Z- A L „,.,...„...A.....a/7, KU P . 1 G -05 ConocoPhillips Well Attributes Max Ang & MD TD Inc Wellbore API /UWI Field Name Well Status Ind(*) MO (ftKB) Act BM) (ftKB) I Alaska. 500292090800 KUPARUK RIVER UNIT INJ 56.37 4,600.00 10,086.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date Well conrar - 1G - 0s, 3/20/2012 7 57 34 AM SSSV: Flapper Locked Out Last WO: 8/2/1988 29.99 2/17/1983 Schematic Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,472.0 1/5/2011 Rev Reason: WELL REVIEW osborl 3/20/2012 .."" Casing Strings HANGER, 20 �" g g Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (t.. Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 103/4 9.950 29.9 2,523.9 2,278.4 45.50 K - 55 BTC Casing Description String 0... String ID ... Top )ftKB) Set Depth (1... Set Depth (TVD) ... String Wt.. String ... String Top Thrd _ ___. PRODUCTION 7 6.276 299 10,071.0 7,055.9 26.00 K -55 BTC Tubing Strings Tubin Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, _� T UBI NG 31/2 9224.5 I 6,418.4 I 9.30 J - 55 I BTC AB - MOD 30.80 Completion Details I Top Depth Q r J )TVD) Top Inc! Nomi... SAFETY VLV. 1,e31 t. .• 1 Top (ftKB) (ftKB) ( °) Item Description Comment ID (!n) 20.4 20.4 0.31 HANGER CIW TUBING HANGER 3.500 1,830.6 1,756.4 33.85 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE - LOCKED OUT FLAPPER ONLY 2.812 6/24/2008 8,806.1 6,113.2 45.60 PBR BAKER PBR 3.000 8,819.8 6,122.6 45.41 PACKER BROWN HB RETRIEVABLE PACKER 3.000 8,963.9 6,225.1 43.35 BLAST JT STEEL BLAST JOINTS (5) 2.867 SURFACE. da 9,060.1 6,295.5 41.38 PACKER BROWN HB RETRIEVABLE PACKER 3.000 30 - 2,524 9,087.4 6,315.9 41.50 BLAST JT STEEL BLAST JOINTS (3) 2.867 9,162.8 6,372.3 41.81 NIPPLE OTISXNIPPLE 2.813 GAS LIFT, 8,767 7 9,179.0 6,384.3 41.88 SEAL ASSY BROWN ANCHOR SEAL ASSEMBLY 3.000 9,181.0 6,385.8 41.89 PACKER BROWN 31-I PERMANENT PACKER 3.000 PBR, 8,808 9,185.8 6,389.4 41.91 MILL EXT MILL OUT EXTENSION 2.992 �„ 9,207.1 6,405.6 42.53 NIPPLE CAMCO D NIPPLE NO GO 2.750 PACKER, 8,820 9,223.5 6,417.7 42.53 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 9226 during (PROF on 3.015 9/23/2007 INJECTION, 8,857 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth - I (TVD) Top Inc! INJECTION, 41.' /n/ Top (ftKB) (ftKB) (°) Description Comment Run Date ID (!n) 8,924 (/� 8,938.0 6,206.5 43.69 PACKER 3.5" WEATHERFORD PACKER **FAILED TO SET 9/2/2008 1.750 REMAINDER OF PACKER ** PACKER, 8,938 -7 ' ttN 9,509.0 6,628.6 41.65 FISH 1.5" CV Empty Pocket; Fell to Rathole 8/7/1987 8/7/1997 9,520.0 6,636.9 41.62 FISH 1.5" OV Lost in Hole 1/25/1994 1/25/1994 Perforations & Slots IPERF, Shot 8.9785,050 @ Top (TVD) Btm (TVD) Dens Cp r Top (MB) Btm (ftKB) (ftKB) (9913) Zone Date (ch. Type Comment 8 ,976.0 9,050.0 6,2338 6,287.9 C -3, C -4, 1G-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP El 9,095.0 9,131.0 6,321.7 6,348.6 C-1, 1G -05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP PACKER, 9,060 9,332.0 9,336.0 6,497.6 6,500.5 A -5, 10-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP 111 9,348.0 9,378.0 6,509.4 6,531.5 A-4, 10-05 2/17/1983 12.0 IPERF 120 deg Ph; GeoVann TCP INJECTION, Notes: General & Safety 9,073 t, Entl Date Annotation iiii 9 /16/2010 NOTE: Mandrel @ 8924 -Leak found 6/21 /2006 @ C -sand; tbg test failed 2/9/08 confirmed C3/C4 leak t I 9/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF, 9,0955,131 U I! J si= ' INJECTION, 9,152 NIPPLE, 9,183 I. :,; SEAL ASSY, 9,179 8. ..a PACKER, 9,181 MILL EXT, / 9,186 WI if It NIPPLE, 9,207 BE iir SOS,9,224 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run IPERF, Stn Top (RKB) (MB) (°) Make Mode! (in) Sery Type Type (in) (psi) Run Date Com... 9,3325,338 1 8,767.2 6,085.4 46.21 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/9/1988 2 8,857,2 6,148.5 44.88 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 6/25/2008 9,348-9,3 8 ® 3 8,924.5 6,196.9 43.87 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 6/25/2008 4 9,072.7 6,304.9 41.44 CAMCO MMG 1 1/2 INJ HFCV ROK 0.000 0.0 8/31/2008 FISH, 9,509 5 9,152.4 6,364.5 41.77 CAMCO MMG 1 1/2 INJ HFCV RK 0.000 0.0 8/30/2008 FISH, 9620 PRODUCTION. 30-10,071 + • TD. 10,086 • • • • 1G -05 Tubing Patch Installation A 10 -403 Application Sundry approval of 7 -25 -08 (308 -260) for 1 G -05 Tubing Patch installation has expired and AOGCC has requested that a new 10 -403 approval be attained to patch this well. The initial sundry approval expired when the tubing patch job was put on -hold for well flow line replacement, which has since been completed. 1G-05 returned to injection in March 2012. Per 1 G -05 leak detect log of 6- 27 -07, St #3 mandrel with DV at 8924' RKB was seen leaking to the C sand. A Caliper on 8 -30 -08 verified the tubing was in fair to good condition for a tubing patch. It is proposed that a 20' OAL retrievable tubing patch be set at 8918 - 8938' RKB to isolate GLM #3, so that 1G -05 can be returned to PWI as an A sand only injector. Procedure: Slickline: 1. RIH & pull a lower straddle patch packer at 8938' RKB. The packer has been in the well since 9/2/08. There was difficulty noted 9/7/08 during the set attempt of the upper run section of the patch with getting latched into this lower packer. Considering the packer has been in the well -4 years with noted latching difficulty warrants pulling the packer. Pulling the packer will open up the tubing up for a new brush & flush, and running new packers will improve odds of attaining a successful tubing patch installation. 2. Brush & flush the 3.5" tubing between 8850 - 9000' RKB in the area where the tubing patch is to be set. E -line: 3. RIH with a 2.74" run OD Straddle Packer and set it at 8938' RKB. This lower packer of a . tubing patch will be set -5' below the top of a full joint just below the leaky GLM #3 to be patched. POOH with setting tools. RD. Slickline: 4. RIH with tubing patch run #2 assembly consisting from bottom to top of an Anchor Seal assembly, -16 x 2 -3/8" Spacer Pipe, and a 2.74" run OD Straddle Packer. Sting and latch run #2 into the lower Straddle Packer set at 8938' RKB, then set the upper Straddle Packer at 8918' RKB to complete the tubing patch at 8918 - 8938' RKB to isolate leaky GLM #3 at 8924' RKB. The upper Packer set location at 8918' RKB puts the Packer -6' above the bottom of a full joint above the GLM. RIH with test plug & set it in the packer at 8918' RKB. Perform an MIT -T to 2500 psi to verify good set integrity of the upper patch packer. Pull the test plug. RD. Return 1G-05 to A sand only injection. JWP 5/30/2012 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, March 15, 2012 TO: Jim Regg �'/ ( 4 ( "z -- P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-05 FROM: Lou Grimaldi KUPARUK RIV UNIT 10-05 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry ..1:C NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1G -05 API Well Number: 50- 029 - 20908 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG120313131854 Permit Number: 183 - 020 - Inspection Date: 3/13/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1G -05 " Type Inj. W ' TVD 6122 ' IA 580 2090 ' 2030 2018 PTD 1830200 ' TypeTest SPT Test psi 1530 , OA 878 • 968 960 962 . Interva 4YRTST P/F P Tubing 1400 • 1400 1400 1400 - Notes: 2.3 bbl's pumped, 2.4 bbl's returned. Good test. - .; :J`.)MAP 1 9 10 12 Thursday, March 15, 2012 Page 1 of 1 • • ~VE~L L ~____ ~ , ',~--- -- ----- J u ProActive Diagnostic Services, Inc. To: AGGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659=5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.5952 1) Caliper Report 30-Aug-08 1 G05 1 Report /EDE 50-029-20908.00 2) Caliper Report 31 Aug-08 30-01 1 Report/ EDE 50-029-21836.00 ISrk-o~3 1rob~4 ~~+~~~ ~~F ~, ~~ ~~~~ Signed Print Name: r r t ~/f ~ Date ~__ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pds~rac~a~raa°F~c•;ss-~®r~loa.corn WEBSITE : wvv~ev,~eaert3~r~3og.c~sraa C:\Documents and Settitigs\Owner\Desktop\Transmit_Conoco.doc I~ 1 Memory Multi-Finger Caliper Log Results Sunnmary Company: ConocoPhillipsAlaska, Inc. Well: 1G-05 Log Date: August 30, 2008 Field: Kuparuk Log No.: 7730 State: Alaska Run No.: 1 API No.: 50-029-20908-00 Pipet Dese.: 3.5" 9.2 ib. J-55 AB-MOD Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 9,224 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ' This caliper data is tied into the Tubing Tai! ~ 9,224' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged is in good to fair condition with respect to corrosive damage, with a maximum wall penetration of 27% recorded in an interval of isolated pitting in joint 295 (9,128'). Other recorded damage appears as scattered pitting and intermittent line corrosion. Na significant areas of cross-sectional wall loss or I.D. restrictions are recorded. A 3~D fog plot of the caliper recordings across the proposed patch interval over Injection Mandrel Station 3 is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pitting (27°~) Jt. 295 @ 9,128 Ft. (MD) Isolated Pitting (26°k) Jt. 66 ~ 2,087 Ft. (MD) Line Corrosion (26%) Jt. 286 ~ 8,923 Ft. (MD) Isolated Pitting (25%) Jt. 289 @ 8,986 Ft. (MD) Isolated Pitting (23%) Jt. 285 @ 8,898 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 5%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~~N~~ S E P s ~ 2008 Field Engineer: J. Halvorsen Analyst: M. Lawrence Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E-maii: PDS~memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 U~ ~~3 -oaa, 'if~~~5 • • PDS Multifinger Caliper 3D Log Plot ~~ S ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1G-05 Date : August 30, 2008 Description : Detail of Caliper Recordings Across Proposed Patch Over Injection Mandrel #3 • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (11.5' - 9224.0') Well: 1 G-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 30, 2008 . Approx. Tool Deviation ^ Approx. Borehole Profile 1 16 775 1544 2340 3116 3896 4673 D 5443 `" Y .~ 6213 Y Q. v O 6984 7761 852 5 ~~ 1 ~~ 4 299.1 9224 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 299.1 25 50 75 100 125 150 175 I_ Z 200 c ' o 225 250 275 • PDS Report Overview ~, Sw Body Region Analysis Well: 1 G-05 Survey Date: August 30, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Cornpany: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No, of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 BTC AB-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~.,, metal loss body 300 250 200 150 100 50 0 0 to 1 l0 10 to 1% 10`% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d total = 306 pene. 2 255 39 loss 194 112 0 10 0 0 0 0 0 Damage Configuration (body ) 40 30 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 34 32 1 1 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n INI ~ IA II A INJ 5 Bottom of Survey = 299.1 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 G-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. Jt. Depth (Ft.) I'en. t11„et Ilns.) Pen. Body (Ins.) I'en. °~o ~i~~i.il I ups ~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 11 t1 0.02 7 _' 2.94 PUP 1 16 O 0.02 7 ' 2.95 1.1 49 U 0.01 6 I 2.97 PUP 1.2 52 t~ 0.02 i I 2.95 PUP 2 63 U 0.02 - .94 3 93 t r 0.0 7 I 2.96 4 125 tl 0.02 2.93 156 U 0.02 7 2.94 6 187 t~ .01 U I 2.93 7 17 U 0.02 8 u 2.93 8 248 t l 0.03 1 1 2.95 9 278 U 0.01 [; I 2.96 10 310 U 0.02 ~ I 2.97 11 341 U 0.01 ~ ~' 2.96 2 373 U 0.03 1 s 2.94 Shallow ittin . 13 402 ~ ~ 0.01 5 ~ ~ 2.97 14 434 t) 0.01 5 I 2.94 15 466 U 0.02 ~ I .95 16 496 ll 0.02 7 U 2.96 17 528 t) 0.05 1 t3 t 2.94 Shallow ittin . 18 558 t) 0.04 1 i S 2.98 Shallow ittin . 19 5 0 t) 0.02 2.95 20 622 U 0.01 b I 2.95 21 653 t) 0.01 5 2.92 22 683 U 0.0 7 I 2.96 23 713 U 0.01 6 I 2.95 24 745 U 0.02 7 I 2.95 25 775 O 0.01 Z I 2.98 26 806 U 0.01 ~ I 2.96 27 835 U 0.03 13 2.96 Shallow ittin . 28 867 t) 0.01 (i _' 2.95 29 899 t) 0.02 I 2.97 30 931 tr 0.01 (~ I 2.95 31 962 U 0.01 - ? 2.98 32 994 U 0.02 1 2.97 33 1024 U 0.02 ti I 2.95 34 1053 t) 0.01 6 I 2.97 35 1085 U 0.02 7 I 2.97 36 1115 U 0.01 6 1 2.96 37 1144 U 0.02 2.95 38 1174 tl 0.01 5 t) 2.96 39 1206 U 0.01 i I 2.96 40 1 37 (~ 0.02 ~ I .96 41 1269 t) 0.02 7 I 2.95 4 1300 c_) 0.01 5 I 2.97 43 1329 tr 0.02 I 2.96 44 1360 t ~ 0.01 b 1 2.97 45 1392 U 0.02 7 I 2.96 46 1421 r ~ .02 7 ' 2.95 47 1453 n 0.01 5 I 2.96 _ Penetration Body Metal Loss Body Page 1 ' • • PDS REPORT JO INT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 G-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. )t. Depth (Ft) I'c~n. Ul~sc~t (Irn.) Pen. Body (Ins.) Pen. °/~ Metal I u.. ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1484 ! ~ 0.02 ~ 2.96 49 1516 c ~ 0.01 ~ I 2.98 50 1544 t I 0.01 5 1 2.96 51 1573 t) 0.02 ~ -1 2.95 52 1604 a 0.02 7 2.95 53 1636 ~ ~ 0.02 7 1 2.98 54 1667 U 0.02 7 2.94 55 1698 O 0.01 6 I 2.97 56 1 27 a .O1 b I 2.97 7 1759 a 0.01 =1 ' .97 58 1790 t ~ 0.03 10 I .96 5 .1 1822 t1 0.01 ~ 1 2.98 PUP 58.2 1828 t~ 0 t~ ~~ 2.81 SSSV 58.3 1839 (1 0.02 i i 2.96 PUP 9 1843 t ~ 0.01 5 I 2.93 60 1872 (~ 0.03 11 s 2.94 61 1904 U 0.04 1 ~ 5 2.93 Sh Ilow ittin . 6 1934 U 0.01 .5 I 2.95 63 1965 t ~ 0.02 £1 1 2. 2 64 1996 t~ 0.02 f~ 2.93 65 2028 tt 0.03 12 2.95 Shallow ittin . 66 2058 a 0.07 ~6 ~ 2.91 Isolated ittin . 67 2089 t ~ 0.02 t3 1 2.97 68 2120 t ~ 0.02 ~) 1 2.97 6 215 t) 0.0 t3 a .97 70 2182 t ~ 0.02 ~ I 2.94 71 2214 a 0.02 7 ~' 2.93 72 2245 t 1 0.03 12 _' 2.94 73 2276 i ~ 0 01 5 _' 2.96 74 2308 a 0.01 V I 2.98 75 2340 U 0.01 6 I 2.96 76 2371 t~ 0.02 7 I 2.96 77 2402 t t 0.01 6 I 2.93 78 2431 t ~ 0.01 5 1 2.93 79 2462 U 0.01 6 _' 2.93 80 2493 t ~ 0.02 7 1 2.94 81 2525 a 0.02 2.95 82 2556 U 0.02 '~ I 2.93 83 2587 U 0.01 `~ .91 84 2619 U 0.03 I1 -1 2.92 85 650 (~ 0.01 v 2.92 86 2680 t~ 0.02 ~ 2.93 87 2 711 l1 0.03 10 .93 88 2 742 l1 0.01 _~ 1 2.91 8 277 tt 0.02 (~ ~ 5 90 2805 U 0.01 ~1 ? 2.95 91 2837 t~ 0.03 11 1 2.94 92 2867 ~ t 0.02 ~~ 1 2.94 93 2898 t~ 0.01 2.91 94 2928 U 0.02 - i 2.98 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 C,-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. Jt. Depth (Ft.) 1'c~n. UI_~se~t (Ins.) Pen. Body (Ins.) Pen. °h, Mc(al Ic~ss °~<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2960 ~? 0.02 ~ 2.93 96 2991 a 0.01 t~ ' 2.91 97 3022 a 0.02 ~ I 2.94 98 3 54 U 0.02 7 _' 2.97 99 3085 O 0.01 5 i) 2.97 100 3116 (~ 0.01 b I 2.97 101 3148 t1 0.01 6 I 2. 5 102 3180 t? 0.01 > 1 2.96 103 3211 t? 0.04 I i I 2.91 Shallow ittin . 104 3245 a 0.02 _' 2.93 105 3275 U 0.01 _' I 2.95 106 3307 a 0.01 ~ 1 2.97 107 3335 a 0.01 5 I 2.97 108 3366 t) 0.01 (> I 2.91 109 3399 (> 0.01 ~ 2.96 110 3429 a 0.00 1 2.95 111 3460 U 0.01 5 _' 2.94 112 3490 t) 0.01 ~' 2.96 113 3521 U 0.0 5 _' 2.93 114 3552 (1 0.01 5 1 .94 11 3584 U 0.01 ~ _' 2.94 116 36 3 U 0.02 7 I 2.97 117 3644 l) 0.02 7 1 2.98 118 3676 U 0.02 ~) 1 2.96 119 3707 O .0 6 3 120 3739 U 0.03 11 I 2.97 121 3769 a 0.0 2.93 122 3802 (? 0.02 i I 2.96 123 3833 U .01 2 ~' 2.91 124 3865 U 0.02 i (1 2.95 125 3896 (1 0. 2 7 I 2.97 126 3926 n 0.02 ~~ 1 2.98 127 3957 U 0.02 £3 I 2.97 128 3988 t) 0.01 b I 2.94 129 4019 (? 0.01 =£ I 2.94 130 4052 ! ? 0.03 1 t 1 I 2.94 131 4083 i ? 0.01 (> 1 2.95 132 4115 i? 0.02 7 1 2.97 133 4145 U 0.01 5 1 2.93 134 4176 O 0.01 6 1 2.95 135 4 07 U 0.01 S 1 2.96 136 4236 t) 0.02 ~) I 2.96 137 4267 n 0.02 ti I 2.96 138 4299 t! 0.01 6 1 2.97 139 4329 i 1 0.01 1 i 2.96 140 4358 t! 0.01 -1 I 2.96 141 4390 U 0.02 t3 I 2.95 142 4421 U 0.03 1 l) 1 2.94 143 4453 t? 0.03 II 1 2.94 144 4484 O 0.02 7 2.94 _ Penetration Body Metal Loss Body Page 3 • • PDS REPORT JO INT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 G-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. Jt. Depth (Ft.) I'~•n. Lllx~•t (Ins.) Pen. Body (Ins.) Pc•n. °i1> Mc•t~~l INKS °~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4514 t) 0.02 ~ 2.93 146 4546 (t 0.02 ~ I 2.93 147 4578 I t 0.01 (~ I 2.96 148 4610 t t 0.02 ~) I 2.95 149 4642 t t 0.02 i > 2.96 150 4673 t ~ 0.02 I 2.95 151 4705 it 0.03 Li 2.95 Shallow ittin . 152 4734 (i 0.01 5 I 2.96 153 4765 tt 0.02 7 I 2.96 154 4796 U 0.02 7 I 2.96 155 4825 (~ 0.01 5 I 2.96 156 4856 t~ 0.01 5 1 2.94 157 4888 i t 0.01 5 I 2.96 158 4918 i ! 0.03 I I I 2.93 159 4949 U O.D1 5 I 2.94 160 4980 U 0.03 10 I 2.93 161 5011 (t 0.02 7 1 2.95 62 5041 U 0.02 ~) I 2.95 163 5073 U 0.01 6 _' 2.93 164 5105 i t 0.01 ~ I 2.94 165 5136 t1 0.0 ~ I 2.91 166 5167 tt 0.01 4 2.93 167 5197 t) 0.01 ~ 2.94 168 5228 tt 0.02 ~) I 2.94 169 5260 a 0.01 (~ Z .93 170 5290 U 0.02 _' 2.91 171 5321 i t 0.02 ti 2.91 172 5352 i t 0.02 7 I 2.91 173 5381 U 0.02 7 I 2.93 174 5413 (t 0.02 7 2.93 175 5443 U 0.01 5 I 2.94 176 5473 i t 0.02 ~ i t 2.94 177 5504 U 0.02 7 I 2.93 178 5534 U 0.02 ~ 1 2.96 179 5564 U 0.02 ~) 2.9 180 5596 i t 0.02 ') I 2.92 181 562 8 t t 0.02 7 2.94 182 5656 t t 0.02 ~ ~ t 2.94 183 5688 i J 0.01 (~ 2.92 184 5719 O 0.01 (~ 2.93 185 5750 (t 0.02 _' 2.94 186 5780 tt 0.02 E3 1 2.91 187 5811 (t 0.02 t3 U 2.92 188 5842 U 0.02 ~) 1 2.92 189 5873 tt 0.02 7 1 2.94 190 5904 t~ 0.02 t3 ~' 2.97 191 5935 (~ 0.02 7 I 2.95 192 5966 t t 0.00 1 2.92 193 5997 tt 0.01 6 I 2.96 194 6028 U 0.02 7 (t 2.97 Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 G-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. Jt. Depth (Ft.) I'c~n. UI»~~t (Int.) Pen. Body (Ins.) Pc~n. °~b Mcl.+l Ic~ss ';'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 195 6061 l) 0.01 i 1 2.96 196 6091 l) 0.02 ~~ 2.97 197 6123 ~~ 0.02 ~ I 2.96 198 6152 ~ I 0.02 7 I 2.94 199 6183 a 0.02 7 2.93 200 6213 t 1 0.01 t, i ~ 2.95 201 6245 t? 0.01 ~ ~ ~ 2.95 202 6277 ~? 0.01 i, 1 2.97 203 6307 t~ 0.01 6 I 2.94 204 6338 t~ 0.01 5 U 2.93 205 6369 t~ 0.02 7 .96 206 6400 U 0.02 ~~ 2.94 207 6431 t~ 0.02 ~~ i i 2.92 208 6462 t~ 0.02 ti i? 2.90 Lt. De osits. 209 6493 U 0.01 V I 2.95 210 6521 (~ 0.02 8 _' 2.91 211 6552 U 0.03 11 _' 2.95 212 6583 U 0.0 ~) ~' 2.94 213 6614 ~ ~ 0.01 6 _' 2.93 214 6644 +. ? 0.02 i I 2.9 215 6675 t ~ 0.02 ti I 2.95 216 6705 U 0.03 I (~ 2.98 217 6737 U 0.02 fs I 2.92 218 6769 t~ 0.02 ~ I 2.94 19 6800 U 0.02 9 1 2.9 220 6832 t) 0.02 t3 1 2.95 221 6863 a 0.02 ~ I 2.96 222 6893 I I 0.02 ~ i i 2.96 223 6924 t~ 0.02 ~) I 2.94 224 6954 a 0.01 6 I 2.94 225 6984 t) 0.02 ~i I 2.95 226 7015 t~ 0.02 ~~ ~' 2.94 227 7046 a 0.01 6 1 2.93 228 7078 U 0.02 7 ! 2.93 229 7108 (~ 0.02 7 _' 2. 3 230 7139 a 0.04 16 i 2.91 Shallow corrosion. Lt. De osits. 231 7171 t) 0.02 7 I 2.95 232 7200 ti 0.01 5 I 2.96 233 7232 ct 0.02 ~t 2.94 234 7264 ~~ 0.03 1 ~ 2.94 Shallow ittin . 235 7293 t~ 0.03 12 ~' 2.95 Shallo ittin . 236 7321 l) 0.02 ~) ' 2.97 237 735 U .02 ~i I 2.92 238 7385 tl 0.02 I 2.93 3 7417 ~ ~ 0.01 5 I 2.94 240 7448 U 0.03 1 ~' _' 2.96 Shallow ittin . 241 7478 t~ 0.02 ') ~' 2.93 242 7510 a 0.02 ~~ 1 2.94 243 7540 ~ i .02 ~~ 1 2.94 244 7571 !~ 0.02 ~~ ' 2.96 Penetration Body Metal Loss Body Page 5 • PDS REPORT JO INT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 G-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. Jt. Depth (Ft.) 12~n. LJlnc~t {ImJ Pen. Body (Ins.) Pc~n. %~ ~Ic~l.cl I css °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 245 7603 t) 0.02 9 ~' 2.94 246 7633 U 0.02 7 1 2.94 247 7665 11 0.01 4 I 2.96 248 7698 I) 0.02 7 I 2.95 249 7729 ~ ~ 0.02 7 1 2.94 250 7761 t~ .02 ~) I 2.92 251 7792 c) 0.02 - I 2.92 252 7824 t) 0.02 I 2.94 253 7856 t) 0.02 ~ I 2.91 254 7886 ~) 0.02 I 2.93 255 7917 a 0.02 £3 I 2.94 256 7946 a 0.02 £3 2.94 257 7977 1~ 0.04 I' I 2.93 Shallow ittin . Lt. De sits. 258 8008 t) 0.02 I 2.95 59 8037 ~) 0.03 t l I 2.93 260 8069 a 0.02 ~ I 2.95 261 8100 i) 0.02 £3 1 2.94 262 8130 U 0.02 £i ' 2.93 LL De osits. 263 8162 ~~ 0.02 ~> I 2.95 Shallow ittin . 264 8191 ~ t 0.02 i 2.93 265 8223 ~) 0.02 t3 2.92 266 8256 )~ 0.03 1 ; I 2.93 Shallow ittin . 267 8286 ll 0.02 9 I 2.96 268 8316 U 0.03 12 1 2.91 269 8348 U 0.06 ?2 2 2.94 Isolated ittin . 270 8376 U 0.02 ~) 1 2.96 271 8407 U 0.01 5 I 2.94 272 8438 U 0.02 8 I 2.93 2 73 8466 ~) 0.01 6 1 2.95 274 8495 U 0.03 13 I 2.96 Shallow itti 275 8525 U 0.03 1 1 1 2.94 Shallow ittin . 276 8556 11 0.03 11 I 2.96 277 8587 U 0.02 t3 I 2.96 278 8616 It 0.02 7 I 2.95 279 8645 Il 0.03 11 1 2.96 280 8675 t) 0.04 15 ~ 2.94 Shallow ittin . 281 8707 U 0.02 9 ~ 2.95 282 8738 I) 0.03 lU 2.94 282.1 8764 U 0 l) I) N A GLM 1 Latch ®8:3 283 8776 U 0.04 14 _' 2.95 Shallow ittin . 283.1 8809 u 0 l) a N A PBR 283.2 8818 t) 0 t) U N A Brown'HB' Retrievable Packer 284 8828 U 0.02 ~J I 2.95 284.1 8860 ~? 0 1) ~? N A IN 2 Latch @ 12:30 285 8867 ~) 0.06 .' ; 2.91 I lated it in . 286 8898 ~~ 0.07 Z(, 2.94 Line corrosion. 286.1 8928 tl 0 U i) N A IN 3 Latch ~ 12:30 287 8936 ~~ 0.05 'U I 2.91 Isolated ittin . 288 8966 ~) 0.03 13 2.95 Blast t. Shallow ittin . 289 8975 tl 0.06 25 _' 2.93 Blast t. Isolated ittin . _ Penetration Body Metal Loss Body Page 6 PDS REPORT JO INT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 G-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 30, 2008 Joint No. Jt. Depth (Ft.) I'c•n. Ut,tir•t (Irn.) Pen. Body (Ins.) Nc~n. "r~, ~lc•t~il I uti~ ~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 290 8995 tl 0.06 2.91 Blast t. Isolated ittin . 291 9015 ti 0.04 15 I 2.92 Blast t Shallow ittin . 292 9035 (1 0.06 23 2.96 Blast t Isolated ittin . 292.1 9054 ii 0 t) ii N A Brown'HB' Retrievable Packer 292. 9067 it 0.04 17 I 2.93 PUP Shallow ittin . 292.3 9073 i i 0 t 1 U N A I N 4 Latch ~ 12:00 292.4 9081 U 0.04 1 ~ I 2.92 PUP Shallow ittin . 293 9088 t~ 0.05 _' 1 _' 2.96 Blast t. Isolated ittin . 294 9099 (~ .05 1 t9 4 .97 Blast t Sha low ittin . 295 119 t~ 0.07 '~ 2.95 Blast t. Isola d ittin . 6 913 i t 0.01 2.94 Blast t. 296.1 9154 ~ ~ 0 i) n N A IN 5 Latch ~ 7: 0 296.2 9162 t? 0 !~ ~! 2.81 X Ni le 297 9166 i~ 0.06 I 2.91 Blast t. Isolated ittin . 297.1 9180 (1 0 ti a 3.00 Brown'3H' Permanent Packer 298 9192 t~ 0.05 I tt ~' 2.96 Blast .Shallow ittin . 298.1 9207 ~ ~ 0 t ~ i ~ 2.75 D Ni le No-Go 299 9209 t i 0.03 1 ~ I .94 Blast t. 29 .1 9224 t) 0 U i~ N A Tubin Tail Penetration Body Metal Loss Body Page 7 PDS Report Cross Sections ~V _ ~'~ ,. Well: 1G-05 Survey Date: August 30, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.2 f -55 BTC AB-MOD Anal st: M. Lawrence Cross Section for Joint 295 at depth 9127.583 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 44 ° Finger 8 Penetration = 0.068 ins Isolated Pitting 0.07 ins = 27% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~--~u ~`'a, PDS Report Cross Sections Well: 1G-05 Survey Date: August 30, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.2 f -55 BTC A&MOD Anal st: M. Lawrence Cross Section for Joint 66 at depth 2087.48 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 41 ° Finger 23 Penetration = 0.066 ins Isolated Pitting 0.07 ins = 26% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 ConocoPhillips Alaska, Inc. KRU 7G-05 1 G-05 API: 500292090800 Well T e: INJ An le TS: 43 de 8975 SSSV Type: TRDP Orig 2/17/1983 Angle @ TD: 40 deg @ 10086 sssv Com letion: (1831-ta3z, ' 00:3 500) Annular Fluid: Last W/O: 8/2/1988 Rev Reason: Leak note @ GLM . . /f3/CV C/O Reference L Ref L Date: Last U ate: 2/17/2008 ~ Last Ta : 9483 TD: 10086 ftK6 Last Ta Date: 7/26/2007 Max Hole An le: 56 de 4600 Casin Stri -ALL STRINGS ~ Descri Lion Size To Bottom ND Wt Grade Threed CONDUCTOR 16.000 0 80 80 65.00 H-40 PBR SUR. CASING 10.750 0 2524 2278 45.50 K-55 (saos-88°7, PROD. CASING 7.000 0 10071 7056 26.00 K-55 oD.3.soo) Tubin Strin -TUBING Size To Bottom ND Wt Grade Tread 3.500 0 9224 6418 9.20 J-55 BTC AB-MOD PKR ~. (8820.8821, Pertorations Summa OD:6.15s) Interval TVD Zone Statue Ft SPF Date T e Comment 8976 - 9050 6234 - 6288 C-4 C-3 74 12 2/17/1983 IPERF 120 de Ph• GeoVann TCP 9095 - 9131 6322 - 6349 C-1 36 12 2/17/1983 IPERF 120 de Ph~ GeoVann TCP 9332 - 9336 6498 - 6501 A-5 4 12 2/17/1983 IPERF 120 de Ph; GeoVann TCP 9348 - 9378 6509 - 6531 A-4 30 12 2/17/1983 IPERF 120 de Ph; GeoVann TCP Ga s Lift MandrelsNalves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt Injection 1 8767 6085 Camco MMG DMY 1.5 RK 0.000 0 8/9/1988 MandreWahe In'ection MandrelsNalves (8924-8925, St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 2 8857 6148 Camco MMG DMY 1.5 RK 0.000 0 7/27/2007 Closed 3 8924 6196 Camco MMG HFCV 1.5 RK 0.188 0 2/9/2008 1 4 9073 6305 Camco MMG HFCV 1.5 RK 0.250 0 7/22/2006 PKR 5 9152 6364 Camco MMG DMY 1.5 RK 0.000 0 8/2/1988 Closed (90649ost 1 LEAk FOUND 6212006 C-SANDi TBG TEST FAILED 2/9108 Confirmed C3/C4 leak , oD:6.1s6) Other lu s ui .etc. -JEWELRY De th ND T Descri don ID 1831 1756 SSSV Camco TRDP-1A SSA 2.813 Injection 8806 6112 PBR Baker 3.000 MandrelNahe 8820 6122 PKR Brown'HB' RETR. 3.000 4 (9o7a-so7a 9060 6296 PKR Brown'HB' RETR. 3.000 , 9163 6372 NIP Otis'X' 2.813 9181 6386 PKR Brown '3H' PERM. 3.000 9207 6405 NIP Camco 'D' Ni le NO GO 2.750 9223 6417 SOS Brown 2.992 s22a sale rn 2.992 Fish - FISH De ih Descri don Comment 9509 1.5" CV Em Pocket Fell to Rathole 8/7/1987 9520 1.5" OV Lost in Hole 1/25/1994 NIP (91639164, 00 3 500 : . ) PKR (9781-9182, 00:6 156) . NIP (9207-9208, 00:3 500) . TUBING (0.9224, 00:3.500 , 10:2.992) Pert (9332-9336) Pert (9348-9378) • • ~ ~ ~ d ~ SARAH PAUN, GOVERNOR ALASSA OII. A1~TD GAS 333 W. 7th AVENUE, SUITE 100 COI~TSERQA7`IOAT COMI~'IIS5IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Daniel Hemnann Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 ~~~~~~~ lUL ~, ~ 200 ~. (~ ~~ Anchorage, AK 99510 ~ ~ ~J Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 G-05 Sundry Number: 30~i-26~ Dear Mr. Hemnann: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this .~, da of Jul 2008 Y Y~ Encl. Sincerely, STATE OF ALASKA /~ *2/ 1'~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~)v~ APPLICATION FOR SUNDRY APPROVA 20 AAC 25.280 .{~a~." ~` ,_ ['~1~~ . ~'~~"~~C)fi 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ 'Other ^/ Alter casing ^ Repair well Q ~ Plug Perforations ^ Stimulate ^ Time Extension ^ set patch . Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 183-020 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20908-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 1G-05 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25640 RKB 90' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10086' 7068' 9483' 9509', 9520' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 2434' 10-3/4" 2524' 2278' PRODUCTION ggg1' 7" 10071' 7056' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8976'-9050', 9095'-9131', 9332'-9336', 9348'-9378' 6234'-6288', 6322'-6349', 6498'-6501', 6509'-6531' 3-1/2" J-55 9224' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BROWN'HB' RETR. ; BROWN'HB' RETR. ; BROWN'HB' RETR. pkr= 8820' ; 9060' ; 9181' Camco TRDP-1A SSSV= 1831' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ~ ° 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 6, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Daniel Herrmann @ 263-4119 Printed Name Herrm Title: Wells Group Engineer Signature ~ ~ Phone 265-1544 / Date Q~! ~~ f Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness p2CQ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: u~~ APPROVED BY ~,,'r ~~ Approved by: MMISS THE COMMISSION Date: f~t~ Form 10-403 Revised 06/2006 -, Submit in Duplicate .. ~ ~ E : ~ ~ _, ~ ~~~ ,~uh ~ ~ 2008 ~~~~~~ ~ ~.zz.~ • • We111G-OS Proposed Tubing Patch Install for Injection Profile Modification 1G-OS is an injection well with 3.5" tubing. A leak detect log ran on 06/27/08 indicated a leaky GLM at 8924' . No other leaks were detected in the well A 20' tubing patch will be set over the leaky GLM #3 and returned to injection. Recent Work Complete: 6/27/08: LDL run and GLM #3 at 8924' found to be leaking with DV in place. Proposed Tubing Patch Install Procedure: Slickline: RU Slickline. RIH with caliper and run from tubing tail to surface. Tubing is 20 yr. old J-55. E-line: 2. RU E-line. RIH with 3.5" packer. Set packer @ 8934' RKB. This will place the lower packer ~10' below the leaky GLM #3 at 8924' RKB. RIH with upper patch assembly consisting of anchor-latch assembly, 16' of 2 3/8" spacer pipe, and 3.5" packer. Latch into packer set at 8934' RKB. This will place the upper packer at 8914' RKB, ~10' above the leaky GLM #3 at 8924' RKB, completing the patch at 8914' to 8934' RKB. Return the well to injection and obtain valid injection test. JDH 7/7/2008 .r~- ll Attrib t ' '" P~ ~~ ' ~ W ~UP 1 G-05 >~( ~ ~O~~ ) ~t S~ t"' e u es , WaUWre i+FauWl FwW Lsoro I::eu Swwa dau,u u,u wznn.uou (i i Iota Deptn (nKb) 500292090800 KUPARUK RIVER UNIT ~INJ 56.37 10,071.0 Comment H2S (ppm) Date Annotation End Date KB13rd (tt) Rig Release Date _ _ • ~I ~~~ ~ ~F .Flapper Locked Out Last WO: 8/2/1958 29.99 2117/1983 ~ a ... ~ ~ Nlnotation Depth (M(B) End Date Annotation End Date ~ st Tag: 9,447.0 6/2412008 Rev Reason: GLV C/O, set PLUG 719/2008 Casing Strings 1 Sac Geµh ;.et Depth iT':G/ ~ VJt I Casing Description OD (in) ID lin) Top (ftKB) IgKB) (ftKB) OhsIR) Gratle Top Thread co„auaor, eD ProduMion 7 6.151 0.0 10,071.0 7,055.9 26.00 K-55 sssv, 1,e:f1 p Tubing Strinys i J r ~ ,r,ln Tn~~,l r,-s~.ri1 ,~ ~I,I io i~, r,p;nnel Irvil ,,.t o.~Nm r.Llrnrel '.1 l~al er ti~ r~~rn,..,n sunaoe, 2s2a ~ TU"'d~. I _. ~ __t II ~Jt b^-AL r.. Other In Hole (Al l Jewelry: Tubing Ru n & Retrievable, Fish, etc.} GAS LIFT, 8.767 ,1...... ..... - PBR, 8,806 E C~ PACKER, 8,820 (~i~ [... Q -.~~ INJECTION, 8,857 INJECTION, 8,924 IPERF, 8,9]fi-9,050 INJECTION,- 9,073 IPERF,_ 9.095-9.131 777 RR INJECTION, 9,152 NIPPLE, 9,163 PACKER. 9.181 NIPPLE, 9,207 PLUG, 9,207 } 808, 9,223 TTL, 9,224 ~. IPERF, 9,332-9, 33fi IPERF, 9,348-9,378 Fish, 9,509 Fish, 9,520 Production, 10,071 TD, 10,071 Conductor 16 15.060 0.0 80.0 80.0 65.00 H-00 Surface 10 3l4 9.794 0.0 2,524.0 2,278.4 45.50 K-55 Perforations snot Top (TVD) Btm (TVD) Dens Top (ftKB) BM (MKB) (ftKB) (ftKB) Type Zone (shot... Date Comment % / /I % /!/ /~~,. d a' t1~i~~~~~~~rs1- NO.4775 ~~~ r-`~ s Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~N~~ JAL ~~~$ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ ~~~ 3 Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 iL-20A 10215099 PRODUCTION PROFILE _Qi:} ~ 06/26/08 1 1 iG-05 12080389 LDL l 06/27/08 1 1 36-10 12061714 INJECTION PRO LE 'ry' _ t / "- 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / ~ 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ 'fir-- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY C ~ 06/29/08 1 1 2N-303 12061717 SBHP SURVEY d- 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - / 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY S' 06/29/08 1 1 1G-09 12080401 INJECTION PROFILE ~-7 --- ( /(~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~° .-- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ b~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY - f 06/30/08 1 1 iD-07 12080398 SBHP SURVEY - .j 07/02/08 1 1 2N-341 12061720 SBHP SURVEY _- p 06/30/08 1 1 3C-15 11982441 USIT - (~ / (p 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE J O -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ,g 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • 1 V-VJ 411V1116 klKWaa y.,.aawa', ` ~i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 12, 2048 4:08 PM To: 'Frenier, Heather N' Subject: RE: ?'G~ (.~83~-020 tubirt~ patckr s~rrr+dry Heather, Since this is an injection well, it is probably best to be safe and submit a sundry (10-403). Tom Maunder, PE AOGCC From: Frenier, Heather N [mailto:Heather.N.Frenier@conocophillips.com] Sent: Tuesday, February 12, 2008 3:21 PM To: Maunder, Thomas E (DOA) Subject: 1G-05 tubing patch sundry Mr. Maunder, l'm working on a procedure to patch a leaking injection mandrel in 1 G-05, and it's not clear to me, from the Sundry Notice Requirements matrix, whether I need to file a form 10-404 (or another form) before we perform the work. Any guidance you can give would be greatly appreciated. Thanks, Heather Frenier EDP Engineer CPAI, NSOD Wells Group (907) 263-4518 Heather. N. Frenier@conocophillips.com FFB ~ ~ zoos Zn 2i2oos i~Ljr k~~(:X2 -- ~7G~~~~~~~r Schlumberger -DCS 2525 Gambell Street, Suite 400 "Anchorage, AK 99503-2838 ATTN: Beth Well Job # off, ~~~ N~"J $ 207 Log Description = -- - °-•°--°~-•~-•~~'` "Date N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 10/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ` ~ C - 08108/07 1 1B-14 11837493 PRODUCTION PROFILE ~ - 08/27107 1 1A-18 11839651 PRODUCTION PROFILE d- 08/30107 1 1Y-18 11837499 PRODUCTION PROFILE ~ - 08/30/07 1 1G-14 11839652 INJECTION PROFILE (J ~ ?j- ~ 08/31/07 1 1A-01 NIA USIT - 08131107 1 1Y-04 11839653 INJECTION PROFILE f~i5 09101107 1 1Y-32 11839655 PRODUCTION PROFILE ~ - 09/02!07 1 2T-TAB-01 11839656 INJECTION PROFILE L` - - 09/03/07 1 2K-25 11846439 INJECTION PROFILE U = ( 09/06/07 1 2K-18 11846440 INJECTION PROFILE I - (j 09/07/07 1 16-18 11846441 PRODUCTION PROFILE ~/- 09108107 1 2T-20 11846442 PRODUCTION PROFILE 09109107 1 2N-310 11850433 SONIC SCANNER 7b'~ -(~ ~ 09/16107 1 2N-310 11850433 SONIC SCANNER-FMI "~ - f~`~ (~ 09116107 1 1J-176 11846443 USIT "3 - 09117107 1 1 E-29 NIA UCI ~ - ~ 09/19107 1 3F-21 11837503 RSTI WFL 09120107 1 2B-10 11839661 INJECTION PROFILE ~ - 09122107 1 iG-05 11837506 INJECTION PROFILE vSC 09123/07 1 2H-13 11839662 INJECTION PROFIL < - 09/23107 1 16-05 11837508 INJECTION PROFILE j-.L' , 09/24107 1 3H-08 11839663 PRODUCTION PROFILE ~ 09/24107 1 1Y-31 11839664 PRODUCTION PROFILE J ~' - ~ 09125107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - ~ ~ 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER ~~~ -. 09128/07 1 1G-11 11837513 PRODUCTION PROFILE - 09/29107 1 1Y-22 11837515 PRODUCTION PROFILE b 09130107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor kêfl 7/t11ö7 DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC FROM: Bob Noble Petroleum Inspector 1G-05 KUPARUK RIV UNIT IG-OS 3- 0 'J-D \ tö Reviewed By: PIS "'(In .. uprv ....);~ Comm Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IG-05 API Well Number: 50-029-20908-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070714193055 Permit Number: 183-020-0 Inspection Date: 7/14/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ./ Well I lG-05 IType Inj. i W i TVD 6122 /i IA 900 I 2630 ! 2580 2580 lOA ---L__------L P.T.Di 1830200 !TypeTest ¡ SPT i Test psi 2630 140 ! 150 I 150 150 i I - -- / I Interval 4YRTST P/F P Tubing 1940 I 1940 I 1940 1940 Notes: SCANNE.D AUGO ß 2007 Friday, July 20, 2007 Page I of I RECEIVED AUG () \') Z006 08/01/06 Schlumbepgep 20"''' IC ~ j~' '\ 'i . . ìo.l...I~~~' L\ IlJG ! h _ "J ~,3CJ\!~:~~,~~J ;.. ,..I- J.. ~ On & Gas Cons, corr~ NO. 3899 Ar.cl1crage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Ur~ 1~3 -ö8cJ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description BL Color CD Date 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE WIDEFT 07/26/06 1 1Y -05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. ~;,~. 6(..-z(è4 P.I. SupervIsor \ ì tt.h DATE: Wednesday, June 02, 2004 SlJBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC FROM: Chuck Scheve Petroleum Inspector IG-05 KUPARUK RIV UNIT IG-05 \ e3~ 0:+0 Src: Inspector Reviewed By: P.I. Suprv :Sf:!:.c-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IG-05 API Well Numbe 50-029-20908-00-00 Inspector Name: Permit Number 1830200 Inspection Date: Chuck Scheve 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 1 G-05 Type Inj. G TVD 7067 IA 450 2070 2040 2040 P.T. 1830200 TypeTest SPT Test psi 1530.5 OA 325 325 325 325 Interval 4YRTST P/F P Tubing 3000 3000 3000 3000 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02, 2004 Page I of 1 D~s~.te: ,,Z' ~ .. I I I · I I It' I IS I t# I:[! .""d_ ,- I ~ I~1 ____t I I ! I I .I I I I , I ! I I I I I I · I I I ......... I I I I I I I I ! I I 1 I I ...... I- I I I I I .. ,I I I I I I I I I I I __1 ......... I I 1 I I cl~t~ l Iml I I Trek OF I I s~/ I I · ~r~s Im I w/ I~ I ~__~rm I~ t nm~_ I sT~I I.__1 I I, I I I I I I I I I____1 I I I_ I I __1 I I I ....... l I ,I I .t I I I. I I I ,,. I I I I I I , I ~ I I ' I I ..... I I t ,,I I t 1_ I I I I I I ~ I pm%,.._q I I I I I I I I I I 1 I C~ I I .I I I II I I _ _1, t I iI I I I I I, ! I I I ........ I ! I .I ,I , I I I I I I I I I I I I ,,,I I_____1 I I I ! I I I I I ....... I DEC 2 .t~o / ., I baasir, a Oil & Gas Cons. ,,llnornrn:ss'on i ~ ' _ .... t'! U~ Z ~-. 0 n/ · = ~'ro4aoe ~ater InJ. S = blt Uater InJ. I! = J~Lnatble InJ. G = Gas InJ. I = lot lnJeottn~ 11/20/8~ Ammlar F].u:l.d: Gredie~ :' M. eoel ' · ,,.3 ~ Dr'.tllll~ Hud SCANNED DEC 1 9 2002 Alaska Oil Gas Consc~ation Commission 30t]i Porcu@in¢ Drive Anchora§e, Alaska §§E;01-3192 907-279-1433 To: X~/~ C ~ Permit The following data is hereby acknowledged as being received: Copy sen(~.o sender: Yes No / ARCO Alaska, Inc."~" Post Office ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ORI61 December 16, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 1G-05 Convert to WAG Inj. 1 Y-29 2X-09 Fracture 3A-02 Cement Squeeze Well Diagnostics If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) REC£IVF-D Alaska 0ii & Gas 00ns, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ~OILANDGAS~SERVATIONCOMMISSION 0 RIG IN A L 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 Exploratory Stratigraphic Service 4. Location of well at surface 971' FSL, 666' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 478' FSL, 1961' FWL, Sec. 32, T12N, R10E, UM At effective depth 169' FNL, 2089' FWL, Sec. 5, T12N, R10E, UM At total depth 242' FNL, 2101' FWL, Sec. 5, T12N, R10E, UM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) RKB 90' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-5 9. Permit number/approval number #83-2O 10. APl number 50-029-20908 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE measured 10086' MD feet true vertical 7067' TVD feet Effective depth: measured 9975' MD feet true vertical 6982' TVD feet Junk (measured) Top of Van Gun Fish @ 9508' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 1 6' 300 SX AS II 2494' 10-3/4" 1300SXAS III Measured depth True vertical depth 80' MD 80' TVD 2524' MD 2278' TVD 10044' 7" 1000 SX Class G 10072' MD measured 9348'-9378', 9332'-9336', 9095'-9131', 8976'-9050' 7056' TVD true vertical 6510'-6532', 6498'-6501', 6321'-6348', 6234'-6288' Tubing (size, grade, and measured depth) 3-1/2', 9.2#, J-55, tubing w/tail @ 9224' Packers and SSSV (type and measured depth) BOT HB-1 packer @ 8796', Brown 3H perm. packer @ 9181', Camco TRDP-1AE SSSV ~ 1955' 13. Stimulation or cement squeeze summary Intervals treated (measured) ALL ZONES P,E( EIVF_D 14. Treatment description including volumes used and final pressure Initial (~as Slug for WAG Injecti~Ec 1 B !991 Representative Daily Average Production or Iniection Data., ....... - .~.~'~T~'~uil & L~as uull~, uu,, ...... Oil-Bbl ~s-Md Water-Bbl ~ ~~resspre ..... ~ubing Pressure AQCnU[uyu Prior to well o~ration 0 0 3 8 0 0 4 8 0 2 3 5 5 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 10~000 0 420 3878 16. Status of well classification as: Water Injector_ Oil _ Gas Suspended Service WAG In!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~' °{x')' ~ Title Operations En~]ineer Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE W Z ~ E O T L E T ! B PR ~ B PR .:.0 C SI ~I 13 PR i2 B PR 13 B PR !5 B PR TOTAL.S' W Z S E 0 T L N A L E T -2 B SW 3 B SW 4 B ~I 6 B SW 9 B ~I 14 B SW 16 B OI TOTALS' -_ KDO-S h~wr~NINO WELL REPORT FOR 11/23/91 DRILLS[TE 1~'~ 7" 10" TP 'TT WC H2S. CSG CSg PSI CHK DEG % PPM PSI PSi 233 i76 132 69 122 1340 870 67 163 176 110 90 130 1300 850 52 171 1'76 151 95 145 1325 0 28 0 0 0 99 110 1180 580 0 161 176 108 72 95 1300 1000 59 170 176 135 98 210 1320 680 59 174 176 121 60 35 1060 280 55 163 176 112 80 150 1090 0 38 .. PRODUCTION WELL STATUS gAS LIFT STATUS I CN GAS I r-,Id AFl TEMP METER RATE I_.I OEO READIhlG MSCF EB 0 1381 0 0 290 0 0 0 0 0 0 0 0 1670 0 0 426 0 0 0 0 0 0 0 3767 . 0 INJECTION WELL STATUS ALLOW ACT 7" 10" INJ INJ TT CSO CSO PSI PSI DEO CHK PSI PSI 2750 2394 99 66 950 80 2750 2430 98 176 620 280 ~100 3868 80 100 420 150 ~100 3885 81 100 500 0 2750 2324 0 66 1950 100 4100 3872 80 50 890 210 2750 2412 0 176 950 240 4100'3874 79 32 400 180 INJECTION RATE INd INJ METER RATE RATE READINg BPD MMSCFD 0 3763 0.000 0 2720 0.000 0 0 10.380 0 0 3.422 0 7351 0.000 0 0 4.292 0 7152 0.000 0 0 4.314 SWI' 20986 + PWI' 0 = 20986 22.408 S/I IMPACT C H M O R I D EPL S N E BBI_S 0000 0 0 0000 0 OOO0 0 0 2qO0 20 l ~ 0000 0 0 ,~nO0 0 0000 ,."} ' 0000 0 '-' 1'7 S/I C H M O R I D S N E 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 RECEIVED D EO 18 !Ugl Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate m Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 971' FSL, 666' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 478' FSL, 1961' FWL, Sec. 31, T12N, R10E, UM At effective depth 169' FNL, 2089' FWL, Sec. 5, T12N, R10E, UM At total depth 242' FNL, 2101' FWL, Sec. 5, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 10086' 7067' feet Plugs (measured) feet 6. Datum elevation (DF or KB) ~)0' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1G-5 Injector 9. Permit number/approval number 83-20/8-659 10. APl number 50-029-20908 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9 9 75' true vertical 6 9 8 2' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 2494' 10 3/4" 1OO44' 7" Cemented Measured depth True vertical depth 300 Sx AS II 8 0' 8 0' 1300 Sx AS III & 2524 2278' 250 Sx AS I 1000 Sx Class G & 250 Sx AS I measured 9348'-9378', 9332'-9336', 9095'-9131', true vertical 6510'-6532', 6498'-6501', 6321'-6348', Tubing (size, grade, and measured depth) 3 1/2", 9.2#, J-55, tubing w/tail @ 9224' Packers and SSSV (type and measured depth) D 8976'-9050' JUN o719 9 6234'-62-~a8s~a Oil & Gas Cons, Comrniss~ol Ar~chorage BOT HB-1 packer @ 8796', Brown 3H perm. packer @ 9181', Camco TRDP-1AE SSSV @ 1955' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Convert from WI to WAG iniection. 14. Prior to well operation Subsequent to operation Representative DailyAverageProductionorlnjectionData OiI-Bbl Gas-Mcr Water-Bbl CasingPressure TubingPressure -0- 0- 7800 2675 2480 -0- -0- 7900 2600 2505 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil m Gas Suspended Service Wag Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Sr. Operations Engineer SUBMIT JN DUPLICATE ARCO Alaska, Ir~. ~ ; ,. Subsidiary of Atlantic Richfield Cot, WELL /_P.. -s CONTRACTOR , , ,=MARKS WELL SERVICE REPORT IPBDT I FIELD- DISTRICT- STATF-.~ I DAYS ' IOPE~TION AT RE~RT~IME ~ R cE'iVED ...... ,, u,, & Gas 0ons, Commission Anchorage I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK [Signe~t~......- _ ' . STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL.COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ WATER INJECTOR _ 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 83-20 3. Address 8. APl Number P. 0. Box 100360~ Anchorage, AK 99510 50- 029-20908 4. Location of well at surface 9. Unit or Lease Name 971' FSL, 666' FWL, Sec.29, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 478' FSL, 1961' FWL, Sec. 32, T12N, R10E, UM 1C-5 At Total Depth 11. Field and Pool 242' FNL, 2101' FWL, Sec.5, TllN, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i Pool 90' RKB I ADL 25640 ALK 2~71 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 16. No. of Completions 02/03/83 02/13/83 0~/17/83'] N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (M~D) 19. Directional Survey ( 20. Depth where SSSV set ~ 21. Thickness of Permafrost 10086'MD/7067'TVD I 9975'MD/G982.,TVD YES ~ NO ~ 18~1 feet MD !500' (~ppPoz)- 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL. RFT. CBL/VDI /CCI /GR_ ~R/C~I_ 23. CASING, LINER AND CEMENTING. RECORD SE~ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 1~" ~:~ H-40 Surf 80' 21~" 390 sx AS II ln-3/4,, as-~ K-~ Surf 2526' !3-!/2" . !300 sx AS ~!~ & 250 :x AS I 7" ~G_O~ K-~ ~,,rf 10072' 8-3/~" !000 sx Class G & 259 ~, AS I 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) Perforated w/12 spf, 60° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 93~8'-9378'ND/G510~-G532~TVD DEPTH INTERVAL (MD) AMOUNT & ~IND OF MATERIAL USED 9332 ~ -9336'ND/6~98 ' -6501 ' TVD .c~ c,,~%, ~l~_ ~.~ ~/~o/o,I 9095'-9131 'MD/6321 ' ~6348'TVD 8976' -9050,MD/623~ ' -6288, TVD 27. PRODUCTION TEST . Date First Production Method of Operation (Flowing, gas lift, etc.) N/A . DateofTest Ho~rsTested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE {GAS-OILRATIO . TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co/r) 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 NOTE: Perforated 11/2/82. Fractured well 8/10/84. Converted to water ~n3~6tor~B~, Workove~ performed 8/4/84 and 8/5/88. ..., Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC5/028 ~ 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand GEOLOGIC MARKERS o .. MEAS. DEPTH 8974' 9129' 9319' TRUE VERT. DEPTH 6232' 6347' 6488' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~/}F~A~/ ~t~/)~v/ 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 ,,-~.~ STATE OF ALASKA ..-_. . AL/ A OIL AND GAS CONSERVATION COt ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown . ~ Re-enter suspended well 7"; Alter casIng [; T,me extension Change approved program Plugging '~ Stimulate .! Pull lubing Amend order .r Perforate .r' Other 2 Name of Operator ARCO Alaska, Inc.. . 3 Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 971' FSL, 666 FWL, Sec. 29, T12N, RIOE, UN At top of productive enterval 478' FSL, 1961' FWL, Sec. 32, T12N, RIOE, UM At effective depth 169' FNL, 2089' FWL, Sec. 5, T12N, RIOE, UM At total depth 242' FNL, 2101' FWL, Sec. 5, T12N, RIOE~ UM 11. Present well condition summary Total depth: measured [0086' MD feet Plugs (measured) true vertical 7067' TVD feet 5. Datum elevation (DF or KB) RKB 90' . 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Permit number Pprmit #83-20 9. APl number 50-- 029-20908 10..Pool Kuparuk River Oil Pool None Effective depth: measured 9975' MD feet true vertical 6982' TVD feet Casing Length Size Structural 80' 16" Conductor 2494' 10-3/4" Surface Intermediate Production 10044' Liner Perforation depth: measured Junk (measured) Cemented 300 SX AS II 1300 SX AS III feet Top of Van Gun fish ~ 9508' Measured depth ~ue Vertical depth 80' MD 80' TVD 2524' MD 2278' TVD & 250 SX AS I 7" 1000 SX Class G ].0072' MD 7056' TVD & 250 SX AS I true .vertical 9348'-9378' 9332'-9336' 9095'-9131' 8976'-9050' 6510'-6532' 6498'-6501' 6321'-6348' 6234'-6288' Tubing (size, grade and measured depth) 3-1/2", 9.2#, J-55, tubing w/tail ~ 9224' Packers and SSSV (type and measured depth) BOT HB-1 packer @ 8796_' ,_Brown 3H perm. packer fa 91RI': C, amcn TRllP-]AF gSSV @ !955' 12.Attachments Description summary of proposal ~ Detailed operations program IT; BOP sketch ~ Convert from WI to WAG Name of approver 15. I hereby certify that the foregoing is true and correct to the. best of my kr~vte:dge Signed /~~ ,/~,~~,~~ Title /<~L ~)~~..J 13. Estimated date for commencing operation August/September ~,~ 14. If proposal was verbally approved ~' Date approved Commission Use Only Notify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test I] Location clearance! Date Conditions of approval · ;~iGINAi. SIGNED ~.Y LONNIE C. SMITH Approved Copy Returned Commissioner by order of the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate Sundry Notice Well 1G-5 No BOP will be used for the proposed work. No workover fluids are required. The estimated BHP is 3700 psig. STATE OF ALASKA ~ ALASr,,,-~ OIL AND GAS CONSERVATION COM~,..$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown '~ Stimulate ~ Plugging ~ Perforate - Pull tubing - Alter Casing ~ Other ~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A1 aska, I nc. RKB 90' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 971' F5L, 666' FWL, 5ec.29, T12N, R10E, UM At top of productive interval 478' FSL, 1961' FWL, Sec.32, T12N, R10E, UH At effective depth 169' FNL, 2089' FWL, Sec.5, T11N, R10E, UN At total depth 242' FNL, 2101' FWL, Sec.5, T11N, R10E, UH 7. Well number 1G-5 8. Approval number 8-498 9. APl number 50-- 029-20908 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 10086'MD feet Plugs (measured) None 7067 'TVD feet Production 9975 'MD feet 6982 ' TVD feet Junk (measured) Top of Vann Gun fish (~ 9508 ' Length Size Cemented Measured depth 80' 16" 300 sx AS II 80'MD · 2494' 10-3/4" 1300 sx AS III & 2524 'MD 250 sx AS I 10044' 7" 1000 sx Class C & 10072'MD 250 sx AS I 12. Perforation depth: measured 9348'-9378'MD, 9332'-9336'MD, 9095 ' -9131'MD , 8976'-9050'MD true vertical 6510'-6532'MD, 6498'-6501 'MD, 6321 '-6348'MD, 6234'-6288'MD Tubing (size, grade and measured depth) 3-1/2", 9.2#, J-55, tubing w/tail ~ 9224' Packers and SSSV (type and measured depth) Brown "HB" pkrs @ 8820' & 9061'~ Brown "3H" pkr ~ 9181' & Camco "TRDP-1A" SSSV ~ 1831' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 14. Attachments (Workover Wel 1 Hi story) Daily Report of Well Operations X~ copies of Logs and Surveys Run - 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/029 True Vertical depth 80 ' TVD 2278'TVD 7056'TVD Tubing Pressure Date ~/11l~ Submit in Duplicate ~,,~ ARCO Oil and Gas Company Well History - Initial Report -_Daily Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operalions are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ]County. parish or borough ARCO Alaska, Inc. Ii NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25640 Auth. or W.O. no. ~Title AK3234 I WORKOVER 1Stat,~.K 1G-5 lwell no. API: 50-029-20908 Operator ARCO Spudded or W.O. begun IARCO W.I. 56.0000 Prior status if a W.O, ACCEPT Date and depth as of 8:00 a.m. 07/27/88 { TD:10071 PB: 9975 SUPV:ML/KR 07/28/88 ( TD:10071 PB: 9975 SUPV:JM/LB 07/29/88 ( TD:10071 PB: 9975 SUPV:JE/LB 07/30/88 ( TD:10071 PB: 9975 SUPV:JE/LB 07/31/88 ( TD:10071 PB: 9975 SUPV:JE/LB 08/01/88 ( TD:10071 PB: 9975 SUPV:JE/LB 08/02/88 ( TD:10071 PB: 9975 SUPV:JE/LB I Date 07/26/88 Hour 1830 HRS Complete record for each day reported NORDIC 1 RU WL PULL CV MW:10.8 LSND MOVE RIG FROM 1G-4 TO 1G-5. ACCEPT RIG 1830 HRS, 7/26/88. ATTEMPT TO KILL WELL. WITH 10.8 PPG MUD. CIR¢ VALVE PLUGGED. RU WL TO PULL CV. DAILY:S45,519 CUM:$45,519 ETD:S45,519 EFC:$460,000 TESTING BOPE MW:10.8 LSND RU WL RIH PULL CIRC VALVE. KILL WELL WITH 10.8 PPG MUD. ND TREE, NU 11" BOPE..TEST BOPE. MUD FLOW FROM ANNULUS, CIRC & COND. WELL STATIC. PU TBG W/ 700009 TBG FREE FROM PBR. POOH 2 STDS, PU BAKER STORM PKR.~.SET @ 25'. ND BOPE. ND MCEVOY 11" 3M TBG HEAD. NU McEvoY 7-1/16", 5M TBG HEAD. TEST PACKOFF 3000 PSI. NU 7-1/16" BOPE. TESTING BOPE. DAILY:S51,863 CUM:$97,382 ETD:S97,382 EFC:$460,000 · RIH W/ 5" OVERSHOT MW:10.8 LSND FIN TESTING BOPE. POOH LD STORM PKR. POOH CHANGING COLLARS TO BTC AB-MOD. PU OS; RIH. DAILY:S40,810 CUM:$138,192 ETD:S138,192 EFC:$460,000 POOH W/ FISH MW:10.8 LSND RIH W/ OVERSHOT. TAG PBR BBL @ 8776'. LATCHED FISH , PULL & ROTATE FREE. CIRC & MONTIOR WELL. POOH W/ FISH. DAILY:S34,172 CUM:$172,364 ETD:S172,364 EFC:$460,000 POOH W/ FISH MW:10.8 LSND FIN POOH W/ PBR & PKR.' RIH W/ OVERSHOT. LATCH TBG STUB. RU E-LINE. RIH W/ 2-5/8" CHEM CUTTER. PU ON TBG W/ 15M9 CUT TBG @ 9160'. RD WL. POOH W/ FISH. DAILY:$38,383 CUM:$210,747 ETD:S210,747 EFC:'$460,000 POOH W/ FISH MW:10.8 LSND FIN POOH W/ FISH. LD CARBIDE BLAST RINGS, GLM & TBG STUB. RIH W/ OVERSHOT; TAG TBG STUB @ 9160'. LATCH & PU 5M9, ROTATE DF 20 TURNS TO RIGHT & RELEASE LATCH ASSEMBLY. POOH W/.LATC~ ASSEMBLY. DAILY:S32,439 CUM:$243,186 ETD:S243,186 EFC:$460,000 POOH W/ 1-1/4" STINGER MW:10.8 LSND FIN POOH W/ OVERSHOT. RECOVERED CUT OFF TBG , & LATCH SEAL ASSM. MU 1-1/4" STINGER. RIH CIRC & COND . STAB INTO PAKER. CIRC TO CLEAN TBG TAIL. POOH W/ 1-1/4" STINGER ASSEMBLY. DAILY:S48,244 CUM:$291,430 ETD:S291,430 EFC:$460,000 The above is correct For form prepa~tion and distribution. ===, Prn~llr~JMRnu~l. Section 10. JDate [ Title ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description or' all cores. Work performed by Producing Section will be reported on "lnlerim" sheets unlil final completion. Report official or representative test on "Final" form. 1) Submit "lnlarim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I State · z~:[CO Alaska, Inc. I NORTH SLOPE i AK Field ILease or Unit KUPARUK RIVER UNIT ~ 1G-5 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 08/03/88 ( TD:10071 PB: 9975 SUPV:JE/LB 08/04/88 ( TD:10071 PB: 9975 SUPV:JE/LB The above is correct NORDIC 1 8) RIH W/ 2.75" IMP. BLOCK MW:10.8 LSND FIN POOH W/ 1-1/4" STINGER. RUN 3-1/2" COMPLETION W/ BROWN SEAL ASSEMBLY & LATCH. CAMCO 'TRDP-1A' SSSV @ 1831', BROWN 'MB' PKRS @ 8820' & 9061, BROWN '3H' PKR @ 9181', & TT @ 9224'. STAB INTO BROWN '3H' PERM PKR W/ 150009. RU WL RIH W/ 2.625" GR, WOULD NOT PASS 8861', POOH. RIH W/ 2.75" IMP. BLOCK. DAILY:S29,100 CUM:$320,530 ETD:S320,530 EFC:$460,000 NU TREE MW:10.8 LSND MAKE 3 RUNS TO SET STANDING VALVE IN "D" NIPPLE. SET PKRS W/ 2500#. TEST TBG 2500# 30 MIN. SHEAR PBR. TEST CASING TO 2500 PSI TEST SSSV. SET BPV. ND BOPE. NU MCEVOY TREE. DAILY:S36,140 CUM:$356,670 ETD:S356,670 EFC:$460,000 JWell no. Signature ~t j,~(1,';~.,~,.-.. ~,' J,,._t(.[;<~ , For form prep~J~tion and distribution see Procedurc=~jManual Section 10, Drilling, Pages 86 and 87 JDate JTitle ASSOCIATE ENGINEER 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 sus0ended for an indefimte 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 Reporl" form may be used for reporting the entire operation if sDace is available. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK3234 Operator ARCO ICounty or Parish NORTH SLOPE Lease or Unit Title ADL: 25640 WORKOVER Accounting cost center code State I we. no. iG-5 Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 08/05/88 ( 1' TD:10071 PB: 9975 SUPV:ML/JS API: 50-029-20908 IA.R.Co. W.I. ~Total number of wells (active or inactive) on thisI Icost center prior to plugging and 56,0000 Jabandonment of this well 07/26/08 ! 1030 HRS Complete record for each day reported NORDIC 1 RIG RELEASED MW: 6.9 DIESEL FIN NU & TEST TREE. DISPLACE W/ FRESH WATER, FILTER WATER, DISPLACE WATER TO DIESEL. TEST CASING TO 3500 PSI. SET BPV. RIG RELEASED 0200 HRS, 8/5/88. NOTE: RIG MOVED TO EDGE OF PAD TO REPAIR STEERING SYSTEM, WILL THEN MOVE TO 1G-6. DAILY:S83,469 CUM:$440,139 ETD:S440,139 EFC:$460,000 Old TD New TD Released rig Date IPB Depth Kind of rig Classifications (oil, gas, et{:.) Type completion (single. dual. etc.) Producing method Official reservoir name(s) Potential test data V~ell no. Date Reservoir Producing Interval Oil or gas Test lime Production Oil on test Gas 0er day , Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective da:e corrected · . ,., The above is correct Signature For form preparatiq~n~and distribution, see Procedures Ma't~al, Section 10, Drilling, Pages 86 and 87. IOale ITitle ASSOCIATE ENGINEER STATE OF ALASKA ALASKM OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown r~ Re-enter suspended well ~ Alter casing © Time extension ~ Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order [] Perforate [-] Otherj~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 90' feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 971 ' FSL, 666' FWL, Sec. At top of productive interval 478' FSL, 1961 ' FWL, Sec. At effective depth 169' FNL, 2089' FWL, Sec. At total depth 242' FNL, 2101' FWL, Sec. 5, 29, T12N, RI OE, UM 32, T12N, RIOE, UM 5, T11N, RIOE, UM T11N, RIOE UM 7. Well number ,tO-5 8. Permit number 83-20 9. APl number 50-- 029-20908 10. Pool Kuparuk Ri ver Oi 1 Pool 11. Present well condition summary Total depth: measured true vertical 10086 ' MD feet Plugs (measured) None 7067 ' TVD feet Effective depth: measured 9975'MD feet Junk(measured) Top of Vann Gun fish true vertical 6982 ' TVD feet ~ 9508 ' Casing Length Size Cemented Measured depth True Vertical depth Conductor- 80' 16" 300 sx A5 II 80'MD 80'TVD Surface 2494' 10-3/4" 1300 sx AS II I 2524'MD 2278'TVD & 250 sx AS I Production 10044' 7" 1000 sx Class G lO072'MD 7056'TVD & 250 sx AS I Perforation depth: measured 9348'-9378', 9332'-9336', 9095'-9131', 8976'-9050' true vertical 6510'-6532', 6498'-6501 ', 6321 '-6348', 6234'-6288' Tubing (size, grade and measured depth) 3-1/2", 9.2#, J-55, tubing w/tail ~ 9224' Packers and SSSV (type and measured depth) DOT HB-1 packer ~ 8796'~ Brown 3H perm. packer ~ 9181'~ Camco TRDP-1AE SSSV ~ 1955' 12.Attachments Description summary of proposal j~ Detailed operations program [] BOP sketch ~ 13. Estimated date for commencing operation July 24. 1988 14. If proposal was verbally approved JUN 2 7 19 8 Name of approver A[~S~ 0[~ & 6as Cons. ~mmissi~te approved 15. I hereby certify that the foregoing is true and correct to the'b~tC~?r~ knowledge Signed ~)~ ~ Title A ssocia ~ Commission Use Only (SA3/0007) Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity ~ BOP Test ~ Location clearance ~,~ ...... ~ Imegri~ T~ Approved Copy Returned O.~AL ae~D ;" ~ ~ by order of BY LONNE C, Commissioner the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate -. Pre-Ria ooerations - KRU 1G PAD TRIPLE PACKER WORKOVERS General Procedure 1G-5 1. Obtain-C sand BHP after well has been shut in at least one week. 2. S_et plug in D .nipple to isolate A sand. · Cut tubmng with chemical cutters below both the blast joints and the second GI_M between the packers. Fli_o o.aerafions lp. MIRU Nordic. Kill well with drilling mud. ND tree. NU BOPS. · Pull hanger to floor. PU storm pkr and set same 1' below fl3g spool. 3. Change out tbg spool to 5000 psi equipment. 4. Retrieve storm pkr. POH changing out couplings to AB MOD. 5. GIH with pkr retrieving tool, picking up drill pipe. Retrieve pkr and tbg down to the cut made below the second GLMinpre-rig operations. 6. GIH with WP. Clean out fill down to the-bottom GLM. 7. GIH with an overshot and fiShing BHA on 3-1/2" tbg. Fish blast joints. 8. GIHwith an oVershot and fishing BHA on 3-1/2" DP. Fish remainder of completion from above the permanent pkr. 9, Make a clean out run with 1-1/4" CS Hydrii tail pipe. Run a csg scraper to the permanent Pkr and enough 1-1/4" to clean out any fill on top of the D nipple. 1 0' POH LDDP. 11. Run new completion with steel blast jts and 2 packers across the C sand. 12. Release rig. Turn well over to production for individual zone testing and injection. JUN g- 7 lgBB Alas~,a 0it & ~,as Cons. Commission Anchorage 7-1/16" 5000 PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAi"IS 4 BLIND RAHS 5 TUBIN6 HEAD 2 1. 16" CONDUCTOR SWAGED TO 10-3/4" 2. 11"-:3000 PSI STARTING HEAD 3. ! 1"-3000 PSI X -1-1/16"-5000 PSI TUBING HEAD 4. 7-1 / 16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ;3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST DLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE-TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO ;3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY. WITH ;3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSi. 9. OPEN PIPE RAMS. BACKOFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO ;3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO :3000 PSt. 12. TEST KELLY COCKS AND iNSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY R E C E IV E D JUN 2 7 ]988 Alaska 0il & Gas Cons. Commission Anchorage JG dULY 26, 1986 (NORDIC RIG 10-~3/4") ARCO Alaska, Ir Post Office vox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 20, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. Well Action 1G-5 Conversion 2A-4 Conversion 2A-5 Convers i on The wells are conversions as listed below. Anticipated Start Date November 30, 1987 November 25, 1987 November 25, 1987 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:pg'0129 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~---~ STATE OF ALASKA '---" AL,- .... A OIL AND GAS CONSERVATION CG .... rSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, ^Dchorage~: AK 4. Location of well at surface 99510 971' FSL, 666' FWL, Sec 29 T12N RIOE UM At top of productive ~nterval ' ' ' ' 478' FSL, 1961' FWL, Sec.32, T12N, RIOE, UM At effective depth 238' FNL, 202' FWL, Sec. 5, T11N, RIOE, UM At total depth 242' FNL, 210' FWL. Sec. 5; T11N; RIOE: UM 11. Present well condition summary Total depth: measured 10086' ND feet true vertical 7067' ND feet 5. Datum elevation (DF or KB) RKB 90 6. Unit or Property name Kuparuk River Unit 7. Well number 1G-5 8. Permit number Permit #83-2 9. APl number 50-- 029 -20908 10. Pool Kunarnk Rivpr Oil Pno1 ! feet Plugs (measured~lone Effective depth: measured 9975' MD feet true vertical feet 6982' MD Junk (measured) None Casing Length Size Cemented Measured depth Structural 80' 16" 300 SX 80' MD Conductor Surface 2524' 10,75" 1300 SX 2524' MD X X X ;t::rk't~XO~ ~¢:ixt t e Production 10071' 7" 1000 SX 10071' MD xx x xWcXe~xx x x Perforation depth: measured 8976'-9348' MD true vertical6225'-6510' TVD Tubing (size, grade and measured depth) 3.5", 9.2 lb, J-55 Packers and SSSV (type and measured depth) Camcn TRDP-IAF fa lC)6.g, R~'own ~H @ _9!81_'' RNT HR_I ra 12.Attachments Description summary of proposal [] Deta]le~J o-lCe~tions program [] Convert from production to water and oas inic_ctinn 13. Estimated date for commencing operation November 30, 1987 ~ue Vertical depth 80' TVD 2500' TVD 7062' TVD RECEIVED N(_):,/2 3 !98'; A!aska 0il & Gas Cons, C0mrniss~;n Anchorage BOP sketch [] 14. If proposal was verbally approved Name of approver ..~. ~ ~ %j L/~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/~,t~, /./~-,~ t/~ Title Sr. Operations Engineer Date11/12/87 Commission Use Only Conditions of approval Notify commission so representative may witness[] Plug integrity [] BOP Test [] Location clearancel Appr°vaIN°' '? ~'¢/.~- .' Approved Copy '~ Mech-c...~,ic~! ~ ........... ,,.-',~'.S, ~tv ~o.-Jt Returned ORIGINAL SIGNED BY //_,~ ~? LONNIE C. SMITH by order of Commissioner the commission Date /// Approved by Form 10-403 Rev 12-1-85 Submit in triplicate ATTACHMENT I I Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Lo9 Date Drill Site Well No. Lo~ Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 18 lB-1 12/26/81 18-2 6/25/81 18-3 11/16-18/81 3/12/82 18-6 11/18/81 9/10/82 18-7 11/23/81 18-8 12/28/81 8/4/82 18-9 6/24/82 8/3/84 Drill Site 1C Well No. lC-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8' -. Log Date 5/9/81. 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Lo9 Date 10 10-1 · 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 ~_,~10-8 (WS-8) 5/i0/78 Attachment II ~-- Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lQ ~1Q,.~12/1785. Drill Site Well No. Lo9 Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Lo9 Date Drill Site Well No. . 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/!2/83 1F-7 t-d. aska Oil & Gas Cons. Lo9 Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment I I ~-.~ _ Page 3 Drill Site 1Y Well No. Lo9 Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~~ 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1¥-9 6/20/83 ~-Y~-.~ 5/10/83 ~_. ~ 11/21/83 ~7t28/8~ 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2~28~85 2C-7 10/15/84 12Cr16~1211!/80 Drill Site Well No. Lo9 Date 2Z' 7/10/83 2Z-2 : 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF' pg: 0052 Alat~ Oil & Gas Cons. Comm..it:" Anchora? Drill Site Wel 1 No. 1H-3 ~1H-4 ~,~. ~'~1H-6 ~1H-7 ~1H-8 Lo9 Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site ' Well No. Loo Date 1E 1E-lA 1E-2 x~8/19/81 "8/17/8D'-y '~1/17/84/ 1E-3 "10/18/81~. ~11/7/81/ 1E-4 '~8/4/80~ '~10/27/81 ~o/2]/8~ '--11/12/82/ '~J3/28/8 l'q, '~10/28/81/2 ~ '~ 8/28/8~> ~ "~11/1/8 '"'11/28/84 "-8/26/82 "'8/29/82 "-9/1/82 "~5/7/83 "-2_/17/83 ~-1/17/83 ~1/13/83 '~f10/31/82 '~10/27/82) ~ "~6/13/83 ~1o/18/82B ~, '~7/18/83 / "-10/16/82 1E-5 1E-6 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 Drill Site 1G Well No. "~1G-3 ~1G-4 '~1G-8 Lo9 Date 9/7/82 - 9/25/82R, 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Loo Date 1F ~1F-1 2/19/83 ~,~F-2 2/3/83 r-3 1/31/83 "1F-4 5/29/83 ~1F-5 10/25/82 ~1F-6 10/28/82 '~ 1F-7 11/19/82x,,. ~ 5/7/83 RECEiV "/, F E B 2 1 ]986 Alaska 011 & Gas ~ons. ~mmlsslon Ancnorags ARCO Alaska, In; Post Office ~,_.~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 · Mr. L. C. Smith Alaska Oil and Gas COnservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED 0~1 ~ ~s C~ns. Commission Anchora~ ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany STATE OF ALASKA ALASKA~'~L AND GAS CONSERVATION C('"--'~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit' 10. Well Number see attached I6. Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: 11. Field and Pool Kuparuk River Field ' Kuparuk River Oil Pool (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate I-q Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] . Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of J^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SE? 2 o 19 5 Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of'my knowledge. Signed :::~, //~-~¢~ ~,~.-~-~ Title Kuparuk Operations Coordinator Da,e The space below for Commission use 9/18/$5 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy .R. eturn~l / .... By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1E- 6 -26 IF- 2 - 4 - 5 - 8 1G- 2 - 3 - 4 - 5 IL- 1 - 3 - 5 - 7 -16 IQ- 1 - 2 - 7 - 8 -11 -12 -13 -14 iR- 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 2B- 5 - 6 ' ' - 7 - 8 - 9 -10 -11 -12 2C- 1 - 2 - 3 - 4 - 5 MARK: 009 Permit 80- 78 82-166 81-211 172 132 162 82-138 149 161 83- 20 84-173 158 123 145 181 84-231 232 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API# 029-20493 029-20840 029-20881 20846 20807 20836 029-20813 20824 20835 20908 029-21196 21182 21155 21171 21202 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 '21333 21351 21385 029-20933 20950 20934 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 029-20962 20972 20968 20973 20978 Lease & Serial # Convert Date 25651 469 10/15/85 " " 10/15/85 25652 2578 10/15/85 " " 10/15/s5 " " 10/15/85 " " 10 / 15 / 85 25640 2571 10/15/85 " " 10/15/85 " " 10/15/85 " " 10/15/85 25659 2585 12/15/85 " " 10/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25634 2567 10/15/85 " " 12/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25635 2568 10/15/85 " " 10/15/85 " " 10/15/85 " " 10/15/85 25641 2572 12/15/85 25646 2577 12/15/85 " " 12/15/85 25548 2662 12/15/85 25656 2582 12/15/85 " " 10/15/S5 " " 12/15/85 " " 10/15/85 25655 2581 12/15/85 " " 12/15/85 " " 10/15/85 " " 10/15/85 25654 2580 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 $ E P 2 o Alaska. Oii& G~s Cons. Comm!ssior, ARCO Alaska, Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 2.76 1215 DAI'E'05 .... iU-.-85 TRANSI-I]]TTAL. N0:5~86 :' I';; A N.7 i'-I ]: l'T I::: D I--I I:: R E l,,J ]: ]' H A 1:;; I:: 'TI-I E: F 0 I... I... (:J W ]: N (; < I.:: C r.." :1: F:' T A N D R l.'."'F U R N · (3 N E .7 :[ C. N I::. D C 0 F:' Y :1: T FZ M S .- F." I... E: A.7 IE A C J< P. 0 W L. r.': I) G r.:: OF THIS 'rRANS'NITTAL, JS'R/",.~I:: .... I;]UENC[.: OF:' I:::V[::NI',S' ' F 7 R U N L Y N E,? 1:;: E C 0 I:;: 1.'.' ..... ' '" (-) i .... -'- [:. I-,. ,.,. 4 -.. '2 .... o "-i i F-7 RI.--=TF,~:rE:VE L_ '¥' N IF_ ;:: F;,'ECOI-::DEF;:,S',.34 .... 2:?-8.5 i G -- 4 I_ t' N ,::"" '",.~ I::: R E :;' 5' LI F;: l:-i:. B 0 M B :';;-' F:' BtJ(:)4-")t-o.~,:. "' '"~, -i (2--5 ,S'BHF' 'C' ,S'AND 04-26-85 il_--::] ' C' ,S'AND,S ONLY F:'I;','U 04-2t -85 . ; L-2' ' C' ,S'AND F'I::U 04-25-85 ~ Q....6 TAG F." ]: LL/5'BttF' 04-23-85 : Q-7 TAG F'IL.L../,S'BHF' ' A' SANDS ,34.-t 6--8'":, 2 A -- i ,.7 Ii-,' I--1F:' :2A-4 5'BHF' 04-22-8:5 :2A.-5 I.-.ALL OFF TE:,.~T (.)4-.2i-"'5 "~ A- 5 F A 1._ L. (.') F-' F 'f'E,% T ¢ 4 -- ''> ''> - 8'": ?.A-7 ,.~ Ii, Hr 2B-t2 E/LINF SF:'IN/TCI. SURVEY I_EAI< DE'I'ECI'IC)N 'C'SAND F'BU F'BU RUN 'f'OI-'<QUE 'fUR ~/ ....... '" ' "<' N, ~, I"~ I:: I", r-.~ D ~-.~,.,, PBU-PULL TOF,:ii~UE "f'UF;:i',I/ AMERAI)A ROMB,.? I:i'.tJN T(]F:(;]UE TLJRN/AHI:"'F:~ADA,.'? PI:':U-I::'UI_L TOR[,!UI=_ ' TURN/ AHiEI:k&DA l-'.', 0 M r4 S i."<UN 'FOFi:~UE TU',:~N/AHF. RADA,~ RUN TOFiQUI.Z ]'UFiN/AMI::'Fi:ADA,S' F'BLI-F'LIL. L TOI:~I...':!UE TUI--<N/ A. MEF<ADA ROMBS F'BU PBU F'BU PBLI F'BU PBU F:' B U I.'-' B U I::' F J U ACI(NOWLEI) G ED · [.'." R l L I....'1: N (.':. J(.) !.-I i'-I ~? ]' 0 i"~ * M 0 t--.~ ]: I... N L,"I( C L E I:;' K 04-t 6-85 :'.!C-.4 ~ 4-2q--8'"~ ?.C-4 04--"~5:.. -'":',=.-, '.:.!['.-5 6,4-2t -8.5 2 D - 2 2. I)-- t 0 ..-?. D- i 0 2F--8 2F'-i t 2F-i 1 ::.'. I.'; - i 26-.1 2(.';--.8 26-8 ";: E: C' 1:': I F'T !:-: F:' A 1::. 3 ~ C t.l R R I E R ~,:- '.': H E V R 0 i-.I --'~ 04-.23-8S; 04 ..i '85 04 - 2 t -' 8 '5 04 -' 2 t - 85 04_.,-~¥ ,-.,,::- ..:. -- ,S) ~~ -',¢. O-q--. i 9-8.5 04-20--85 O4-i 8-85 O4-i '" ¢-- 6'4 .... i'=' "~ O 3; -" 2 ~ -' 85 0 'S -.. 2 2 - ~:; ~, 0 l' I S O'F I $ Ol']:,S' C A N C 0 C A PI C 0 (::ANCO CAMCO C A iq C 0 C A i't C O O'F 7 $ CAMCO CANCO OTIS' OTIS CAMCO CAMCO BAI< El:i; BAI< ER/TOFkQUI-': ]'URN OTIS BAI<ER/TOFiQLJE TLJRN 0 T I ,S' B A I( r-." R B A I< E R / l'O R r2 u E TU R N 0 T I $ C A i',1C 0 ~.~.~_ ~/¢;2~,?~-'E'-~.~ CAMCO [:ANCO ~./ OT ]::¢ Alaska Oil OTIS' /~.,1.,,~, ~o~ DATE: · . ....... · ×.STATE (:IF AI..ASKA · :,(',S' 0 H ]: 0 -~'UN I (:IN K. 'l' LII. ]: iq/VAULT · -ARCO Alaska, Inc. ~ Post Office ~360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1/31/85 Transmittal No: 5019 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 nsmitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. ~BU SURVEYS .Otis-.~r - 1~-2 1/24/85 1~-~ 1/20/85. -.. 2G-7 1/23/85 2V-8A 1/24/85 2Z-4 1/19/85 2Z-6 1/19/85 ._ .~.. .._ '& SEQUENCE OF EVENTS · "·.~.~ -_2B-lO 1/21/8~/ -. 2BU SUR~EYS Lynes .. ,,~-6~' 1/21/85" Tool #1317 /' /.~F-7 1121185 . " #1516 " #1511 " #1508 .- /cat Receipt Acknowledged: i/2i/85 "PBU" i/2i/85 "PBU" 1/21/85 "PBU" n ~'mF. ~ ~ ! i- ~ Alaska 0il & Gas Co.s. Cornmis~!on Date: Anchora,qe .. DISTRIBUTION B. Currier Drilling · · BPAE Geology Chevron Mobil W, Pasher · G. Phillips Phillips Oil State of AK Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary o! AtlanticRich!ieldCompany f- ARCO Alaska, In?-'. Post Offic ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ~CO ALAS~, I~. AT~: Records Clerk ATO-1115B P.0.~-~100360 ~ -~/~f°rage' AK 99510 · . , , /T/~n~itted herewith are the following it.s. Please acknowledge receipt rand retu~ one signed copy of this transmittal. OTIS PBU SURVEYS 2W-8/' 1/08/85 lB-7 '" 12/14/84 2F-12 1/06/85 2F-5 ~- 1/02/85 2W-5 -/- 1/07/85 ~w-6 .... 11o7185 !2W-7 1/07/85 i lA-1 '~ 12/31/84 lA-1 ~'[.._~ 12/15/84 I1A-1~ 12/23/84 :l~-5.~- 12/25/84 ~F-3 ~ .~2/3~/s4 2V-SA ~ ~2/~6/84 2B-~0 ~ ~2/~7/84 1Y-9-~ 12/20/84 .~c~ ~2/~o/84 2F-2 ~ 12/29/84 2F-14- 1/04/85 2F-9~ ~/o2/8s API 02 9-21228 ' 02 9-2D616 029-21097 029-21073 -- 029-21220' -- 029-05900 029-20908 -- 029-21178. 029-21084 029-20935 029-21 063 029-21048 029-21090 029-21077 CAMCO PBU SURVEYS 1E-12 ~ 12/14, 16/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Drilling W. Pasher Date:f~aska Oil k, (~as cpn~ Cn~,~miSSjc,q Anchorag~ State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&H NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. ,, . Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ' '.S S/PRESS ANAL¥S S ~lA-2 · 5/11,12/84 Torque Turn (Pressure & Temp Surveys) ................. ~iA-_6~' 7/06/84 Camco ,:,.,~i~:,.~.,,~ ,.:~ ~'! /1B-11~I~ 7/10,12/84 Camco .. --~>IA-10 5/10/84 /lC-1 12/17/83 zlC-6 8/04/84 /!¢-~0-' 12/2!/83 /1G-11 12/23/83 5/21/84 /1G=_3 6/26/84 ~%~.~.~> 6/30/84 L/~G~, 5/26/83 1q-6 8/11/84 /¢~ ~> 7/07/84 /~-4 12/27/83--.0tis ~tY-5 12/14/83 Otis ~lY-7 12/15/83 Otis /~1 7/03/84 Otis ~Jl 4/10/84 C~ Otis Otis Static Otis Cam~o Camco Otis Camco Torque Turn (Pressure & T_m~p Surveys) Camco Static Cmnco Camco HP Camco Camco Otis HP Static Receipf~ac~nowledged: DISTRIBUTION Date: B. Adams D & M W.¥. Pasher G. Phillips F.G. Baker Drilling P. Bgxter Geology Phillips Oil BPAE Mobil J.J. Rathmell R & D Chevron NSK Operations C. R. Smith S tat ~-of?Alas~ ~ 'ti '×:~:~" ' ~'-~/~"' ~ ~ ~ ~.~ Sohio Union Well Mi]es 277 $~37 Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items, Please acknowledge receipt and return one signed copy of this transmittal, ~i!- 5/28/84 2C-1 11/09/83 <~2~]> 4/24/83 (~C_---~? 4/22/83 ~2~_3 4/28/84 ~23-~? 4/29/84 5/04/84 '~Vc-~ 5/06/84' 2X-5 8/12/84 .... , 3C-6 5/19/84 3C-6 5/17/84 '-Otis Lynes -Lynes Lynes Lynes Camco Camco Otis Camco Camco Dresser PBU Flow Survey (Gradient). Otis Static Gradient Otis Cam~o DrEsser Dresser Mini Drawdown &Buildup Survey /cat Receipt Acknowledged: B. Adams F.G. Bake'r P. Baxter BPJ~ Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W,V, Pasher G, Phillips Phillips Oil J,J, Rathmell R & D C. R. Smith Sohio Union Well Miles ARCO Alaska, In Post Office ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1G-5 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/L49 Enclosure If RECEIVED SEP 2 4 1,,q l, ~,t~ska U,t & Gas Cons. Commission .~cnoraoe ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS.:':... .'AND GAS CONSERVATIOI ,ISSION WELL COMPLEI i tl OR RECOMPLETIOh "(EPORT 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. 83-20 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20908 4. Location of well at surface 9. Unit or Lease Name 971' FSL, 666' FWL, Sec.29, T12N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 478' FSL, 1961' FWL, Sec.32, T12N, R10E, UM 1G-5 At Total Depth 11. Field and Pool 242' FNL, 2101' FWL, Sec. 5, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 90' RKB ADL 25640, ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/03/83 02/13/83 02/17/8:3 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10086'MD,7067'TVD 9975'MD,6982'TVD - YES [] NO [] 1955 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL, EFT, CBL/VDL/CCL/GR, GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SlZEI WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 300 sx AS II 10-3/4" 45.5# K-55 Surf 2524' 13-1/2" 1300 sx AS Ill & 250 sx AS I 7" 26.0# K-55 Surf 10071' 8-3/4" 1000 sx Class G & 250 s~ AS I 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) 9348' - 9378' 3-1/2" 9224' 9181' & 8796' 9332' - 9336' 9095' - 9131 ' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8976' - 9050' 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 IGAS-OILRATIO TEST PERIOD I~ 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 RECEIVED SEP 2 41 4 ~Jask'a 0i~ & Gas Cons. Commission Anchorage Form 10-407 GRUS/WC11 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEoLoGIc MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8974' 6232' N/A Base Upper Sand 9129' 6347' Top Lower Sand 9319' 6488' 31. LIST OF ATTACHMENTS Workover Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Ar~ rlr~ll~nn I~nnr 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". AFl'CO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Kuparuk River Field ICounty or Parish Lease or Unit Title North Slope Borough State ADL #25640 Alaska Well no. 1G-5 W/O Auth. or W.O. no. AFE 103951 Recompletion Nabors i-ES Operator ARCO Alaska, Inc. Spudded or W.O. begun JA.R.Co. Date Workover Date and depth as of 8:00 a.m. Complete record for each day reported 7/26/84 I otal number of wells (active or inactive) on thisj ost center prior to plugging and bandonment of this well J 56.24% our I Prior status il a W.O. I 1500 Hrs. 8104/84 thru 8/05/84 Old TD New TD Released rig Date 2000 Hrs. Classifications (oil, gas, etc.) O±l Producing method Flowing Potential test data 7" @ 9587' 9587' PBTD, RR Diesel & crude RU & rn 231 its, 3½", 9.2#, J-55 IPC BTC compl string w/3-H perf pkr @ 9181', "D" Nipple @ 9207', Tbg Tail @ 9224'. ND BOPE, NU & tst tree to 3000 psi. Displ well w/30 bbls diesel, followed by 291 bbls crude. RR @ 2000 hrs, 8/5/84. I PB Depth IKind of rig 8/5/84 I IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands ~//Cflorage' 9587' PBTD Rotary 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 9/12/84 ~itle Drilling Superintendent ARCO Oil and Gas Company,~,"' Well History - Initial Report - Daily ~).~structione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 103951 ICounty, parish or borough North Slope Borough Lease or Unit ADL #25640 Title Recompletion JState Alaska Well no. 1G-5 W/O Nabors 1-ES Operator ARCO Alaska, Inc. ARCO W.I. Pr or status 56.24% if a W,O. Spudded or W.O. begun JDate JHour Workover 7/26/84 1500 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 7/27/84 7/28/84 thru 7/30/84 7/31/84 8/Ol/84 8/02/84 8/03/84 9510' PBTD, Circ out gas 10.0 ppg NaC1 Accept rig @ 1500 hrs, 7/26/84. Pull BPV, build brine vol, pmp 27 bbls carbonate pill, followed by 80 bbls, 9.2 ppg brine. Build vol & wt up to 10.0 ppg, circ well w/10.0 ppg brine. 7" @ 9510' 9510' PBTD, PU pkr 9.8 ppg NaC1 Set BPV. ND tree, NU & tst BOPE to 3000 psi. POOH w/3½" tbg. RIH w/3½" DP, tag top of fsh @ 8829', POOH, LD SBR & 3½" tbg fsh. Redress OS, TIH, engage fsh @ 8804', POOH & LD pkr, tailpipe & OS. RIH w/bit/scrpr, tag btm @ 9587' DPM, POOH. 7" @ 9510' 9510' PBTD, RIH w/pkr on WL 9.8 ppg NaC1 RIH w/R-3 pkr, set @ 9401', tst csg to 2200 psi. Set pkr @ 9210', pmp 30 bbls @ 2500 psi, no comm w/ann, POOH, LD DP. RIH w/6.125" gage ring/JB to 9250'. RIH w/2B-pkr & tailpipe, pkr stopped @ 8755', POOH. Rn 6.125" gage ring/JB to 9250'. MU perm pkr assy, RIH. 7" @ 9587' 9587' PBTD, LD DP 9.8 ppg NaC1 Unable to get past 8755' w/pkr assy, POH & LD. to 9300', POOH to 8000', CBU, no fluid loss. RIH w/CO assy 7" @ 9587' 9587' PBTD, POOH w/GR/CCL 9.8 ppg NaC1 Fin POH. RIH w/2-B pkr, unable to get below 8755'. Rn JB/gage ring to 9510'. MU & RIH w/3-H pkr & 295 jts, 3½" DP to 4590', unable to get lower. Rev circ to cln hole, add sinker bar, unable to get below 4590', POH. 7" @ 9587' 9587' PBTD, LD DP 9.8 ppg NaC1 Fin POH, std back 3½" DP. Rabbit ea std 3½" DP. 295 stds 3½" DP, set pkr @ 9181', POOH. ECEi VED RIH w/pkr & Alaska Oil &,Gas. Cons. Commission ~nChorago The above is correct Signature/~,~,~_.~ ~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate 9/12/84 Drilling Superintendent ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 21, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent wells at the Kuparuk River Well Action 1F-2 Fracture 1F-10 Conversion 1F-11 Conversion 1F-13 Conversion 1F-15 Conversion 1G-3 Fracture 1G-4' Fracture 1G-5 Fracture 1G-6 Fracture 1G-6 Conversion 1G-9 Conversion 1G-14 Conversion 1G-16 Conversion 2C-7 Fracture If you have any questions, please call notices on the Field' Date Performed 8/23/84 8/13/84 8/12/84 8/16/84 8/16/84 8/10/84 8/30/84 8/10/84 8/12/84 8/28/84 8/24/84 8/24/84 8/24/84 8114184 me at 263-4253. Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 3. A~dress . ~.. O. ~v I00350 4. Location OT W~~ ' SURFACE LOCAT ION' T12N, R109E, 5. Elevation in feet (indicate KB, DF, etc.) 12. 971' FSL, 666' FWL, Sec. UM 29 I 6. Lease Designation and Serial No. 7. Permit No. o") 8. A¢¢1 ~r~b~r 50-- 9. Unit~o~ ~e~s~ ~a;~n~ ~ KUPARUK RIVER UNIT 10. Well Number 1G-5 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL AD! 256/40 Al K 2571 POOl_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (RKB)90' (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On August 10, 1984, the "A" sands of Kuparuk well 1G-5 were hydraulically fractured and propped to improve production. treatment consisted of 170 BBLS of gelled water as pad and fluid and 8,000 LBS of 12/20 sand as proppant. The carrying Prior to pumping, equipment and sand was tagged with R.A. tracer performance. lines were tested to 5000 psi. to aid determination of job The 14. I hereby cert~~to the best of my knowledge. ~/,~.j~~/~. KU PARUK Signed Title OPERATI ONS COORD I NATOR The space below for Commission use 9/19/84 Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, I Post Offic~ ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 22, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1G-5 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry you have any questions, please Sincerely, Gruber Associate Engineer JG/tw GRU1/L04 Enclosure Report call me for the subject well. If at 263-4944. Oil & Gas Cons. Gommission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 971' FSL, 666' FWL, Sec.29, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 83-20 8. APl Number 50- 029- 20911FI 9. Unit or Lease Name Kup~ru~ Rfver Unit 10. Well Number !G-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool RKB 90' 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) APL 25640 .ALK 257! Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1500 hrs, 07/26/84. Pulled BPV. Pumped 27 bbl carbonate pill followed by 80 bbls, 9.2 ppg, brine. Bled off ann gas pressure and circ w/lO.O ppg brine. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Backed out lockdown screws, POH & LD 3-1/2" tbg. Tagged top of fish @ 8829'. Milled over & engage fish. .. CBU. POH & LD SBR & 26.66' of B-l/2" tbg fish. Redressed overshot and RIH. Engaged fish ~ 8804' & chased downhole to 8992'. POH to 8780'; CBU - packing off. POH. Stuck pkr in hgr spool and worked free. LD pkr, tailpipe and overshot. PU bit and scraper and RIH. Tagged btm @ 9587'DPM. POH. PU R-B pkr. POH w/BOT perm. pkr assy & LD. RIH w/2-B pkr, on W/L, to 8755' (would not go past this depth) POH. RIH w/JB/gauge ring to 9510' - no problems encountered. RIH w/B-H pkr w/B-I/2" DP for spaceout. RIH to 4590' - would no go past this depth. Rev. circ. to clean hole. POH & std back B-1/2" - rabbit each std (piece of plastic lodged in 75th std). Checked pkr & tail assy. RIH w/pkr & tail assy. Dropped ball and set pkr @ 9181' w/BO00 psi. Unlatched f/pk'r~& POH. Ran B-l/2" completion assy w/tail ~ 9224', B-H perm pkr @ 9181', HB-1 pkr ~ 8796' & SSSV @ 1955'. Set BPV. ND BOPE. NU tree and tstd to BO00 psi. Disp well w/BO bbls diesel and 291 bbls crude. Set BPV. Secured well & released rig @ 2000 hrs, 08/04/84. RECEIVED AUG 019t]4 Alaska 011 & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~ ~/A~ ..... ~ ~//~,/~_~/~ ~/J/~t,/,'~-- Title Area Drilling Engineer The ,p~ce be~/~ f~o-m~sion use/ "~" ' Conditions of Approval, i~any: Approved by By Order of COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1 ~0 GRU8/SNB9 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' -. · Attached are notices-of intention to fracture 1G-1, -2, -3, -4, -5,--6, -7 and -8. If you have any questions, please call Kuparuk wells me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Tripiicate) RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Alaska. Inc. is a Subsidiary o! AtlanticRichlieldCompany STATE OF ALASKA ' ALASKA uIL AND GAS CONSERVATION C~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER 4. Location of Well SURFACE LOCATION' 971' FSL, 666' FWL, Sec. 29 T12N, R109E, UM 7. Permit No. 83-20 8. APl Number 50- 029-20908 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1G-5 11. Field and Pool KUPARUK RIVER FI ELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KUPARUK R I VER O I L (RKB)90' ADL25640 ALK 2571 I POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1G-5 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre-post frac logs are included in the treatment program. Fluid- Gelled Water Proppant: 12/20 sand ANTICIPATED START DATE- BBLS 1 67 LBS 7,500 July 27, 1984 Subsequent Work Be-ported on Form No./~ Dated --~./..~/,~ RECEIVED J U L 1 219 4 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERAT ! ONS COORD I NATOR The space below for Commission use Date 7/10/84 Conditions of Approval, if any: 9RII~IIIA[ SIIIIEB' BY LONNIE C. SMITH By Order of Approved by. COMMISSIONER the Commission ,~Pproved Copy Returned / Date ?:_~z-r4 1 Form 10~103 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 28, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1G-5 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1G-5 to a selective single completion. Since we expect to start this work on July 8, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J B Kewi n . . ,.w!~.[ _ Area Dril ling Engineer JBK/JG'tw GRU8/L17 Enclosures RECEIVED JUN 2 t~ Ig~4 Alaska Oil & Gas Gons, Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '-'-'. ALASKA ,_ .- AND GAS CONSERVATION C,..,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-XIx 2. Name of OperatOr 7. Permit No. ARCO Alaska, Inc. 83-20 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-20908 4. Location of Well 9. Unit or Lease Name Surface: 971' FSL, 666' FWL, Sec.29, T12N, RIOE, UM Kuparuk River Unit OTHER [] TD: 242' FNL, 2101' FWL, Sec.5, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' 6. Lease Designation and Serial No. ADL 25640 ALK 2571 10. Well Number lO-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stim u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other ~i~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1G-5 to a selective single completion, The procedure will be as follows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A retrievable packer will be run to verify zone isolation between A and C sand. Well will be cement squeezed if communication exists between "A" and "C". 4. The well will then be completed as a selective single. A 13-5/8", 5000 Psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: July 8, 1984 RECEIVED JUN 2 8 1984 Alaska 0il & Gas Cons. Commission Anchorage Date 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe , ~,'~, Title The space be~w for C~missi~CZuse Conditions of Approval, if any: ~.pproved C:op¥ Returned ....... ~I~.~,.[ SIGNED ,--, 1~¥ [0'~![,:,, C. SMITH By Order of Approved by COMMISSIONER the Commission Date Form 10403 GRU8/SN09 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate / KUPARUK EKE; I NEERI I',C TRA~ I ~AL #_Z~- TO: William VanAlen FF~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the foll'owin9' PLEASE NOTE:~~F-FI LM, T- TAPE, PC- PrOTOCOPY PLEASE RETURN RECE I PT ~ Ak-X3D ALASKA, I NC. ATTN: SHELBY J. ~/ATTI-IB~ - ATO/1115-B P. O. BOX 100360 .ANa~E, AK. 99510 R k {' I:~IV E D A,AS ELL COMPLETIUN OR RECOMPLETIOi fiEPORT AND LO'G 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-20 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20908 4. Location of well at surface 9. Unit or Lease Name 971' FSL, 666' FWL, Sec. 29, T12N, R10E, UM "[LOCATIONS1 Kuparuk River Unit At Top Producing Interval VEP, iFIED 10. Well Number 478' FSL, 1961' FWL, Sec. 32, T12N, R10E, UN 16-5 SurC ~ At Total Depth 1~ B.H. F.~ 11. Field and Pool 242' FNL, 2101' FWL, Sec. 5, T11N, R10E, UM .=_i._~~: Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 90' RKB ADL 25640 ALK 2571 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 02/03/83 02/13/83 02/17/83J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10086'MD,7067'TVD 9975'HD,6982'TVD YES [] NO []I 2026 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL, RFT, CBL/VDL/CCL/GR, GR/CCL 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 80' 24" 300 sx AS II 10-3/4" 45.5____~ K-55 Surf 2524' 13-1/2" 1300 sx AS III & 250 sx AS I 7" 26.0# K-55 Surf 10071' 8-3/4" 1000 sx Class G & 250 sx ~,S I 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) 9348 ' -9378 ' 3-1/2" 8883 ' 8863 ' 9332' -9336' 9095'-9131' w/12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8976' -9050' . . 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 IGAS-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. ' . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Upper Sand Base Upper Sand Top Lower Sand MEAS. DEPTH 8974' 9129' 9319' TRUE VERT. DEPTH 6232' 6347' 6488' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Dril]ing History, Gyroscopic Survey (2 copies) 32_ I hereby certify that the foregoing is true and correct to the best of my knowledge Signed --~/-~ Title Area Dri l 1 i ng Engr. // ? Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and .log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 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". 1G-5 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2030 hrs, 02/03/83. Drld 13-1/2" hole to 2550'. Ran 61 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2524'. Cmtd 10-3/4" csg w/1300 sx AS III & 250 sx AS I. ND Hydril & diverter. Pumped tob job (60 sx AS I). Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 9400'. Ran DIL/SFL/FDC/CNL & RFTs. Ran GR. Cont drlg 8-3/4" hole to 10,086' TD (02/13/83). Ran 243 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 10,071'. Cmtd 7" csg w/lO00 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro/CCL (PBTD = 9975') Ran CBL/VDL/CCL/GR. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS I & 102 bbls Arctic Pack. Disp well to NaC1. Ran 3-1/2" completion assy w/tail @ 8883', pkr @ 8863' & SSSV @ 2026'. Tstd packoff to 3000 psi. Ran GR/CCL. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr. Perforated well. Flowed well to tank. SI well. Secured well & released rig @ 2230 hrs, 02/17/83. JG2DH20:sm 03/11/83 Alaska. Oil a Gas Anchora~ b'°~nn~is.~io~ ~3VROS£:OPIC DIRECTIONAL SURVEY RA'DIUS OF CURVATURE METHOD OF COHPUTA'rION SURVEY R~N DY I. ORLT~R COHPUTED FOR SDI B~ OCEANTECHCFH LIND~..EY'~ ' ~ RS~L.L."" ~ ~ ' ) TRUE R T DEPTH RECORD OF SURVEY "~RS, DRIFT zPTH ¢4NGLE D H SUB SER DRIFT DI'REC DEG, TOTRL COORD I Nh'rE..,,:' 0 0 0 , 1 O0 0 22 1 00. 200 .0 27 200. 300 0 17 299. 4 O0 0 I I 399 5O0 1 13 499. 600 3 33 700 5 39 699. 8:00 8 51 798, 9 O0 1 I 9 897'. 1000 13 25 llOO i6 0 1091 12(,018151187' i~O8 21 17 1281 ' O0 22 46 1374 150024441465 1600 27' 7 1555 1700 '-,R~ 43 1643 1800 31 19 1730 1900 35 lO 1814 2000 37 4 1894 2100 4! 54 1971 2200 43 32 2045 23:00 41 53 21 18. 00 O0 ,00 99 99 99 89 56 75 23 93 64 21 30 O0 53 46 82 40 02 80 96 4.3 90 -90, O0 10,00 I10,00 209,99 309,99 409,99 509.89 609,56 708.75 807,23 904,93 1001 ,64 1 097,21 1191 .30 1284.00 1375.5,.3 1465,46 1553.82 16.40,40 1724,02 1804,80 1881 ,96 1955,43 2028.90 N' . OOE N73,93E N65, .0SE S61 , 1 .TE N68,62E S6 O, 07E S42,67E S4'l , 73E S30,42E S26, i .~E S22.12E S15.17E S 12,33[: Si3,20E SiS,TSE S18.50E S20.68E $20,47E S~8,17E S17, 15E S16 8.2E SIS,90E S15,42E S14,43E 77 105 t38 175 213 254 298 345 -398 454 515 580 646 2'5 S 44 23 E 84 S 5'J 23 E 82 S 5,9 7'0 E 13 S ~"d"' 07 '" 62 S 79 9:.'"E: 80 S 94 5;k'. 63 S I1 i 0:.::, :-.:: 83 S 127.5:::. ,: 6 S 144 '~ n . z* . 43; ::~ 1 E. i . 4 :~:: L{ 42 S i 7':~. 73'-'.: E 74 S 197,63 E 27 S ,.'~15.1n. E. Oi S 29 q/' 4:, 59 S 25 49 7:::! S 22 .55 f 39 S 21 i,i. 08 S 20 30 i:'"..,' S 20 f-': l S 20 ' o 2 0 'i S I 9 5 ~. S 19 :.;..!, S S S 19 iO 5.. 18 ,: ';"' 18 '2,t. :.7. ;/:, .! , o ARC, O, KUPARUK '~' 29 T12N RIOE UI'I · ,-, E C. , , , GYROSCOPIC SURVEY SURFACE LOCATION © JOB NO 971 'FSL, 666 "F:tdL 177'2 i::i i3 i:::i, i:: ',..' 'ii; 0, 0 0 i:::"t", RECORD OF' SURVEY I,tEAS, D.RIFT [)EPTH ANGLE D M. 2400 44 6 2500 46 56 2600 48 9 2708 48 5'0 2800 .48 30 2900 50 37 7.0.00 50 32 31:00 5'1 22 3200 52 19 3300 ~2 ;31 ;3400 ~3 12 35.0.0 53 26 36,00 53 52 3700 52 56 380:0 53 29 390.0 53 22 OO,O 53 57 .. 100 54 44 4200 54 50 4,70'0 55 43 4400 56 16 45:00 55 56 46.00 56 22 47:00 55 57 4800 56 2 4900 55 56 5000 55 44 51 O0 55 18 TRUE VERTICAL DEPTH 2192,05 2262,11 ,2329.'61 2395.88 24,6:1,93 2526,.79 2590,30 2653,30 2715,:08 2776,.87 2836.45 2896,i9 2955.46 3015..08 3074,97 3134,56 3193,8.2 3252,12 33'09 69 3366 56 3422 49 3478 26 o~ 96 3589 65 3645 58 3701 53 3757 69 3814 30 SUB SEA 2. 102,05 217'2, '11 2239,61 2305. '88 2371,93 2436,79 2500,30 2563,3 O '2625,08 2686,07 2746,45 2806.19 2865,46 '2925,08 2984.97 3044,56 ,3103,82 3162, 12 3219,69 3276,56 3332,49 338'8.26 3443,96 3499,65 3555,58 3611 . 53 3667,69 3724,3 O DRIFT DIREC DE:G, 813,85E SI3,43E 812,9'2E 812,97E Sl 3,50E S12,98E Sl3,0OE $12,47'E S12,23E Sl 1 .60E S11,17E S 10, 87E 810.63E 8 8,80E 8 8,38E S 8,55E $ 8,28E S 8,57E S 8,47E $ 8.12E $ 8,25E S 8,28E S 8,4~E S 8.18E S 8,43E $ 8.43E S 8,07E S 8,07E uoOxb INA TE 5: TOTAL '* - ' C: L 'i c, '- t. ,:. O R E :::. D i '"" ~ ~=.TAI.ICE [)E[],./i 0 Cit,: T i:, :[ S T K.~i. JC E 712,'39 S 237,1 .75 E 749 781.71. $ 248.58 E 820 853.55 S 265.40 E 893 926,53 8 282,17 E 968 999,62 S 299.36 E 1043 1.073,7.0 S 3i6.79 E 1119 i148,~,? S 3.34. ~. 1694, 1773.37 S 1852,80 S 1932.48 S 2012,86 S 2093.72 S 2175.11 S 2257.16 S 2339.30 S 242! . 47 S 2503.66 S 2585,68 S 2667,67 S 456.04 E 467.87 E 479.66 E 503 67 E 515 53 E 527 33 E 539 '~ E 551 34 E 563 34 E 575 32 E 587 ,18 E 1831 19 '1 0 t991 2072 1 2235 2._717 2480 2483 2566 264O "~-" 31 14 $ 18 ':'9 S 17.,.'-~o ':> 25 l:,. .... 86 S 17 i6 't9 E 549 .... ~.~ 15E 4':'-~ S 16 40 16 F:.': 46 S 58 S t6 i2,.."~'-;',. E lO S i. 6 274 ..9.: .5_6. S ........ 5.9_;~:,.-35-- E ......... 28 ~. 4 ,. I..2___S_?t2_-L7-~ ........... '-2'8';~t,17 S 610.92 E 2896.3,7 S 12 JO S6 [-'.: 0 ARCO KUPARUK · SEC, 29. T)2H~ Ri OE,UN ,,0 GyROoCOPIC SURVEY JOB NO Ii?2 SURFACE LOCATION 97I'F'SL,666'Ft~)L o U R :, E YE D ..- ~ .5:: F' E' E; L:.I 3 KB ELEV 9£,.00 i.::'f', RECORD OF SURVEY , TRUE MERS. DRIFT VERTICAL DEPTH ~HGLE DEPTH SUB DRIFT , SEA DIREC DEG. TOTAL COORDIIIATES CLOSURES DISTANCE ANGt_E D H $ '~,:00 54 56 3875.49 3781 "49 S'8 23E 2912,37 S 622.54 E ~' .... · 53~8:'0 54 55 3928,96 3838.96 S 7,92E 2993.40 S 634.04 E 3059 82 S 11 57 33 E 5480 54 22 ,3986.83 3896,83 $ 7,,88E 3074,18 S 645.25 E 3141 17 S 11 5i i4 E 55~08 54 'O 4045,35 3955.35 S 8,15E 3154.48 S 656,56 E 3222 08 S 11 45 26 E 5600 53 23 41,04.56 '4014,56 S 8,20E' 3234,25 S 668.02'E 3302 51 S 11 40 i2 E 5~00 5~ 1.7 4'164 ~8 ~074 ~8 S 8' 42E ~'~ , , , J,.;,13,62 S .. 679,61 E 3382 59 R~ 11 35 ~.D':= E 5889'52 35 4224,.55 4134 55 S 8 98E 3,:~2. 691 68 E 3462 28 R 11 31 25 E 59.88 50 41 4286 62 4196,62 S14,23E ...... ~ S . , ,s4~, .... 707,45 E 3540 66 S 11 3t ,~z E 600:0 5i i 4349,75 4259,75 S16,4OE 3544, ..?~.¢~ ~Z,.~.~,~,;~.~.=.3618 04 S ll 36 24 E 610e 51 32 4412,3I 4322,31 SI6,30E ~te, "?~' ~,~S.E ,.~.36S5 79 S 11 42 24 E 6200 51 46' 4474,36 4304,36 Si6, JOE 3694,o~_:.,,.,,~._,._ .' ~ ~i ' 63O0 6400 52 13 4597 04 4507 04 S~5 75E 3846 ~1%~ ~:5,1l'~,:?~:'~t''~'''~ " , . , k;~,.,,J 53 s Il 57 5,, E 6500 51 28 4658,82 4568,82 915,73E 3921 79.S ~ ~36.45 E 40'lO O0 S 12 2 "2;~ E ~608 51. 13 4721,29 4631,29 SiS,50E 3996 99 S 857,48 E 4087.94 S 12 ~. zL~ ~ 6700 50 51 4784,18 4694.i8 SIS,4OE 407i 94 S 878,I9 E 4165 56 S 12 iO i3 E '~.00 50 55 4847,27 4757,27 S15,O2E 4146 80 S 898 54 E 4243 04 S ~2 13 33 E 88'5~ 29 4909,93 48~9,93 S15,OSE 4222 07 c' 9i8 76 E 4320 88 S 12 16 35 E 7000 5~ 2~ 4972,20 4ee2,20 S14,82E _~.297. 6~___~ ....... 9~.¢_~_.~_~ ........ 4399 04 S ~2 39 25 E 7100 5~ 25 5034,52 4944,52 S14,87E 4373 27 S 958 95 E 4477 17 S 12 22 4 E 7200 51 44 5096,67 5006,67 SI4,90E 4448 98 S 979 7300 51 2 5159,08 5069,08 S14,5~.E 4524 54 S 998 7400 50 41 5222,21 5132,21 S14,55E 4599,61 S 1018 7500 50 2 5286,00 5196,00 S14,27E 4674,19 S 1037 7600 49 32 5350.57 5260,57 SI4,J2E 4748, 19 S 1056 77.00 50 27 5414,86 5324,86 S14,37E 4822.40 S 1075 7800 51 16 5477,98 5387,98 S13,97E 4897,59 S 1094 7900 51 31 5540.38 5450,38 S13.78E 4973.46 S 1113 07 E 4555 96 E 46.33 46 E 4.7il 62 E 4787 45 E 4940 43 E 5018 i7 E 5096 44 S 12 2,1 .39 E 51 S 12 02 S 12 29 6 E 98 S J2 30 P:R E SO S 12 7::-:.: SS E 86 $ 1°~. S4 I~ E 39 S I'2 3b 47' E 5i S 1o 36 DOG L. E {:; S E ',/E R i T 'Y' S E (': 'f' i [:l H D E [4 ,.,' J O 0 F T' D :I: ~'::, "t' F:i i.i C: E 3059: 7 [: ::3 i40 99 · 3 ;;::: ;,:,.: i ~:~ 4 7 $ .02 2 0 :'::; '~' '"" "" ..... :, ,:, ~. 346 i f3 '2 :7.< 54 0'19 ~ 6 i 7' 6 3695 47 -'-, ...... r ,, -, - ,", ¢' ¢' .,2, : F' ::!: ;:.3.52.43 ::; 9:3 J . :3 '9 -"i 0 ',:.:; 7 , S 6 4 i 4:.'. 5.50 4243, 00 432 0. :~ 6 4 :S 99, 0.3 -i. 477 , 16 ,' ;'L" rS' F.: ,J...j ..., ..., , ~. 4 ~-:, 3 :::.;, ~,'-:' I 4 ,-:' ::': 7 , '::~- 7 ., Li i ,::.~ , :3 ';'" 50 '::" ,:,. 4 '";' 0 sec:, 29, TI 0 GYROSCOPIC SURVEY JOB HO 1~ .~URF~C;E LOCATION 971 FSL,666 FWL KE< EL...EV 9i).!)0 F'T, RECORD OF SURVEY . TRUE HEA$, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES DEPTH ANGLE DEPTH SEA DIREC D N DEG. 86i08 49 22 59 ?2,96 5882,96 8!2,67E C L 0 S U R E S D I STAHCE ANC;L E D H 8700 47 3.8 6059.22 5949,22, S12.45E 8800 45 31 61.0,7.96 6017,96 S12,20E 89.0:0 44 17 6'178.79 &'088.79 Sll'.,67E :9000 42 ,52 6251,24 6161.24 811,43E 91,,0i0 41 33 63'25.30 6235,30 SiO,48E 9200 41 58 6399,90 6309,90 $10,42E 93.00 42 32 6473,92 6383.92 SIO.SSE 5987,52. S 5252 5331 5410 5490 5569 5646 5509,~;~ S 1237.99 E 5582,~:~ ,S 1254,27 E 5721 ~iI S 12 39 46 E 5653 ~(~,F'~J"J~:.}~,.~Zi:'~F:.:':" 5794. 24 S 12 39 31 ~ 5722 4~:;:~* '~ "'~ - '~" ~&:~:,~.~ ..... ,~ ,..~.~ 7'S S 12 38 1.4 ~ 5921 , 44k:.$ ~.~3,10i,'.::a:::ii~O~ . ~,~. ~;~35,42 E 61~4. 6.~ ' 12 23 E 21 S 12.33 2i E 2'5 S 12 32 26 E 54 S 12 31 39 E ';R S 12 30 5:::~ E 35 S 12 30 i6 E: 89 S 12 29 31 E 91 S 12 29 :5 E 94:0.0 42 32 6547.61 6457,61 SIi,15E 6053,88 S 1348 30 E 27 E 25 E 27 E OS E 67 E 78 E 9508 41 40 6621,81 6531.81 SlI.15E 6119.66 S 136t '~FOO 41 26 6696,64 6606,64 SI1,42E 6184,70 S 1374 J7 O0 ,JO 47 6771.99 6681,99 S11,43E 6249.15 S 1387 98'00 40 26 6847,91 6757,91 SIi,27E 6312,96 S 1400 9900 39 59 6924,28 6834,28 SiI,23E 6376,28 S 1412 9950 39 40 6962,68 6872,68 S10,73E 6,i07,71 S 1418 6202 6269 6335 6401 6466 65.30 6562 'rile FOLLOiiIIt,iG IS EXTRAPOLATED TO TD J0086 39 40 7067.37 6977.37 Si O.7.:E ..6.49__7 .... Ol._S 1_434,94 E BOTTObl HOLE CLOSURE 6649,63 FEET AT S 12 27 43 E 6649,68 S 12 27 4.7. E ~4RC:O KUP~RUKG-,.' ~ G~'')t&Ll~C,UPiC: ..... SURVEY jO~ NO 1372 SEC.29,TI'2H,R10E,Ut,! SURFACE LOC~:~TION .97~'FSL.,666 HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 1O0 FEET OF SUB SEA DEPTH, S U F.: ~.,,' E Y E [:, ..... K B E L E V TRUE t'1E~.. URED VERTICRL ~LIB HD---TYD VERTtCRL DEPTH DEPTH ~EA DIFFEREHCE CORR. ECT IOH TOT¢~[.. CO0 RD ! N~ITES 0 190 2.90 :39O 490 59.0 69O 791 893 995 1 O9,'3. I203 I 3O9 1417 1 527 I 639 I 753' 1871 t 994. 2124 ;~261 2397 2541 2691 2843 3800 3159 3327. · .'349 0 ;3658 3825 3994 4166 4.342 4521 ~ I90. 2. 9 O. 390, 490. 590. 690. 790. 8..90., 990, 1 090, 1190, 1290. ! 39'0, 1490. 1590. 1698. 1790, 1890, 1990.. 2090, 2190. 2290. 2390, 2490 :'590 2698 2790 289 0 2990 3090 7.i90 7.290 3390. 7...449 O. -90 .'0 0 100 0 0 200 0 0 300 0 0 40 O 0 :0 ;.~ O' 0 O '0 6 00 0 0 7O0 'i 800 2 900 4 '2 1:000 8 ,: ,I. 1100 J 200 i 9 : 7, 1300 27 ' "' i 400 37 ' 1 '0 1500 48 I 1 , 1600 63 i5 J 700 80 17 1800 I 03 2;3 1900 t34 2 0 O (, I 70 36 21 O0 207 37 2200 '251 44 2300 ~ 01 50 24 00 352 5 2 ~'; 00 4 09 57 26 O 0 469 6 0 2 3 0 0 5 9 9 6 7 2 '3 (:l 0 66 ~4'. 69 3000 735 6 3 i O 0 :303 6 S ~. I' .J ~ 7~ 00 '7~ ~: '" .. :.._l ,'6 :~ 4 0 0 i f) ',~ t:i 7 ':J 1 7 17 52 7'6 i 06 :. '. .... i4:2 ': "" ';::';' '":' " ! ' ~",:.':':' 4 ' ..::'' '"':""' '! '; 27 ~ ,,, , ;., : ,; ~,.,:::3 "'; ....:3:32 4.50 r7 · _,S 'i 7i 0 :.'.-'. J i 92 O I 1270 1:396 i 527 i661 i,'793 1927 2 066 2¢.":' 0 9 ,00 S ,3! ,35 N ,28 i',1 ,26 N . , S ,63 S ,53 S ,t3 $ ,80 S i 5 S 57' S 'i'i S ;.-.? 4:3 ,96 S 10 S 91 ,50 o0i S .,02 S ,9'3 S ,62 S ,02 S ,91 S 7'6 S i7 S 4I S 32 S 0'1S ~0 S 51 S ,00 ,90 I .55 1,95 5,97 1 i , '17" t8,50 26,80 44, i 0 59,4'3 ,..c, 83,6 i i 0 O. 90 J J 9,07' J~".....':) "',.' 160 3 ..... i 83,77 208.43 :' 3 i ': 9 255.52 306,32 3 34. 07 3 8 8, i 413 q4 438,75 459,0 i 478.9 i 499,54 5'20,,13 541 , 78 ARCO K'UPMRLK G-5 GYR'O.qCOP_'fF::: SLIRVEY dOE: NO 137c' SE£:, '2'9, T ! 2N, R l OE, UH SURFACE i....OI:~ AT't' Oi,I '9;"' i: F'SL, 666 "t=i~iL HEASURED DEPTH Ahlb OTHER DATe4 FOR EVERY F..VEN tO0 FEET OF SUB SEA DEPTH, ::3 U R "/E i' i::i' D - K E', E L. i::: · · TRUE MEASURED VERTICAL. SUB I'tD-TVD VERTICAl. DEPTH 'DEPTH 'SEA DIFFEP..Et,tCE COF.'. "r' .............. R E .... ! I 0 N I t..~ 'T A L C 00 F,' D I N R T E 47.0'1 3590, `3500 11 I 0 4879 3690, 3600 i 5057 3790, :~700 1267 52~2 3890,, 3808 i 3-'i2 5405 ~990, :24900 i4i5 5576 4090, 4000 i485 5743 4190, 4100 1552 5985 4298., 4200 '161,5 6064 4~90, 4:300 1674 6225 ,t498, 4408 i 7,35 6388 4590, 4500 1798 6709 ,1790, 4700 ~,19i9 6868 4090,, 4800 1978 7029 4990, 4908 2038 7189 5090. 5000 2099 7349 5190, 5i O0 2i 59 7506 5290, 5200 2216 7661 5.390, 5;!: 00 227 i 7819 5490, 5400 2329 7'980 5590. 5500 2389 8140 5690. 5608 2450 8304 5790, 5700 2514 8469 5890, 5800 2578 8626 5990, 5900 2636 8774 6090, 6000 2684 8916 6190. 6100' 2725 905,.3 6290, 6200 2762 9187 6.390, 6300 2796, 9,322 6490, 6400 28,31 9457 6590, 6500 959I 6690, 6600 290i 9724 6790, 6700 2933 '~855 6890, 6800 2965 9985 6990, 6980 2995 8:0 2504,17 S 79 2650.79 S 7'8 2~'~'' ' ~' " 75 2938,46 /3 v,u,..~ 55 $ 70 3'~i4~. ,80S 67 3347,54 S 5'~ 35i¢~ 05 S 6 i 37i 3 35 S :.::,.~:..:~ b ~ d o.,~ ,' ?::4 6 t. ,S 959 3 · ,; ,.~ ,~¢, '. ~0 ,..,... "" '~"~ '""-':'?":~,:':~?'~'*'" t,,~'~'~i~,~,4 ~ ,' 4678, ~'~ 55 58 61 64 64 5~ 41 .37 34. ~5 3 ,S ¥4 32'. 32 SO 4,'.$ 42 4912, ':.,.fi 0:'..,'3,8,3 5i 55,77 S ~-'";':"-' 36 S 541 0,35 S 5528.. 56 S 58'2,1 86 S ":"-' ,_ -"1 S 600'2 O0 S 60'3 i 70 S 61;":=~ 94 S E. 2:::-.,I .3'2-'..' '- · .. 6347', 98 S 64 :-':'.' 4,7 563 4i E 584 97 E 605 97 E 626..~"':' 0 E 645 665 22 E 684,70 E ?08,47 742 t...~ E 7'?;;',:;~';4. E 812 65 E 846 9?:, E 880 O9 E 912,-':~':4c E 944 63 E 976 9i K 1 008,55 E I 038.79 i 068,05 E I 098,0 5 1128 , 01 E 1157 , '? 3 E 1187 '1.5 [:.' I215 73 E 1242 3~'-~ E 1265 86 E 1286 57: E 1305 0,:; E 1.~2i 4i tS 1355 "~ ,.' 6. 140'7', 0 !:'~ 1424 . ,i.,:! [:'. © ~RCO KUPARUk' G"-5 GYROSCOP.TC SL~R'VF:.'r~ ,.~..'l~ i',lO ISi:'2 SEC, 2"3, T I2H, Ri HEiqSURED DEPTH ~HI.'., 01'HER D¢-IT¢~ F'OR EVERY E',?EH 100 F'EET OF' SLiE~ SEh [)Ef::'TH,. TRUE I'IEASUP, ED VER'f IC. AL SUB HD.-TVD VER"I' I CAL DEPTH DEPTH [: 00 R [) I f,i A T E S 086 7067, 6977 3'0~8 23 6 ,:i. S' :i.:;, 0 i S 1 4 ~ 4,9,4 E ¸0 .. ~RCO KUPI~iRUK G.-5 SEC, 29,112tq, RI OE, UH GYROSCOPIC SURVEY SURFACE i..0C¢11' I OH © JO~S NO 971 'FSL., 666 'F:'kit... 1372 INTERPOLATED HERSURED DEPTH :0 2:00.0 3'00,0 40.0.0 ISO0~O 60,0,0 ? ~00:0 8:00'0 9 '00:0 0000 0 086 '4~LI.IES FOR EVEN '1000 FEET OF HERSURED DEPI'H, T~UE VERTiCRL SUB DEPTH SEii TOT~'.~L CO0~(DIHATES O, -90, 995, 9.05, l'e95, 18.05, 2'590. 2500, ~194, 31 04, 3758, 3668, 4350. 4260. 4972, 4882, 560~, 55i3, 62~i, 616i, 7001. 691 I, 7'0&7, 6977, ,00 S 53,2i S .454,4~ S i148,97 S Jg~2,48.S 2749,56 S 3~44 05 S 4297 67 $ 5049 35 S 57~9 99 S .i61 479 72';.'": i298 6431 6493 0 FtRCO KUP~RUK G.-5 SEC, 29, T ~YRO$COPIC. SURVEY' SURFRCE' LOCF)TIOt,I 971 'FSL,666"FWL INTERPOLATED TRUE VERTICAL DEPTHS COORDINATES AHD"CI.r~~ '" V , _ ~ LIRE S F 0 R C~ I E N D E P "i'l,,,i :ii: TOTAL COORDINA,TE.$ CLOSURE D ! S T ~:) f,I C E ANGI.. E D H S .TRUE CODE HEASURED VERTICAL HAME DEPTH DEPTH 6020,13 S 12 36 4i E 6147,47 S i2 34 iO E 6575,45 S i2 29 46 E 6649,68 S 12 27 4S E TOP U,$AND 8974 BS, U,SAND 9129 TOP L,,SAND 93J9 P~TD '9975 ,, 'I ,0'086 6232,,24 6346,99 6487,92 6981,92 7067,37 5772,59 8 1294,64 E 58,74,88 ,S 1314,44 E, .6000,13 S 1'337,84 E 6419,68 S ,, 1422,76 E' 649~,!01 S. 1434,94 E VERTICAL SECTION ARCO ALASKA, INC. KUPARUK G-5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: i" = I000' FEB. 15, 1983 .......... SURFACE .LO'CATION !.S 971' NSL, 666'EWL,-SEC. 29 T. 12- N., R. i0 E., U.M; _ 400 ...... - 800 ..... ' - - T. 12 N., R. I0 E.,U.M. . 666' HORIZONTAL VIEW ARCO ALASKA, INC. KUPARUK G-5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: I" = I000' FEB. 15, 198:5 CLOSURE -S t-'g'0-'28! E- 6650~ ......... : - , Suggested form to he inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. '. ~'. 0p~. atof;'~,i]. ~a~e and Reports and Materials to be received by: ~-'/~'-- ~-' Date .Required 'Date Received Remarks . -- Ccmpletion Report- Yes · Well History' Yes _Samples .-.. .. ....... 4/~ -:-p l -7,, ' -~ ~2 ;'",1. .. _-- ,, . . · .... · COre Description ~Z?~ ~-~ Registered Survey Plat 7~_~ m, , ,u , ,, Inclination Survey ~ .,i /.'./ , , , · Directional Survey Ye,----Pr · .~. Drill Stem Test Reports /~//d~/~_~ Production Test Reports y ~~ ~ , 'ii -'~ Digitized Data ~-e $ KUPARUK ENGINEERING TRANSMITTAL TO' DATE' Wi'lliam Van Allen FROM' D.W. Bose/Shelby J. Matthews Transmitted herewith are the following' PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - FILM, T -'TAPE~PY / R~/~I PT ACKNOWLEDGED' LLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN' SHELBY a. MATTHEWS · P O. BOX 360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen FROM: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following' PLEASE NOTE: ~~'~~J~~ F - FILM, T - TAPE, PC - PHOTOCOPY RECE I PT ACKNOWLEDGED' SE RETURN RECEIPT TO:' DATE: r~ r.._ r ~ ~, ~--.~ ' ,/'/,f ARCO ALASKA INC. ~]g~//i.~~ 8 ,~%~3 ATTN' SHELB~ J. MATTHEWS - AF ' ' P.O. BOX 360 ~ G~s C~s~ Commtss~o~ ANCHORAGE, AK. 99510 A~s~0i~ .t~cho~ge . ARCO Alaska, Inc, Post Office, 60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1983 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 monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well #1 Ravik State #1 A1 so enclosed are well completion reports for' 1-24 1E-21 2-8 1E-22 7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 .1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Repor.ts for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc. is a subsidiary of AllantJcRichfieldCompany STATE OF ALASKA ~--. ALASKA_ .AND GAS CONSERVATION Ct ,VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~k Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-20 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20908 9. Unit or Lease Name FWL, Sec. 29, T12N, RIOE, UM Kuparuk River Unit 4. Location of Well 971' FSL, 666' at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 90' RKB ADL 256/+0 ALK 2571 10. Well No. 1G-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. Feb rua ry ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2030 hfs, 02/03/83. Drld 13-1/2" hole to 2550'; ran, cmtd & tstd 10-3/4" csg. Pumped top job. Drld 8-3/4" hole to 9400'; ran logs. Continued drlg to 10,086' TD; ran & cmtd 7" csg. Ran logs. Ran 3-1/2" completion assy. Perforated well. Secured well & released rig ~ 2230 hfs, 02/17/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45 5#/ft, K-55, BTC csg w/shoe @ 2524' Cmtd w/1300 sx AS II I & 250 sx AS , · 7" 26 O#/ft, K-55, BTC csg w/shoe @ 10,071' Cmtd w/lO00 sx Class G & 250 sx AS I SEE DRILLING HISTORY 14. Coringresumeandbriefdescription None 15. Logs run and depth where run D I L/SFL/FDC/CNL RFT CBL/VDL/CCL/GR GR/CCL O. DST data, perforating data, shows of H2S, miscellaneous data 9348'-9378' 9332'-9336' 12 spf 9095'-9131' 8976'-9050' 17. I hereby certify that the foregoing is true and ,correct to the best of my knowledge. ~_//_ , ~~'~. .... _", Area Drilling Engineer DATE _-~/,/i?'~_ ~ SIGNED (/~F-~,F~'~"-/./"/I'~//U4,'''%''~ TITLE ................... NOTE--Rep/ ~/(/th~s f~rm i-~req%i~ed for each calendar month, regardless of the status of operations, and must be-(led ]< duplicate with the Alaska Oil and Gas~onservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU2/MR22 Submit in duplicate 1G-5 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2030 hrs, 02/03/83. Drld 13-1/2" hole to 2550'. Ran 61 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2524'. Cmtd 10-3/4" csg w/1300 sx AS III & 250 sx AS I. ND Hydril & diverter. Pumped tob job (60 sx AS I). Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 9400'. Ran DIL/SFL/FDC/CNL & RFTs. Ran GR. Cont drlg 8-3/4" hole to 10,086' TD (02/13/83). Ran 243 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 10,071'. Cmtd 7" csg w/lO00 sx Class G. Instld 7" packoff & tstd to 3000 psi ~ ok. Ran Gyro/CCL (PBTD = 9975') Ran CBL/VDL/CCL/GR. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS I & 102 bbls Arctic Pack. Disp well to NaC1. Ran 3-1/2" completion assy w/tail @ 88~', pkr @ 8863' & SSSV @ 2026'. Tstd packoff to 3000 psi. Ran GR/CCL. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr. Perforated well. Flowed well to tank. SI well. Secured well & released rig @ 2230 hrs, 02/17/83. JG2DH20' sm 03/11/83 Transmitted her~cith are the following: Pr.VASE NOIr: BL BLURr.~, S- SEPIA, F- Frr~I, PC - PHOICCOPY January 31, 1983 Mr. Jeffrey E. Kewin Senior Drilling Engineer ARCD Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re~ Kuparuk River Unit 1G-5 ARCO Alaska, Inc. Permit ~o. 83-20. . . Sec. 29 T12N Ri0E ~H~. Sur Loc 971'FSL, 666'~, , , , .~ Btmhole Loc. 2341'FW~L, 498'FSL, Sec. 32, T12N, R10E, UbS. Dear l.~r. '~win: mnc~osed is the approved application for permit to drill the above reforonced uetl. if coring is conducted, a one cubic inch chip from each foot of recovered'core is required. Samples of well 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 ~o~o~ information ~hall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. P~any rivers in Alaska and their drainage systems have been classified as important for the sp~ing or migration of anadromous fish. Operations in the~e areas are subject to AS 16.05.870 and the'regulations promulgated thereunder (~ztle ~, Alaska Administrative Code) Prior t~ commencing operations you may be contacted by thg Habitat Goordinator'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 comz~encing operations you may be contacted by a representative of the Department of Enviror~entai Conservation. To aid us in schadu~' ~zng field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. Oeffrey B. Kewin Kuparuk River Unit iG-5 -2- January 31, 1983 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. Where a diverter system is required, please also.notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event-of suspsnsion or abandonment, please give this office~adequate advance notification so that we may have a ~tness present. Very .~truly yoMrs, C. V. Chatterton Chairman of ~y ORDSR OF Alaska Oil and Gas Conservation Co~ission Enclosure cc.. Department of Fish & Game, Habitat Section w/o encl. Department of~ Environmental Conservation w/o encl. be ARCO Alaska, Inc..~ Post Office [ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 12, 1983 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk 1G-5 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 1G-5, along with a $100 application fee. ° A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map. ° A diagram and description of the surface hole diverter system. ° A diagram and description of the BOP equipment. Since we estimate spudding this well on February 5, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer Enclosures JAN2 z, ~983 Alaska Oil & Gas Cons. r, , Anchorage "°rnm~ssiorr ARCO Alaska. inc. is a subsidiary of AHanticRichfie!dCompsny ~--- STATE OF ALASKA ALASKA -.IL AND GAS CONSERVATION C._ ,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I-] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address Po 0o Box 360, Anchorage, Alaska 99510 4. Location of well at surface 971' FSL, 666' FWL, Sec. 29, T12N, RIOE, UM ..,,f -., ~, At@ tOPTarget."o, proposed producing920, FSI_, 2200'interval 0'~!¢..~., A/V2 ~ .?~'~.~' FWL, Sec. ~2, T12N, R10E~ 8',,ul!~ ~ ~' At total depth · 2341' FWL, 498' FSL, Sec. 32, T12N, R10E, UM d/ZC/lOl~¢ ~0//]5 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. ... Unit or lease name Kuparuk River Unit 10. Well number 1G-5 11. Field and pool '/$.~,p/aruk River Field Kuparuk River Oil Pool I Pad 60', RKB 90' } ADL 25640 ALK 2571 I 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 32 mi. NW of Deadhorse miles 498' Sec. 29 feet 16-6 well ~ surface 120' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. App~/gxima,~.~~ 9439' MD, 6862' TVD feP. t +2459 02/~)5'/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2819 .. psig@_J~O°F Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 48 o (see 20 AAC 25.035 (c) (2) 3210 .psig@ 6271 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMEN"F - .~_ Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ).4" 16" 65# H-40 PEB 80' 30' I 30' 11 O' I 11 O' 200 cf I 13-1/2" 10-3/4" 45.5# K-55 BTC 2490' 29' 29' 2517'12200' 1200 sx AS Ill & i I 250 sx AS II 8-3/4" 7" 26# K-55 BTC 9411' 28' 28' 9439' 16862' 400 sx Class"G"extended i I I 360 sx Class "G" neat. ) I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field well to approximatey 9439' MD, (6862' TVD) A 20" · , 2000 psi annular diverter will be installed on the 16".conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will_,.be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 Psi for annular). Maximum expected surface psig pressure is 2819 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 Buttress 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 installed and tested upon completion of the job. 1G-6 will be 120' away from 1G-5 @ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ +3650' MD - approximately 500' MD above top 'of West Sak Sands. SIGNED ~/~~ TITLEArea Drilling Engineer DATE The spac o C on use ~ / / Samples required ~YES '~JO Permit number APPROVED B~'~ ~:nrm 1N-~N1 P.I~I I1 /Pl311 CQNDITIONS OF APPROVAL I Directional Survey required i ~[YES []NO Mud log required I APl number []YES ~XIO I 50- 029-20908 Approval date j by order of the Commission Submit in triplicate ...... F, Ur"'A~UX FIELD.-', ','40RI'Hi ,S'I~P,E; x~ASKA---t-----~'~/,) ........... --7-, ........ -ZT---' . , ~- , , = , . ~ ~ , /- : ~ ~ i ~ . , ~, , --:--t--- ....... ~~-~-j !iH:: ~.~ i,~ ~!-~,- ---:-,~--~- .... 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L~Z~--~----.---t ~ : ----:-~-- .... ~-~4---- ................. , ................ , .......... ~ ..... :--~ I-: : :ff .... : ...... i :-:--:'- i ...... ~'--: 7-7 ....... -J~' :"-:' 1-' :.,, i ........... .... ........ .... ~ I :"~r"---" ;:-:~6-o::::~:-:-:~-::~F::-::':-:I:::--:~:~;::-~-~:: :::::~-: :~-4-~:::~:::~:-~:~-:~:::~:::!---:-:-:-~':?',:-~:~ ~:-':::~: [ 7 ~~~&~~~~:7~~: . _:_:_:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..---;-:~a~-~-- -~-~-:--t ~--~--tt-:-:--:--ri-~--~--:-- --: :t'~?~ -~7;-:~l-~-r'T-: 1-: .... ~ ~ ....... -'~:,:..,;~ ..... : -:' ' ;,~ ": :'; :-~¢~f ¢----¢~:--I-~-:-, ..... :---~-~D ~ ..... ~--, '~ .... ~- -~ i -~ ....... ~ ..................... : ........ . .... ~ -®. O. . Surface Dive _~r Ssstem I. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets.~ 4. 10" ball valves, hyraulically actuated, w/lO" ~/ lines to reserve pit. Valves to open automati~ cally upon closure of annular preventer'. 5. 20" 2000 psi annular preventer. 6. 20" bell .nipple. JAN~ 4 ~;~8~ 16" Conductor that gas or fluid flow to surface is · detected. If necessary, manually over: ride and close ball valve to upwind diverter line. Do not. shut in well under any circum~-~ances. MaintenanCe &' Operation ~-- l. UPon initial installation close annular ! preventer and verify that ball valves i - _ h_ave opened properly. · I 2. Close annular preventer and blow air ~= . through diverter lines every 12 hours° 3~ Close annular preventer in the event 1=?-'5/8" 5000 PSI ,~SRRA BOP STRUCK DR'iLLi~g SPOOL ' -'s 'C - o ,., . . ,, "~ ' ' ~' ~~a Gas Udns, Commission 16" Bradenhead 16 2000 PSI x lO' ~3 ?$I c~$;ng head 10" 3000 PSI tubing he~_d ]0" 3000 PSI x adapter spool ." 5ooo ." 13-5/8 5000 PSI drill~nB ~o~1 w/choke and kill lin~ . -- ' 13-5/8,,_" 5000 PSI pi~'ra~-- - -: '"-:' :.-' .'. '---: 13-5/8,,_ 5000 PSL bliad rN% :-'-"' . ':':~-~"--'. 13-5/8 5000 PSI an:lar - -'-' '.' ?'--[=-.~=-':"' . A~h~~ ~I~ ~T -- : i- - _..:".+- ::.- - . - _ ~ ~ FILL A~~TOR ~E~I~ ~ P~P~ ' ~ ""' ~'~ ~IT~ ~YD~ULI~ ~ID. ~S~ ~AT A~-~T~ P~~ IS ~ ~I -- WI~ 1'500 PSI ~.~~ ~ ~r~ ~~R. ~S~VE TINE Th~ C~E ~ ~ITS S~~- ~ OFF. .. L~IT IS 45 SE~(~ ~I~ T~Z ~ l~ PSI 13-5/81 ~{~'/. ST',,q~ TEST FILL BOP STACK ANO H,LN[FOLD WITH X~c~l'IC DI-.~EI.. ~D. P~D~E~I~ DEPT~ ~I~ S~T ~ S~T I~ ~~. ~ ~ L~ ~N S~S IN H~. ~E ~'tU~ PR~~ ~O C~ ~ ~P~S Y~VB ON ~qIF~D. ~T ALL C~4~Y~S TO lO ~o re;roTES. S~[O TO ~0 ~[. PIPE ~.. ~E V~V~ DI~ ~~'~ OF ~.-- V~ZYB, IF ANY, '~I~ TO ~RO PSI. - ' _ ' ~1 TOP S~ OF PIP~ S~ ~ PIPE E~3. - H[t~T~. B~ED TO Z~ PSI. ~ 80~ S~ OF PIPE P~. ~G ~iD TEST TO 3~ ~I ~ lO ~~. B~D TO ZERO PSI. ~ ~IIFOLD' N~D LI~ ~ F~ ~ ~C - ~I~1. - _ T~ ~IDPIP~ Y~Y~ TO ~ ~I_ - ' P~ rEST INF~TI~ YI~R. - _ - ' - Z~ SZ ,. ~0 ' '/' ~,~.~. / ~ 70° ZI ~?. 7377 ~.. Z~/~ /~ ¢ ' ~ '1~. 'I~ 7" D5 !.~ ARCO Alaska. Inc. ~.,~oaru~ P'C. leCl '~,, z?,e/zz 3/,T~' /'~ cale ~_~].."'/"" Z'Z. ,.'?ZZ J scale drawn by 'd~,.. j dwg ,' n o '/'/5'.' ?..'~7.£,,'L J I CHECK LEST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~fS,~_.~, /- Zf-~3 / / (2) Loc ~ ......... t, ..... /'" ~, f"~'~]' ,('2 thru' 8) Company (3) Admin(~ ..... ll)/~'~S~g'3 (4) Casg (12 thru 20) 1. Is the permit fee attached ............... .......................... 2. Is well to be located in a defined pool ...... 3. Is well located proper distance from property ii~ii{!iiii}iiiiiiiii 4. Is well located proper distance from other wells . 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ........... wai; 8. Can permit be approved before ten-day '''''.'''.'.''''''''..''' (5) (21 thru 24) . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. rev: 12/06/82 21. 22. 23. 24. 25. YES NO / .... ¢' ,~ ~',.,.,',~; · _ti',ff ~" ........ ~ Does operator have a bond in forCe Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating'- Test to ,~~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. REMARKS ........................ i ~, i'i iA',; ......... (;~ 0 . ....... U-~ f:~" ........ -6i~-/-oi,'~,-~ POOL , CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve, the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. b I S T A P E ',tE[~ IFICAI,!I ON LISTING ~IP 010,HO2 VE~IFIC'..~TI[]~.~ LISTING PAG~ ~Xi~Li~ I.,[L:N(;TH : lO24 lbE TYPE * INFOP,~$ATION RECORDS NE~ CONTE~,;TS Mt : A~CO AI..,ASKA. INC, '~ : 1g'5 ANG.. ECT~ 29 gUN: N, TAT: ALASKA TRY: Li,S,A, * COi:,IMF]NT$ ** U~,ilT TYPE CATE SIZE CODI~:: 000 000 016 ()00 000 00q 065 00O 0O0 008 065 000 000 004 065 000 000 004 0~5 000 000 002 065 000 000 008 065 00(,) 000 006 065 000 000 00~ 065 R~C :: 4,000 M. 65 OF -- 3,570 fa 65 DF = 2,650 ~ 65 D'F : 1,858 ~ 148 DF DATA FOR}~,T REC[~RD ** <~TRY q'Y P~,] SIZE NEPR .4 1 66 tP' 010,,H02 YE!tIFICATI(]i'it LISTIN(; PAGE 3 S P E (71 v SERVICE I I') 73 65 lin b 0 FILE SIZE PROCE~8 ,SA I~PLE NU, f. jE V EI.~ 0 4 0 0 4 0 0 4 0 1 0 4 0 1 O 4 0 1 0 4 0 0 4 0 1 0 4 0 0 4 0 0 4 0 0 4, 0 1 0 4, o 0 4. 0 0 4 0 0 4 0 C 0 D E 68 68 6,8 68 68 68. 68 68 68 68' DATA ** CPT 9402.0000 5FL, U :~ -33,S313 Ga ,,i'{::li~, 2.0527 NCNL ~ 78,1875 NR~T ,,.,Pt 9 00.0000 -" ' 34,2 a 1 ! 40B 1,9951 :~ 78,1875 rqRAT 300. ',') ('> O 0 $ FI, -30,2656 GR 2 · 441 q. r'~ C J',, I., 78,2500 r,~ ¢ A T [,,l P T 9100 . 0 :.) 0 () ,$ r L £' P -89.0~25 EP'[' 91)00.90(~0 SF!,U 6,1 }~ 36 I b 7 a, 1 fil 75 244. 8, (; 000 F C N L 3,0.332 6,1875 78. :t ,i 7 5 244.8. 0000 3,9 332 4,742~ 78. 250o 2438 ' OO0O 2,9102 66.~375 23~30,0000 17.7969 60.0313 3.0195 37.4 *~ g i~ 2 ~ 94_:,. ti (.) 0 F C FCNI~ k' "; 5.5938 IL, l) 32,7637 DaHt) 737.5000 CAI~I 3,3184 5.5938 ILD 32.7637 DRHO 737.5000 ClbI 3,318q 4:, 3 .'428 I I, D 29,81340 L) R H (.'~ 706.00 (.~ 0 C A .[, [ 3.4531 6.765b lbo 7~qO.OOO0 C~LI 3,9508 19.593 .~ I l., L: 3 2,4 'l 0 '1 D R l-! {. ! 774.<)000 CALl' 3.25'I~ 45.a~i37 IL, L', 1. 0 6 8.00 0 (,! C A I~ I. 2. 709!) 5,N672 0,0977 8.7500 5,8672 0.0474 9,8281 4.2031 0,0376 10,7344 7,0195 0.0195 10,2266 !8.593E 0.O000 9.8906, 76,8750 0,0205 1(},0625 { 0 B 7~.. 26. 56 ?, 107.6250 ~,aR iT 3.7930 :PT 8800,0000 SFht~ 2,3965 ) -76,3125 GR 119.6875 t 0 g 2,2 ~ 32 N' C N L 1736,000 (') ( t19.6875 ~'~RAT 4.0078 :~T 8700,0000 8F ,.,,U 2,1660 > -71,81~5 GR 1 ~6.t)6~5 lOB -999,2500 NCNL -999,2500 ~ 116~06~5 ~RAT ~PT g600.0()00 SF > -68, ()625 (;R 246, ~ 5 (.)0 {[)B -9. 99,2500 NCT,.~b ~ 246,2500 *~R A'r -99q,~500 <PT 8500.0000 SFI..,U 3.23~3 ~ -84,0()00 GR ~75,~750 JOB. -9q9.2500 NCNL -999,2500 ~ 175,9750 ~9'R hT -999.250O ~ P T 8 400,000 () S F'I, tj :3.8672 ~ -77.8125 GR 157.2500 lOB -0Q9,2500 ~,)CN b -g99,2500 .' ~ 157.~50() ~ 'I -999,2500 CPT 8300,0000 SF'L~ 3,2734 > -78.b625 GR 108,b250 t[)B -999. 2500 NCNL -999. 2500 ~ 108.6250 ,,~R~.7' -999.2500 ~PT 8~00 0000 S ~ l.., L~ 3.8730 ) -51~500() 6~ 92.8750 4OB '999; 2500 r,,cr~, L -gO9,2500 ~ 92,R750 ,~RAT -999.2500 :' -o8 ~'l 1 ~ ~ GR 105. 9375 4t']B -999,2500 NCNL -999,2500 ~ lO5,U375 {PT' ~000, ()000 ,SF[.b 3. '2q69 ~ -17,2650 G~ 103.0000 qt)F -999.2500 r,.~ C ~' L -q~9.2500 > 103.()000 ~ ~.'I' -999.250O I. 0654 122. 250n -999. 1,6514 45.3125 437,0000 3.9 ~ (r) 5 2.2324 -999.2500 386.7500 4.4883 2.~852 -999, 500 -999,2500 -999.2500 2.6563 '999,2500 -999.2500 -999.2500 3,1055 -999.2500 -999.2500 -9gg.2500 3,611.3 '999,2500 '999.2500 '999,2500 3,2715 -999.2500 -999,2500 -999,2500 4,0703 -g99,2500 -999. 2500 -999.2500 3,677'! -999.2500 -999.2500 -999.2500 3.04~ -999.2500 -999.2500 -999,2500 1.2002 -99q'250n -999.2500 I L D I L, DRDO C&LI I LD L) R I40 CAL'I I I,, D DRHO CALI I. hD C A b I: ILD D R H 0 CALl I D R H 0 CAbI I b CAt.,I ILl} C.AL I i b DRHU CA b I I bE) CALl 1,6436 0.0151 11,1250 2.1777 10.9375 2, 0 2 '999,25 0 10,9141 2,7422 -999,2500 10,6797 3,1602 '999,2500 11,2187 3,7871 -999,2500 11,9922 3,2324 -999.2500 11.1328 4,1406 -999,2500 ~2,1719 3 6836 -999:2500 11,6406 3,5684 '999,2500 10.7109 1 2090 -999:250C) 10,6094 ;P' OI.O,HO~ VER[BT[CATI[tN LI.o.?It)t<; PAGE 5 999,25o0 NC~ L 163.2500 N~AT 7500 0000 8FLU -3.'2,5 ] 13 GR -999,2500 NCNb 168.7500 NRA. T 7200 o9()0 .SFLU 26 ~ 765 ~.,,. (jR ~o~ -~99 2._oo .~ 139~7500 NRA ...P ..7 7300,0000 SFI'.,U P -24 7656 CR ~ ]'1 9 ' .... ~[..E ,- 99.2500 NCN.L 1. 28,8750 N R A ]' [C P T 7200,0000 S [~' [., U P .,'2.9, '7656 GR H 0 B - 999,2500 N C t,i IR 159.0000 ,RAI [;PT 7100 0000 8FI, t.' .P ' -32:2~1.3 GR HOB -999.2500 NCr,iL R 110,6875 NR. AT -999 2 1.12 -999 -999 3 · 11.8 -999 -999 3 1.63 -999 -999 5 168 -999 -099 1 139 -999 -999 2 128 -999 -oo9 . 159 -999 -999 11.0 -999 -999 gPT 70_~0 0000 SF'I.,I) '2_ P -,:,, 2:7t~13 GR 105 H[]~ -999,2500 NCNb -g99 R 105.0000 NRAT -999 IF:PT ~900. 0000 SFI,U P -40,0313 GR ltOB -999.2500 NCNL 68.00, OOO0 ,5 F 1.: U -35,'t813 GR 2 82 -999 -999 ,250O ,7109 ,6250 ,2500 7070 , ,2500 250o '2500 7 B 71 2500 25 o ,2500 .6289 .7500 ,2500 .4B93 '75 (,)0 25o0 25(,)0 ,8242 .8750 ,2500 .25(')0 ,0000 .2500 '2500 1055 .~S'75 2500 2500 .3379 ,0000 .2500 .2500 .2909 .2500 2,341.~ 75,8750 R ~,~ R A FCa L, R iV R A I [., N t,} P H I F C N 1.., b P H I' FC N L R~'~RA I LM N p H I IbM FCSL RNRA '! L ~ F C N I., I,~ P H :[ FCNL R ~ R l NPHI FCNL I IL, .~ NPH] FCNb I1:.~ i'~ P H I -999.2500 '999,2500 -999.25o0 -999.~50o 6,!45 3,250o '999, - 9,2500 -~9.25(':)0 3,3516 '999.2500 '990.25(')0 '999.2500 3,3516 -999.250() -999,2500 -999,2500 1.5752 .9 : soo -999 500 -999,2500 2,3242 -999'2500 -999.2500 -999,2500 1,8B48 -g99,2500 -999.2500 -999.2500 2,1.680 -999.2500 -g99,2500 -099,250() 2,4844 -999.2500 '999,2500 -999.2500 2.4B05 -999.2500 :999,2500 q99,2500 2.2754 -999.2b00 I L D D R H [} C; A L I I IL, I) CAI., l I L D 1.'} R .N 0 C A b I I IJ D l) R H 0 CA b I ILD D R H 0 CALI :.I. t, D t) R H U CALl i t, D £) R H 0 C A L I I L D DRH [) CAL, I 3[ LD D R H 0 C .~ L, I DRHO CALl I LD 2,4492 -999,2500 11,7344 .3,673~ -g99,2500 12,8594 3,4238 '999,~500 11. 156 2,1523 -999.2500 10,3750 1.5811 -999,2500 10.6328 2,2715 -999,2500 10,4375 1,8115 -999,2500 1.0,8437 2 2422 -999:2500 11,1562 2,4785 -999,2500 10.9297 2,5176 -999.2500 10,1562 2.2383 '999,2500 VP 010,H02 VERIFU'iCATION [~IST1NG PAGE: 6 40B -999,250H ~ 75,8750 NRAT - (~ 99 -999 2 91 -999 - 999 P 38,5313 GR 8.8 gOB -999,25o0 NCN[., -999 ~ ~8,3750 NRAT '999 EPT 6500 0000 SPLU ~0~ -999 2500 NCNL ~ 107 ~250 NRAT 2 107 999 -'999 3 96 -999 -999 EPT 6300,0000 SFLU 3 p -44,5000 GR 105 HOB -999,2500 NCNL -999 ~ 105.1~50 N~AT -999 EPT 6100.0000 SFLU P -41,7~13 GR HOB -999.2500 NCNL ~ 103,2500 ~qPAT EPT 5200,0000 SFPU P 51.5313 GR HOB -999,2500 R 79.1250 EPT 5800,0000 SFI, U P -53,0000 GP NOB -999,2500 NCNb ~ 95,3125 ~RAT fi. PT 5700,00(~0 8 FI,.,LJ 2 83 -099 -g99 3 1, 03 -999 -999 2 88 ,'999 999 3 79 -999 -999 3 95 -999 -999 , 500 3574 '2500 .2500 .2500 ,7402 ;3750 2500 ' ¢ ') · ,25(. 0 ,8262 ,6250 ,2500 .2500 6465 8125 250 o 25('70 ,3516 ,1250 ,~50o , 500 7461 "1.250 , ,2500 ,0020 ,2500 .2500 ,2500 .65S2 .1fl75 2 5O0 ,5195 .1250 ,2500 .2500 .7734 3125 250(? 250fl 2,339 ~.~ RNRA NPHI FCNL NPHI F C N b RNR~ N p H I FCNL RNRA NPHI F C N .1.~ I[,a ~ P H I F C N L R ~ R .A NPMI FCN1 .... RNRA II..M NPHI F C N I., RN RA NPHI RNRA N P 1,I I FCN L I N P H I F'CN l, RNRA -999.2500 -999.2500 2,5156 -999,25O0 -999,2500 -999. 2500 2,7637 -999,2500 -999,2500 -999,2500 2,8477 -999,2500 '999,2500 '999,2500 3.76'16 -999 2500 -999'2500 , -999,2500 3,3320 -999.250O -999,2500 -999.2500 2,7695 -999.2500 -999,2500 -999,2500 3.1719 -999,2500 -999,2500 -999,2500 3,1543 -999.2500 -999.2500 -999.2500 3,8105 -999,2500 -999,2500 -999.2500 3.9199 -999.2500 -999.2500 -999.2500 2,6719 C'A 1., I I L D CADI I LD DRHO CALl I L 1) D R H ti CALI I L D D R H D C A L, I, I LD i.)RHO C A L I I 1,, D D R H u CA[,I I LD DRH('] CAI,,I I LD D R H [) CAI,I ILO D R h 0 CALl l LL" DRH('t C A L I 10,5000 2,5781. -99g,2500 9,3047 2,8320 -999,25.00 10,3984 2,~984 -999. 500 9.9609 -999,2500 10,17~9 3,4531 -999,2500 11.5000 2,9102 -999,2500 10,B203 3,353~ -999,250 1,0.7422 3,1680 -999.2500 11,2813 3 9336 -999~2500 10.4844 4 1250 -999:2500 .1,3,59351 2,8027 qP 010,HO2 VERI'F'ICi~.TIOrs! blMTIt'~G PAGE 7 -lOB -999.250() NCNL :.~ -4.7 031:3 GR "~ [.) B -999 2500 NCNb ~ 5~ 2500 NRAT B4,3750 ,,,999,2500 -999,2500 5,81e, 4 54,2500 -999. 2500 -999. 250(3 3,4:766 97.0000 -999,2500 -ggg. 25 00 EP~I' 5300.0000 P -52,2~1,3 gOB -g99.,2500 t~CNL R ~ 1.9375 EPT 57.00,0000 SF[,U P -58.7~1.3 GR ~' [) ~ g 9 9 ,, 2 5 0 (,, N' lt,i [., R 79,6875 NRA'I~ EPT 5,1.00 0000 P -.65:6875 GR HOB 2,3027 NCNL ~ 6 ~. 5625 EPT 5000,9000 SFL{I P -6o oooo FtOB 2:2227 R ~)1,8125 NRA7 F. PT 4 900,0000 SFbU P -59,781.3 GR WiJB 2,2598 NCNL P 06,7500 NRAT .,P ,'I 4.800,0o00 SFLU P -60 7 t.~ 1. 3 HOB 2:2'!15 R 72,6250 NRAT EPT 4700. 0000 P -69 6875 GR HOB 2: 2324 NCNb k 5R-, 7500 NRA'r 81.9315 -999,250n -999. 2500 5 7305 79' ,6875 -999,2500 - 999,2500 6.0938 68,5625 2498. 0000 3.1133 4,1289 81 ,B1.25 2158. 0000 3,6309 5.6328 R6.7500 2518,0000 3,2246 4.5352 72.6250 3.4053 5.7891 55,7500 2074,0000 3.5742 I.'~i P H !. RNRA N P H 1 FCNL R b,I R A F C {~ L RNR~. IIL. M I~"CN b F C .N L R ~a R A FCNI, IL~ FCNL RN~A I NPP I FCNL RaR~ IL,q N P H I FC N I.., RNRA F C N I: -999,2500 -999,250('3 -999. 2500 8 ~938 -99g: 500 -999.2500 -999.2500 3,7109 -999.2500 -999,~500 -999, 500 4.0352 2 -999, 500 . 250 -999.'" 0 ~00 -999,2~ 2,9629 -999,2500 '999,2500 '999.2500 4,7383 -999,2500 -999.2500 -999,~500 5.4727 32,4219 727,0000 3.4355 4.4648 41.9922 537.5000 4.0117 9,0469 34,5703 5O0O 700'5q38 8.6172 38.3789 531.0000 3.6855 6,5117 41.0156 541.5000 3.8301 [) R l.t C Ab I I L D D R n [1 ('_'ALI I, L D D R n 0 C h I,, I I hD D R H 0 CALl I CALI i .L, D D R H 0 C A b I I [~D D R H 0 I .b D DRHO CAI,, I I bD D R H (] CALl I b D D R H 0 C A L I ILO D R H 0 CAbI -999,2500 12,4844 7,3125 -999,2500 10,90~2 3,9687 -g99,2500 12,9609 4,~656 -999. 500 12.0000 3,1230 '999. 500 13,0'103 5,0703 '999,2500 12.4531 5.6250 0,0337 11.9219 4,7695 0.0181 11.9531 9,0391 0.029t~ 12.1875 9.5859 0,0449 11.0469 7.q883 0,0322 11,9297 ;P 01.0,H02 VE~RIFIC~TION LiSI'ING 'PAGE 8 !~PT 4600 0000 SFLU ) , - 62 7813 G R lOb 2 2213 NCNL ~ 74 6250 NRA'l) gPT 4500 0000 SF[,U :~ -82 5625 GR 4OB ~ t641 NCNL 824:9 74.6250 6934 16 7344 2396. 3.4531 4400,0000 SFI.,U 5 25o. 0 ,,69,6875 GR 77 3~25 2 9Io k t.N I,, 1894 0000 77;3125 NRAT 3 5996 EPT 4300,0000 SFLIJ ~ -79,4375 GR 40 [~ 2,2813 N C N Ii, R 65,5625 EPT 4200 0000 SFt~u ? -,71:1875 40 ~ 2,3301 ~,i C N ~ 67,6875 NPAT 8. 2969 6 3625 21 3 0000 3 .,44 ~14 7,82S~ 67,6875 1993.0000 3.6191 P 79:6~ 5 (;R 56,3125 gOB 2.2070 ]'qCNL 21,72.0000 R 56,3125 NRAT 3,6074 BPT 4000. 0000 P -84,6875 GR iqOb 2.1270 NCN ~ 42.3438 ~P'r 3900.0000 P -90,3125 HOB, 2.2637 NCN f,, P 66. ~ 750 N ~ ~ '1' EPT 3800.0000 P -71.1875 GR HOB 2.3~52 t,!CNL R 73,4375 NRAT 3600,0000 SFt.~U P -90.4:375 P, OP 2, ? ! ~7 R 63,09 '.4 14,0625 42.3438 23R6.0()00 3.8672 66.8750 2029.0000 3.5430 7.0820 73.4375 3.3!05 12.2500 35,343~ 242.'t 313223 9,56?5 63.0q38 3.7520 IL~4 NP~I F'CN 1., R N' R A I L a N p PI I F'CNL F'CNI. NPH I FCN [, BPF~ I. FC I NPHI FCNL I[,~ NPHI FCNI_,, RNRA I NPHI FCN I, F'CNL 1' NPH 1 ~ CNI~ 6,3164 43,1641. 517.5000 4,1250 1,6.4531 39.3066 627.OO00 3,~203 5,7188 40,8691 465,0000 4.0703 9,4S44 38,5742 557,0000 3.8340 8.6484 40.8691 500,5o00 3.9805 7.1836 4,2.4316 579.0000 3,7500 21,3750 46,8262 560,5000 4.2539 8.4141 40,¢203 539.5O0O 3,7598 8.1797 34,8633 597.500O 3.7539 13.0859 36,2793 672,0000 3. 6055 9.8672 45.507~ 513.0000 4.1641 O R H 0 I LD L) R H 0 CAb I I L D D R ft 0 I LD 13 R }t O C A L I I LD DR HE} CALl ILD D R lq (1 CAL, I I L D DRHO CALl I C A L, I I DRHO C,~L I DRF]O CALl I LD b R H 0 C A L 1 6,9336 0,0327 11.953} 20.0781 0,0229 10.9297 6,4944 0,0425 1..3,0938 10,5078 0,0259 12.0000 9,2R91 0,0503 13.9141 7,7813 0.0195 10,5234 19,5469 0,0151 1.0.7813 8,8750 0,0342 1.1,1328 9,1328 0,0386 14,8906 13,6016 -0.0029 12.3125 10,5391 0.042O 10.1953 II<'~ i,I il 1 i i1 ~I:.] ii! Iq i ~P 010,H02 VE,RIF'IC:AT!O~ O(iO 8FLU :PT 35(,0.4' 0375 } '79, 2,2051 NC N [.~ 6 7, '3 '750 ~ R g, T ]PT 0000 ~ 5000 NRAT ;"PT 3200,00o0 SFLU > ' 79 5625GR , ~)'OB ] ,9697 mCNL ~ 54,5000 N~ ~T 00,0000 o [ I., b 85.3125 GR 2,089 ~4 N C'N L 4:1,2~13 F..PT 2900,0000 SFI,U ~ -74. I:)~25 GR ~OB 2,0801 N CNI> ~ 45,4063 NRAT 2~00,0000 SFbU 81,9375 GR 2,13't8 NCNL 49,281.3 NR~T EPT 27(!0,0000 SFLt. 1 P -89.1¢75 GR SOB 2.0890 R 47,3125 EPT 2500,0000 SFI.,U P ..71, ~1~8't 5 HOB 1,. '107 NCbb 7,9922 ~7,375O 2012,0000 ,~, (') 3c.~ l 73,5000 1795,000() 3.7715 9 .3672 4g'5313 · 2718,0000 3.6094 9.09 54,5000 1923, OI)O0 ~ I, 73a4 41 2326,0000 3,46,4~ 5 3906 73,8125 1733,0000 4,3867 1,1953 .5,4063 2570,0000 3,5977 8,765a 49.2813 3.4551 14.1328 47.3125 2536.0000 3.591a 14,0234 51,8750 ~60,0000 3.6504 9,5025 33.6250 1540.0000 I b M FCNb 9,~750 49, 512 460,5000 4,3672 o,1094 44,6289 425,5000 4.2148 , 9q22 675 ~ 5000 4,0234 8,9453 47 ~191 426~ 000 4,5078 38.8 84 610,0000 3.8125 6.10~6 56,005~ 375,7500 4,6094 12,6563 41.5527 646,5000 3.9746 9,6875 38,~230 660,5000 3,6~36 15,1128 4~.5039 62~.5000 4,07R1 15,6641 42.5781 58~,0000 2000,0000 54,3945 341.7500 i b D ORHO C a b I ILD C a I.,, I 1ED CADI I LD D R H 0 C~LI I L, D 0 R H L) Cahl I L, D DR H O C~XLI I bD i:') R H 0 CaLl I bD CALI II,D DRH[J C hLI DNHU q~I,I CALI P A G I 0,0703 0,0254 10,851,6 10.29bg 0,0771 11.8203 11,1719 -0,~024 11, 187 9,8984 0.0020 11.,101~ 3,5391 iO.O010 12,40~3 7,4336 0,0181 11,0859 !3,5938 0.001.5 I1,6250 10,7734 0,0034 12.4063 1.6,2031 0,0010 11,5000 17,21~7 o.oo2a 11.4922 lO,9922 -0,611~ 9.6328 ,VP OIO,H02 VF. RIFIlCATIOr~I 33,6250 ,EPT 2497.5000 SFb[i ;P -70.6875 GR :MOB 2.0117 ~C~iL ;R 32.8750 ~RAT 4.1953 10,0000 32,8750 15~9,0000 4,]~06 I I,~~ NP~I FCt~I, :* FIL[~,, TRAILER ** 'ILE ~A~E :SERVIC,001 ;ERVICE NA~E : ~ERSION ~ )ATE : tAXI~i{.J~ LENGTH : 1024 'ILE TYPE : IEXT FILE NAgE EOF ********** 4,5117 2000.0o00 57.8613 304.2500 5.0547 IL, D CALl PAGE 10.5781 '0.5752 9.6250 10 ~* TAPE TRAILER ** ;ERVICE NA~E :$ERVIC )ATE :83102/22 )RIGI~ :FSIA ~ONTINOATION g :01 4EX'T TAPE NAME : ~[.}MN~ENTS :bIBRARY TAPE REEL TRAIbER ** ~E~VICE NAaE :SERVIC )A, TE :83/02/22 JRIGIN : ~ONTI~OATION ~ :O1 qEXT REEL NA~', : ~.'OM~E~TS :LIBRARY T~PE EOF
