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Home My WebLink About181-152 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. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop Kuparuk 1A-09 50-029-20669-00 181152_1A-09_IPROF_27May2022 1A-15 50-029-20711-00 182017_1A-15_iProf_02Jun2022 1A-22 50-029-22127-00 191003_1A-22_RBP-LSL_22June2022 191003_1A-22_SBHPS-RBP_09June2022 1B-101 50-029-23173-00 203133_1B-101_MechCut_24Jun2023 1B-14 50-029-22452-00 194030_1B-14_CHC_15Mar2022 194030_1B-14_RCT Cutter_24Feb2022 194030_1B-14_UPCT Cutter_20Jun2022 194030_1B-14_Whipstock_13Apr2022 19430_1B-14_CHC_21Mar2022 1C-09 50-029-20859-00 182185_1C-09_IPROF_15Jan2023 1C-133 50-029-23013-00 201077_1C-133_RBP_07Apr2022 1C-152 50-029-23548-00 215114_1C-152_IPROF_20Mar2023 1C-15L1 50-029-22932-60 203032_1C-15L1_CHC_04Feb2022 1D-01 50-029-20393-00 179059_1D-01_PPROF_25Jun2023 1of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38308 T38309 T38310 T38312 T38311 T38274 T38276 T38314 T38315 T38316 2/29/2024 1A-09 50-029-20669-00 181152_1A-09_IPROF_27May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:11:35 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-09 KUPARUK RIV UNIT 1A-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-09 50-029-20669-00-00 181-152-0 W SPT 6042 1811520 1510 2550 2550 2550 2550 292 346 350 350 4YRTST P Adam Earl 7/12/2023 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-09 Inspection Date: Tubing OA Packer Depth 1030 1810 1785 1785IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714090750 BBL Pumped:0.5 BBL Returned:0.5 Friday, September 1, 2023 Page 1 of 1          MEMORANDUM To: Jim Rper ! Zai � Sl t l�2C7 P.I. Supervisor l FROM: Guy Cook Petroleum Inspector I Well Name KUPARUK RIV UNIT 1A-09 IInsp Num' mitGDC200507161328 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 11, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A-09 KUPARUK RIV UNIT 1A-09 Src: Inspector Reviewed B P.I. Supry Comm API Well Number 50-029-20669-00-00 Inspector Name: Guy Cook Permit Number: 181-152-0 Inspection Date: 5/6/2020 ✓ Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A 9- Type Ini w' TVD f 6042 TUbmg 2420 2420 2450 - 2484 PTD - 1811520 Type Test L 11 SPT (Test psi 1510 L IA 610 _ 1915 1880 1870 BBL Pumped: 0.9 1113131, Returned: 0.8 CIA 312 401 j-----400 aoo -- -- Interval OTHER — PIF -- P Notes: MITIA post patch per Sundry 320-162. Testing was done with a Little Red Services pump truck and calibrated gauges. vJ�6lSz ��nc�e iL�z�t7 Monday, May 11, 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: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc. P.O. Box 100360, Anchorage, Alaska 99510 181-152 50029206690000 ADL0025647 KRU 1A-09 N/A Kuparuk River Field/Kuparuk River Oil 7255 6539 N/A N/A 7049 6354 6691 6037 Conductor 80 16 80 80 Surface 2142 10 3/4 2242 2242 Production 7134 7 7234 6520 6760-6822,6953-6962 6098-6152, 6268-6276 3 1/2 J-55 6890 6213 Baker FHL 6691' md & 6037' tvd Camco TRDP-1A 1845' md & 1845' t N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 320-162Dusty Freeborn Well Integrity & Compliance Specialist Dusty Freeborn/Jan Byrne n1617@conocophillips.com 659-7224 Tubing patch extension✔✔ ✔✔ ✔ Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.05.08 15:44:43 -08'00' By Samantha Carlisle at 3:56 pm, May 08, 2020 SFD 5/11/2020VTL 5/26/20 SFD 5/11/20 RBDMS HEW 5/11/2020 DSR-5/11/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 8, 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 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch extension set across a known tubing leak KRU 1A-09 (PTD 181-152). 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: 2020.05.08 15:43:30 -08'00' Date Event Summary Executive Summary Set a retrievable tubing patch extension from 6648'-6677'. Performed SW MIT-IA to 1915 psi post patch. 5/6/2020 (SW) STATE WITNESSED (GUY COOK) MIT-IA TO 1915 PSI, POST PATCH (PASSED). 4/22/2020 BRUSH n' FLUSH TBG FROM 6683' TO 6600' RKB, SET 2.72" P2P EXPANSION JOINT SPACER & ANCHOR LATCH (OAL 28.16' OPEN / RIH OAL 22.16') (SN: CPP35248 / CPEJ27202 / CPAL35112) @ 6648' RKB, MIT IA 3000 PSI PASS. DRAW IA TO 516 PSI. COMPLETE. 4/21/2020 ATTEMPT TO PULL 3 1/2 TEST TOOL @ 6677' RKB, BAILED ~4' OF SAND FROM TEST TOOL, PULLED 3 1/2 P2P TEST TOOL @ 6677' RKB. IN PROGRESS. 4/11/2020 (AC EVAL): CMIT T X IA PASSED 4/8/2020 PUMPED 165BBLS S/W 70BBLS DIESEL UTUBE CMIT TO 3000PSI FAILED 4/6/2020 RAN 24 ARM MEMORY CALIPER LOG FROM 6660' RKB TO SURFACE. ATTEMPT NEW RELAY CALIPER TEST STRIP UNABLE TO GET NEW FIRMWARE TO COMMUNICATE W/ TOOLS. JOB COMPLETE. 3/27/2020 PERFORM LEAK DETECT LOG. TUBING LEAK FOUND @ 6662' W/ LRS PUMPING 0.75 BPM TUBING PRESSURE 1600 PSI AND IA @ 1000 PSI. 2/11/2020 (AC EVAL) CMIT T x IA TO 3000 PSI (PASSED) Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811520 Type Inj W Tubing 2420 2420 2450 2484 Type Test P Packer TVD 6037 BBL Pump 0.9 IA 610 1915 1880 1870 Interval O Test psi 1509 BBL Return 0.8 OA 312 401 400 400 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 ConocoPhillips Alaska Inc, Kuparuk / KRU / 1A Pad Guy Cook Weimer / Hills 05/06/20 Notes:MITIA post patch per Sundry # 320-162 Notes: 1A-09 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 1A-09 05-06-20.xlsx Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: DSL/RKB 7,049.0 4/22/2016 1A-09 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Expansion Joint 4/22/2020 1A-09 jhansen8 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 33.0 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) 31.4 Set Depth (ftKB) 2,241.8 Set Depth (TVD) … 2,241.7 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 29.4 Set Depth (ftKB) 7,234.1 Set Depth (TVD) … 6,520.5 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5 x 2.875 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 27.8 Set Depth (ft… 6,890.6 Set Depth (TVD) (… 6,212.9 Wt (lb/ft) 9.20 Grade J-55 Top Connection BUTT AB-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 27.8 27.8 0.07 HANGER MCEVOY HANGER 3.500 1,844.9 1,844.8 0.72 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,664.5 6,014.3 28.92 SBR BAKER SBR 2.810 6,690.7 6,037.2 28.73 PACKER BAKER FHL PACKER 3.000 6,764.9 6,102.3 28.67 BLAST JTS BLAST JOINTS (OAL=72.21') 2.992 6,845.2 6,172.8 28.31 NIPPLE AVA BPL PORTED NIPPLE 2.750 6,847.8 6,175.1 28.29 XO Reducing CROSSOVER 3.5 x 2.875 2.875 6,861.5 6,187.2 28.18 LOCATOR BAKER LOCATOR 4.000 6,862.5 6,188.1 28.18 PACKER BAKER DB PACKER 3.250 6,882.3 6,205.6 28.02 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,889.9 6,212.3 27.96 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,645.0 5,997.2 29.06 P2P EXPANSION JOINT SET 2.72" P2P EXPANSION JOINT SPACER & ANCHOR LATCH (OAL 28.16' OPEN / RIH OAL. 22.16') SN:CPP35248 / CPEJ27202 / CPAL35112) " 4/22/2020 1.610 6,662.0 6,012.1 28.94 TUBING LEAK TUBING LEAK FOUND @ 6662' W/ LRS PUMPING 0.75 BPM TUBING PRESSURE 1600 PSI AND IA @ 1000 PSI. 3/27/2020 2.990 6,683.0 6,030.5 28.79 PATCH Upper Patch Assy (2.72" UPPER PIIP (SERIAL # CPP35059), SPACER PIPE, ANCHOR SEAL (SER # CPAL35032), OD-2.72", ID-1.61", OAL-21') 4/22/2016 1.610 6,685.0 6,032.2 28.77 TUBING LEAK TUBING LEAK IN SBR IDENTIFIED DURING IPROF 1/18/2016 2.810 6,703.0 6,048.0 28.67 PACKER 2.72" PARAGON II PACKER (ser# cpp 35057, ID-1.61", OAL 3') 4/22/2016 1.610 6,845.2 6,172.8 28.31 SLEEVE-O 2.75" AVA TPI 10/22/200 5 2.310 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,760.0 6,822.0 6,098.0 6,152.4 C-3, C-2, C-1, UNIT B, 1A-09 11/3/1981 4.0 IPERF 4" Hyperjet 6,953.0 6,962.0 6,268.1 6,276.1 A-5, 1A-09 11/3/1981 4.0 IPERF 4" Hyperjet 6,971.0 7,004.0 6,284.1 6,313.5 A-4, 1A-09 11/3/1981 4.0 IPERF 4" Hyperjet 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 6,620.6 5,975.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY 0.0 8/16/2006 10:00 2 6,727.9 6,069.9 CAMCO KBUG 1 INJ DMY BK-2 0.000 0.0 8/15/1985 Notes: General & Safety End Date Annotation 8/29/2006 NOTE: WAIVERED WELL IA x FORMATION 8/14/2006 NOTE: IA Leak @ 2574' plugged with Sealtite Flo-Seal Sealant 10/8/2005 NOTE: IA LEAK @2574' (TecWel leak detect log) 1A-09, 4/26/2020 4:09:38 PM Vertical schematic (actual) PRODUCTION; 29.4-7,234.1 IPERF; 6,971.0-7,004.0 IPERF; 6,953.0-6,962.0 SOS; 6,889.9 NIPPLE; 6,882.3 PACKER; 6,862.5 LOCATOR; 6,861.5 SLEEVE-O; 6,845.2 NIPPLE; 6,845.2 IPERF; 6,760.0-6,822.0 INJECTION; 6,727.9 PACKER; 6,703.0 PACKER; 6,690.7 PATCH; 6,683.0 TUBING LEAK; 6,685.0 SBR; 6,664.5 TUBING LEAK; 6,662.0 P2P EXPANSION JOINT; 6,645.0 GAS LIFT; 6,620.5 SURFACE; 31.4-2,241.8 SAFETY VLV; 1,844.9 CONDUCTOR; 33.0-80.0 HANGER; 27.8 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 11/4/1981 1A-09 ... TD Act Btm (ftKB) 7,255.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292066900 Wellbore Status INJ Max Angle & MD Incl (°) 38.78 MD (ftKB) 5,500.00 WELLNAME WELLBORE1A-09 Annotation Last WO: End Date 8/16/1985 H2S (ppm) DateComment SSSV: TRDP 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: Extend existing 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.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KRU 1A-09 Will 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): 7255 Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Backer FHL packer Camco TRDP-1A safety valve 6691 MD/6037 TVD 1845 MD/1845 TVD 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: 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 907-830-9777 or 808-345-6886 COMMISSION USE ONLY N/A P.O.Box 100360, Anchorage, Alaska 99510 50029206690000 Tubing Grade:Tubing MD (ft): 6098-6152,6268-6276,6284- 6314 Authorized Name: Dusty Freeborn Perforation Depth TVD (ft):Tubing Size: MD N/A PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025647 River/Kuparuk 181-152 80 2242 ConocoPhillips Alaska, Inc. Length Size 6539 65207 16 10 3/4 J-55 TVD Burst 6890 7234 Perforation Depth MD (ft): 6760-6822,6953-6962,6971- 7004 7134 80 2242 Authorized Title: Well Integrity & Compliance Specialist Dusty Freeborn/Jan Byrne N1617@conocophillips.com 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 4/20/2020 3 1/2 80 2142 m n P s O 1 6 5 6 t h hh Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by dusty.freeborn@conocophillips.com DN: CN=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-04-13 15:06:35 Foxit PhantomPDF Version: 9.7.0 dusty.freeborn@co nocophillips.com By Samantha Carlisle at 3:27 pm, Apr 13, 2020 320--162 10-404X X DSR-4/13/2020 X DLB 4/14/2020 VTL 4/14/20 quired? Yes No Comm.S XX 4/14/2020 dts 4/14/2020 JLC 4/14/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 13 April 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 1A-09 (PTD 181-152) to extend the retrievable tubing patch to cover an additional 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. Digitally signed by dusty.freeborn@conocophillips.com DN: CN=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-04-13 15:07:10 Foxit PhantomPDF Version: 9.7.0 dusty.freebor n@conocoph illips.com KRU 1A-09 (PTD# 181-152) Description Summary of Proposal Well Work Justification & Objectives (and date required if appropriate): 1A-09 was reported to the AOGCC for an increase in IA pressure. The well was shut in on 1 Oct 2018 for LTSI. Diagnostics indicated the tubing has a leak at 6662', above the existing tubing patch. A tubing patch needs to be installed in order to regain tubing integrity. Risk/Job Concerns: PC has seal tite repair at 2574'; Do not let IA pressure fall below 500 psi. Do not perform MIT-OA; PC leak maybe effected by OA pressure. Tubing patch from 6683'-6703' covers tubing by C-sand leak. IC EP PO's have been sealant squeezed SSSV may have leak in control line Lower packer of patch will be the upper packer of exisiting tubing patch at 6683' Patch will be installed over the SBR and will need an expansion joint. DO NOT PERFORM WORK UNTIL 10-403 HAS BEEN APPROVED Steps: DSL 1. Brush and flush patch setting area of ~6650' to top of patch at 6683'. 2. Set anchor latch, expansion joint, spacer pipe into P2P at 6683'. Pin expansion joint lighter than anchor latch to allow for expansion joint sheer. 3. Sheer expansion joint and pull up ~4-5' and set upper packer at 6658' (2' above upper collar of 4' pup at 6660'-6664). Total patch length after expansion joint sheer is 25' mid-element to mid-element. Expansion joint should be placed to allow for ~1'-2' of pipe shrinkage and 4'-5' of pipe expansion at the SBR. 4. Perform MIT-IA to 3000 psi. Record initial, 15 min and 30 min pressures. A. If MIT-IA fails trouble shoot failure mechanism B. If MIT-IA passes, bleed IA back to ~500 psi and turn well over to operations to be BOI. AOGCC witnessed MIT-IA and 10-404 submittal will be required. Annular Communication Surveillance 14 Well Name:11A-09 Start Date:14-Jan-2020 13 Days:90 End Date:13-Apr-2020 50 70 90 110 130 150 170 0 500 1000 1500 2000 2500 14-Jan-2017-Jan-2020-Jan-2023-Jan-2026-Jan-2029-Jan-201-Feb-204-Feb-207-Feb-2010-Feb-2013-Feb-2016-Feb-2019-Feb-2022-Feb-2025-Feb-2028-Feb-202-Mar-205-Mar-208-Mar-2011-Mar-2014-Mar-2017-Mar-2020-Mar-2023-Mar-2026-Mar-2029-Mar-201-Apr-204-Apr-207-Apr-2010-Apr-2013-Apr-20Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 14-Jan-2017-Jan-2020-Jan-2023-Jan-2026-Jan-2029-Jan-201-Feb-204-Feb-207-Feb-2010-Feb-2013-Feb-2016-Feb-2019-Feb-2022-Feb-2025-Feb-2028-Feb-202-Mar-205-Mar-208-Mar-2011-Mar-2014-Mar-2017-Mar-2020-Mar-2023-Mar-2026-Mar-2029-Mar-201-Apr-204-Apr-207-Apr-2010-Apr-20Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: DSL/RKB 7,049.0 4/22/2016 1A-09 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TUBING LEAK 3/27/2020 1A-09 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 33.0 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) 31.4 Set Depth (ftKB) 2,241.8 Set Depth (TVD) … 2,241.7 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 29.4 Set Depth (ftKB) 7,234.1 Set Depth (TVD) … 6,520.5 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5 x 2.875 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 27.8 Set Depth (ft… 6,890.6 Set Depth (TVD) (… 6,212.9 Wt (lb/ft) 9.20 Grade J-55 Top Connection BUTT AB-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 27.8 27.8 0.07 HANGER MCEVOY HANGER 3.500 1,844.9 1,844.8 0.72 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,664.5 6,014.3 28.92 SBR BAKER SBR 2.810 6,690.7 6,037.2 28.73 PACKER BAKER FHL PACKER 3.000 6,764.9 6,102.3 28.67 BLAST JTS BLAST JOINTS (OAL=72.21') 2.992 6,845.2 6,172.8 28.31 NIPPLE AVA BPL PORTED NIPPLE 2.750 6,847.8 6,175.1 28.29 XO Reducing CROSSOVER 3.5 x 2.875 2.875 6,861.5 6,187.2 28.18 LOCATOR BAKER LOCATOR 4.000 6,862.5 6,188.1 28.18 PACKER BAKER DB PACKER 3.250 6,882.3 6,205.6 28.02 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,889.9 6,212.3 27.96 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,662.0 6,012.1 28.94 TUBING LEAK TUBING LEAK FOUND @ 6662' W/ LRS PUMPING 0.75 BPM TUBING PRESSURE 1600 PSI AND IA @ 1000 PSI. 3/27/2020 2.990 6,677.0 6,025.2 28.83 PIIP TEST TOOL PIIP Test tool set in upper packer at 6683' (OAL = 66") 1/8/2018 0.000 6,683.0 6,030.5 28.79 PATCH Upper Patch Assy (2.72" UPPER PIIP (SERIAL # CPP35059), SPACER PIPE, ANCHOR SEAL (SER # CPAL35032), OD-2.72", ID-1.61", OAL-21') 4/22/2016 1.610 6,685.0 6,032.2 28.77 TUBING LEAK TUBING LEAK IN SBR IDENTIFIED DURING IPROF 1/18/2016 2.810 6,703.0 6,048.0 28.67 PACKER 2.72" PARAGON II PACKER (ser# cpp 35057, ID-1.61", OAL 3') 4/22/2016 1.610 6,845.2 6,172.8 28.31 SLEEVE-O 2.75" AVA TPI 10/22/200 5 2.310 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,760.0 6,822.0 6,098.0 6,152.4 C-3, C-2, C-1, UNIT B, 1A-09 11/3/1981 4.0 IPERF 4" Hyperjet 6,953.0 6,962.0 6,268.1 6,276.1 A-5, 1A-09 11/3/1981 4.0 IPERF 4" Hyperjet 6,971.0 7,004.0 6,284.1 6,313.5 A-4, 1A-09 11/3/1981 4.0 IPERF 4" Hyperjet 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 6,620.6 5,975.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY 0.0 8/16/2006 2 6,727.9 6,069.9 CAMCO KBUG 1 INJ DMY BK-2 0.000 0.0 8/15/1985 Notes: General & Safety End Date Annotation 7/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8/29/2006 NOTE: WAIVERED WELL IA x FORMATION 8/14/2006 NOTE: IA Leak @ 2574' plugged with Sealtite Flo-Seal Sealant 1A-09, 3/28/2020 5:22:02 AM Vertical schematic (actual) PRODUCTION; 29.4-7,234.1 IPERF; 6,971.0-7,004.0 IPERF; 6,953.0-6,962.0 PACKER; 6,862.5 SLEEVE-O; 6,845.2 IPERF; 6,760.0-6,822.0 INJECTION; 6,727.9 PACKER; 6,703.0 PACKER; 6,690.7 PATCH; 6,683.0 TUBING LEAK; 6,685.0 PIIP TEST TOOL; 6,677.0 TUBING LEAK; 6,662.0 GAS LIFT; 6,620.5 SURFACE; 31.4-2,241.8 SAFETY VLV; 1,844.9 CONDUCTOR; 33.0-80.0 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 11/4/1981 1A-09 ... TD Act Btm (ftKB) 7,255.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292066900 Wellbore Status INJ Max Angle & MD Incl (°) 38.78 MD (ftKB) 5,500.00 WELLNAME WELLBORE1A-09 Annotation Last WO: End Date 8/16/1985 H2S (ppm) DateComment SSSV: TRDP tubing leak 6662'x S Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, November 26, 2017 6:29 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure spike and sustained casing pressure of 1A-09 (PTD 181-152) 11-26-17 Attachments: 1A-09 schematic.pdf; 1A-09 90 day TIO 11-26-17.J PG Chris, KRU WAG injector 1A-09 (PTD 181-152) had an IA pressure spike earlier today. The pressure reached as high as the injection pressure of"2400psi. Attempts to bleed the pressure off were unsuccessful. Therefore the well was shut in and freeze protected. Initially the IA could not be bleed below^'2200psi. However, since being shut in at 12:30PM,the pressure has slowly declined and is currently at 1840 psi and still dropping. DHD diagnostics consisting of MITs and packoff testing as well as well intervention work to set a plug, perform a leak detect log etc will be pursued as necessary. Prior to the returning the well to injection, proper paperwork will be submitted. Attached are the 90 day TIO and schematic. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 SCANNED , 1 STATE OF ALASKA • IRSKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I[— Plug Perforations 1 Fracture Stimulate I- Pull Tubing UI— Operations Shutdown '" Performed: ,,..,,,, Suspend Perforate ! Other Stimulate r Alter Casing Change Approved Program'< Plug for Redrill - Perforate New Pool -- Repair Well fl Re-enter Susp Well'-- Other:Retrievable Tubing Patch '. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development f,.... Exploratory .- 181-152 3.Address: 6.API Number: Stratigraphic f....... Service P- P. - P. O. Box 100360,Anchorage,Alaska 99510 50-029-20669-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 KRU 1A-09 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 7255 feet Plugs(measured) None true vertical 6539 feet Junk(measured) None Effective Depth measured 6995 feet Packer(measured) 6691, 6862, 6703 true vertical 6305 feet (true vertical) 6037, 6188,6048, Casing Length Size MD ND Burst Collapse CONDUCTOR 47 16 80 80 SURFACE 2210 13 2242 2242 PRODUCTION 7205 10 7234 6520 SCANNED ;SUN 1 5116 Perforation depth: Measured depth: 6760-6822,6953-6962,6971-7004 RECEIVED True Vertical Depth: 6098-6152,6268-6276,6284-63113 MAY 10 2016 Tubing(size,grade,MD,and TVD) 3.5 X 2.875,J-55,6891 MD,6213 TVD A00 Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 6691 MD,6037 TVD PACKER-BAKER DB PACKER @ 6862 MD, 6188 TVD PACKER-PARAGON II PACKER @ 6703 MD,6048 TVD PACKER-PARAGON II PACKER @ 6683 MD,6030 TVD TRDP-CAMCO TRDP-1A @ 1845 MD, 1845 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation - 1571 - 2383 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations f✓ Exploratory (.. Development Service Stratigraphic - 16.Well Status after work: - Copies of Logs and Surveys Run E Oil � Gas � WDSPL Printed and Electronic Fracture Stimulation Data l GSTOR WINJ Ri WAG i...... GINJ l SUSP f SPLUG J 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: 316-070 Contact John Peirce Cad 265-6471 Email John.W.Peirce(c�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature c y' Phone:265-6471 Date 4...........„. Form 10-40 Revised 5/2015 V7 L 57/0/no Submit Original Only ,.Xd7/6 RBDMS L' MAY 1 0 2016 z KUP • 1A-09 ConocoPhi lips 4 Well Attrib Max Angle&MD TD Al;,I L Irk,- Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Ben(ftKB) 7...,.......: IIipc 500292066900 KUPARUK RIVER UNIT INJ 38.78 5,500.00 7,255.0 ... ^yM Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1A-O9,514/2016807.52 AM SSSV:TRDP Last WO: 8/16/1985 39.01 11/4/1981 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 7,105.0 11/17/2012 Rev Reason.TAG,SET PATCH pproven 4/25/2016 _ Casing Strings HANGER;27.8Cas ngDescriptionOD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...WtlLen(I.Grade Top Thread CONDUCTOR 16 15.062 33.0 80.0 800 6500 H-40 WELDED Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE103/4 9.950 31.4 2,241.8 2,241.7 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen p...Grade Top Thread PRODUCTION 7 6.276 29.4 7,234.1 6,520.5 26.00 K-55 BTC Tubing Strings Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ibkt) Grade Top Connection TUBING 3.5 x 2.875 3 1/2 2.992 27.8 6,890.6 6,212.9 9.20 J-55 BUTT AB-MOD a: Completion Details J./5..CONDUCTOR;33.0-80.0• Nominal ID � Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item DesCom (in) 27.8 27.8 0.07 HANGER MCEVOY HANGER 3.500 SAFETY VLV;1,844.9 dr 1,844.9 1,844.8 0.72 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,664.5 6,014.3 28.92 SBR BAKER SBR 2.810 • 6,690.7 6,037.2 28.73 PACKER BAKER FHL PACKER 3.000 6,764.9 6,102.3 28.67 BLAST JTS BLAST JOINTS(OAL=72.21') 2.992 6,845.2 6,172.8 28.31 NIPPLE AVA BPL PORTED NIPPLE 2.750 6,847.8 6,175.1 28.29 XO Reducing CROSSOVER 3.5 x 2.875 2.875 SURFACE;31.4-2.241.8 6,861.5 6,187.2 28.18 LOCATOR BAKER LOCATOR 4.000 6,862.5 6,188.1 28.18 PACKER BAKER DB PACKER 3.250 6,882.3 6,205.6 28.02 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,889.9 6,212.3 27.96 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) 6,683.0 6,030.5 28.79 PATCH -Upper Patch Assy(2.72"UPPER PIIP(SERIAL# 4/22/2016 1.610 CPP35059),SPACER PIPE,ANCHOR SEAL(SER GAS LIFT,6,620.5 6 CPAL35032),OD-2.72",ID-1.61",OAL-21') 6,703.0 6,048.0 28.67 PACKER 2.72"PARAGON II PACKER(ser#cpp 35057,ID- 4/22/2016 1.610 1.61",OAL 3') 6,845.2 6,172.8 28.31 SLEEVE-0 2.75"AVA TPI 10/22/2005 2.310 SBR;6,664.5 Perforations&Slots 0 • Shot PATCH;6,663.0 • ; Dens PACKER;6690.7, [[[ Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date k) Type Com 6,760.0 6,822.0 6,098.0 6,152.4 C-3,C-2,C-1, 11/30981 4.0 IPERF 4"Hyperjet UNIT B,1A- 1 09 PACKER;6,703.0 1 F 6,953.0 6,962.0 6,268.1 6,276.1 A-5,1A-09 11/3/1981 4.0 IPERF 4"Hyperjet 6,971.0 7,004.0 6,284.1 6,313.5 A-4,1A-09 11/3/1981 4.0 IPERF 4"Hyperjet Mandrel Inserts INJECTION;6,727.9 1 St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 6,620.6 5,975.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY 0.0 8/16/2006 IPERF;6,760.06,822.0 ! I 2 6,727.9 6,069.9 CAMCO KBUG 1 INJ DMY BK-2 0.000 0.0 8/15/1985 Notes:General&Safety End Date Annotation 10/8/2005 NOTE.IA LEAK @2574'(TecWel leak detect log) 8/14/2006 NOTE:IA Leak @ 2574'plugged with Sealtite Flo-Seal Sealant NIPPLE;6,845.2 - 8/29/2006 NOTE:WAIVERED WELL IA x FORMATION SLEEVE-0;6,845.21 7/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;6,861.5 PACKER;6,862.5 1.)5,1211' f-f Lin" I NIPPLE;6,882.3 111 SOS,6,889.9 ift IPERF;6,953.06,982.0 IPERF;6,971.0-7,004.0 _.. PRODUCTION,29.4-7,234 1-i 1 A-09 DTTM JOBTYP SUMMARYOPS START 4/22/16 TUBING TAGGED TD @ 7049' RKB. BRUSHED PATCH SET AREA FROM 6660' -6740' CASING RKB WHILE LRS PUMPED 20 BBLS DIESEL. DRIFTED 2.72" x 16' DUMMY PATCH PATCH TO 6800' RKB. SET LOWER 2.72" PIIP © 6703' RKB (MID ELEMENT). SET UPPER PATCH ASSY @ 6683' RKB (MID ELEMENT). *JOB IN PROGRESS; RIGGED DOWN TO PERFORM UNIT MAINTENANCE; **PATCH STILL IN NEED OF TEST** UPPER PIIP SERIAL#CPP35059 ANCHOR SEAL SER#CPAL35032 LOWER PIIP SERIAL#CPP35057 v=6 \.-‘52 'RECEIV ED • A N R 0 5 2016 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. March 30, 2016 Attn.: Makana Bender . --- 333 West 7th Avenue, Suite 100 DATA LOGGED e, Anchora Alaska 99501 �/Z/201(p Anchorage, M.K.BENDER SOO RE: Injection Profile: 1A-09 Run Date: 1/18/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-09 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20669-00 Production Profile Log 1 Color Log 50-029-20669-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ ✓tt t., 40 / _6R-eat • ‘,``6. t- t52 V Or Tit ,gp I//7, sA THE STATE Alaska Oil and Gas - of e LASKA Conservation Commission 1Z SrE 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 --•.` Main: 907.279.1433 o�ALAs*P Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer %ANHUI FEB 2 3 .01 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-09 Permit to Drill Number: 181-152 Sundry Number: 316-070 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, PL4z \ Cathy . Foerster Chair DATED this IU day of February, 2016. RBDMS LL FEB 1 1 2016 • • RECEIVED STATE OF ALASKA F B 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 ) ) /6 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations Shutdown r Suspend r Perforate E Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r' Perforate New Pool r Re-enter Susp Well E Alter Casing r Other: Retrievable Tubing PatcfF 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillipsAlaska,Inc. • Exploratory r Development r 181-152 3.Address: 6.API Number: P.0.Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20669-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes r No 5-- w KRU 1A-09•' 9.Property Designation(Lease Number): 10.Field/Pool(s): _ADL 25647 . Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,255' - 6,539' - 6995 6305- 4600 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 47' 16" 80' 80' Surface 2,211' 103/4 2,242' 2,242' Intermediate Production 7,205' 7" 7,234' 6,520' Liner Perforation Depth MD(ft): Perforation Depth TVD(R): Tubing Size: Tubing Grade Tubing MD(ft): 6760-6822,6953-6962,6971- 6098-6152,6268-6276,6284- 3 1/2 x 2 718 J-55 6,890' 7004 . 6313 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER • MD=6691 TVD=6037 PACKER-BAKER DB PACKER . MD=6863 TVD=6188 SSSV:CAMCO TRDP-1A SAFETY VALVE - 1845=MD,1845=TVD 12.Attachments: Proposal Summary I] Wellbore schematic l] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch D Exploratory r Stratigraphic E Development r Service F 14.Estimated Date for 2/17/2016 15.Well Status after proposed work: Commencing operations: OIL r WINJ 17 WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG T GSTOR E SPLUG r Commission Representative: GINJ r Op Shutdown E Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce JohnPeirce @ 265-6471 Email JhnW.Peirce@cop.com Printed Name Title Sr.wel 1 er Signaturet°?Y___ —e''----- one Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 co-o-7o Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No I J Spacing Exception Required? Yes ❑ No V' Subsequent Form Required: / —4 0 Ll- /r APPROVED BY / Approved by: / COMMISSIONER THaYE COMMISSION Date: Z'-/�bmitfoand - Form 11110-403 Revised /2015 Approved ap IIc}tion Is vatyc3i r4Q[cord e( t Of approval. Attachments in Duplicate v7-L- /lb Ii/6 Y'Kt3 2 /!c- r` RBDMS F .3 1 1 2016 • • 1A-09 Retrievable Tubing Patch Installation On 9/27/15, an IPROF was run in 1A-09 injector indicating that all injection was entering the A sand at -1,000 BWPD / 2150 psi WHIP. In December 2015, the injection rate suddenly doubled to -2000 BWPD / 2350 psi WHIP. Another IPROF was ran 1/18/16 that shows that there is now a C sand leak at the base of the upper packer of the C sand selective located at 6690' RKB. The IPROF shows 77% PWI to the C sand leak, and 23% entering A sand at 2800 BWPD. There is a significant oil rate benefit for restoring 100% 'A Sd only' PWI in 1A-09 to support offset A Sd producers. It is proposed that a retrievable tubing patch be installed at 66.8.3 - 6703' _ RKB to isolate the C sand leak at 6690' RKB. ✓ Procedure: Slickline: 1. RIH to tag PBTD to determine if a pre-patch CT FCO is required to uncover any of the A5/A4 sand perf intervals located between 6953 - 7004' RKB. The last tag was 9/27/15 at 7048' RKB. 2. RIH to Brush & Flush 3.5" tubing at 6660 - 6740' RKB in the area of the tubing where the tubing patch is to be set. 3. RIH with a -20' OAL Dummy Patch drift BHA consisting of a 2.72" OD x 3' OAL (top section) and a 2.075" OD x -16' OAL (bottom section) to simulate the upper run dimensions of the planned tubing patch installation. Run the top of the drift BHA to 6683' RKB where the upper packer of the tubing patch is targeted for set. POOH with drift BHA. Coil Tubing (if needed): 4. Perform a CT EGO to as deep as possible to remove fill from the wellbore before setting a tubing patch. DSL or E-line: 5. RIH & set a 2.72" OD retrievable lower Straddle Packer at 6703' RKB in the tubing. POOH. 6. RIH with -19' OAL run #2 assembly consisting from bottom to top of a Snap-Latch Seal assembly, -15' Spacer Pipe, and an upper retrievable 2.72" OD Straddle Packer (top). Latch into the lower Packer at 6703' RKB and then set the upper Straddle Packer at 6683' RKB in the tubing (inside Slick-Stick Seal assembly covered by the SBR) to complete the Tubing Patch at 6683 - 6703' RKB. POOH. 7. RIH with a test plug and set it in the top Packer of the tubing patch at 6683' RKB. MITT to 2500 psi to verify good set integrity of the upper straddle Packer and the tubing above the Tubing Patch. POOH with test Plug. RD. Return 1A-09 to 'A sand only' PWI service & obtain valid injection rate. JWP 2/1/2016 • S Loepp, Victoria T (DOA) From: Peirce, John W <John.W.Peirce@conoco hilli s.com> P P Sent: Tuesday, February 09, 2016 4:01 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 1A-09(PTD 181-152, Sundry 316-070) MIT-IA 07-17-15 AOGCC (1A-09)4 YR STATE WITNESSED (BOB NOBLE) MIT-IA PASSED TO 3000 PSI. Initial BLEED-IA T/1/0/00 = 2200/640/120/0. IA FL © SF. Pressured IA to 3000 psi w/1.6 bbls diesel. MIT-IA Starting T/I/O/OO = 2200/3000/250/0. 15 min T/I/O/OO = 2200/2900/250/0.(-100) 30 min T/I/O/OO = 2200/2880/250.(-20) Bled IA to 660 psi in 6 min. Final T/I/O/OO = 2190/660/110/0. Hi Victoria, The last MITIA on 1A-09 looks like it was done 7/17/15. See the information attached (above). Thanks, John Peirce Sr Wells Engr CPAI Drilling &Wells (907)-265-6471 office From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, February 09, 2016 2:39 PM To: Peirce, John W Subject: [EXTERNAL]KRU 1A-09(PTD 181-152, Sundry 316-070) MIT-IA John, When was the last MIT-IA on this well? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa)alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@c! ka.gov 1 KUP INJ 1A-09 v. ConocoPhiUips Well Attrib Max Angle TD Alas,Ir'Cs. Wellbore API/UWI Field Name Wellbore Status ncl(1) MD(ft ) Act Btm(ftKB) CwwcoPhillips 4 500292066900 KUPARUK RIVER PNIT INJ 38.78 5,500.00 7,255.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 1A-09,2/1/20161:35:47 AM SSSV:TRDP Last WO: .6/16/1985 39.01 11/4/1981 Yams/echemabc(actual) Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date Last Tag:CTMD 7,105.0 11/17/2012 Rev Reason:GLV C/O lehallf 7/22/2015 .1nr ,- Casing Strings HANGER;27.8 ® Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...(Grade Top Thread CONDUCTOR 16 15.062 33.0 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 31.4 2,241.8 2,241.7 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread 1, PRODUCTION 7 6.276 29.4 7,234.1 67752:0)).....5.. ,520.5 26.00 K-55 BTC �1 11 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3.5 x 2.875 3 1/2 2.992 27.8 6,890.6 6,212.9 9.20 J-55 BUTT AB-MOD Completion Details a,rs„an,re"n=e,re.nv,ers,,,n."r' uw. Nominal ID �. Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) -�-��CONDUCTOR;33.0-90.0' M 27.8 27.8 0.07 HANGER MCEVOY HANGER 3.500 1,844.9 1,844.8 0.72 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 SAFETY VLV;1,844.9 n. I:i 6,664.5 6,014.3 28.92 SBR BAKER SBR 2.810 6,690.7 6,0372 28.73 PACKER BAKER FHL PACKER 3.000 6,764.9 6,102.3 28.67 BLAST JTS BLAST JOINTS(OAL=72.21) 2.992 6,845.2 6,172.8 28.31 NIPPLE AVA BPL PORTED NIPPLE 2.750 6,847.8' 6,175.1 28.29'XO Reducing CROSSOVER 3.5 x 2.875 2.875 6,861.5 6,187.2 28.18 LOCATOR BAKER LOCATOR 4.000 SURFACE;31.4-2,241.8- Il 6,862.5 6,188.1 28.18 PACKER BAKER DB PACKER 3.250 6,882.3 6,205.6 28.02:.NIPPLE CAMCO D NIPPLE NO GO 2.250 L: 6,889.9 6,212.3 27.96 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 6,845.2 6,172.8 28.31 SLEEVE-0 2.75"AVA TPI 10/22/2005 2.310 Ili Perforations&Slots Shot Dens GAS LIFT;6,620.5 ftKB Top(ftKB) Btm Top(TVD) Btm(ND) (shots/ �/ (ftKB) (ftKB) (ftKB) Zone Date ft) Type Com MX.' 6,760.0 6,822.0 6,098.0 6,152.4 C-3,C-2,C-1, 11/3/1981 4.0 IPERF 4"Hyperjet \V" UNIT B,1A- 09 6,953.0 6,962.0 6,268.1 6,276.1 A-5,1A-09 11/3/1981 4.0 IPERF 4"Hyperjet SBR;6.664.5 7e'. 6,971.0 7,004.0 6,284.1 6,313.5 A-4,1A-09 11/3/1981 4.0 IPERF 4"Hyperjet PACKER;6,690.7 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run INJECTION;6,727.9 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 6,620.6 5,975.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY 0.0 8/16/2006 2 6,727.9 6,069.9 CAMCO KBUG 1 INJ DMY BK-2 0.000 0.0 8/15/1985 Tr Notes:General&Safety j End Date Annotation IPERF;6,760.06,822.0^ _ I 10/8/2005 NOTE:IA LEAK @2574'(TecWel leak detect log) - 8/14/2006 NOTE:IA Leak @ 2574'plugged with Sealtite Flo-Seal Sealant 8/29/2006 NOTE:WAIVERED WELL IA x FORMATION li 7/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 - NIPPLE;6,845.2 SLEEVE-O;6,845.2 II I LOCATOR;6,861.511111 PACKER;6,862.5 '. Ir 1-1 1-t I NIPPLE;6,882.3 I SOS;6,889.9 11 IPERF;6,953.06,962.0 ] r I IPERF;6,971 0-7,004 0--I PRODUCTION;29.4-7,234.1 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. January 8, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 ZK.BENDER RE: Injection Profile : 1A-09 Run Date: 9/27/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-09 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20669-00 Injection Profile Log SCANNED 1 Color Log 50-029-20669-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: G ✓Qts- t,� 644(4, . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,July 20,2015 TO: Jim Regg P.I.Supervisor (e( ��i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-09 FROM: Bob Noble KUPARUK RIV UNIT 1A-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3TSP-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-09 API Well Number 50-029-20669-00-00 Inspector Name: Bob Noble Permit Number: 181-152-0 Inspection Date: 7/17/2015 Insp Num: mitRCN150719135851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - r- --T- Well 1A-09 [Type Inl I W-ITVD 6042 - Tubing 2200 - 2200 • 2200 • 2200 - PTD L- 181152o . TypeTest,i sPT Test P si I 1510 - IA 640 3000 ' 2900 • 2880- ;� Interval !4YRTST PAF I P " OA 1 120 250 - 250 250- Notes: Monday,July 20,2015 Page 1 of 1 Ima~roject Well History File Cover ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the onginal file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~"//- /~_~__ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes, No. [] //,G'~ayscale items: n Other. No/Type ~ Poor Quality Originals: [] Other: NOTES: [] Maps: [] Other items scannable, by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCEN~MARIA WINDY Project Proofing BY: ~ROBIN Scanning Preparation VINCENT SHERYL MARIA WINDY ~.~ x30 = ~'~' BEVERL~VINCENT SHERYL MARIA WINDY BEVERLY ROBIN~.~ SHERYL MARIA WINDY BY: Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN'SCANNIi~G PREPARATION: BY: /~ YES DATE: h l4"' 'S' NO Stage 2. IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY ROBIN VINCE~ARIA WINDY DATE',/ .,,./ ReScanned (i~tdiv~dual pa.qe [,~pecial afze~fion~' ~cannlncj ct~mple~ed) RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked (do.a) 12/10/02Rev3N OTScanned,wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2011 TO: Jim Regg {�'cl P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-09 FROM: Chuck Scheve KUPARUK RIV UNIT 1A -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT IA -09 API Well Number: 50- 029 - 20669 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS110727065759 Permit Number: 181 -152 -0 Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A -09 - IType Inj. W' TVD 6042 - IA 920 3020 - 2980 2970 - P.T.D 1811520 - { ITypeTest 1 SPT 1 Test psi 1510 OA 170 300 300 300 Interval 4YRTST P/F P ' Tubing 2425 2425 2425 2425 Notes: (1 )H Wednesday, July 27, 2011 Page 1 of 1 ~~~1~~ . ` t ~flno~ ~: hil~i ~ :...~ ~A~~. 2:~ ~. ~o;a .. . cof' ps . ~,,,~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ . Apri123, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: `? ~ ~;, ~: 1 Ni.~ i~,~- q ; ,~ Enclosed please fmd a spreadsheet with a list of wells from the Kuparulc field (KRL)).. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering.the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru April 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since L._ Perry ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4123110 1A. 1F. 1Q & 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF ri/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6/2010 1A=05 50029206270000 1811040 SF Na 6" Na 4.25 4/7/2010 1A-08 50029203130000 1780400 SF n/a 10" n/a 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" Na 2.55 4/2/2010 1A-15 50029207110000 1820170 SF n/a 4" Na 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" n/a 4.25 4/1/2010 1Q-02 50029212480200 2051420 22" n/a 22" n/a 7.2 4/6/2010 1Q-03 50029212490200 1842330 27" Na 27" n/a 3.4 4/6/2010 1 Q-05 50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1 Q-06 50029212240000 1842080 32" n/a 32" n/a 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" Na 32" n/a 3.82 4/1/2010 1 Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 471 /2010 1Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1/2010 1Y21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1/2010 1Y-24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1/2010 1Y-28 50029223800000 1930890 28" n/a 28" n/a 5.52 4/1/2010 1Y 31 50029223810000 1930900 6'8" 0.65 24" 3!2112010 5.52 4/1/2010 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Superviso DATE: Friday, July 20, 2007 FROM: Bob Noble Petroleum Inspector SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lA-09 KUPARUK RIV UNIT 1A-09 Src: Inspector \J' \ 5'r C6 \ NON-CONFIDENTIAL Reviewed By: P.I. Suprv J&!..- Comm Well Name: KUPARUK RIV UNIT IA-09 API Well Number: 50-029-20669-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070 7 ¡ ') 125703 Permit Number: 181-152-0 Inspection Date: 7/1512007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --~ ¡Type Inj. ! w I {IA. Well! IA-09 TVD I 6043 < 1400 i 3020 I 3000 3000 ! I I .(' ì i P.T.Di 1811520 !TypeTest 1 SPT Test psi I 3020 . OA ! ~5/) 160 i 160 160 I i I . ~ I ,/~ Tubing I 2300 I 2300 I 2300 2300 Interval 4YRTST P/F P i L~_ -- Notes: SCANNED AU G 0 6 2007 Friday, July 20, 2007 Page 1 of 1 07/23/07 Scblum~el'øep ~ "\. f! I::: ß# if:: NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ,JUL 2 5 Z007 SCANNED JUL 2 7 2007 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: I~!í:ì",ka Oil St Cons. Commission Anchorage u::r:c...-- t ~ I - is a. Field: Kuparuk Well Color CD Job# Log Description Date BL \1J 2M·20 11629044 PRODUCTION PROFILE 07/11/07 1 3M-20 11665456 INJECTION PROFilE 07/13/07 1 2M-27 11665457 INJECTION PROFilE 07/14/07 1 1R-20 11632727 lDL 07/12/07 1 2M-17 11632731 INJECTION PROFilE 07/14/07 1 3M-27 11632732 lDL 07/15/07 1 1R-15 11632734 INJECTION PROFilE 07/17/07 1 2L-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V-08A 11665459 USIT 07/16/07 1 2Z-16 11665458 SCMT 07/15/07 1 2N-343 11665463 INJECTION PROFilE 07/20/07 1 1 L-07 11632735 INJECTION PROFILE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM . State of Alaska _ Alaska Oil and Gas Conservation CommissP TO: Jim Regg Ml'; r¡ 01 3c fC& P.I. Supervisor 1 DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-09 KUPARUK RIV UNIT IA-09 \ t:/Y \~ \" FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv]6?- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-09 API Well Number 50-029-20669-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060824 I 43022 Permit Number: 181-152-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IA-09 Type Inj. w TVD 6043 IA 1835 2660 2660 2640 2640 P.T. 1811520 TypeTest SPT Test psi 1510.75 OA 660 670 670 670 670 Interval OTHER PIF P Tubing 2000 2000 2000 2000 2000 Notes Post seal-tite repair MIT. I well house inspected, no exceptions noted. / SCANNED SEP 082005 Wednesday, August 30,2006 Page I of 1 ~ - 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D tit Ol . r An~prage Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 181-152/306-218 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20669-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1 A-09 8. Property Designation: 10. Field/Pool(s): ADL 25647, ALK 465 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7255' feet true vertical 6539' feet Plugs (measured) Effective Depth measured 6995' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURF CASING 2142' 10-3/4" 2242' 2242' PROD CASING 7134' 7" 7234' 6520' Perforation depth: Measured depth: 6760'-6822',6953'-6962',6971'-7004' true vertical depth: 6098'-6152',6268'-6276',6284'-6314' SCANNED AUG ð 1 2006 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6850' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'DB' pkr= 6697'; 6862' Cameo TRDP-1A SSSV= 1844' 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-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Guy Schwartz @ 265-6958 p,;"'o<I Nom, Guy SC~ CJ Title Wells Group Engineer '-2.'::;-0 (.. Signature ~::. ~ Phone Date ""'- ~--~ PreDared bv Sharon AlfsuD-Drake 263-4612 _.I- ~ RBDMS BFL AUG 3 1 20 ",4b ß" -.t:> . ~ '-/ - . Form 10-404 Revised 04/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED AUG 3 0 2006 n o RIG 1 ~J/41 "Grl~~~mit Original Only KRU 1Ä-09 ConocoPhillips Alaska, Inc. 1A-09 API: 500292066900 Well Tvoe: INJ Anole ((j) TS: 29 deo ((j) 6759 SSSV Type: TRDP Orig 11/4/1981 Angle @ TD: 26 deg @ 7255 Comoletion: sssv Annular Fluid: Last W/O: 8/16/1985 Rev Reason: Pull PLUG, Set (1844-1845, 00:3.500) GLM #1 Reference Loo: Ref Loo Date: Last Undate: 8/18/2006 Last TaQ: 6995' RKB TD: 7255 ftKB Last Too Date: 10/312005 Max Hole Anole: 39 deo ((j) 5500 Casin STRINGS Descriotion Size Too Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 80 80 65.00 H-40 ¡ndrellDummy SURF CASING 10.750 0 2242 2242 45.50 K-55 Valve 1 (6621-6622, PROD CASING 7.000 0 7234 6520 26.00 K-55 00:5.797) Tubina Strina - TUBING Size 1 Too I Bottom I TVD 1 Wt 1 Grade I Thread 3.500 I 0 1 6850 I 6177 1 9.30 1 J-55 1 BTC AB-MOD Perforations Summarv SBR Interval TVD Zone Status Ft SPF Date Tvoe Comment (6665-6666, 00:3.500) 6760 - 6822 6098 - 6152 -3,C-2,C-1, 62 4 11/311981 IPERF 4" Hyperjet B 6953 - 6962 6268 - 6276 A-5 9 4 11/3/1981 IPERF 4" Hyperiet 6971 - 7004 6284 - 6314 A-4 33 4 11/3/1981 IPERF 4" Hvoeriet Gas Lift MandrelsNalves PKR St I MD I TVD I Man Man Type I V Mfr I V Type V OD I Latch I Port I TRO Date I Vlv (6697-6698, Mfr Run Cmnt 00:6.156) 1 I 66211 59761 Camco I MMG-2 I I DMY 1.5 I RK 1 0.000 1 0 8/16/20061 Iniection MandrelsNalves St I MD I TVD I Man Man Type I V Mfr I V Type V OD I Latch I Port I TRO Date I Vlv Mfr Run Cmnt 2 I 67281 6070 I Camco I KBUG I 1 DMY 1.0 I BK 1 0.000 I 0 8/17/19851 Closed Injection Other (I luos, eQUiD., etc.\ - JEWELRY 'ndrel/Oummy Depth TVD Tvpe DescriDtion ID Valve 2 1844 1844 SSSV Camco TRDP-1A 2.813 (6728-6729, 6665 6015 SBR Baker 2.813 00:5.313) 6697 6043 PKR Baker 'FHL' 3.000 - - 6835 6164 SLEEVE-O 2.75" AVA TPI set 10/22/2005 2.310 Perf 6835 6164 NIP AVA BPL PORTED NIPPLE 2.750 (6760-6822) - - - - 6849 6176 XO 2.875 - - 6850 6177 PUP 2.441 6862 6188 PKR Baker 'DB' 4.750 6882 6205 NIP Camco 'D' Nioole NO GO 2.250 6890 6212 SOS Camco 2.992 SLEEVE-D 6891 6213 TTL 2.992 (6835-6836, 00:2.750) General Notes Date 1 Note 1018l200511A LEAK ®2574' lTecWelleak detect 1(0) ,¡ PKR (6862-6863, 006.156) PUP (6850-6891, 00:2.875) NIP (6882-6883, 00:3.500) SOS (6890-6891, 00:3.500) TTL (6891-6892, 00:3.500) Perf - I--- (6953-6962) - I--- - I--- - I--- - t= Perf - (6971-7004) - I--- - I--- - I--- DATE 8/15/06 8/16/06 8/17/06 8/22/06 1A-09 Well Events Summary Summary SEAL TITE PC LEAK @ 2,574' WITH 3 BBLS OF FLO-SEAL SET DV @ 6621' RKB. MITT 3000 PSI, PASSED. LEFT 3000 PSI ON IA FOR CURING SEALANT. IN PROGRESS. PULLED 2.81" PXX PLUG FROM SBR @ 6665' RKB. MITIA-PASSED , POST SEAL-TITE IA LEAK (WITNESSED) I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleekenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /1A 08/22/06 Sauvageau/Noble - AES Jeff Jones 5~ ~\"\ \ Packer Depth Pretest Initial 15 Min. 30 Min. Weld 1 A-02 , Type In;' I W TVD I 5,908' TubinQ 1900 1900 1900 1900 Interval 0 P.T.D./1810710 I Type test I P Test psi I 1500 Casing 1140 2550 2540 2540 P/FI P Notes: MITIA as required by sundry approval 306-217 for OA 680 700 700 700 repair of IA leak at 3028'. Sealtite sealant was squeezed into leak on 8/14/06. Weld 1 A-09 I Type In;' I W TVD I 6,043' Tubing 2000 2000 2000 2000 Interval 0 P.T.D./1811520 I Type test I P Test psi I 151 O. 75 Casing 1865 2660 2660 2640 P/FI P Notes: MITIA as required by sundry approval 306-218 for OA 660 670 670 670 repair of IA leak at 2574'. Sealtite sealant was squeezed into leak on 8/15/06. Weill I Type In;' I TVD I TubinQ Interval p.T.D.1 I Tvpe test I Test psi I Casing P/FI Notes: OA Well' I Type In;' , TVD I TubinQ Interval P.T.D.I I Type test I Test psi I Casing PIF/ Notes: OA Weill I Type In;' I TVD I TubinQ Interval P.T.D.I I Type test I Test psi I Casing PIF/ Notes: OA Well I Type Inj. I TVD I Tubing Interval P.T.D.I / Type test I Test psi I Casing P/FI Notes: OA Weill I Type In;' I I TVD I TubinQ J nterva P.T.D.I I Type tesd Test psi I Casing P/F Notes: OA D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 1A Pad 08-22-06.xls Re: lA-02 (181-071) and lA-09 (181-152) FOI up , . MJ, It appears that your repairs have been successful as evidenced by the witnessed MITs on August 22. Your plan is acceptable. Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 8/28/2006 4:27 PM: Tom, Jim, ~ANNED AUG 2. 9 2.DDô Subsequent to the recent Sealtite repair treatments (10-403/404 Sundry #'s 306-217 and 306-218) and following passing State Witnessed MIT's on wells 1A-02 (181-071) and 1A-09 (181-152), ConocoPhillips intends to return these injection wells to a normal 4 year MIT cycle and remove them from the failed MIT report. ConocoPhillips would like confirmation from the Commission that the plan is acceptable. Please let me know if you have any questions regarding the treatments or the MIT results. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 1 of 1 8/29/2006 9:31 AM KRU MIT data 8/22/06 . . Tom, Jim, & Bob, Attached are passing KRU MITs as witnessed by Jeff Jones on 8/22/06. 3S was the last KRU drill site due for MITIAs in August. C02 is still due this month and is tentatively planned for this weekend. 1A-02 & 1A-09 MITs were completed due to recent repair work. CPAI will be in contact to discuss regulatory requirements to leave these wells on injection post repair. At this time, both wells remain on the failed MITIA report. 10-10 MIT was an initial MITIA post RWO. The RWO replaced rotten tbg. This well has been removed from the failed MITIA report. I am leaving the slope this afternoon, please let Perry Klein know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1A Pad 08-22-06.xls» «MIT KRU 10-10 08-22-06.xls» «MIT KRU 3S PAO 08-22-06.xls» Content-Description: MIT KRU lA Pad 08-22-06.xls MIT KRU lA Pad Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU ID-IO 08-22-06.xls KRU ID-IO 08-22-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU 3S PAD 08-22-06.xls MIT KRU 38 PAD 08-22-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 8/29/2006 9:27 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /1A 08/22/06 Sauvageau/Noble - AES Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. We1l11A-02 I Type Ini. I W TVD I 5,908' Tubing 1990 1900 1900 1900 I nterval 0 P.T.D.!1810710 I Type test I P Test Dsil 1500 Casinç¡ 1140 2550 2540 2540 P/FI P Notes: MITIA as required by sundry approyal 306-217 for OA 680 700 700 700 repair of IA leak at 3028'. Sealtite sealant was sQueezed into leak on 8/14/06. 10-404 re[ ort to be submitted. Well!1A-09 I Type Ini. I W I TVD I 6,043' Tubing 2000 2000 2000 2000 I ntervall 0 P.T.D.!1811520 I Type test I P Test Dsil 1510.75 Casing 1865 2660 2660 2640 P/FI P Notes: 45 min TIIIO: 2000/2640/670. Sundry 306-218 for OA 660 670 670 670 repair of IA leak at 2574'. Sealtite sealant was saueezed into leak on 8/15/06. 10-404 re[ ort to be submitted. Weill I Type Ini. I TVD 1 Tubing I ntervall p.T.D.1 I Type test I Test Dsil Casing P/FI Notes: OA Weill I Type Ini. I TVD T Tubing Interval I P.T.D.I I Type test I Test Dsil Casing P/FI Notes: OA Weill I Type Ini. I TVD I Tubing I ntervall p.T.D.1 I Type test I Test DSi! Casinç¡ P/FI Notes: OA Weill I Type Ini. I TVD I Tubing Interva¡ p.T.D.1 I Type test I Test Dsil Casinç¡ P/FI Notes: OA Weill I Type Ini. I TVD I Tubinç¡ I ntervall p.T.D.1 I Type test I Test psil Casino P/FT Notes: OA D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 1A Pad 08-22-06.xls l't/-/ S-J @ 11 ¡~\ II feE @LLnlUlb '~n ~.í7ì n I. I. d 1.1 r.· I ß~ .¡ !.! !U! ¡ ¡U\ I ¡ \.;;;;;.,..I '-' l..iU ~ 1.'-" .C~ 11¡~1 ,~ß ~ \ i. 11,' In\. 1..:::.J U'..1 u U ie f FRANK H. MURKOWSKI, GOVERNOR / j I / I f j 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 AI,ASIiA OIL AND GAS CONSERVATION COMMISSION Guy Schwartz Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1A-09 Sundry Number: 306-218 ~CMNs.ü?: ,j~ Dear Mr. Schwartz: 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 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 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 if 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. Sincerely, DATED thisÆay of June, 2006 Encl. ,tt - IS- ¡) e ConocriP'hillips e Guy Schwartz Wells Group Engineer Drilling & Wells P, 0, Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 June 16, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 1 6 2006 Subject: Application for Sundry Approval for 1A-09 .Alaska Oil & Gas Cons. Commission Anchorage /r \q\...l~ Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming well work on the Kuparuk weIl1A-09. If you have any questions regarding this matter, please contact me at 265-6958. Sincerely, Gc;¡Æ; Wells Group Engineer CPAI Drilling and Wells GS/skad ~~ ~J)? J£ ør,!Y1/tv. ,5c;1v:.. RECEIVED . STATE OF ALASKA JUN 1 ALASKA Oil AND GAS CONSERVATION COMMISSION 6 2006 APPLICATION FOR SUNDRY APPROV A~/8ska Oil & Gas Cons. Commission 20 MC 25 280 Anch 181-152 6, API Number: 50-029-20669-00 9. Well Name and Number: 1 A-09 1, Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Alter casing 0 Repair well 0 Plug Perforations 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 2, Operator Name: 4. Current Well Class: ConocoPhillips Alaska, Inc. Development 0 3. Address: Stratigraphic 0 Perforate 0 o Stimulate Exploratory 0 Service 0 P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 100' 8. Property Designation: ADL 25647; ALK 465 11. Total depth MD (ft): 7255' Casing Waiver oraae o o o Other 0 Time Extension Re-enter Suspended Well 5. Permit to Drill Number: . 10, Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): Total Depth TVD (ft): Effective Depth MD (ft): 6539' 6995' Length CONDUCTOR 80' SURF CASING 2242' PROD CASING 7234' Size MD TVD Burst Collapse 16" 80' 80' 10-3/4" 2242' 2242' 7" 7234' 6520' Perforation Depth MD (ft): 6760'-6822',6953'-6962',6971'-7004' Packers and SSSV Type: pkr= BAKER 'FHL'; BAKER 'DB' Camco TRDP-1A 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14, Estimated Date for Commencing Operations: 16, Verbal Approval: Commission Representative: Perforation Depth TVD (ft): 6098'-6152',6268'-6276',6284'-6314' Packers and SSSV MD (ft) pkr= 6697'; 6862' 1844' Tubing Size: 3-1/2" 13. Well Class after proposed work: Exploratory 0 Development 0 15, Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 June 26, 2006 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Guv Schwartz / Signature 6'u.., C7r1( , / ~ Commission Use Only I Contact: Title: Phone 265-6958 Conditions of approval: Notify Commission so that a representative may witness Tubing Grade: J-55 Tubing MD (ft): 6850' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Guy Schwartz @ 265-6958 Wells Group Engineer Date t -1'- "" Sundry Number: ,... , " ?t1l Ð - ,;.£..1 -n Plug Integrity 0 BOP Test 0 Mechanical Integrity Test g location Clearance 0 Other: c.cf'~~.:U~ç>Ec...~ð]~ c.~\NÀ\-~ ~ \.\ G¡~\ kQ\-~~1- ,d ~,) R8DMS BFl,lUN 8,,,,,,,,", Fo," Re,,;",'c '-'OJ aT J Á 1.1t A APPROVED BY 2 0 :~-t)-6 Approved by: V P W l COMMISSIONER THE COMMISSION Date: ..........0 R'le1 N 1\ 1'- 4u 4 'I?·ô(:. Form 10-403 Revised 7/2005 . , \J In.... ~i¢~7æ ConocoPhiUips Alala, Inc. . KRU 1ðt -09 . 11A-09 API: 500292066900 Well Tvpe: INJ Anole @ TS: 29 deo @ 6759 SSSV Tvpe: TRDP OriQ Completion: 1114/1981 Anole @ TD: 26 dea @ 7255 Annular Fluid: Last W10: 8116/1985 Rev Reason: PULL PLUG (Ii> 6882' SSSV Reference Loa: Ref Loa Date: Last Update: 519/2006 (1844-1845. I - Last Tao: 6995' RKB TD: 7255 ftKB OD:3.500) - Last TaQ Date: 101312005 Max Hole AnQle: 3~5500 - ILL Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 65,00 H-40 SURF CASING 10,750 0 2242 2242 45,50 K-55 - PROD CASING 7.000 0 7234 6520 26.00 K-55 Gas Lift I UDInQ ~trlna - TUBING I ndrel1Dummy Size Top I Bottom I TVD I Wt I Grade I Thread Valve 1 (6621-6622, 3.500 0 I 6850 I 6177 I 9.30 I J-55 I BTC AB-MOD OD:5.797) Interval TVD Zone Status Ft SPF Date Type Comment 6760 - 6822 6098 - 6152 C-3,C-2,C-1,l 62 4 1113/1981 IPERF 4" Hype~et B SBR 6953 - 6962 6268 - 6276 A-5 9 4 11/3/1981 IPERF 4" Hvperiet (6665-6666. 6971 - 7004 5284 - 6314 A-4 33 4 IPERF 4" Hvperiet OD:3,500) ,Gas Lift St MD TVD Man Mfr Man Type V Mfr I V Type I V OD I Latch Port I TRO I Date I Vlv Run Cmnt 1 6621 5976 Cameo I MMG-2 I DMY I 1,5 I BK 0,000 I 0 I 91111985 I PKR St MD TVD Man Mfr Man Type V Mfr I V Type I V OD I Latch Port I TRO I Date I Vlv (6697-6698, Run Cmnt OD:6.156) 2 6728 6070 Cameo I KBUG I DMY I 1.0 I BK I 0,000 I 0 I 8/1711985 I Closed Other (I IUQs. eauip.. etc.) _II=WI= QV Depth TVD Type Description ID 1844 1844 SSSV Cameo TRDP-1A 2.813 6665 6015 SBR Baker 2.813 6697 6043 PKR Baker 'FHL' 3.000 Injection .. 6835 6164 SLEEVE-O 2.75" AVA TPI set 1012212005 2,310 1 ndrelfDum my 6835 6164 NIP AVA BPL PORTED NIPPLE 2,750 Valve 2 6849 6176 XO 2,875 (6728-6729. 6850 6177 PUP 2,441 OD:5,313) 6862 6188 PKR Baker 'DB' 4,750 - 6882 6205 NIP Cameo 'D' Nipple NO GO 2.250 Perf - 6890 6212 SOS Cameo 2,992 (6760-6822) - - 6891 6213 TTL 2.992 - - Notes - - Date I Note - - 101812005 IIA LEAK @2574' lTeeWelleak detect 1001 SLEEVE-O (6835-6836, OD:2,750) .. I PKR (6862-6863. OD6.156) PUP (6850-6891. OD2.875) NIP (6882-6883, OD:3.500) SOS (6890-6891 , OD:3.500) TTL (6891-6892, OD:3,500) Perf - - (6953-6962) - - - - - - - == Perf - (6971-7004) - - - - - - ./ e e lA-09 IA Repair Procedure 6-14-06 Well Background: 1A-09 fails an MITIA with a leak rate of about .5 gaVmin. at 3300 psi. The IA leak also (just like 1A-02) apparently communicates with the OA open shoe. The well passes an MITT so indicates that the leak was somewhere in the 7" casing. With such a small leak conventional leak detection methods were not adequate so CP AI enlisted TECWEL (Ultrasonic Leak tools) to help find the leak path. The tool successfully pinpointed the " leak at 2574' md behind pipe in the 7" casing (the 10 %" surface casing is set at 2242' md). Plan forward to repair the well is to use Sealtite by spotting product across the known leak point and squeezing the sealant into the leak. If successful this will allow the IA to test and return the well to injection. ' Procedure Outline: 1. RIH and set WRP plug in tubing at 6650' mdjust below bottom GLM @ 6621' md. 2. Pull DV in GLM (6621' md) and circulate 9.8 ppg brine around tubing! IA until stable. 3. Pump 2 bbls SeaLTite sealant (sealant is 9.4 ppg) from surface into IA (returns taken up tubing side). 4. Displace sealant to leak area with diesel to the leak pt. (Sealant will float on top of the 9.8 ppg brine). 5. Shut in at surface and bullhead sealant into the formation. Hold 1000 psi differential and allow to cure 4 hours. Increase to 2000 psi and hold for 8 hrs. Lock in pressure for 7 days and allow to cure. 6. Pull WRP plug! replace DV and MITIA after 7 day cure time is complete. 7. Return well to injection. . Final Job Report Manufacturer: TecWel AS Document no. : IN-WLD2005 09-077 4 Appendices 4.1 Log-LeakPoint .. c.. , ,~-- . .... . ... , ..-- -' ,- ... " "i=" ., -, . .. ,. ,- ... .,- ,., ........ - .. ..... ., \ ~ ... ... . .... ...... " ,., ~ ...... ....... .. ... " --- -~" .. ... ,- ,_. ~..._.... ., .. .. .. . "''' ,.- - .. I ... ... i-' .. .,', '.. .... ¡...- ¡. .,.. 'm. . I:mmII a Revision 0 26QO '~ 1m þ~ ... I I \.,5···· ··1 ... . ! $ it .. .' ~; i .... ... - .. , ., _n -.". >-",., .,.. ...-- _,n' ~~ '. ,<~, ., d2.., .. '; ... f····· ., .... ...., , ¡...... .. . ~i2 1- :"""4" ì :;;;> = ""I c¡¡ .~"t,.... ._, :!~=t= .'. ,nm . .. ,. ,-:": .... ... ,- !~n -.- ... " 1m ....¡- ....... ....... .," .._- , , ... , :!;.. ..' ¡, 0-.- -, .. )..... ... ,- ".. -"" ,. -~ . -.-^ ~- _~t[: ¡ f , ¡...... , .- 1- .. .... f··· .... ... .. +." I·" .' ... I· .. ,(? .. .' .. ~... .... ,. ... , .. .., ". ! ... ..... ¡. .... ,- ,...." !,. I- i- ".... ...... " .,. ¡ ",. .., . ,m ¡.. .. , Page 3 of 9 10-31-05 ..Tecwel report for lA-02" . . \ <6\-O~ , Tom, Here is the report and data we got for 1A-02. similar. Can't find my electronic copy of 1A-09 but it is very (4 \¥\-.\ ~J The sundries are headed your way!! Thanks, Guy «FJR-1A-02.pdf» Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com Content-Description: FJR-IA-02.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/19/200610:01 AM RE: lA-09 (PTD 1811520) cause off ailed MW identified by ne... e Sub.icct: RE: lA-09 (PTD 1811520) cause ofÜliled MlTlA identiiied by new LDL tool From: NSK Problem vVell Supv <n1617@conocophillips.com> Date: Mon, 17 Oct 2005 09:21 :53 -0800 To: NSK Problem Well Sup\' <n1617@conocophillips.com>, Thomas Maunder <tom _ maunder@~admin.statc.ak.lIs> CC: James Regg <jim_regg@admin.state.ak.us> Tom, The other wells are: 3G-24 - tbg leak found between bottom GLMs at 9346' 3F-13A - Tbg leak to OA found in the packer at 5678' 30-19 - casing leak found in the liner at 5512' All these will have sundries for repair that will report the leak depths once a repair plan is decided. Marie -----Original Message----- From: NSK Problem Well Supv Sent: Monday, October 17, 20059:14 AM To: 'Thomas Maunder' Cc: 'James Regg' Subject: RE: lA-09 (PTD 1811520) cause of failed MmA identified by new lDLtool " Tom, The work load here is such that if a report isn't required there isn't time or resources to create it or it would take time away from monitor the wells for integrity and catching any compliance issues to avoid NOVs, our highest priority. The email was something I sent you as a courtesy as I thought you'd be interested from both a well and engineering prospective. This work will be reported on the summary list of completed wellwork submitted to AOGCC as required. If a repair is made on this well, the sundry will mention the leak depth. Yes, our internal guidelines have changed, internal waivers are no longer issued for failed MITIAs if the well also had a failed MITOA. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, October 17, 20058:01 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: lA-09 (PTD 1811520) cause of failed MmA identified by new LDL tool Marie, Good news on the new diagnostic tool. Is it possible to submit a "report" of the work on lA-09? You could submit it with a 404. What are the other wells that you indicate were successfully logged? You state that lA-09 no longer meets CP AI internal requirements. Have the internal requirements changed? Look forward to your reply. lof2 3/6/2006 10: 18 AM RE: lA-09 (PTD 1811520) cause off ailed MIl identified by ne... e Tom Maunder, PE AOGCC , NSK Problem Well Supv wrote, On 10/16/2005 4:18 PM: Tom, This note is to inform you of recent diagnostic results on 1A-09 (PTD 1811520). This well has a failed MITIA (Sundry approval 303-307) that was assumed to be a packer or casing leak as an MITT wlTTP passes. The leak rate was too slow to identify the depth with known logging tools. A new ultrasonic leak detect logging tool (tecwel) was ran in the well on 10/8/05 and identified the leak depth at 2574'. I reviewed the 303-307 sundry for the failed MITIA and didn't see any issues. CPAI has determined this well no longer meets our internal requirements and the well has been SI. The leak is in close proximity to the OA cmt shoe and the OA shoe leaks. At this time, it is uncertain when or how the well will be repaired, but the appropriate sundry will be submitted at that time. Tecwel can measure leak rates down to something around a quart or cup per minute. Three other wells with small leaks were logged successfully. Marie McConnell Problem Well Supervisor 659-7224 20f2 3/6/2006 10: 18 AM TO: Jim Regg P.I. Supervisor State of Alaska ) Alaska Oil and Gas Conservation Commi ) DATE: Thursday, April 07, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lA-09 KUPARUK RIV UNIT lA-09 ~y " ~Oo MEMORANDUM FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ 4 fZ,lfor;' Comm Well Name: KUPARUK RlV UNIT lA-09 Insp Num: mitJJ050331212343 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20669-00-00 Permit Number: 181-152-0 Inspector Name: Jeff Jones Inspection Date: 4/1/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lA-09 Type Inj. S TVD 6043 IA 290 3300 2980 I 2800 P.T. 1811520 TypeTest SPT Test psi 1510.75 OA 450 490 500 500 Interval OTHER P/F F Tubing 2500 2500 2500 2550 Notes: Well has known tubing by IA communication. 6.3 BBLS diesel pumped. 1 well house inspected, no exceptions noted. SCANNED MAY 3 1 2005 Thursday, April 07, 2005 Page 1 of 1 SSSV (1844-1845, 00:3.500) Gas Lift 1drel/Oummy Valve 1 (6621-6622, 00:5.797) SBR (6665-6666, 00:3.500) PKR (6697-6698, 00:6.156) Injection 1drelIDummy Valve 2 (6728-6729. 00:5.313) Perf (6760-6822) SLEEVE-O (6835-6836, 00:2.750) PKR (6862-6863, 00:6.156) NIP (6882-6883, 00:3.500) PUP (6850-6891, 00:2.875) SOS (6890-6891 , 00:3.500) Perf (6953-6962) Perf (6971-7004) ConocoPhUUps J )ska~ Inc. LJI I :-',.:-:':::-::::::"::::'::::::':;:::;:":'::'::' ........................................... ___4!...i,,!\'~..l . . ;':: A ù~ ·········w¿ '11'-"""'" "" .':;";;:: .',0"" ."'~,,. o - I =E =E =t 1A~09 API: 500292066900 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 6992 Last Tag Date: 9/5/2004 CåsingSttiog···ALL.. STRINGS Description CONDUCTOR SURF CASING PROD CASING TlIbil'1g String 'TUBING Size I Top 3.500 0 Pél10rati Oris.' Summary Interval TVD 6760 - 6822 6098 - 6152 ...L- Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: ) KRU 1A-09 INJ 11/4/1981 8/16/1985 Angle @ TS: 29 deg @ 6759 Angle @ TD: 26 deg @ 7255 Rev Reason: TAG FILL Last Update: 9/6/2004 7255 ftKB 39 deg @ 5500 Size 16.000 10.750 7.000 Top o o o 6953 - 6962 6268 - 6276 6971 - 7004 6284 - 6314 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr Mfr _ 1 6621 5976 Camco MMG-2 InjêCtiol1·.Maric:lrèlslVàlvès St MD TVD Man Man Type V Mfr Mfr 2 6728 6070 Camco KBUG Othêr{plugs, eqlli:);, etc.) . JEWELRY Depth TVD Type 1844 1844 SSSV 6665 6015 SBR 6697 6043 PKR 6835 6164 SLEEVE-O 6835 6164 NIP 6849 6176 XO 6850 6177 PUP 6862 6188 PKR 6882 6205 NIP 6890 6212 SOS 6891 6213 TTL Gèné"alNdtes Date I Note 11/18/2001 WAIVERED WELL - T x IA communication Bottom 6850 Zone :>3,C-2,C-1,l B A-5 A-4 Status Bottom 80 2242 7234 TVD 80 2242 6520 Wt 65.00 45.50 26.00 Grade H-40 K-55 K-55 Thread TVD 6177 Wt 9.30 Thread BTC AB-MOD Grade J-55 Ft SPF 62 4 Date Type Comment 11/3/1981 IPERF 4" Hyperjet 9 33 4 11/3/1981 IPERF 4" Hyperjet 4 11/3/1981 IPERF 4" Hyperjet VOD Latch Port TRO Date Vlv Run Cmnt 1.5 BK 0.000 0 9/1/1985 V Type DMY V Type VOD Latch Port TRO 1.0 BK 0.000 0 Description ID 2.813 2.813 3.000 2.310 2.750 2.875 2.441 4.750 2.250 2.992 2.992 DMY Date Vlv Run Cmnt 8/17/1985 Closed Cameo TRDP-1A Baker Baker 'FHL' 2.75" AVA TPI with 19/64" port; set 7/17/04 AVA BPL Ported Nipple Baker 'DB' Camco 'D' Nipple NO GO Cameo IA-09 MITrA 04-01-05.xls ) ') Subject: 1A-09 MITIA 04-01-05.xls From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sat, 02 Apr 2005 13:43:43 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: jim _regg@admin.state.ak.us .\ ~\ ~~S·~ Tom, Attached is a MITIA that failed on 1A-09 (PTO 1811520) on 04-01-05. This well is currently a water injector operating under the sundry # 303-307 due to a previous failed MITIA. If we were able to obtain a successful MITIA, our plan was to put the well on MI. However, since the MITIA failure we will now continue to operate under the current sundry of water injection only. This well is being considered a candidate for a rig workover to solve the problem. Please call with any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907 -659-7224 «1A-09 MITIA 04-01-05.xls» Content-Description: 1A-09 MITIA 04-01-05.xls lA-09 MITIA 04-01-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 SCANNE[} IJ. P R 1. ¿~ 2005 1 of 1 4/5/2005 8:31 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Emaíl to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk River Unit/1A 04/01/05 Sauvageau/Rogers Jeff Jones :~~} ~r\J Packer Depth Pretest Initial Well 1 A-09 Type Inj. S TVD 6,043' Tubing 2,500 2,500 P.T.D. 1811520 Type test P Test psi 3000 Casing 290 3,300 Notes: MITIA was conducted to determine if MI was possible. OA 450/490/500/500 15 Min. 30 Min. 2,500 2,550 Interval 0 2,900 2,800 P/F F Interval P/F Interval P/F Interval P/F Interval P/F Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 1 A-09 MITIA 04-01-05.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg --- - 7/lb. 1D1 P.I. Sup;~'isor k t'iti DATE: Wednesda~. June 30. 20(14 SlIBJECT: !\.techanicallntegrlt) Tests CONOCOPHILLlPS ALASKi\ rNC FROM: John Crisp Petroleum Inspector IA-09 KUPARUK RIV UNIT IA-09 Src: Inspector Reviewed Bv: P.I. Supn' '561.2- Comm NON-CONFIDENTIAL \Vell Name: KUPARUI\. RIV UNIT I A-09 Insp Num: mitlCr040628 1 63400 Rellnsp Num: API Well Number: 50-029-20669-00-00 Permit Number: 181-152-0 Inspector Name: John Crisp Inspection Date: 6/27/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IA-09 IT~'pe Inj. N TVD 6539 IA -lOCI -100 -100 -100 P.T. 18115~0 TypeTest SPT Test psi I:; 10.7; OA -100 -100 -100 -100 Interval REQVAR P/F P Tubing 0 3000 ~930 :!890 Notes: 2 year 1\IITT wI TTP. Sundry 303-307. This !\.IITT for known T~ M.4))k:\!x'J~ Q:\,,\:\'f.-4t~"\ I J(1.r¿ 7f/bloJ,- Wednesday. June 3O. 200..\ Page I of 1 UIC File Review Date: Subject: PTD #: Orders: Reviewers: Initiating Action: October 14, 2003 ConocoPhillips KRU Well lA-09 (Water Injector) 182-162 CO 173 originally and most recently CO 432 B AIO 2B and prior versions Tom Maunder, P.E. k©] i~ Application for Variance Review Summary 1. According to the available records, lA-09 was converted to a water injection well in February 1986. It was converted to a WAG injector in February 1990. On August 30, 2000 the well failed the normal 4-year MIT. The Commission was notified and the well was converted to water injection. A diagnostics plan was agreed to and the well remained in service. The diagnostics were performed in early December 2000. The conclusion of the diagnostics was that there was a packer leak or a production casing leak. The calculated leak rate based on the pressure loss was 0.16 gpm (1.25 pints/min). This leak rate is below the threshold of the available logging tools. The well successfully demonstrated tubing integrity. On December 21, ARCO submitted a sundry notice (300-316) requesting to keep the well in service. 2. Apparently that sundry notice was never returned to ARCO, although I do remember working on this issue. The sundry was submitted immediately after the Commission office was moved and during that process some documents were lost. 3. ConocoPhillips and its predecessors did obtain email approval to keep the well in WATER ONLY service and has been operating the well according to the guidelines established for injection wells with known communication. The well most recently passed a MITT on July 19, 2002. 4. Chronological Review of files revealed: a. CO 173 originally (May 6, 1981), most recent order CO 432 B (December 12, 2002) b. AEO: EPA exempted all aquifers for the Kuparuk River oil and gas field [40 CFR 147.102(b)(3)]. c. AIO 2 (June 6, 1986) - Class II underground injection authorized within the KRU. The well is located within the authorized area. Note: There are differences in the well conversion date and the effective order date. Alaska was delegated primacy for the Class II UIC program in the state on June 19, 1986. d. MIT II was assessed December 10, 1987 and again June 23, 1995. "MI indicated" was determined on both occasions. e. The most recent information in the well file is dated February 8, 1990. o Technical Evaluation of Request - Submitted monitoring records indicate that ConocoPhillips has been operating the well within the guidelines for established for operating injection wells with known communication. There appears to have been a paper work "glitch" regarding the originally submitted sundry notice. Approving this 403 application will not promote waste or the movement of water outside of the intended injection zones. This is no fresh water to protect. Recommendation File Review indicates compliance with provisions of 20 AAC 25, CO, and AIO (as superceeded). Approval of ConocoPhillips' request is recommended subject to following conditions: a. The well may remain in WATER ONLY service. b. Submit monthly report of daily well pressures (T/FO) and injection rate. c. If monitoring data indicates any further integrity loss, the Commission must be notified and a new action plan determined. d. If ConocoPhillips believes that a determined integrity loss could result in fluids being injected into strata other than the Kuparuk formation, injection must cease and the well secured. e. Perform tubing integrity test MITT every 2 years. STATE OF ALASKA !'" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program [--1 Suspend E~] Operation Shutdown r-'] Perforate Repair well [--] Plug Perforations [~ Stimulate Pull Tubing [--1 Perforate New Pool [--1 [-'] Variance E~] Time Extension Re-enter Suspended Well Anr~ular Disp. r-~ Other [] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development r-] Exploratory r-] Stratigraphic r-] Service E~] 5. Permit to Drill Number: 181-152 6. APl Number: 50-029-20669-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-09 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk 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): 7255' 6539' 7134 6430 Casing Length Size MD TVD Burst CONDUCTOR 80' 16" 80' 80 SURF CASING 2142' 10-3/4" 2242' 2242 PROD CASING 7134' 7" 7234' 7234 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 6760-6822', 6953-6962', 6971-7004' 6098-6152', 6268-6276', 6284-6314' 3-1/2" ? :i'"'," J-55 Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'FHL'; BAKER 'DB' pkr= 6697'; 6862' SSSV= SSSV SSSV= 1844' 2. Attachments: Description Summary of Proposal [~1 13. Well Class after proposed work: Detailed Operations Program r-1 BOP Sketch O Exploratory FI Development r'"l .... ,, , ' '~e'rVide'~ []":};' 15. Well Status after proposed work: 14. Estimated Date for Commencing Operations: 12/2000 16. Verbal Approval: Date: 8/31/01 T. Maunder Collapse Tubing MD (ft): , ~ '{',i.i;)"6~91' ,,. ,.:: &".:.~j:~,," Oil r'] Gas ['~ Plugged ['-1 Abandoned E~] WAG r-~ GINJ r-~ WINJ r-] WDSPL r-1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. !;:ignatiuS?me UJ Loveland.~' ~ ~ Contact: MJ Loveland/Nina Woods Title: Problem Well supervisor Phone 659-7224 Date /~,J~.j~ ~'~ Conditions of approval: Notify Commission so that a representative may witness ISundry Number: 3~ - ..~ ~ Plug Integrity r'-] BOP Test F1 Other: Mechanical Integrity Test ['-~. Location Clearance E~ ...... ............. ,. ,..,, Approved by: COMMISSIONER THE COMMISSION Date: , ORIGINAl,.._ SUBMIT IN DUPLIOATE Form 10-403~~Revised 2~2003 · Phillips Alaska, Inc. Kuparuk Well lA-09 SUNDRY NOTICE 10-403 VARIANCE REQUEST 10/03/03 The purpose of this Sundry Notice variance request is for approval to continue water-only injection with a failed MIT. DS lA-09 is an injection well that failed its 4-year UIC MIT on 8/30/00. The AOGCC was notified at that time of the failure and an action plan for diagnostics was approved. A tubing plug was set on 11/27/00. On 12/1/00 diagnostics were performed with the following results: · An MIT-tubing passed @ 3000 psi. Initial / 15 minute / 30 minute tubing pressures were 3000/2900/2900 psi. · A combination T x IA MIT (CM1T T x IA) failed. Initial T/I/O: 3140/3000/400 psi, 15 minute: 3100/2750/400 psi, 30 minute: 3060/2625/400 psi. · The tubing was bled to 1000 psi and an MIT-IA was performed: T/I/O: 1100/3000/400 psi, 15 minute: 1100/2750/400 psi, 30 minute: 1100/2550/400 psi. · The leak rate into the IA was calculated over a 1-hour time period to be 0.16 gpm. The diagnostic tests indicate a leaking packer or production casing. The tubing is competent based on the MITT results. There were no indications of Tubing x IA communication. Previous . wellhead pack-off tests passed on both the tubing and production casing hangers. There is no evidence of IA x OA communication. The liquid leak rate (LLR) into the IA is too low for logging tools to determine the IA leak point. Since the original diagnostics were completed the following follow-up compliance diagnostics have been completed · An MIT-tubing passed @ 3600 psi. Initial / 15 minute / 30 minute tubing pressures were 3600/3450/3450 psi. The following Action Plan is proposed to support the variance request for continued injection: ACTION PLAN 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform MIT-tubing every 2-years to at least 2500 psi ( 0.25 x 6043' tvd @ packer = 1510 psi); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut-in the well should MITs or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notificationl NSK Problem Well Supervisor 12/11/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@ admin.state.ak, us and Bob_Fleckenstein @ admin.state.ak, us OPERATOR: FIELD / UNIT / PAD-' DATE: OPERATOR REP: AOGCC REP: Phillips Alaska Inc. KRU lA 07/19/02 Jerry Dethlefs Not witnessed Packer Depth Pretest Initial 15 Min. 30 Min. WelIJlA-09 I Type~njl N ! T.V.D. I 6015 ITubin~ll 25001 36001 34501 340011nterval"i' V P.T.D. I1811520 I Type T&stI P I Test psiI 2500 I Casing I 375l 3751 3751 3751 P/F I P Notes: AOGCC Sundry requiring. MITT every 2 years. Test against A-2 tubing plug set @ 6882' md. WellI I Type injI' IT.V.D. I ~ Tubin~l I "' I I I I Interval I P.T.D.I I Type Test, , Test psiI 1500 ! Casing I I I I Ip/F j Notes: P.T.D.I Notes: T.V.D. T.V.D. T.V.D. P.T.D.I Notes: P.T.D.I Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1A-09 07~19-02.xls 10/3/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance X Perforate _ Other _ Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360 Anchorage, AK 99510-0360 Location of well at surface 4711' FNL, 4789' FEL, Sec. 5, T11N, RIOE, UM At top of productive interval 1369' FNL, 1586' FWL, Sec. 8, T11N, RIOE, UM At effective depth At total depth 1570' FNL, 3587' FEL, Sec. 8, T11N, RIOE, UM 5. Type of Well: Development Exploratory B Stratlgraphic _ Sewice_X (asp's 540359, 5970657) (asp 's 541580, 5968526) 6. Datum elevation (DF or KB feet) RKB 1 O0 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1A-09 9. Permit number I approval number 81-152 1811520 10. APl number 50-029-20669 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured 7255 feet Plugs (measured) · true vertical 6539 feet Effective depth: measured 7134 feet Junk (measured) true vertical 6430 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16' 250 Sx AS II 80' 80' SURFACE 2142' 10-3/4" 1000 Sx AS III, 250 AS II 2242' 2242' PRODUCTION 7134' 7" 1113 Sx CI G, 250 Sx AS I 7234' 6520' Perforation depth: measured true vertical iTubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 6760-682~; 6953-6962';6971-7004' 6098- 6152';6268- 6276';6284- 6314' 3-1/2", 9.3#, J-55 Tbg @6891'MD. BAKER 'FHL' @ 6697' MD; BAKER 'DB' @ 6862' MD. CAMCO TRDP-1A @ 1844' MD. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation Dec. 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~'~~' ~ .~~ Title: Problem Well Supervisor ?,/ Jerry Dethlefs FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance B Mechanical Integrity Test __ Subsequent form required 10-_ Approved by order of the Commission Commissioner Approvalno. Date Form 10-403 Rev 06/15/88 *, SUBMIT IN TRIPLICATE STATE ~ ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin,stafe.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: Phillips Alaska, Inc. FIELD / UNIT/PAD: Kuparuk / GKA / 1A-09 DATE: 12/1/00 PERMIT ' " PRETEST START 15 MIN 30 MIN NUMBER TBG TYPE PACKER .REQ TBG.'. TIME TIME TIME & INJ TEST ANN. TVD CASING . TBG TEST CSG' .TBG TBG TBG START P F " WELL FLUID TYP. FLUID MD SlZE/WT/GRADE SIZE PRESS ' PRESS: CSG CSG CSG TIME · NUMBER .PRESS PRESS PRESS PTD: 1811520 N "'P ~'IESE'I' 6,'043 " 3.5" 1,511 1,4~0 3,000 2,900 " 2,900 ....... [] [] Well #: 1A-09 SW 6,697 7"- 26# - K-55 250 250 250 250 944 COMMENTS: MIT -Tubing with tubing tail plug in hole '1 PTD:18115201N I P I DIESELj 6,043J I3.5" 1,511 3~140 3,14013,10013,060.I Ir'il[] Well #: 1A-09 SW 6,697 7"-26#- K-55 250 3~000 2,750 2~625 .1206 COMMENTS: Combination Tx IA (CMIT Tx IA) with tubing tail plug in hole PTD:18115201N I P I DIESELI 6,043I 13.5"J 1,51111,10011,1°0 1,10011,100I Ii-lIE] Well #: 1A-09 ' SW 6,697 7" - 26# - K-55 2,625 3,000 2, 750 2,550 1252 COMMENTS: MITIA afterbleeding tubing to 1100 psi. Leakrate down IA calculated @ O. 16 gpm ~e",T~: I I I I I1°1 I I I I I~1~ COMMENTS: ~:,::: I I I I I o I I I I .I I~ I~ COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Distribution; orig - Well File c - Operator c- Database c - Trip Rpt File ~'. Inqn~_tnr TEST TYPE: M = ANNULUS MONITORING. P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. WELL TEST: 0.00 Initial 0.00 4- Year~ 0.00 Workover 0.00 Other X 0.00 OPERATOR REP SIGNATURE: PeterNezaticky , AOGCC REP SIGNATURE: Not witnessed ARco Alaska, Inc. (1844-1845, 0D:3.500) SBR (6665-6666, 00:3.500) PKR (6697-6698, 0D:6.156) Perf (6760-68~ BPI SLEEVE. (6835-6836. 0D:2.750) PKR (6862-6853, OD:6.15,3) NO GO (6882-6883, OD:3.500) TUBING (0-.6891, OD:3.500, ID:2.992) Peri (6953-6962) Peri (6971-7004) GKA 1A-09 IlA091:.;:.i'i: !'~!i:";: ::::. :i~ ,:: 11:::7! :~"..'ii :'..i.'.: :,'" ::~: :," i:.ii.:,.ii:~:'.:'~:: i':ii:,i~i?;i.!~:/:;:;i:::?'i:':i.i, :i: .:. :,: .' ", :.' ~: :' ::'~i" :: i:/:.....':~.: :i !~'i:' :" :i: :./: ~::i':i' i./..:,::,:i'.:. :ii' :l AP1:1000292066900 J Well Type: IINJ J Angle @ Ts:J29 de9 @ 6759I SSSV Type: JCamco TRDP J Ori~! Completion: J1114/81 J Angle @ TO: j26 deg @ 7255 J Annular Fluid:l I Last W/O: 1~1~/8B I Rev Reason: JTag a,. BPI sleeve J I I I I Jby~mO Re~e.~Lo~: I I RefLo~Date:! I Last Update: IlOr~4~8 Last Tag: J7002 J TO:J7255 ftKS J ' J , .... Last 3~ag, ,D..at~! !.1~0~8 . I Max Hole ~le: 139 deg @ 5500 . ! I C~{i~iS~i~'~:i~i~UCT~:~:i ,.:~ :; ! i.; i:i i ;i'~!!i ~ ;: i.::'::: :i!::. :?:~;;::.: :::.~;. ii:: : .::: .:':::i:':. i~;;;:~;il;!::ii'::. ,:i '; 16.ooo 0 80 B0 I... 05.00 I. H-40 I Ca~ih'~ "string' .SURFACE ", " .' ::. i:": ;: ,;:;;; :::. :::;!!;;~:!::! !i~.' ;;:': ::!'!: :,:/.i:ii ':..~i ~!:.;:!:;i;!ii :.;::i /:';!?! :?i:.i.!:~. 10.750 0 22.42 2242 I 45.50 I K-$5 .I Ca',ih'~:~Stdh{t':-~,.R~OU¢'r~oN:....,'i.: '. ' ":. :'. · :,' ...' · "' ~.', :.. i. Size I Top I Bottom TVD I Wt IGrade I Thread 7.o00 'I 0 I 7234 6520 i 20.00 I K-55 I Tublng'Strin~ -TUBING . . ' ' .. . 3.500 0 6891 6213 I 9:~°. .... I ~55. I BTCAB-MOD 1ES6i'"~'~S~Ha'~':.';~ :..!,;, :>:¥,.i.::~,~':..:.~;.. ':~ ~i.:~,~;,':,!i:~;:~:,?.i.~;,;'.~".~ ,.,';, ,'?. i... ::.T:~ ~' ,. ,.~ ;. ~ ~: !. :'i:..?i.':.!:: .=~:;?'.: !:.-'..:..; ~nter,,.,~ I 'rVD I Zone pt,,t, slFeetlSPq D,,te ~'rypo I ,:omme., 6953-6962 16268-6276 I ^-5/ I91 4111/3/8111PERF 14"HYPeriet ' 6971-7004 16284-6314 I ^-4 / I 331 411113/8111PERF 14"Hyper~et Gas'LlftMandmls/valves . . · ... ', ' .... :, . s*"l "d I~v~l '~"" I ..nIVMfr I vfype Ivo. l~.~.l.o.l~.ol ..~ / v,~ I I I IMfr I Typ°! I I / I I I Run l::ommentl .~...!..6.S~lJ. s.9?6!..Camc? I. MMC--2 I . . I 0~ ! !.5 ! ~K I0.0001 01. s/1/8~. / I s*"l ~0'i'Wol ~" '1'"""" IvMfr IvType Iv°~l~"*~"l"°"l~"°l ~"~° / w~; I I I I Mfr I Type I I I / I I I Run I::ommentl 21 07281 60701 camco I KSU~ I . I .~MY I 1.0 /SE 10.0001 OI 8/17/85 IC~osed I Depth I~DI Type I' ' Description · ' I ID I I IP°RTE° I I / NIP I. I SLEEVE I I / other'.IiS!~i~,ie.'qbip:;'ietC.)-JEWELRY. :. :' ... :.:. '.... DePthl'r~DI Type I Description 1~.1~41 sssv ICamooTRDP-1A 66651 6o151 seR IBaker 66971 60431 PKR IBaker 'FHL' 6862] 6188] PKR IBaker'DB' 68821 62051 NO ~O ICamco 'D' Nipple 68901 62121 SOS ICamco 68911 62131 TTL I 2.813 I 2.813 I 3.000 I 4.750 I '2.250 I 2.992 I 2.992 KUPARUK ENGINEERING TO: DATE: TRANSMITTAL # /~ ! D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: LEASERETURN RECEIPT TO: DATE: Ab"~'~'r',~'' d;~ ~ ~.:'.3:: '~'~'., ~ .... ~.~..,~t')!'i ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-152 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20669 4. Location of Well SL: .569' FSL, 487' FWL, Sec 5, T11N, RIOE, UM BHL: 1169' FSL, 1696' FEL, Sec 7, T11N, RIOE, UM 9. Unit or Lease Name Kuparuk River Unit: 10. Well Number 1A-9 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KR:IRn' IADL 256/~7 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Kuparuk River NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I--I Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [~( Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] OTHER [] ~ Field Oil Roo acid. (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, May 2, 1982, Kuparuk Well 1A-9 was stimulated with 12% hydrochloric acid. A mud and silt remover was mixed with the A total of 99 bbls of acid were squeezed across the following intervals using a coiled tubing unit. 6760-6822' 6953 6962' 6971-7004' MD Diesel was used to displace the acid. Nitrogen was circulated intermi~tentiy with diesei to expedite the cIeanup. AII pressure equipment was tested to 4000 psi. Aii injected and produced fluids were fiowed to surface vesseis and disposed of. The Kuparuk Well 1A-9 test rate increased_from 1304 BOPD to 1898 BORD as a result of the action. ~~]VFD A-22 MAY 2 81982 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~X ~~~____.~ Regional Signed , ~, -_ Title The space b~H~ow for Commissi°/l~se fil~l~K~l Ull Ut uae vvl,o. VUlillllil$~|O[} Anchorage Engineer Date Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~" Post Office Bdk J0 Anchorage, Alaska 99510 Telephone 907 277 5637 April 21, 1982 Mr. C. V. Chatterton State of Alaska 0il and Gas Conservation 3001 Porcupine Drive Anchorage, AK~ 99504 Commission .Dear Mr. Chatterton: Attached please find Sundry Notices of Intention for Kupaurk Wells 1D-2, 1D-4, 1D-5, 1E-3, 1E-5, 1D-3, 1C-1, 1A-7,:{.';:I:'A?='~i, 1.A-10, and 1A-11. The work on these wells is scheduled for the latter part of April, 1982. Also attached is the subsequent notice for Well 1B-gGI which was perforated in late December, 1981. We apologize for the untimeliness of this report. A recent review of our records revealed this submission had been overlooked earlier. Sincerely, bl Attachments STATE OF ALASKA ALASKA L AND GAS CONSERVATION C reMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~( OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-152 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20669 4. Location of Well SL: 569'FSL, 487'FWL, Sec 5, T11N, RIOE, UM BHL: 1569'FNL, 1696'FWL, Sec 7, T11N, RIOE, UM 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-9 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB- 100' I ADL 25647 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk Rlver Field Kuparuk Rlver 0il Poo NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate J~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposed to stimulate the Kuparuk Sands with a¢ld. Aold will be spotted wlth a rolled tublng unlt wlth BOP assembly tested to 4000 ps1. All circulated and flowed flulds w111 be diverted to tankage on location. The well w111 be tested subsequent to the stimulation. Expected start date ls Apr11 26, 1982. Subsequent Work It¢I::'ortecl APR 2 6 i9:82 Lqi & ~'' ~[h_e,p~ce b~ for'C--ommission use(~ Conditions of Approval, if any: 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Operations Title Approved by Engineer Date Approvad Copy Returned -- By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL COMPLETION OR RECOMPLETION REPORT AND LO _ 1. Status of Well Classification of Service Well OIL EX] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-152 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 5o- 029-20669 4. Location of well at surface 569'FSL, 487'1-WL, Eec ~, II'IN~ R'i0E~ UM 9. Unit or Lease Name Kuparuk 25647 At Top Producing lnterval 1369'FNL, 1586'FWL, Sec 8, T11N, R10E UM 10. WellNumber 1A-9 At Total Depth 1569'FNL, 1696'FWL, Sec 8, T11N, R10E, UH 11. Field and Pool Kuparuk River FieId 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ~' i~0;~-1~'' RKBI ADL 25647 ALK 465 Kuparuk River OiI Pool 12. Date Spudded10/22/81 13' Date T'D' Reached10/31/81 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°r° 116' N°' °f C°mpleti°ns-11/4/81 ' -- feet MSL 1 :17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7255' 6540' 7134' 6431' YES E~ NO []I 1901 feetMD 1700' (approx) '"22. Type Electric or Other Logs Run DIL/BCHS/GR, FDC/CNL/GR/ CAL, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" 65~ H-40 Surf 80' 24" 200 sx Permafrost 10 ~/4" 45.5~ K-55 Surf· 2242' 13 3/4" 1000 sx AS III & 250 AS II 7" 26~ K-55 Surf 7234" 8 3/4" 1113 sx CIass "G" cement 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) · 6760'-6770' 6984'-6994' w/4 SPF 3 1/2" 6715' 6640' 6770' -6780' 6780 ' -6792 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6792' -6802 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6802'-6812' ~ ' N/A ' 6812 ' _6822' 6953' -6962' 27. '" ' ' PRoDuCTiON TEST . .- Date First Production i Method of Operation (Flowing, gas lift, etc.) 2 28 82 Fiowin( Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OILRATIO 1/?b./~t? 19, TESTPERIOD e 1204 ~7 - 96/64J 371 Flow Tubing. Casing Pressure CALCULATED -~ OIL'LBBL . GA-S.MCF WATER_BBL OIL GRAVITY-API'(corr) Press. i40 " .. 24'-HOURRATE~ 1438 "5.34 '23 3 28. . CORE DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. , . · j : : , ,. . . . , .... -, /;,, :';/.],. ,(~ '~ -, , ,, . crT 10-407 ;:.'?';:Su!~.~m~!lj in dupf~c~l~:~~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~;?~'~ .. . 29. ' ' *:" 30. ' ' : " · . 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 Kuparuk River Form. 6750' ' 6089' N/A Base Kuparuk River Form. 7060 ' 6364' · 31. LIST OF ATTACHMENTS , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,.Vl. Title Area 0ps. Engr. Date /1''- // 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 co.mpleted for separate production,from more than one interval (multiple completion), so state in item. 16,'and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken; indicate "none". tz nrrn I TRAi!St-!ITTAL ~ ~Z ~ TO- ~/~ ~//~ ~~ FROM: J. J. Pawelek/Ann Simonsen DATE· =~?_.~ .2 -~., WELL ,,=,.,~_"'~"=' Transmitted herewith are the fol'lowing' PL:.~E HOTE' BL - BLUELI~E, S - SEPIA, F - FILH, T - TAPE · , //9 RECEIVFD Ca ! PT ,;Cr.,~C ~ PL DATE' ARCO ALAS>iA, INC. ATTH: Ar.4ti SIFi0~.ISE~I- AFA/311 P.O. BO:< 360 "~ .... 9951 NORTH SLOPE E~:GINEERI?;G ( TRAi~SHITTAL # /',q'/ TO- ~Y,,,~ Z,,/~~ FROM: J. J. Pawelek/Ann Simonsen WELL "'~';~' Transmitted here:.:ith are the following' p~-~ T.,~t ~ .r ~ L...~,..E HOTE' BL - BLUEL.~IE S - SEP.,~,, F - FILM, T - TAPE RECEIPT ACK;:0WLEDGED' ARCO ALASKA, INC. ATTH: AN~i SIMO~ISE~! - AFA/311 P.O. BOX 360 '""" ~"~"- ," a~510 ~,C~';O;',~u,- , Ar., _,. Alaska O# & Gas Cons. AnChorage Comr~i~$1o~ · ARCO Alaska, Inc.~'~ Post Office t._..~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 25, 1981 Mr. Hoyle Hamil ton State Of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 11-3 DS 15-11 DS 12-14 DS 14-12 DS 13-8 DS A-7 DS 14-13 DS IA-9 DS 14-14 DS B-8 DS 14-15 DS B-9GI Dear Sir: Enclosed please find the following' (1) The Completion Reports for DS 13-8, DS 14-14, DS 14-15, DS 15-11, DS 15-12, DS A-7, DS lA-9 and DS B-8. (2) The Monthly Drilling Reports for DS 11-3, DS 12-14, DS 14-13, DS 15-12, DS lA-9 and DS B-9GI. Sincerely, P. A. VanDusen District Drilling Engineer PAV' GA: 1 tc Enclosures j. RECEIVED DECO ? 1981 Alaska 0il & 8as Cons. Comm~sslo~ Anchorage ARCO Alaska, Inc, is a subsidiary of AtlanticRichfieldCompany '~ " i' ~' STATE OF ALASKA ~ .... F~ ALASKA~ .... ,,AND GAS CONSERVATION G~. .... ,ISSION --¢ ~' WELL COMPLETION OR RECOMPLETION REPORT AND LOG' 1. Status of Well Classification of Service Well OIL IX) GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-152 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o-029-20669 4. Location of well at surface 9. Unit or Lease Name 569'FSL, 487'FWL, Sec 5, TllN, RIOE, UM '~~ Kuparuk 25647 At Top Producing Interval ii VEPdFIED 10. Well Number To be Submitted i:su~. ~ lA-9 At Total Depth/S~I~'~.,.,,, /~'/~,,._.B' J'J. F--__ _ 11. Field and Pool ~NL,-~u~u---FWL, Sec 8, TllN, RIOE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk 0i 1 Pool llO'RKBI ADL 25647 ALK 465 12. Date Spudded 10/22/81 13. Date T.D. Reached 10/31/81 14' Date C°mp" Susp' °r Aband' J 15' Water D'epth' if °ffsh°re 116' N°' °f C°mpleti°ns 11/4/81 -- feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (Mg+TVD) 19. Directional Survey J 20. Depth where SSSV set 21. Thickness of Permafrost 7255'MD 6540'TVD 7134'MD 6431 'TVD YESlX:] NO[]J 1901feetMg 1700' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/GR/Cal, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD cASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80' 24" 200sx Permafrost 10,3/4" 45.5# K-55 Surf 2242' 13-3/4" lO00sx AS III & 250 lkS II 7" 26# K-55 Surf 7234' 8-3/4" lll3sx Class.."G" cmt . 24. Perforations open to Production (MD+TVD of Top a.nd Bottom and 25. TUBING RECORD . interval, Size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6971' - 6984' 6760'- 6770' 3~" .. 6715' 6640' 6953' - 6962' '6984' - 6994' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6812' . 6822~ ' DEPTH INTERVAL (M.D). AMOUNT & KIND OF MATERIAL USED 6802' - 6812' N/A 6792' - 6802' 6780' - 6792' "~ 6770' - 6780' , ,.. 27. PRoDoCTION T~ST Date First ProduCtion' ' "I Method of Operation (Flowing., gas.lift, etc.) - Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OILRATIO , . TEST PERIOD...~ .' I , Flow Tubing Casi.ng P:ressure . CALOULATED O.I'L-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 wa te r. Submit core chips. ,~ ,,~ [. ~ .~ ~' ~ i,i': ii '~' ~ D' : .: . . . . . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC, MARKERS · ' "-._.. ' : ..:.. .'! '- . · · . NAME. ' Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of 'each phase. .. To B Subm.itted: N/A .., 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . '~//~_,.,, f,~ Titl~Sr Dril 1 i ng Engr Date /'¢/¢///~/ ' Signe -_ . · , / .. 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 s~parate 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 Drilling History NU hydril & diverter. Spudded well @ 0700 hrs, 10/22/81. Drld 13-3/4" hole to 2255' Ran 54 its. 10-3/4" 45.5# csg w/shoe @ 2242'. Cmtd 10-3/4" csg w/lOOOsx AS Iii and 250 sx AS II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi-OK. NU BOPE & tstd to 3000 psi-OK. Tstd csg to 1500 psi-OK. Drld FC & cmt. Tstd csg to 1500 psi-OK. Drld FS & 10' new form. Tstd form to 12.5 ppg' EMW-OK. Drild 8-3/4" hole to 7255'. Drld 8-3/4" hole to 7255', as of 10/31/81. Dri 11 i ng Hi story NU hydril & diverter. Spudded well @ 0700 hrs, 10/22/81. Drld 13-3/4" hole to 2255' Ran 54 jts. 10-3/4" 45.5# csg w/shoe @ 2242'. Cmtd 10-3/4" csg w/lOOOsx AS Iii and 250 sx AS II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi-OK. NU BOPE & tstd to 3000 psi-OK. Tstd csg to 1500 psi-OK. Drld FC & cmt. Tstd csg to 1500 psi-OK. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-OK. Drild 8-3/4" hole to 7255' Ran DIL/BHCS/GR & FDC/CNL/GR/C,a,I~,., Ran 170 jts 7" 26# K-55 BTC csg w/shoe @ 72~4' Cmtd 7" csg w/lll3sx Class-u cmt. Instd 7" packoff & tstd to 3000 psi-OK] PU 3½ D.P. Drill out DV. Test csg. ~_._to 3000 psi-OK. Clean out to 7134'. Displace well to NaC1/NaBr brine. Ran CBL/VDL/CCL/GR. Ran Gyro. Arctic packed 7" x 10-3/4" annulus w/300 bbl H20, 250sx AS 1 and 92 bbl Arctic Pack. TIH w/casing guns and fire 4 spf thru: 6971'-6984', 6953'-6962', 6984'-6994', 6812'-6822', 6802'-6812', 6792'-6802', 6780'-6792', 6770'-6780' & 6760'-6770. Ran 3½" cOmpletion assy w/tail @ 6715' and pkr @ 6640'. Land tbg. Test seals to 3000 psi-OK. Drop ball & set pkr. Test packer w/1500 psi on annulus-OK. Close SSSV. ND BOP's. NU tree. Pull dummy from GLM. Displace NaC1/NaBr brine to diesel. Set dummy in GLM. Check SSSV-OK. Set BPV. Secure well & released rig @ 0400 hrs., 11/4/81. 1. Type of Request: Operation Shutdown m Stimulate ~ Pull tubing Alter casing Repair well 2. Name of Operator STATE OF ALASKA ~(A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUN 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska. In[;, 3. Address P. O. Box 100360, Anchorage, AK 99510 Plugs (measured) None Junk (measured) Plugging Perforate _ Pull tubing Other X 6. Datum elevation (DF or KB) 1 lO' RKB 7. Unit or Property name Kuparuk River Unit f~et 1A-09 9. Permit number/Approval number 9-595 10. APl number 50-029-;~0669 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 569' FSL, 487' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1369' FNL, 1586' FWL, Sec. 8, T11N, R10E, UM At effective depth 1433' FNL, 1659' FWL, Sec.8, T11N, R10E, UM At total depth 1570' FNL~ 1695' FWL, Sec. 8, T11N~ R10E, UM 12. Present well condition summary Total Depth: measured 7 2 5 5' feet true vertical 65 3 9' feet Effective depth: measured 71 3 4' feet true vertical 643 0' feet 13. Casing Length Size Structural Conductor 8 0' I 6" Surface 2242' 10 3/4" Intermediate Production 7234' 7" Liner Perforation depth: measured 6760-6822, true vertical 6100-6152, Cemented 250 Sx AS II 1000 Sx AS III & 250 sx AS II 1113 Sx Class G & 250 SX AS I 6953-6962, 6971-7004 ' MD 6268-6278, 6284-6314 ' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6891' Packers and SSSV (type and measured depth) Baker DB @ 6862', Baker FHL @ 6691'; Camco TRDP-1A @ 1844' Stimulation or cement squeeze summary Intervals treated (measured) Measured depth True vertical depth 80' 80' 2242' 2400' 7234' 6528' RECEIVED Treatment description including volumes used and final pressure Convert from water injector to WAG injector.. Representative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (injecting) - 0 - - 0 - 800 1000 2450 14. 390O ~ Subsecluent to operation (injecting) - 0 - 1 5 0 0 - 0 - 1 0 0 0 15. Attachments ~ 16, Status of well classification as: Copies of Logs and Surveys run -- I Water Injector __ WAG Injector X Daily Report of Well Operations X Oil _ Gas Suspended .--- Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Senior Operations Engineer Date 2 / ~'~/Y~ suBMIT I~1DUP'LICATE Form 05/17/89 W Z S E 0 T L N A L E T 'OTALS: W Z E 0 T L N A L E T 7 B SW 9AGI 1 A SW "2 B PW 3 B PW 4BSW ,5 A SW ,6 B PW KDGS ~': '.g WELL REPORT FOR 07/~ x DRILLSITE lA PRODUCTION WELL STATUS OAS LIFT STATUS 7" 10" TP TT WC H2S CSG CSG PSI CHK DEG % PPM PSI PSI INdECTION WELL STATUS ALLOW INd PSI ACT 7" 10" INd TT ~CSG CSG PSI DEO CHK PSI PSI 2500 2452 100 66 310 50 4000 3887 121 209 0 0 2500 2471 99 66 2300 80 2500 1547 156 12 150 300 2500 622 157 10 0 0 2500 2110 96 176 0 160 2500 2493 98 176 0 0 2500 1843 15~ 12 1350 800 GAS INd TEMP METER RATE DEG TOTAL MSCF 4994 INdECTION RATE INd INd METER RATE RATE TOTAL BPD MMSCFD 232972 4575 0.000 0 0 1.436 251486 1834 0.000 476217 3383 0.000 526854 1139 0.000 628474 4576 0.000 128550 952 0.000 310823 4170 0.000 PAGE 1 S/I IMPACT C H M 0 R I D EPL S N E BBLS 310 S/I C HM 0 RI D SN E 0000 0 0015 12 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 'OTALS: SWI: 11937 + PWI: 8692 = 20629 1.436 KDG$ MORNING WELL REPORT FOR 06/30/89 DRILL$ITE lA W Z '3 E :: T L N A L E T 1 BPR 2 APR 3 B PR 4 B PR 5 B PR /_-,APR 8 B PR 10 B PR PRODLICTION WELL STATUS 7" 10" T P T T W C H 2 S C :S G C :E; G P:S I CHI< DEG Y. PPM PS I PS: I 1:30 176 10:B 9:3 125 1:340 680 200 176 82 0 150 176 120 42 200 176 40 5 200 17/., 1:35 89 150 176 78 2 200 17/-, 114 :-_-:7 200 176 105 /:,2 25 1300 560 0 1225 1040 30 850 240 90 1340 600 30 1200 750 20 1140 830 42 1260 850 GAS LIFT STATUS GAS IN,J TEMP METER RATE DEG TOTAL MSCF 88 5194 1285 86 5993 795 90 4894 651 84 5594 326 90 53~4 718 88 1994 479 92 7494 997 84 5895 1497 TOTAL'.3: INdECTION WELL STATUS W Z S E 0 T ,ALLOW ACT 7" 10" L N A L E T 7 B SW 9 A F'W 11 A SW 12 B F'W 13 B SW 14 B :::W 15 A S W 16 B PW I N,_i F':S I 25 (')0 245 ~'~ 90 66 :3 ~'~ 0 2.50C) 2450 144 66 40 .....· .-.'.~,c~() 2.=, 1 ("~ :_::';" .,_ 6/., .,: '-'= .., (.) ' 40 2500 81 (') 1.:,'-"-'-.' 47 (')_ :-]:C) 2500 2500 :--:6 176 0 0 25(]c~ 2500 84 176 0 150 250 ('~. .-._'-.' .=, -._ '~' .=, 84 17/., 0 c~. 2500 1050 150 3 2200 1725 I N,J TT C'._:;G C'.:;G PSI DEG CHK P'.SI PSI 6748 INdECTION RATE S/I IMPACT C H M R I D EF'L S N E BBL:S TOTALS: 0000 0 0 0000 0 0 0000 0 0 0000 0' 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 :_:;/I. PAGE 1 C I N,J I N,.i H M 0 METER RATE RATE R I D TOTAL BPD MMSCFD '.3 N E 40 210635 3367 0. 000 60' 437146 726 0.00C~ 245300 1045 0. 000 44227:2: 1 '::'"""._ ..~ (') ,000 503497 6825 0. 000 605415 4795 0. 000 123596 11:36 0. 000 284914 1495 0. 000 ::_;WI: 1716:3 + PWI: :354:3 = 20711 0.000 COMMENTF-;: CELLAR BOXES NW+NE=i", SW+SE=i" DOWNHOLE COMMI_iNICATION: lA-11, lA-16 SHI_IT-IN CODE :36 = FLOW LINE MAINTENANCE :--~HUT-IN CODE :2:5 = C:HOKE REPAIR 0700 36 0000 0 0000 0 0000 0 0000 0 0000 0 0130:35 0000 0 ' .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X Operation Shutdown _ Re-enter suspende{ _ _ Plugging_ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other__ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well:. Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 569' FSL, 487' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1369' FNL, 1586' FWL, Sec. 8, T11N, R10E, UM At effective depth 1433' FNL, 1659' FWL, Sec.8, T11N, R10E, UM At total depth 1570' FNL, 1695' FWL~ Sec. 8, T11N~ R10E, UM 12. Present well condition summary Total Depth: Effective depth: measured 7 2 5 5' true vertical 6539' measured 71 3 4' true vertical 6430' feet Plugs (measured) feet None feet Junk (measured) feet None RKB 110 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 A-09 //~ -~ ,.~ ,- 7 ·/t 9. Permit number 81-15;,~ 10. APl number 50-029-20669 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' I 6" Surface 2242' 10 3/4" Intermediate Production 7 2 3 4' 7" Liner Perforation depth: measured 6760-6822, true vertical 6100-6152, Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6891' Cemented Measured depth True vertical depth 250 Sx AS II 8 0' 80' 1000 Sx AS III & 2242' 2400' 250 sx AS II 1113 Sx Class G 7234' 6528' & 25O SX AS I 6953-6962, 6971-7004' MD 6268-6278, 6284-6314 ' TVD Packers and SSSV (type and measured depth) Baker DB @..6862'~ Baker FHL ~ 6691';. Camco TRDP-1A @ 1844' 13. Attachments Description summary of proposal_ Conversion from water injector to WAG injector 14. Estimated date for commencing operation 15. July, 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operation program BOP sketch Status of well classification as: Oil Gas Suspended Service Water In!e(;t~)r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR ~MMISSIO~ USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance m Mechanical Integrity Test_ Subsequent form require ,Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner IApproval No~,. '~~ Approved Copy Returne~d~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Procedures 1A-09: A Only SPFO/SRT. A Only Gas Iniection 1. Pull ported AVA at 6835' RKB. 2. Run AVA blanking sleeve. 3. Allow well to stabilize at maximum water injection rate. 4. Operations Engineering to perform SPFO. 5. Operations Engineering to perform SRT after well has stabilized. 6. Convert well to A Sand onlygas injection for 10 weeks~, NC Gas In!ection. A/C Water Iniection 1. Fill wellbore with liquid to avoid being blown uphole. 2. Pull AVA blanking sleeve at 6835' RKB. 3. Run ported AVA with 2 ea 28/64" ports. (port size may change based on SPFO/SRT results from above) 4. Begin A/C gas injection. 5. Operation Engineering will communicate when to switch well to A/C water injection, based on gas injection rates. 1A-15: A Only SPFO/SRT. A Only Gas Iniection 1. Pull ported AVA at 8390' RKB. 2. Run AVA blanking sleeve. 3. Allow well to stabilize at maximum injection rate. 4. Operations Engineering to perform SPFO. 5 Operations Engineering to perform SRT after well has stabilized. 6. Convert well to A Sand only gas injection for 10 weeks. NC Gas In!ection. NC Water Iniection 1. Fill wellbore with liquid to avoid being blown uphole. 2. Pull AVA blanking sleeve at 8390' RKB. 3. Run ported AVA with 2 ea 30/64" ports. (port size may change based on SPFO/SRT results from above) 4. Begin NC gas injection. 5. Operation Engineering will communicate when to switch well to NC water injection, based on gas injection rates. 1A-09 WAG Conversion No BOP's and no workover fluids will be used. Estimated BHP is 3300 psi at 6200' TVD. Mr. C.. V.' Cha~;~ 'rton May 27, 1986 l Page 2 KUPARUK · ATTACHMENT I_y~?~..~.., ~ ~ ' ""' RIVER UNIT. INJECTIO~ LOGS INJECTION PROFILES Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 lA- 13 2/4/83 10/17/83 1A-14 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 ,* 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 1E-23 1E-27 1E-30 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 !0/7/83 Well Number Date of Initial Injection Date of Injection Profile 1F- 10 8/13/84 10/30/84 1F- 11 8/12/84 9/24/B4 1F-!3 8/16/84 9/25/84 1F-15 8/16/84 9/26/84 --. -Well Number Date of Initial Injection Date of Injection Profile ~ 1G-3 1G-6 1G-9 1G-i4 1G-16 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 ATTACHMENT I I Drill Site lA KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Well No. Loo~ Date 1A-4 7/6/83 1A-5 10/29/83 1A-7 2/8/82 5/7/82 1/25/82 3/23/83 1A-11 1/19/83 3/21/83 1A-12 3/8/82 1A-14 4/1/82 1A-15 6/5/82 1A-16A 5/11/82 6/8/82 Dri 11 Si te Wel 1 No. Log Date lB lB-1 12/26/81 1B-2 6/25/81 lB-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Wel 1 No. Lo9 Date 1C-1 5/9/81 1C-2 5/8/81 lC-3 7/13/81 1C-4 11/8/81 3/9/81 1C-5 2/26/81 lC-6 ::11/30/81 lC-7 5/19/81 lC-8 ' 5/21/81 Drill Site Well No. Lo9 Date 1D 1D-1 ~ 1/80 5/23/83 1D-3 B/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 ~...~D-8 (WS-8) 5/i0/78 Attachment Page 2 Drill Site Well No. Log Date 1H Drill Site lQ 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 Well No. Log Date Drill Site 1E Wel 1 No. 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 Lo9 Date 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 Well No. ~Log Date 1G 1G-1 1G-2 1G'3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. Lo9 Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/!2/83 /7 gE. C, BI V.4: Alaska Oil & Gas Cons. ArC,rage 1F-7 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 !0/28/82 !1/19/82 5/7/83 Page 3 Drill Site 1Y Wel 1 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 1Y-9 6/20/83 5/10/83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 5/ 3/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Well No. Log Date 2C-4 2/19/85 2~28/85 2C-7 10/15/84 ~2C'~1~12tllt4~ Drill Site 2Z' Well No. Lo9 Date ~~_ 7110/83 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'O052 Alaska Oil & Gas Cons. Anchorage Drill Site lA Wel 1 No. ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log 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 5/11182',,,,. ~ 6/8/82 ,} Drill Site Well No. Log Date ~'18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81"--~ - '~ 3/12/82/ "18-6 11/18/81> ',~ 9/10/82 ~.. ~18-7 11/23/81 ~18-8 12/28/81'-,, "~ 8~4/82 / 6/24/82 :~/ ~18-9 ~ 8/3/84 18 Drill Site 1C Wel 1 No. \ "~1C-1 ~'~1C-2 "1C-3 ',ulC-4 '~1C-6 "~1C-7 '~ lC-8 Log'Date 5/g/8'1 518181 7/13/81 1118181') 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D "%1D-1 1/80 ~ ~' 5/23/83// "~lD-3 8/5/80 1D-4 ~7/30/80~ ~ 8/13/80/ ~ '~1D-5 6/11/81 ~1D-6 6/9/81 '~1D-7 6/8/81 XJlD-8 (WS-8) 5/10/78 RECEIVED FEB ~ ! ]gS~ Anchorage ARCO Alaska, Inc. ~ Post Office B~,, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 1A-9 1A-12 Kavik #1 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L118 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA · ANDGAS CONSERVATION C MISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 81-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20669 4. Location of well at surface 9. Unit or Lease Name 569' FSL, 487' FWL, Sec.5, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1369' FNL, 1586' FWL, Sec.8, T11N, R10E, UM 1A-9 At Total Depth 11. Field and Pool 1570' FNL, 1695' FWL, Sec.8, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ' ...... Kuparuk Ri ver 0i 1 Pool 110' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/22/81 10/31/81 11/04/81 *I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7255'MD,6539'TVD 7134'MD,6430'TVD YES [~X NO []I 1844 feet MD 1700' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR, FDC/CNL/GR/Cal, CBL/VDL/CCL/GR, Gyro 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" 250 sx AS II 10-3/4" 45.5# K-55 Surf 2242' 13-3/4" 1000 sx AS III & 250 s~ AS II 7" 26.0# K-55 Surf 7234' 8-3/4" 1113 sx Class G & 250 :.x 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) 6760' - 6822' 3-1/2" 6891 ' 6691 ' & 6862' 6971' - 7004' w/4 spf, 120° phasing 6953' - 6962' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/28/82 F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 1/24/82 19 TEST PERIOD I~ 1204 I 447 96/64 371 Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 140 -- 24-HOUR RATE ~' 1438 534 -- 23.3 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE is "~' ! .... '~ ~: ? Form 10-407 * NOTE: Wel 1 was recompl eted 8/16/85. GRU13/WC03 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS I MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. I , Top Upper Sand 6750' 6089, N/A , Base Upper Sand 6820" 6151' Top Lower Sand 6945' 6261' Base Lower Sand 7000' 6310' ', _._ 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to _the best of my knowledge ._ Associate Engi neet Signed I~~ ~ Title 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 forrn for each additional inter'val to be separately produced, sE°wing 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~,07 State --'~ North Slope Borough Alaska -~' Well no. Xupat'ttk Ri~et: AZ)I, 256~7 lA-9 Autt~ o~W.O, no. A~ 603074 ~eco~plet~ ~S, #.Z A?! $0-029-20669 ~ or W.O, be~u~ '; ' '~. IDm ._ ~, if · W.O:. ~ozkovez' I 8/10/85 ~. _ I~$ ~nd d=p~ "' C~ mom for e~h d~ ~ ~o~8~,&~ ~ ,, ~., .-. 811~/85 7" 0 72~4-~'- '~:' ......... 7134 ' PB~,,, Ci~e:~;:"~ . Tla w/ret.~'g:.t~.. ~ 6637~**, 9.9 PP8 ~aC1/~, ~00E w/X-~cbo:. TIB w/mill, mill Circ out gas bubbI~::~ 8/14/85 7" ~ 723~' ~ 7134' PBTD, POOB~'w~;B~[setCins 9.9 NaCI/N~:~,::~ "~'.. Circ, P~R.v~pk~ &: tall'pipe aasy. RIE Co 7087', CO Co 7134", POOR. PU ~ridie .plU~.~ ~IR,~ aec s~ ~ 6700', CsC Co 2000 psi, POOR.. 8/15/85 7" ~ 7234' 9.9 pp~ P~R, heads, ~ $ cst BOPS. Tsc cs~ co 3500 psi. plu~, POOR~ pkr ~ Call pipe. The above is corre~t~ S n ur.e\. \\ w. For fo~rm preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 anc~ 87. S. 'CON'DON [Oatll~,.~ k"~ ~ [ Title Drilling Superintendent Number all daily well history forms consecutivefy as they are prepared for each well. [Pag~ no. ARCO Oil and Gas Company Daily Well History-Final Report Instn~otions: Prepare and submit the 'Finll Rll~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Refl~rt" 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 Rel~rt" form may be used for reporting the entire operation if space is available. I Accounting District r countyor Parish I State Alaska North Slope Boroush Fie~d ~Lease or Unit Kuparuk River [ ADL 25647 Auth. or W.O. no. ITitle AFE 603074 I Recompletton WWS #1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 8/16/85 Date and depth as of 8:00 a.m. AP1 50-029-20669 A.R,Co. W.I. 56.24% IDate 8/10/85 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our IPrlor status if a W.O, 1600 hrs. I 7" @ 7234' 7134' PBTD, RI{ Crude/Diesel Set Baker "DB" pkr @ 6853', POOH, RD Schl. RU & rn 218 ~ts of 3-½", 9.3#, J-55, AB MOD BTC & 8RD IPC tbS w/perm pkr @ 6862', retry pkr @ 6691', SSSV @ 1844', "D" nipple @ 6882', TT @ 6891'. Stab into lower pkr & cst seals. Set top pkr & hook up control in. Tst ann to 2500 psi, closed SSSV, set BPV, ND BOPE, NU tree &tst Displ well to to crude w/diesel cap. Release Rig @ 0315 hfs, 8-16-85. cost center code Alaska Well no. 1A-9 ~/o Old TD Rel eased rig 0315 hrs. New TD Date Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth Kind of rig 8/16/85 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7136' Rotary Well no. Date Reservoir Producing Interval , Oil or gasTest time Production Oil on test Gas per day P~mp 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. 'Number all dally well history forms consecutively as they are prepared for each well. iPage no, 2 ARCO Alaska, Inc. {r Post Office B(~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1A-9 Dear Mr. Chatterton: Enclosed is a copy of the 1A-9 Workover Well History to include with the Well Completion Report, dated 09/19/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L86 Enclosure RECEIVED F i -3 1 4 1986 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. { Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 7, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- Well Action Date Performed on the 1A-9 Fracture 1 0/1 7/85 1A-1 2 Fracture 1 0/1 4/85 1R-1 5 Fracture 1 0/23/85 1R-1 6 Fracture 1 0/23/85 If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) cai ! me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ........ STATE OF ALASKA ('" '~' ALASKA OIL AND GAS CONSERVATION cOM MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Na~,~,~(~pe,~,SKA, INC. 3. Ad~ress O oBOX 1 0 0 3 6 0 ANCHORAGE ALASKA 9 9 5 1 0 · · · 4'L°~..~l~kV~l~ LOCATION' 569' FSL, 487' FWL, Sec. 5 T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 1 0 ' (RKB) I 6 . Lease Designation and Serial No. ADL25647 ALK 465 7. Permit No. 81-152 8. APl Number 50- 029-20669 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1A-9 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ]~] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13, Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 17, 1985· the "A" sands of Kuparuk well 1A-9 were hydraulically fractured and propped to improve production. The treatment consisted of 253 BBLS of gelled diesel as pad and carrying fluid and 1,008 LBS of 100 mesh and 12,096 lbs. of 20/40 sand as proppant. 61 BBLS of gelled diesel was used as a flush. Prior to pumping· equipment and lines were tested to 6000 psi. Oil & 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use KU PARUK Title - OPERAT i ONS COORD i Date 11/6/85 Conditions of Approval, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. [ Post Office Box~ J360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the 1A-12 1A-9 If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU12/L35 Enclosures following wells: 263-4944. ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ALASKA IL AND GAS CONSERVATION C ,,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator 3. Address P_ 0. _~'_× 100360, .~_-.chorage, .~ 995!0-03~_0 4. Location of Well Surface: 569' FSL~ 487' FNL, Sec.5~ T11N~ R10E~ UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 110' 6. Lease Designation and Serial No. ADL 25647 ALK 465 7. Permit No. 81-152 8. APl Number 50-- ~O~_Ot't££~ 9. Unit o~'~.~as~N~a~e Kuparuk River Unit. 10. Well Number 1A-9 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: 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 [] Other [] Pulling Tubing [~j)( Pull 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). Accept.ed rig ~ 1600 hfs, 8-10-85. Killed well. ND tree. NU BOPE & tstd to 3000 psi-ok. Pulled tubing hanger & tubing. Ret.tiered pkr. Tst, d csg t,o 3500 psi-ok. Set pkr @ 6853' WLN. Ran 3-1/2" completion assy w/tail ~ 6891', pkrs ~ 6691' & 6862', & SSSV ~ 1844'. Tstd tubing to 2500 psi-ok. ND BOPE. NU tree & t,std to 5000 psi. Disp well w/diesel & crude oil. Secured well & released rig ~ 0315 hfs, 8-16-85. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~/~~ ~ Associa~;e Engineer Signed ~ Title The space bel(~v for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GEU12/SN07 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. (" Post Office B(~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1A-9 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 1A-9. I have not yet received the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L101 Enclosure k£CEIVED s se e Alaska 0il a Gas - Ancho~n~s' Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA~..'- AND GAS CONSERVATION COl~ ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS ['-I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-152 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 5O- 029-20669 4. Location of well at surface 9. Unit or Lease Name 569' FSL, 487' FWL, Sec.5, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1369' FNL, 1586' FWL, Sec.8, T11N, R10E, UN 1A-9 At Total Depth 11. Field and Pool 1570' FNL, 1695' FWL, Sec.8, TllN, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 110' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/22/81 10/31/81 11/04/81'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7255'ND,6539'TVD 7134'ND,6430'TVD YES [~X NO []I 1844 feet MD 1700' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR, FDC/CNL/GR/Cal, CBL/VDL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 250 sx AS II 10-3/4" 45.5# K-55 Surf 2242' 13-3/4" 1000 sx AS III & 250 s; AS II 7" 26.0# K-55 Surf 7234' 8-3/4" 1113 sx Class G & 250 ,,x 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) 6760' - 6822' 3-1/2" 6891' 6691' & 6862' 6971' - 7004' w/4 spf, 120° phasing 69531 - 69621 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. IDEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 2/28/82~1 F1 owi ng, I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/24/82 19 TEST PERIOD I~ 1204 447 -- 96/64 371 Flow Tubing Casing Pressure. CALCULATED=1~, OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 140 -- 24-HOUR RATE a~, 1438 534 -- 23.3 28. 'CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED SEP2 4 1985 Alaska Oil & Gas Cons, C ' - Form 10-407 * NOTE: Well was recompleted 8/16/85. TEMP2/WC08 Submit in duplicate Rev. 7-1-$0 CONTINUED ON REVERSE SIDE 29. Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 6750' 6820'- 69~5' 7000' inc~uc~e in[ervat tested, pressure clara, att tiuids [ecovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. 6089~ N/A 6151 ' 6261 ' 6310' 31. LIST OF ATTACHMENTS Nnn~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __ Title Associate Engineer Date INSTRUCTIONS General: This form is designed: for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. / Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measUrements given in other spaces on this form and in any attachments. Item 16 .and 24: If this well is completed for separate production from more than one interval (multiple completiOn), so sta~e, in item 16, and in item 24 show the producing intervals fQ.r only the interval reported in item 27. Submii~ a separate form for each additional interval to be separately produced, shOwing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental reCords for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. '~'t Post Office [~/00360 Anchorage, Alask.', 99510-0360 Telephone 907 276 1215 DATE: 09-10-85 Tt{ANSMITTAL NO: 5341 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATION~ ENGINEEkING t{ECOkDS CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRA/qSMITTED HEREWITH ARE THE FOLLOWING ITi~iS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. CASED HOLE LOGS (FINALS): ~lQ-15/ 'CBL 6/12/85 8000-8745 iQ-l-- CCL & PERFORATING RECORD 4/16/85 2V-9--- COMPLETION RECORD 4/25/85 7525-7800 ~2H-15-~ COMPLETION RECORD 4/13/85 6998-7438 2H-2--- CCL & PERFORATING RECORD 4/24/85 2H-14--' CCL & PERFORATING RECORD 4/23/85 ~2~-16--- CCL & PERFORATING RECORD 4/19/85 ~lR-9~ PERFORATING RECORD 8/3/85 7800-8000 VlB-2-~ PACKER SETTING RECORD 6/5/85 7290-7820 ~lA-9~ PACKER S~TTING RECORD .8/15/85 6700-6950 2H-13-- COMPLETION RECORD 4/17/85 7434-7650 ~IR-10''~ PERFORATING RECORD 8/5/85 8300-8550 ~2Z-8-~ COMPLETION RECORD 4/27/85 8920-9030 ~3B-11_- CET 7/5/85 65~0-9100 RECEIPT ACKNOWLEDGED: · DISTRIBUTION: BPAE DRILLING* W. PASHER B. CUF~IER L. JOHNSTON EXXON CHEVRON ~4OBIL PHILLIPS OIL. D &~M NSK CLERK* J. RATHMELL DATE-:~ .... ---SOHIO UNION K.TULIN/VAULT ARCO Alaska, Inc. Post Office Box 0360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1A-9 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on August 7, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JWR/tw SN/L053 Enclosure RECEIVED & Gas Cons. Cornmissiort Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKAO~ AND GAS CONSERVATION CO~v ISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLX~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 569' FSL, /+87' FWL, Sec.5, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 110' ADL 256/+7 ALK /+65 7. Permit No. 81-152 8. APl Number 50-- 029-20669 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-9 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: 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 [] Puli Tubing J~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed OPerations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A-9 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost inte~val. 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: August 7, 1985 14. I her~fy that the foregoing, i_s true and correct to the best of my knowledge. Signed . . Title Area Dri 11 ~ ng Enoi neet The spac~i~lo~/~ssion u; Conditiefns of Appr~l~ if any: Returnec~ Approved by lit IOT{~IE C. SBtTll By Order of COMMISSIONER the Commission Date Form 10403 (JWR) Rev. 7-1-80 SN/082 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate :bMPLETION REPORT FOR SPERRY-SUN ORTH SLOPE~ ALASKA .YROSCOPIC SURVEY By FM SURVEY DATE CqOV, 1, 1981 OSS 16921 )EPTH ANGLE DEPTH SEA RECORD OF SURVEY DIREC DE G. 100!.:: 0 20O 0 300 0 400 0 5Or) 0 600 0 7 O0 0 8 O0 0 900 1000 iiO0 19 299.99 25 399,99 21 499.99 37 599,98 26 699,98 28 799.98 9 899.97 20 999.97 44 1099.97 199.99 SI4.00W 1.47 S 0.C8 E 1.47 S 3 16 12 E 0.117 299.99 515.50W 2.09 S 0.07 W g,09 S 2 8 47 W 0.100 399.99 N52.8()W 2.27 S 0.61 w 2.35 ~ 15 9 i1 w 0.067 - · ., · .... ~....................... - ,~ . ... · · ,. -. - ,,~ .. · . ........ ~ .- . - -c .. ¢~i .... -.. '-. .. 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'::?" ~ ~'e. ~ :'" ' :~...., .:. s ~:..~.:.~.,-:~ a.'[-:~:.?~u:::~,~-~? ::~: .~:.,, ~ ,.~-:~: ~ :-:~'?::'..: ..:..:.~:~..:~::::~:~:,: ~ -:~ .[:..:~x~.:x,~:~:::,:. ,:... ~ ~,::?~":':",-:7.-~.,x~'~ x~:~:.::;~.:~x:::.: ..~: ~x~· -:~.:~.~:~..---~ ":":'::'"'~:':~:'~:?' "?"":".x~.~:.x-:~ ::-..... ::~-- .~':"' '~'"~' ' 'a ~ .o ... ,'- 2700 13 30 2696,49 2596.49 S~5.20E 49,50 S 16,~7 E 52.17 S 18 24 1~ ~ ~.~89 2800 16 42 2793,02 2693.02 S42.10E 6B.~7 S 34.46 E 76,56 $ 26 4~ i5 E ~.210 ~gO(') ~g 48 ~887,97 2'767,97 634,~0E 92.98 S 55.83 E 107,~4 S. 30 ~ 12 E 3,227 _ ' !G?_.43 _~,zoo:/,,,~,,.~.~ ...;~ ~q.'~ :'~ . ~o'~ ~:':'~ ":~:~ ':[::-':;?~f:'j;;L:;~$":~:~:.=~-'%?~:~:~':;::~::?~:. '-:~.:"::~ j:'2 ~:-~'c~.':::: '::.' -'~.4~ ' 2~500 ~1 30 3247,08 3147.08 S28,30E 241.71 S 1~.4.~ E 281.61 S 30 52 Iu ~ 3,006 281.52 3400 32 57 3331,66 3231,66 S29,30E 288,40 S 170,19 E 33~,92 S ~O ~2 2~ E 1,480 3500 33 6 3415,49 3315.49 S2q,20E 336.03 S 196,85 E 389,,4. S 50 21 3, i 0,153 ;~%~r-"~7~'~ ...... ~"'~i'~'.:~"~ ~'-' "% :: ..... :rl~{- * :i-i.-:1 :~ .: .~.q>.-~ :;:...--~:..='-~ .--T-- ......... ~ ....... .=~.'::: '2":.' ~600 ~ ~8 ~99, ~9 ~9,Z~ ~2:8.,:60R.'...:::::;"':'x;-::~:~"~..~V~....$ .:.-:...:':::::Z2~4 I-E' :.;?.::~.:' ~-~..~..:~ .~-O.~w!~s:::.~-:.:&:.:/..- E.. ".; O,zu6 .... .. ~U~ .:.:.... . . .. ,,.- '.~ '.. ' :' ." .~ . :' . ' · · ~ -- ~-, ~. '.-:. ~ . -, .-, .'~ ' '~.." ~ · .' ,:{"): "' ~' { .~ ,~ :' · '4: x ' " ,~' "" . ' ' ~': ' '. 3800 33 42 B666,03 3566,0~ S27.,:8UE' :~':'::~-1,~. S: '275,~8 ~ ~.4,.~7-:.:5.-':..-~:~'..~7.:.:,~.:-"8:....:..~':. :.:'- 0.,279 .'..-.- 3900 ~4 8 37a9.00 3649,00 S27.40E 530.~0 S 301,25 ~2 610.].5 S 29 ~5 9 E 0,~51 610.1~ 4000 34 5 3831,78 3731.78 627,10E 580,47 S 326.93 E ooO,21 S 29 23 21 E 0.107 oo0.21 _~oo~_ ~ ~ 4 ~ s~. ~ ~ ~os~. ~ ~ s~:~:.?g???~s'~z' ~s :s-:;':: :':::.~:t ':~ ~" '~':'-~?-:-s ~o." 40 >::~:..:~'.m?}:~ ~:-~--:8::~:'{:: ~?~:::::::. ::~:..~:..o. ¥ ~ z ":.:": .'s~o. 4500 34 48 4244,98 4144,9a 524,60E 832,79 S 451,7'1 g 947,44 S 2~ 28 45 E 0,492 94'1,3u 4600 34 12 4327,38 4227,38 S23,4.0~ 884,b5 S 4'7~,82 E i003,94 S 28 i3 ~6 E o,'llu 8 0 0 ~ Z 0 4 ¢ 9 ~ · ~ 8 ~ ~ 9 ¢, ~ 8 ' S 27 "9 o E'::':' :--.;,::-9 8'~':' ~ ~ ."S :' '5 z 8 ,'8 9 · E--:" ':: ~Z [. i:"~:-' $':~'~::::~'~::s'.~'t;2:~-~::~:'~::6'.~:;ql:8'.'::~:::':'E':'::'':'~:~;:-::.~:~?' :~:~-i-8 9 ~ ".- ":' ' ~'.:~ ~ ~ . · : ' ' ' :. ~ .,...-::'.-'{-'.:...'-. . .~. .' : .-. · : :.. '-. ':'.;'.:.;:~.: .; ..i... ::~. ;"-~.;.-'.~.;~;~?....;-:....";::$)%',:'.::.-::...;:~::.::;:-'::'~.. ::...: L:.' .::':'i:;'%55~C:':-...'. :~;'- .:.." ·-.:' ~ ~ ~ 6 _ .............. ..... o · 'r w_._ ._~.. '. --_ . ~ .... ~ ...... =_~.:.:~.:~'u=. ..... _.:.u_z ...... '-.'.. - -' ..:"'..: '.":.. ,-.':-,:.:: .~ '~..~'--~ .................... ~ ................. ' 5100 38 41 4738,67 4638,67 S36,60E 1127,03 S 619,35 E 1286,00 S 28 47 26 E 2,870 1285,9~ 5200 ~8 20 4816,90 4716,90 S~5,TOE 1177,32 S 656,0~ E ~347,'Z9 $ 2~ 'T ~7 E 0,492 13~7,'77 L.. :.:::.:ff.';.~ - ... ARC6 WELL BOSS 1:6921 . ' ' .'.2 ~, DEC' 81 . F, bCOI-<D Oh oURVEY :,4EAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDI~'4ATE5 C L 0 S U i:< E S SEVERITY SECTION DEPTt't Ar'4G L E DEPTi4 SEA DIREC DISTANCE ANGLE DEG/LOOFT ~ .. ~(.. · ::::;.~:..'-.. ':. ~:: ."h;;.tti:.;.:i.-;;~"::?;'~'"'.;;,.~h. "-f, /..; ;::..-..'.-. ' ,..'., -:..m' _-.ttf;:~.-... . ::;~ -..':¢;~.:< :..;:~;;f~',,';;'f~..-:~: ::-,.~;:'~:;..:::..:'--.t:" :~:-':.: ¢ ! :i ;';:;:..., .:,:.. ' · .' -' ~:¢'::~;~;;'5~'00 ~8 19 &973.77 48 ~3, ?:7 ......:.:::S~,..~..OE:~.,.,:,:.?:.$:::g~8,:.~.6:: S..¢.. .727,¢2::.-,.E.... 14..~..!..,:Z..2.::...:.:8:..:.:.:::2.9<.:.~.~8..~..-.,:..1..~ ....:.,.o,¢~ . 5600 ~Y 54 ~130.39 ~030,B9 531.30E 1382.87 S 795.52 E 1595,37 S 29 54 37 E 1.175 5700 37 23 5209~56 51~9.56 S~O,lOE 1435.~1 S 826.71 E 1656.~6 S Z9 56 Z2 E 0.68~ 12 "::.528':60E ;.::1539 ol .-5:: .:~u4'30 ;E-'::~ · · 177.5 '~ '~::~..-:$. 29'.::.: 5g, ':.:6. E.,.: ... . .~ 6000 35 16 5451.49 53D1 lo33.'75 -~zoo ~ ~ ~.6~ ~4~.~z-__s'Z8~'0'0~:~' z.~z.~-~ s ~,'~z."E~:~~':'- ~"'"' '"'"- '"'-- - "---'-'" 620r) 33 33 5616.58 5516.58 528.60E 1690.43 S 965.29 E 1940.62 S 29 43 39 E 0.75~ 1940.60 630u 32 31 ~-/00.40 5600.40 528.~0E 1738.38 S 991.27 E 2001.15 S 29 ~i 34 E 1.o37 2o01.13 6400 31 16 5785.28 5685.28 528.70E 1784.83 S 1016.49 E Z053.99 S 29 39 43 E 1.Z55 2053.98 r" '-, " ..... ;' '¢ · :.':. ::, ..: -'.?'" · · ' '.. · :':..' .:' ~ · .: ~. ~::~:~: i:.;.;;.-; ' ?i'A. "C~'~:-~." ;:;i-.::::~',;.;-~:~:;:::.¢ '; ':..: ,, 6600 29 22 5957.76 ~857,76 S28,90E 18"7~,87'S: 1064.63'E. :" ':.:':"'-l,l~l 21~5,19 6700 28 39 6045 .]~.~_._~.~..~_._~_~__._~_¢.,~,,.~_~(:_::.,.~!_~,~_~__~,..:L~_~088 ,08 E 220¢.. 1 S.'29'~.5 14. E '..U.~17 6800 28 39 6132.95 6032.95 S2R.9OE 1958.35 S 1111.26 E 2251.68 S g9 3~ 2i E 0.000 2=51.67 .... 6900 27 52 6221.01 6121.01 528.50E 1999.90 S 1134.01 E 2299.0~ S 29 33 17 E 0.Tu~ 2~99.04 7o0o 2s 55__A~Q.~ ._!.?_ ......... ~.~Oq,.7_~_.~.g_~_,k~.g ..... giO.~...¢ · ~_~ .~.~ ....... 1 !~.~. 9~ ..... g ......... 2~ !,_Q.~ .... $~_~.~ ~ 1 ,.>~_.~; ................. ~. ~ 5o 7100 25 45 6399.40 6299.40 52.7.,:.7.0E.; 2079'54 S 1176.81.E~ 2~'89'43: ,.... ~:. : -,:-- -:;'~$'""29-":30'":'"lg:-E:l::/ :.1.174 EXTRAPOLATED TO TD. ~OJIE ................ E,.EA..SW£LE_. ~ ...... ..~ A,q E D E P T H top up s:~o ~75o ~oa~.oa ~9~7.52 s to~.ss top%L,.~ Sr~D: ~94~ /.::626o.87 .~::.:20!:8' BLJRV DEPTft 7120 6417.42 2087.19 S 1180,87 E 2398.09 S 29 29 59 E 6~17.42 ;~BTD 71~4 6430.05 2092.51 S 118B.71 ;,.:.:~1:. ,.: DEPTH ' DEl;TH -..~.~ .:~.t~; 200 200. ZOO 0 0 0,82 5 O.Z~ E oo,. o ' s ~,. ' ~ :,: :::(4f · ~ ~ . ..:. ..::.':~f.;3::.: ~- ~ .~'~":::;?3::::.:f:..: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '] .; ?~:'t:.:.:::: ::::.:t: '..: :~:;:::.ft::. :f.~ :;,: "::: : ::;~:f :; .::}?:;~:?::;:..::.:'k ~ii :.::: ~ ,J?{~ 1~00 l~O0. 1390 0 0 8.37 S ~.4~, · ':~': t':~' i8oo :.:~: ::.:/ :: :::.:.iaoo. ~:::: i7 ' "~ i900 i900. 1800 0 0 i~.6~ S 9~66 w , · .~ 2000 2000. i9o0 0 0 i4.58 5 ZO.i~ · .:;.~: ~ :::: ::'::. aaoo '22oO.:z ).':' ::.:i::~:.at: ~..:~ .... 2500 2500. 2400 0 r, 24.10 S 6.60 ~'~'~ 2601 2600. 2500 1 i 34.80 S 2.5a E '.~:~ .. . : ,:' .~ . ~ :..:::. :: · :::.:" .':'":.~.'~::...~.::: ::-:~:.':-.:::::.:".: : :: . : : t:.7.:::..:: '::'~ .. ' "::.~ ;~{:::.:' :: ..:.:: ~::'~::.:~:.: '; ."::7:(~ ~::'::: 2 .: .::' . .;.~t~~ ' 280 7 . '.~: · 280 O · ': x 700...:::'::::~..: .::. :: ~.~:.~ :: ~; ::~?:~:::::: 5:9. o:~:t:~:~..~.:~:~::: ~'::?~:.::~aS-:8 :::::::::::::::::::::::::: ? ]:D~ :' :':::. :'' ~ · :::.: · ," ' - r :~:'"::'}::}.:::::: t'~:5'~:;::"::::':~f~:??~:.:~::~".t:~.~::.7: : :~ · .: ::::: .:~":t.:f:'t~~ :. :::::: :' ' ::~:: :~:~::}::.~:t: ?.::t: ~:S~.~'~ :::}:::~ .:J:t.::~..~.::;~ ":2::::' :: : ? .::: :': .'~: : ::' :' -:'. ::: : .' :: , ':,:~ ::. ::?:. 29 ~ 3 : 2900. 28 J 0: ::: : ::~?: ::. :: .~: .:: 5 :~ · : :::::'~. · :.: ~: 96,60 ~: :::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: : ~ :::: · a.~,~ :..L::. · ,':: ~ t. ::::::::::::::::::::::::::::::::::::::::::::::::::: :. : .:..: · cz::.: ::.. : :::. ::. : ::t::.~: t ::.'.::.. :.~:::. :::~:}~ -~ i 3'i ...... 'J'i"~,~'. .... ~ 5'0 o ~ i ............... ~q ................... i~'~:~'-.'~T''~'~-~ ' i o ~;5'~ :'~(?~J ~2 ~500. D200 62 17 . ~70.60 S 160.05 E ~:[~ t . ' :"'..: . ' · · ::::. :: ::::::::::::::::::::::::::::::::: .: ::.:. :.: ::: ::': ':' : :::::: '.::: ,-:: :: ~ "?:::::::.:: ::::: ::::::::::::::::::::::::: .~; ::":-:::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::: :: ' .::' ~:~ : ..: .:.:.::. ::;::.:.::.:.. ~ ;~ :.....:..::::.. .~. :,~:.: :.:::.:.::.::: :::::::::::::::::::::::::::::::::::::::::::::::::::::: ::.:: : :: ff:~!,:: ::' ~~ '.;~::: _3600 · ~ 500: : ~ 2: ::::::::::::::::::::::::::::::::: ::':' 2 U" · :..:::: '::::c::: :: ::' ~ 4 Z · ~ ~ :~:':?...~::.::::::.: t.t~t?:.~-~b :::: :~:: ::: ::~: .::.:. : .:' ARCO 'WELL 'A-9 BOSS 16921 ::: :: : : ~ DEC, f..'l E ASUR E D L)EP TH DEP Tt- 8E.A D I P:F~E. REi~CE.i:::ii: Cu-.,I,,~iCT I oti.: :; TOTAL:: . 3[']41 370r~ ' ,,. 3600 140 20 501.37 ......... 5..961 ................. 3 !'.~ 0 O ........... 3_.Z_Q...~ ........ 1.,(zl ................................ g.l ....................................... .561 · 08 6989 710]. 7 .~..1_1 $ 285,70 4082 3900. 3800' 182: :. ':: ..... 21 621 ~6 ;.::-3~7,75 4445 4200. 4100 245 22 804,35 5 z~38,40 4567 4300, 42[.0 267 22 867 54 S 467 ~$o~ ..'...: : .4soo. '~oo .1 (ess.sa:: ~.: :'::.' .'::: ..~.z_~_',..,~.~:::~~: 5178 4800, 4700 378 28 116~.54 S 6~7,65 ~os ~oo. 4soo 406 543s 5ooo. ~92 _~3s ................ 8_2 .................................. ~Z.R5.7s 8 7~s.~z ~ 5 ~: ~: o o: · ~ oo, o: .:: ~ ::::::::::::::::::::::: 5937 5400, 5300 537 24 1558.76 S 894,37 6059 5500, 5400 559 22 1620.81 S 9g7,82 6180 5600, 5500 580 2i 1680,77 S 959~82 6648 6000~ 5900 648 15 1894.55 S 1075~62 6762 6100, 6000 662 14 1942,60 63oo. 62oo 6s~ 6400. 6300: 701:,' : Z :: .: :::ZO: 79. 5:::::::::(:::: INTERPf)LATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTPi, MEASURED DFP TH 1000 2000 4-000 ,,5000 7O00 VERTICAL SUB]' ' · . : ..:.... DEPTH SEA,. ::':-TOTAL CO0.<D'Ii'~- TE5 .:7:' 'i - :' ::::- . -.....:...:..:_': :t":; . ."..:..-. · · ... ·. '- ~ i' ~'~ ':' · -:': · !i : :--".' · .'-':;..:.:'.:.i.].:: '... · :...:.-..:.:... _ .............. 999. 899, 5,0~ S 1.32 W 1999. 1899. 1fl,58 S 10,14 W 3831. 373i'"'~-:. 326'70 E ' . . '.'. ~ ~ 1 · .':'~"~ i~":~:~;:{:'.~:;t:..]:'.'~:'~?~'z~'5~':~';~g' t-"S;/'.-::{::/::::~9 ii" 5~'.: E~:t].-":.'-.-'.] ::;.t .] .... ]] ...... ]]]L.]].]]...~ .~_ sog. 2o o. 2 s December 14, 1981 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16921 Well No. A-9 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: November 1, 1981 Operator: Marvin Milam Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. ~Kirk'-Afflerbach .District Supervisor KA/pr Enclosures "0"I RADIUSiOF iCURVATURE METHOD .~ ?PLETI.ON REPORT FOR SPERRY-SUN BY FM: LINDSEY, ",:ORTtt SLOPE~ ALASKA SURVEY DATE NOV, 1, '1961 GYROSCOPIC SURVEY 2. O.S&_..1692.1 1500 1 0 1499.,93 1389 1600 0 56 1599,92 1489 .1700 0._55 ....... 1699,91 ........ 1589 1800 0 41 1799,90 1689 1900 0 46 1899.89 1789 2100 0 32 2099,88 1989 2200 0 22 2199.88 2089 ~.~OO ........ 0.,2~ ..... 2299'.8~. .21~9 2~00 1 41 2399.85 2289 RECORD OF SURVEY ...................................................................... r .... ~:- ...... i~'~'~?-''~ ........ ~ "-" :":'"!~,i ~'~':'"i 7!~7"-~ ............. ' ..................... ::. ., TRUE '. :: i;::: :;:'::.i:: : DoG LEG ':LE_~.D.[{IE.T~E~ T I.CAL,: ........ 'SU~._:~ '.' D'_~iE-T~ :~' ~:'~ .:SEVER ~TY )EPTH ANGLE DEPTH SEA DIREC D~ STANCE ANGLE DEG/iOOFT DISTANCE D M DEG, D M S o o o :"6'0~ .... u'{"f~';o'~.~:o.:::~oo~::::::.?.~:~::..o,oS:"~Z'~ :~:;'~5 w;'..: 300 0 19 299.99 189,99 Sla,OOW 1.47 S 0,08 E 1,47 5 3 16 12 E 0.117 1.32 400 0 25 399,99 289,99 S15.50W 2.09 S 0.07 W~ 2,09 S 2 8 47 W 0.100 1.7~ ....... 500 .... Q~2.1 ......... 499,99 ..... 389..99 ....... N52.,8.QW .......... ~ 2.27..S ~.. O,6i.~W .......... ~ ~ 2.35 $~.~1~.?~.9_~1~ .... ~ ............. 0.067 .............. 1.67 600 0 37 599,98 489,98...~.:S 2,90W '"~' '2.56 S ' .~ i'25 W ( ~. 0.267 700 0 26 699,98 589,98 ~S~ 'll~W ~ ~"~ ~. 3 0't83 2 900 0 9 899.97 789,97 528.90W 4,75 S 1,03 W ~,86 S 12 17 7 W 0.317 1000 0 20 999,97 889,97 561,70W 5.04 S 1.33 W 5.21 S 14 46 33 W 0,183 ~!iQQ~..0 ~.~ 1099,9% .... 989,~.~. .......~.~.~.~QW. ......... ~,66 S 2,01 w 6,00 S 19 36 17 w ~,400 z'~-5~ "0 ~s~ ..... z z9~''~g ' Zo~.~ s3g'7ow .~ :':~::~:'~'~:. ' ~.i:~.':g:'~ ~'Z~:..f:~T:~'~:g' ::~'::~ ~:" o zoo 1300 0 43 1299.95 1189,95: ::7,~Z 5 8'29::.$::~:-Z~ 0~083 _.~.~._oQ ...... o._~,l.~.~,.~ ........ z.z~_~ :Z:Z:C~-~' ~.::w: ::...._~::.::::..~ o o~o · 93 553,50W 9,29 S 5,70 W 10,90 S 31 32 55 W 0,250 ,92 S52'90W 10,31 S 7,06 W 12,50 S 34 25 39 W 0,083 ,91 ......S~3.,90W ..... ~_1.1.,:38 S ................. 8,27 W .......... 14,0~.._S...36~.: ........ O~.AZ ....W ...... ~ 0,017 ..... 5, ,90. 'S20,70W 12.55 $: ~ 9'01 W 15,45 S~5.40:?~:48 W 0,233 · 88 SiO,50E 15.45 S 10.16 · 88 516,30W 16,22 S 10,20 ,8.7 ......... .52~.,.,~ O ~ .......... 1 ~,, az+ 5 ....... 10,42 · 85 528.50E.ii::':] 18,58 S . 10,35 · : . . ..: W 18.49 S 3.~ 20 41 W 0.067 8. W 19.17 S 32 9 58 W 0.167 9. W 2'1,27 51:29' ~: 6:1:158 W : 1'301 ARCO WELL A-9 BOSS 16921 9 DEC, 81 · · : R ECQRD._O E ..... 5 URV.EY ............................................... ! ....................................... ____? FIEAS. DRIFT VERTICAL SUB DRIFT TOTAL COOR~ZNATES C U O S U R E S SEVERITY SECTION DEPTH ANGLE DEPTH SEA DIREC ~[STANCE ANGLE DEG/IOOFT P[&TANCE .................. D ...M ............. ' .......... DEG · D ...... M ....... 5 ............. . : ; :: :: · . ,Z~.QQ .... ~ O ....... Z ...... 2.~ 9 ~. ~Z ........ Z~.~ ~., ~.LLs~i, ~O~EC':". L':~ ~., ~Z S~L:~2Z:;,-~:~.E ..;'~ ~ ~* 7~S!L:~ 2 ~;~:Z.%.~ ~ ~. o ~.o ............ 2700 13 30 2696.49 2586.b9 5~5,20E 49.50 S 16.47 E 52.17 S 18 24 14 E 3.~89 51.20 2800 16 42 2793.02 2683.02 S42,10E 68.~7 S 34.46 E 76.56 S 26 ~5 i5 E ~,210 76'~5 _.290.0._19~,~8 2887,97 .... 277.7,9.7 ..... S3~,30~ .... --_92,98 S ............ 53,8.3.E .. 1.07,44.S. B0 .... ~ 1Z._.~ .......... 3,227 1.07,43 3000 23 8 2981,01 2871,01::";::5~8'10E :;~-~:.':::::.i22'52~ :S/ :{: 75,~5 .E 143,89:5:.-31 ~7 ~6 .~.~85 1~,79 3300 3i ~0 32~7,08 ~13T,08 S28,30E 2fi~,71 S ~,4g E 281,6~ S ~0 52 ~0 E ~,005 3~00 32 57 333~,56 ~221,66 ~29,30E 288,~6 S 170,~9 E~ 35~,92 5 30 ~2 2~ E 1,~80 ~,87 .... 35.Q0 ..... 33 ........ 6 ..... 3~15,~9 ....... ~305,~ .... 5.29,.2.0.~....~ .......... ~36.,0~ .S ......... 195,83.. E "389,~.~..~::.~0..~_1._~.__~ ........... 0,1.5~ .... ~500 33 12 B~99,19 3~89, 9~ S: .': 223"27 ~: 3900 34 8 B749.00 3639.00 527.'40E 530,60 S 301.25 E 610.15 S 29 35 9 E 0.~51 4000 34 5 38~1.78 3721,78 527.10E 580.47 S 326.9~ E 666,21 S 29 23 gl E 0,107 666. 4200 33 55 3997,61 3887,61 526e40E .::': 680.16 S~ ~ .377,56~ E : .. 777'93. 5 29.: 2 6.E : 0,221 777, 4300 3~ 6 4080.49 3970.49 g: ~'~. ~ 0.194 _A.~DO_L3 A_~_L__~ 162 · 91 .... ~052,9.L $2 ~ ~ :' :'~':~ 4500 34 ~8 4244,98 4134.98 524,60E 832,79 S 451,77 E 947,44 $ 28 28 45 E 0,~92 947, 4600 34 12 4327.38 4217.38 S23.40E 884.55 $ 474,82 E 1003.94 S 28 13 36 ~ 0,710 4200 .... 3.3 ..... 3 ........ ~410 4800 33 10 4494 4900 34 27 4577 __ 5QQO ....3.5_..5 6__._.~ 6.59 5100 ~8 4~ ~738 5200 38 20 4816 ~.5_3 QQ. 38..19 ...... ~895 · 6.3 ..... ~4:~00,63 ........S. 21_,..6.OE ......935 7:3_ S .... [ ...... ~_96.,.02 E ........... 10.59,0.7 5....27. ..... .5..5 ..... :~.f2 [ ................... 1,269 ....... :..: i~5, : : :,::-: .. ::. ~ ' ~ :~ : . ~ . : .- ::: · ... - :: .: ~ · 67 4628,67 S36,60E 1127,03 S 619,35 E 1286,00 $ 28 4T 26 g 2,870 1285, · 90 4706,90 535,70E 1177,32 S 656,09 E 1347,79 S 29 7 47 E 0,492 1347, ,33 ..... 4785,3~ ..... 535.,20E .... 1227,86.5 ............ 692.,D7 E .......1~0~,~7 .... 5_.._.2.~....~.._ZT,.g _._ O, 195 1409, : '- ::.. : qT.-7~ ...................... . 15 21 ,1~ .... 9~ ~0 7O ~9 91 7-/ ARCO WELL A-9 BOSS 16921 9 DEC, 81 TRUE. MEAS, DRIFT VERTICAL ,SUB DEPTH ANGLE DEPTH SEA .................. D ...... NI DRIFT D I REC 5400 38 19 4973 --55DCL._ ~ 8_~.6___ 5051 5600 37 54 5130 5700 37 23 5209 _..EBI]O 35 .... 35 ...... 5289 5900 35 4.7 5370 6000 35 16 5451 61D.0._..34.__..L1--.5.533 62.00 33 33 5616 6300 32 31 5700 .............................................................. ]] .......... . ...................... DOG LEG ...... TOTAL COORDINATES C L 0 S U R E S SEVERITY SECTIOi~ DISTANCE ANGLE DEG/iOOF'T OIETAmCE · 39 5020.39 S31.30E 1382.87 S 795.52 E 1595.37 S 29 5~ 37 E 1.17~ 1~95.32 · 56 5099.56 S30.10E 1435.41 S 826.71 E 1656.46 S g9 56 22 ~ 0.680 1656.40 · 12 5260,12 ;:$28.,:6OE.?::':::i?lE'39'81'.S ~?.:88~,30 ::.:.6 5.-:'. 0,~03 1775,63 · 61 .....5~23 ,.6i].~S2.8~0 fl.~]~:i 6 ~1 ,:28.'L:S.Z]~:.]:83:~_' 82_E2..f] i 6 90.' 82. :::S]_:29:~~.%]zE ]U::].:_' Q, 985 ......... 1 ~ ~ 0 · 79 · 58 5506.58 S28.60E 1690.43 S 965.29 E 1946.62 S 29 ~3 39 E 0.756 1946.60 · 40 5590.40 S28-30E 1738.38 S 991.27 E~ .2001.15 S 29 41 ~4 ~ 1.037 2001.13 53,9~ ..... ..6~O0..31.--1.6 ...... 5.785,28. 5675,28 ....... S2a,..7.0E___1784,83.S ....... 1016,49.E ...... 2053,99 S._.2D_..3R._._~ ....... E ........... 1,25~ ............ 20 6500 30 28 5871.10 5761.10 $28..00E :'1830.00 $ 10 0.86 E 2105.30 - 0.820 2105 30 6600 29 22' 5957,76 5847,76 S28,90E:~-:-"/1873.87 $'-1064'63 E 2155,19 _a?Q~..28_39 ...... 6045.,.20 .... 5.9.35.,20...]~S2B']9.0~]]~.916.35:.S ]_]1~88,08 E_.:].:'_.2203.71.].:5].Z.9::.~EL'!Z~.E.._':.~, ..... 0.71.7..' ................. Z.Z03.. 70 ... 6800 28 39 6132.95 6022.95 S28.90E 1958.35 S 1111.26 E 2251.68 S 29 3~ 21E 0.000 2251.67 6900 27 52 6221.01 6111.01 S28.50E 1999.90 S 1134.01E 2299.04 S 29 33 17 ~ 0.78~ 2299.04 _.7.000. 26_.55 .... 6309.79 ..... 6199..19 ....... S28.,..~OE .......... 2040,37 S ..... 11.55.,94_._E ...... 234D.06 s_gg~_.~l__~_~--.~ ............ 0.950 ................ 2345.06 7100 25 45 6399.40 6289,40 S27,70E .2079.54 $ 1176.81E 2389,43 $ 29 30 19 ~ 1.174 2389,43'-~,/ 7120 25 33 6417,42 6B07,42 S28e20E 2087.19 S 1180.87 E 2398,09 S 29 29 59 [ 1,103 2398,09 EXTRAPOLATED TO T.D, .7255. 25-.33 ...... 6539,.20-. BOTTOM HOLE CLOSURE 642.9,20 ....... S28-,20.E ....... 2138,5Z+_.S .. 1208.,4Q-.E .......... 24.56,34 .... .S._.29_._2.8 ..... =8_E ............ 0,000 2~56.34 2~56,34 FEET'A'T' S.29 28 8 E - :]. ARCO WELl. A-9 BOSS 16.921 .. 9 DEC, 81 ......... iNT. ERBDLATED TRUE VERTICAL....,DE.P_IH.5.,:~i,CQOi[ADINATE5 ANDi~CLoSU. R.E.5 FQRLGtVEi'i.~E.P.J.~5 TRUE _CODE ............._MEASURED ........... V.ERT I.CAL___ ......... IOI.AL ...... COORD.I NATES .......................... C. ,iL~.._Q_~._U..._R_E ........................ SUB NAME DEPTH DEPTH :' ; .~: ~] DISTANCE ':~..: ANGLE :::::.. : ~::~ SEA TOP UP SND 6750 6089,08 1937,52 S 1099,33 E 2227,67 S 29 34 13 E 5979,08 .BS-UP SND .......... 6820 -.. 6150,51 ..............1966,79 S ....... 1115,75 E 2261,2~ ..... S ~9_._3.~ ~8_. E ..... 6040,51 TOP LW SND 6945 6260,87 2018,34 5 11~3,82:E 2319,92 & 29'3~ 26 E 6~50,87 BS LW SND 7000 6309,79 2040,37 S '1155,94 E 2345,06 $ 29 31 59 E 6199,79 ~B.S--KUP., ................ 70.60 SURV DEPTH 7120 PBTD 71B~ .~ID .......................... 7255 6417,42 2087.19 S 1180,87 64B0,05 2092.53 $ 1183.71 6539,2.0 ........ 21~8,5~-~ ..... 12.08 · 40...._E 2'398,09 S 29 29 59 E 6~07,42 2404.13 S 29 29 46 E 6320.05 2456.34 ..... 5..29_..Z.8 ........ 8._E ......... 6429.20 ARCO WELL A-9 BOSS 16921 9 DEC, 81 .MEA,SURED.._DEPTH..AND .OTHER. DATA.._.F_.QR_F. VF_I~Y.._EVEN .... 100 FEET OF. SUB ,,SEA DEPTH, ................................................................. ..................................................... TRUE .................................................................................................................................................................. MEASURED VERT!CAL SUB MD-TVD VERT!CAL · DEPTH DEPTH SEA DIFFERENCE CORRECTION T OI'AL COORDINATES 210 210 .............. 31~ .................... 310 410 410 510 510 610 ' 610 710 710 810 810 ................ 91G ............................ 910 .~. 1010 1010 1110 1110 121.0 1.210 1310 1310 1410 1410 100 0 0 0 ........ 200 .............. 6l ............................ 0 ........................................ 1 300 0 0 2 . : 4 00 O' .-.. ': :-.' :- '"' 0 .' 2 · . 50~O~/:i::.':i_.:i~: ................ 0__ "- 2 600 0 0 3 700 0 0 4 .......... 80_0 .......... O.__ 0 ............................4. ~ o o' ..:i--;?::.:: .:.'o :..~',.;. ;~.;i~:~: ..';. ~';~ ;' '- o- · i~;: .. ~ lOO0 :..?i:.'-.:.i-',:io:-:ii':.::i.';::.? :i o---'.:?!'::./ '-'i. ~ .... llQO ' i'.;:::': ":0 "'" "':':' :'~ -' 0 ";:7 :::.: ........... 6 1200 0 0 7 1300 0 0 8 ............... 1510 ....................... 1510, ........ 14.0~ ......... Q ..................... 1610 1610, 1500 0'...:!'::.:?' · . 1710 1710, 1600:..: .'.'0 ::i/-;-!~:: 1.81.Q_ 1..81_0_~ ......... 1.700.~ .'-'. ~~.~ -." 1910 19 2010 20 .................... 21lQ .................. Zl 2210 22 2310 23 241_0 24 2510 25 2612 26 10. 1800 0 0 13 10. 1900 0 0 14 10. ....... 20QQ ........... 0 ............................... 0 ............... 15 10, 2100 0 0 16 10 · 2 20 0 0 -?i": ..:-i:':'.:. - 0 : 16 · 1.o,. ............. 2 3 o..;z ...... ~:o_i~ '"~1'2~._:....~' ......... ._ o ......... : ....................... '; ':?.14. 10, 2400 0 0 24. 10. 2500 1 1 36, · 90 S 0,1/-+ E · 53 S .............. O,.D7 ..... ~ ................... · 16 S 0,10 W · 24 S 0-67 W · 6.7 ___S]___i :~'?..Jl:~:~l ,~L~_.t~L-L:iZ_..~;......; ............................................ '~'-~' · 54 S 1.08 W · 31 S 0.92 W .77 .S .............. 1.,_O 4....:~. ............................ · 07 S 1.38 W . ,76 S 17-2,08: W · 72._..5 ............ 22 ,.2..7~N .............................................................. · 6i S 3,55 W .45 5 4,55 W · 39.· S ................ 5 ...8..(*...~ W ........................................................ ,41 S 7.19 W · 50 S _ 8'37ll W · 66...._.5 ...... : 9_.,.Q._~._ _.' ~_~ ............................................................................. ,73 S 9.74 W · 66 S 10.16 W · 54. ,~. .............. 10,..1.5 ..W.. .............................................................. ,28 S 10,22 91 ~-:-.:..-. lO.45 w ~ 7._._s_:_:i_/_~.~:.'. ~ ~_.._~- ........................................................... 94 S 5.92 W 21 .5 3.82 ............. 271~ ...................... 2710 2818 2810 2923 2910 ................ 3032 ......................... 3010 3143 3110 3257 3210 ................ 3374 ......................... 3310 3493 3410 3613 3510 ........... ;~ 7.53__ ........................... 3610 · ..... 26 O0 ............. 3 ........... · 2700 7 · 2800 13 - · ......29 QO .... __21 · 3000 32 Z ............................................ 51.84-S .............. 1-8.39 .....E .................................... 4 72.26 $ 37,88 E 6 99,52 S 58,32 E ..................... 8 ..................... 132.,65_.~ ............ :.._~:~3...,.lO__.E ................................... 11 173.37 S 109,42 E · 3100 46 14 222,22 S 134,08 E , ...... 3200 ....... 6A..: .............. 18 ............................. 276,25...5 ................. 163,1.4 ..... E... ............................. · 3300 83 19 · 332,79.'5 .:::i~::: 194e'76 E · 3400 ,::';.' 19 ':.': 390'17 S::;:.;::i.: 22:6'59 E , ......... 35 QO ._ :~::;::~:-::~'. 2.0 ~]:~.~._:i],_~].:_::::...!:.....]:]../~ ~ 8,23.: SZ~;'.': ..:'252~.~3-.:,E..,.L~L::,_L__...:: ....... ~ ARCO WELL A-9 BOSS 16921 .. 9 DEC, 81 MEASURED VERTICAL DEPTH DEPTH SEA.iD'I'FFERENcE::...i-CORREcTIoN"i: · TOTAL coORDINATES 3853 3710. 3600 142 20 507.36 S 288,75 ................ 397,f~ ......................... 3810. ........... ~70D .........1,66 ....................................... 22 ......................... 567.41 - 4094 : 3910. ·-! ~800i.i:,-ii:i~!i?!i!184:;'.'i'L-;!i'?.: :_'._~:' : '-:-..20- i'... :. -627,33 S' 350,81 E ''--' ~215 ' :??--. ?:--.;; ;~;;' .? ':::: 687 · 65 ' .~ aaa __.;;~ 110 ,.~ 0-O~ ~::":::':.:itL~ :;.~::z i ~ iL .... Z;iJi L:_]:.:L__~ ~ s, 37.. ~57 ~210, 4100 2~7 22 810,56 s ~1~29 E ~579 ~310, 4200 269 22 873,83 S ~69~71 E 5191 4810. 4700 381 28 i173.15 S 652.30 E 5B19 4910. 4800 409 28 1237.B6 59~9 5~0, 5300 5~9 2~ 2565,03 S 897~7~ E 6071 5510. 5400 561 22 2626.8~ S 931.02 E :'_.. 6Bll .'.. · .5710.. ;::'-:"" .'.;Z9 .'.. ;.:';S.-:. ~74~.59 $ : 99~.0, E · ' 6560 6010, 5900 650 6774 6110, 6000 664 ................ 688.7. .............................. 6210., ........ 61.00 .... 7000 6310- 6200 :' 7112 6410, 6300 ' " 722.%--._: .......... 6,5 15 1899,60 $ 1078.31 14 1947.61S 110~.70 .... lB ..................................... 1994,77.,..$ ......... 1.130,63__E 13 2040,37 S 1155.94 12;~: :~:,~'~ 2084,07'$ 1179.15 ARCO WELL A-9 BOSS 16921 9 DEC · 81 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, ................................................ TRUE NEASURED VERTICAL DEPTH DEPTH 1000 999. 2000 1999.- ............................. 3000 ........................ 2981. SEA ::':.':;: TOTAL COORD i NATES_' 889. 5.04 S 1,92 W 1889. 14,58 S 10.14 W 287.1. ........................ 122.57...S .... 75.. 33.,. E ............................................ 4000 383'1. :3721.' : .... '- 580,56 $ 326.70 E 5000 4659' ~549.'..-i:!i:i!:i::.ii]ii:::~::::i..i:?.i~::.-..':.:?:i:079.46 S 581.70 E a.o.o.:}: ........................ 5~+.~.: ..::: ...... ~::-<<L.:::~?:L:_z~.~z'. :.z_.s:_ ....... :]gzz:._~.~::_E.:: ....... : .................................. 7'000 6309, 6199. 2040.52 S 1155.61 E HORIZONTAL VIEW ARCO ALASKA, INC. KUPARUK FIELD~ WELL A-9 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: I" = I000' DEC. I0, 1981 T II N.,R. IOE.,U.M.' 6 487' .~O0 , \ /'-- CLOSURE ~ '_,.,o~q,~/ . S 29° 28' E -?.456 · - . ..... ~,,o° .......... ' ' ~ TVD: 6539' TMD: 7255' ALL DEPTHS SHOWN ARE TVD SURFACE LOCATION IS ...... 569' NSL, 4'87' EWL, SEC. 5 T. II N., R. I0 E.,U.M. 400. 800 1200. 1600 ?.000 2400 VERTICAL SECTION ARCO ALASKA, INC. KUPARUK FIELD,WELL A-9 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE" I" = I000' DEC. 10,1981 ZSO0 444 64( TVD = 6539' TMD = 7255' ALL DEPTHS SHOWN 'ARE TVD Suggested form to be inserted in each "Active" well folder to d~.eck for timely compli~ce with our regulations. '-Operator, W~I1 Name and Number Reports and Materials to be received by: /~-- Date Required Date Received Remarks , Ccmpletion Report Yes, / ~ - d~ ~- ~ / ~ ~'~ _S~les - P l . ~re ~ips Registered Su~ey Plat Inclination Su~ey Dire~ional ~ey' Drill St~ Test Re~s Pr~u~ion T~t Re~rts , ~s R~, Yes /i-. , Digitiz~ ~ta . , ~ STATE OF ALASKA ALASK/~ AND GAS CONSERVATION C,( ]ISSION MONTHLY REPORT 'OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-152 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 5o-029-20669 4. Location of Well at surface 569'FSL, 487'FWL, Sec. 5, TllN, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) lO0' RKB 6. Lease Designation and Serial No. ADL 25647 ALK 465 9. Unit or Lease Name Kuparuk 25647 10. Well No. IA-9 11. Field and Pool Kuparuk River Field Kuparuk 0ii Pool For the Month of, October ,198] 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] @ 0700 hrs, ]0/22/8]. Ran & cmtd ]0-3/4" csg. Drilled 8-3/4" hole to 7255', as of ]0/3]/8]. See Attached Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests ~16", 65# H-40 conductor to 80'. Cmtd w/200sx Permafrost 10-3/4", 45.5# K-55 csg to 2242'. Cmtd w/1000sx A.S. III and 250sx A.S. II¸ 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/BHCS/GR to 7206' FDL/CNL/GR/~al to 7206' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None to Date Alaska Oil & ~as Coa~. ' A~Chora£~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S'GNE~/~J-~~'~ 2~'- ---r Z~._/,~,'/~., T,TLEsr' Drilling Engineer DATE NOTE--Report on this f/mis required fOr each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservatio~ Commission by the 15th of the succeeding month, unless otherwise directed. / Form 10-404 Submit in duplicate Rev. 7-1-80 NOr,, n~kLOPE Ei~GI;'~EERI''n~,,¢ J. J. Pawelek/Ann Simonsen DATE' ///-- ~,Z--~/ WELL """".~",,,-,..,._ . Transmitted herewith are the following' rL~.~= HOTE' BLUEL!~c, - SEP:~,, .. F - FILH, T - TAPE' RECETpT DATE: PL:-,~,~- ,',r_,u;:,~ RECE~FT TO' ARCO ALAS!iA, INC. ATT?I: AN~; SIFiOHSEr! - AFA/311 P.O. BOX 360 ~,,,"',,n"',',"'"- ,~:, 9~510 RECEIVEO ,. NOV?5 1981 ^!asker Oil & Gas Cons, Anchorage ,'~u,-,~, -LOPE E~:GI~-[EER[i:G Pawe?ek/Ann Simonsen Transmitted herev:ith are the following' S - SEPIA, F- FILM, //¢- ¢ RECE ~, PT ACK[;O',.:LED,.,E _ .... :-,~,URI, i~ECE~?i TO' ARCO ALAS!iA, I[4C. ATT~I: Ai.i~i SIi,iO~iSE~I P.O. BOX 360 A:iC''n~'~ "" aaSlO DATE' RECEIVED NOV 1 8 ],qB! - AFA/711~lska 0il & Gas Cons. Commission ' Anchorage ARCO Alaska, Inc. [' Post Office Bo~ t0 Anchorage. Alaska 99510 Telephene 907 277 5637 November 12, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 13-3 ~,_ DA 13-7 DS 14-14 Dear Sir: Enclosed please find the following' · The Sundry Notice of Intent for DS 13-3. The completion Gyroscopic Surveys for DS 13-3, DS 13-5, DS 13-7, DS 14-14, DS A-3, DS lA-9, DS B-9GI. Sincerely, P. A. VanDusen District Drilling Engineer PAV: GA' 1 tc Enclosure Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 November 3, 1981 Re: Our Boss Gyroscopic Survey Job No. Boss-16921 Well No. A-9 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: November 1, 1981 Operator: Marvin Milam Dear Mr. Hines: Please find enclosed the "Original" and one. (1) copy of our Boss Gyroscopic'Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Ken 'Brous s ard District Manager KB/pr Enclosures · .. .. , : DATE OF SuRvEy . NOVEMBER 1~ 1981 ., I AR. CO ALASKA~ INC. L.~.ELL NO, A-9 SEC 5 TllN RIOE KUPARUK FIELD N'ORTH SLOPE, ALASKA ,_E o_s. s__s_ _u. ,R_.~, c_.~ .......... VERTICAL SECTION DIRECTION S-31-37-00-E BOSS-16921 NL SPERRY-SUN . .' ·" R~£ORD OF SURVEY · TRUE SUB COURSE COURSE: DOG-LEG TOTAL . MEASURED V E R'T"I'~'~'[ .......... ~"EA INCLINATION ~I'R~ION SEV RECTANGULAR COORDINATES V~RTICAL DEPTH DEPTH TVD DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST ,ECTIOM {' O0,O0 100,00 68,20 {:::'::":.:'0 S .18 ":6'.::E ' I ~00.00 200.00 ' 168'e0 0 2 s 2:5~' E 19 8~.'S' 17~'E'::i:':.,'"', .79 300.00 500,00 268.20 0 19 S lq 0 W .17 1.~8 S .12 E 1.32 400.00 399.99 368.19 0 25 S 15 30 W .1.0 2.08 S .Oq W 1.75 700 O0 ::.:' 699 98::i:: 800,00 799,98 900.00 899.98 768.18 0 28 S 6 q8 E .10 S6S.~,S 0 9 S 2S 5~ W .35 q,78 S 2 ° 69 · 38 U · 39 W 3.43 3.86 1000.00''. 1100.00:.1 1200.00 1 .. 1300.00 1 1~00.00 1 199.96 1168.16 0 38 S ~6 ~2 W .10 299.96 1268.16 0 ~.3 S ~q 0 W ,12 399.95 1368,15 0 ~6 S 5~ 1,2 W ,14 5,i05 S 5.71 S 6.69 S 7,59 S 8,~3 S .72 2.81 3,79 16 62 99 19 i..... !1 ]0,00 600.00 t ...... !._z...o...o.. o o 1800.00 1900.00 l~f"~';~g .......... i'Tg~';'i"¥ .......... i--S ................. g"g~ ~o u 1599.92 1568.12 0 56 S 52 54 W .09 1799.90 1768.10 0 ~l S 20 ~2 W .39 1899.89 1868.09 0 ~6 S 41 0 W .26 9.35 1.0.37 11,~3 12,57 S 13,63 S 5.05 6.42 7.61 , 32 75 8,38 W 9,03 W 6,31 6,88 :.:..2000. 0 O [: oo.oo 200 · 00 1999.89 1968.09 0 28 S 15 12. W ,~1 2099.88 2068.08 0 32 S 10 30 E .21 2199.88 2168.08 0 22 S 16 18 W ,26 . 14.53 S 15.37 S 16o13 S 9,55 9.56 9.56 0 36 08 72 2300,00 2~00.00 2299,88 2268.08 0 23 S 23 24 W ,05 2399,85 2368.05 1 41 S 28 30 E 1.49 16.73 S 18,33 S 9.78 W 9.21 W 9.12 10.78 2500,00 2600,00 2700,00 2800,00 2900,00 2~99.61 2467,81 5 59 S 39 48 E 4,34 2598.61 2566.81 10 2 Sql 30 E 4.07 2696,~9 266~.69 1~ 31. S ~5 12 E 3,56 2793.02 2761.22 16 43 S 42 6 E 3.30 2887.98 2856.18 19 49 S 5~ 18 E 5.94 23.63 S 3~.17 S' ~8.94 S 5,17 3,9~ 18,02 67.85 S 92,54 S 35,96 E 55,17 E 17. 31. .51. 76. 107. 16 12 63 73 _WJLLLNP_., __A -_%_.S.!..¢__D.,I.!..i_N_Ei..Q.E .... '. L ~ . :.":' :0 A ~ E. 0 E'.S U R V EY .'. N.O V EM ~~J_].%.8.! ....... VERTICAL SECTION DIRECTION S-31-37-00-E ALASKA KUPARUK FIELD NORTH SLOPE, ..~L.QS.,.S._~UL~. ~ E L ._ !R_U.E ............ MEASURED VERTICAL DEPTH DEPTH ...... B 0 SS,.169_21 .......... NL SPERRY'SUN' .":' :'i.:':I'' '":'""' ' ~'"':" ' : " · ....... · RECORD OF SURVEY;:'.:..::.' :" '"' _ U r ' !'" · S U.B ..... ~.~ ..... g_$.. ........... _C Q.LLR_~ E__ .. ~ D ~G '-LiE. G ' ' '.TO :T A l :'.' ';" ..... SEA INCLINATION DIRECTION SEV RECTANGULAR COORDINAT:'S VERTICAL TVD DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 3000.00 2981,02 2949,22 23 9 ~ 00.00 · 3071.851:1 304.0 05 t ~ o..0 o ~Ap__,.~. ,-_~] 7 3300.00 324.7.13 3215,33 3.1 31 3,+00. oo 3331.71 3299.91 ~ ~8 S' S 28 18 E 3.23 241.25 S 1~5.70 E 281,82 S 29 18 E 1,55 287,99 S 171.4.1 E 355,10 5500,00 3600.00 _..~7_...0..0_,. 0.0 ...... 3800.00 3900.00 34.15,54 3385,7~+ 33 7 S 29 12 E 3499.25 3467.45 33 13 S 28 36 E .3_ 5.8 2..,..Z.9_ ............. ~ 5_5...0,.,_.~,9.. ......... -~ ~ ..... 2. 8. ................. _$ .... 2 8 ...... 1.Z__~__ 3666,09 3634,29 33 43 S 27 4~.~ E 374.9,06 3717,26 34 9 S 27 2~+ E · 15 335,56 S 198,05 E 389,58 · 34 '583.44. S 22~.4.8 E 444.,21 ._,....~ ..E~_I~_Z..~_S 250._,_62_E --- ~.~...Q.9 ............. · 33 480.65 S 276,60 E 554..31 .48 530,12 S 302,46 E 609,99 .3 3" 5 8 7 E S ~300,00 4080,55 4048.75 34 7 S 26 1 qqO0,O0 4.162.97 q131,17 3q 52 S 26 ~ '0 O0 424.5.04. 4213,24 34 4o S 24 3 4.bO0.O0 4327.43 4295,63 3~ 13 S 23 2 _..~..Z~.~..,..~..~ ....... ~.~ ~.~.6~ ........ ~.~ Z~.~ ~ ~ ............... ~ 3 ....... ~ ................. ~_. ~.~ ..... ~ ~800,00 4494.,46 44.62,66 33 11 $ 27 5 4.900.00 4577.56 4.545,7~ 34. 28 S 3~ 4 2 E 6 E 6 E 4 E 6 [ q E ~ E · 18 579,99 $ 665'93. · 1~ G29,81 S F21,72 · 20 729.84. S 403,57 E 833,08 · 76 780'67 S 428,52 E 889,4.5 · 86 852,30 S 452,98 E 946,24. · 91 884..06 S 476,03 E 1002,39 1.,.~L .... ~'.9.~.A~J.~S ..... ~_~1~_24 E !J~_7_~ .............. 3.44 984..79 S 520,10 E 1111,27 ~,05 1032,23 S 5~9,06 E 1166,85 5'100,00 4738.80 4707,00 38 42' ' $ 36 36 E '. 3,05. 1126,39 S mS-g.O_Q..,..O_.O .. ~._8_ 1 Z.,._O_}__ 41 _8..5.., 2.~ .......... ~ 8._. ak ................. $__.~..5__.E2 E ........... ~..6.6 _ _ . 1 l_7_6.,_6 ~... S 5300,00 4.895.4.7 4.863,67 38 20 S 35 12 E .31 1227.22 S 5400.00 ~+973.91 4.942,11 38 20 S 3~ 30 E ,4.3 1278'11 S 583,56 E 1224.24 620,57 E. 1284.,53 ..... 6_5.l_~;t_l_E . __1~_~.6_,.6.2 ............. 693,29 E 1408,51 728,73 E 1470,43 5500,00 5600.00 5700.00 5800,00 5900,00 5052,11 5020,31 38 47 S 33 24 E ,83 5130.53 50~8.73 37 55 S 31 18 E 1.57 ~..~..~.~.,~ .............. 517..Z. qo .................. ~7 ..... ~.~ .......................... ~._..~ ........ 6 ..... E 5289.56 5257.76 36 36 S 28 24 E 1,30 5370,25 5338,45 35 4.8 S 28 35 E .81 1329,82 S 763,53 · 1382,22 S 796,74 i4~4.74. _$ ..... 8_ 27 .._9__3_ 1~87,2~ S 857,33 1539,14. S 885,51 1532,71 1594 · 74 1 6.~...~ ...~..! ............... 1715,94. 1774.,91 I ARCO ALASKA, WELL NO, A-9 ~ KUPARUK FIELD INC, SEC 5 TllN RIOE PAGE 3 DATE OF SURVEY NOVEMBER 1, 1':981 VERTIC4L SECTION DIRECTION S-31-37-00-E NOR BOS TH SLOPE~ ALASKA S SURk:EL _.T_R. UE SUB .,- MEASURED VERTICAL SEA DEPTH DEPTtt TVD BOSS-16921 '" ' NL SPERRY-SUN': ' ' · · · · . COURS-E RECORD OF elJRVEY COURSE DOG-LEG.. TOTAL" · INCLI'~N~'~ ....... ~-~-~'~CTION SEV IRECTANGULAR COORDINATES DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST VERTICAL SECTION 6700'00 .: 6045,~2 :,601~'52 ::i:2 ~0. ' 6800.00 61.33,07 6101;27 28 qO 6900.00 6221.13 618~.133 27 53 7000 · 00 6309,90:', 27 :i/5'6 :: !,.' 7120,00:~; ~ 6417,54.:;~~:': 6385'7~. ~ASS. ~s 39. ~q · * THE CALCULATIONS S 28 5q E S 28 30 E O.OO ,79 913,17 E 1832,95 '...::.' 940,0'q E .i. 1889,90 · "::"":'"::'966,50'E .." '1945,63 992.48 E 2000,08 1017.70 E 2052,86 . 5 ' 67 ":::,:. $ .: 1957,66 S 1112.47 1.999.21 S 11.35.22 .:..2 1 0 ~ · 0 9 1.53, S 2 · '!!;!'" 2202,38 2 2 ~T-;'"~ ............ 2297.59 ..2078,851:?S'::!': 117B,02 E ' 2387,85 OF CURVATURE METHOD ** ARE BASED ON THE MINIMUM RADIUS "'i' ,. ::::':.HORIZO'NT/~L;'DISP.Li ,08:':,F.EET.,~ AT SOUTh 2.9 DEG. 32 t :'' : .:::' ':'i'i:, :";:::i::i]i:':.! ::]i' :]']':]:S T:'A'R']~:i::: s' 1.8 o F E E T A B 0 VE S E A L.L- V EL ~ ARCO ALASKA, INC. I...WIL.L .... N.O..,.__A._9__. SEC__5.Z <UPARUK FIELD ,NORTH SLOPE, ALASKA .~.D..S.S__.S_IJR. WF__L MEASURED ..... D.££.T_H__ _ _1..0..0_, .... 200· 300. ," ' PAGE ~ ' · .'DA_T~ OF---S-LLB_~EY .. NOVEMBER 1, 1.9..8.1 .............. . NL SPERRY-SUN I ~LTERP..OLAI£.D.._RECZLR~,_~.RDLF Y .:' TRUE VERTICAL SUB SEA D.E P,,..T, H .... l V.D , :'. '0 '.. i;:.:'::.: i;::'.. i::' .. ' 32 · ' 200, 168, 300, 268, .... B o s s-_1,6_9.21 .............. i'i.. ' · ..:::.":: ·: ~ '..s : o., ....... E ............ -168. 1. S O, E -268, 1, S O. E TOT/~L RECTANGULAR COORDINATES N.O.R_I LiZ~I1LLT H ..... F_~_S.L/_N ES.T .............. ' ' o o. ' s o :?:'::_ ,, ' "'"" 7OD, 700, 668. -668, q, S 800, 800, 768, -768, q, S ................ .~ .~ .0..,. .............................................. ?,. 0 0., ................................................... ~ .6.. 8 · ................... - 8.~.!.,. ........................... 5.,__S O. W 1., ..... ~ ............. 1. W O. W ~.., ...... ,W .................. 1500, 1600, 1000, 1000, 968. -968. 5. S 1100. .1.100. !_~.~..8_'.., ......... -1D68. 6. S 1200, 1200, 1168, -1168, 7, S 1300, 1300· 1268, -1268, 8, S · l.. ~ .0.. 0., ! ~. o. 0., ..! 3 6 8 · .,.. -.1..~.6.,~.._, 1.8,__.,~ 1, W 2, W 3. W 1700, 1800, 1900, '.: 2 o o o. L 21oo. 1500. 1~68. -146B · 1600. 1 568. -1 ~68~, · 1700. 1668, 1668. 1800, 1768, -1768, 1 ~ o o: ....................................................... ! .a .~..R. ,. ........................................... -_..!_8..6.~. · 2200. 2300. 2~00. 2000, 196 210.0...... 2.0..6.... 9. S ~I. 0,S 11, S 13. S !_~ ' s _ 5. W 8. W 8. W 9. W 2200. 216, 2300. 226 2~ o .o.. :. ............................................. 8, " -1968, ~.., - 20__6_8_: 8, -2168, 8, -2268. 8' -236~, 15, $ 15_,_ S 16, S 17, S __18. S__, 10, W 1.O..,. .... W .............. 10, W 10, W 2500, 2500, 2q68 2601, 2600, 2568 270~, 2700, 266~ 2807. 2800, 2768 . .... 2~68. · '2568, . -2668. · -2765, 2~. S 34. S 50. 69. t"h ,- 5, W z~, F 19. E 37. E IARCO ALASKA~ WELL NO. A-9 INC. SEC 5 TllN RIOE DATE OF 'SURVEY ' PAGE 5'~ NOVEMBER 1, 1981 KUPARUK FIELD NORTH SLOPE~ BOSS SURWEL ALASKA BOSS-L6921 NL SpERRY-SUN INTERPOLATED RECORD OF suRVEy` · ' TRUE TOTAL MEASURED 3EP TH VERTICAL DEPTH SUB SEA TRUE RECTANGULAR COORDINATES TVD ELEVATION NORTH/SOUTH EAST/WEST 3100':,' ':'. 3 32q5. 3200. 3168.-- -3168. 216. S 133. 3362. 3300. 3 _ 34~. 3400. 3 :. 3841. 3700. 3 3962. 3800. 3 3 268. -3268. 270. S 162. E 368. -3362. . 327. S 193. E ~':'.'::.i '..:.:.i:::::':??,!:.i:~':i;.'.:':''::::'~'~',':~' - 3 4 68. . E 568' . .... 5r:,. 'E 287';--'"E ........... 318. E 349. E 668. -36.68. 501.. S 768. -3768. 561. S 868. -3868. 621. S ~ 2 o ~ : o 4445. 4200. 4168. 4567. 4300. 4268, : " ......... %_z..7..? .......................................... _~.6 .q..O.: ............................ ' ......... ~.~. ~' .... 5051. 4700. 4668. 5178. 4800. 4768. -4168. 804, S -4268, 867, S -4568, 929, S 379 · 409. E 440. E 469, E 495. E -4468. 988. -4568. 1045. -466B. 1102. -4768. 1.166. S 22. E $ 558 E S :~ LI J J J---~;'d"2'Z-'E: .......... S 649. E . 8 . ..... 295. S '5168 1428 S 824 E 5688, 5200, 5168, · ' 5813. 5300. 5268. -5268, 1494' S 861. E .............................. 5400, 5368 -5368. 1558. S 896. E 5937. ................................................................ , 6059, 5500. 5468. -5468. 1620. S 929. E 6180. 5600, 5568. -5568. :1680. S 6417. 5800. 5768. -5768. 11792. S 1022. E ARCO ALASKA,~ INC, ._'.,!~ .L__L._.._N__Q.:._6_-_ ~ ~ E_. C...~__T~. ~._N.._.~. KUPARUK FIELD NORTH SLOPE9 ALASKA ...~_o .S....s___. ~_W..R._ W_~E..L. ...................... DATE TRUE MEASURED VERTICAL ........ .D.E..._P, L.M_ .................................. O .E..P T H 6648' .._J_~' .._3. 7 6 2 · NL SPERRY-SUN · INTER._P_O. LA_TED R£CO_R..D. OF .S._y.R__V._~Y' SUB SEA TRUF ...T V D .......... _~.~_A~.~ TOTAL RECTANGULAR COORDINATFS N O.B., I.~/S Q U T H E A ~I..LW £.~I .......... 6876. 6200, 6168, -6168, .1989, S 6989, 6500, 6268, -6268, 2035, S .... i ........ .... 7120, 6418, 63H6, -6386, 2 , S 1130, E 1155, E 1,1..~8., ...... E ...................... · 1'i"8 2. E ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Hoy le H. Hami lton/~~ Chairman Commissioner Harold R. Hawkins Petroleum Inspector October 26, 1981 Wi~tness BOPE Test on ARCO's Kuparuk River Field Well No. lA-9 Sec. 5, TllN, R10E, U.M. Permit No. 81-152 October 24,._ !981 - I left Anchorage at 7:15 a.m. by Wien Airlines to ~Udhoe Bay arriving in Prudhoe at 9:30 a.m. and at ARCO's Kuparuk River Field, Well No. 1A-9 at 12:15 p.m. When I arrived on location the BOPE was being nippled up. BOPE test started at 4:00 p.m. and finished at 6:30 p.m. were no failures. The There I filled out an A.O.G.C.C. report which is attached. In summary, I witnessed the BOPE test on ARCO's Kuparuk River F~ileld, Well No. 1A-9. The test was performed adequately. O&G #4 4./~0 STATE OF A[,ASKA ALASYJ~. OIL & GAS CONVI:RVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator A ?,~'~_~ Location: Sec ~ T Drilling Contractor · Representative Permit ~. , ~/_ / cas ng Set Representativa Location, General ' .~ Well Sign ,,. General Housekeeping Rase rve pit ,~,' Rig BOPE Stack Annular Preventer Pipe Rams ACCUMULATOR SYSTEM Full Charge Pressure. ~_~~ psig Pressure After Closure j,~ psig 200 psig Above Precl~arge Attained: Full Charge Pressure Attained: N2 /~,ff~, .q./O0 . ~3~90/_9~,_~'F) psig Controls: Master ~/~ Remote minj-D sec min--- sec ~,~'Blinds switch cover Test Pres sure Kelly and Floor Safe Upper Kelly. Test Lower Kelly 'Test Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: .~o0. · 0o.o .300 35ooo Failures ._ty Valves Pressure . ~' Pressure JO Test Pressure / Test Pres sure " / ~ Test Pressure Ball Type Ins ide BOP Choke Manifold No. Vel vas No. flanges Adjustable Chokes / l{ydrauically operated choke / ~ z----r. -:~7:.:r .............. /~-~ Test Ti,ne fi_ hrs. _ff ~'? Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: days and Distribution origg - AC&GCC cc - Operator cc - Supervisor Inspector October 9, 1981 Mr. P. Ae VanDusen' District Drilling Engineer ARCO Alaska, Inc. P. O. ]~ox 360 Anchorage, Alaska 99510 Re~ Kuparuk 25647 No. 1A-9 ARCO Alaska, inc. Permit No. 81-152 Sure Loc. t 569'FSL, 487~FWL, Sec 5, T11N, RIOE, UM. Bottomhole 'Locel 1804'FNL, 1948~FWL, Sec 8, TllN, R10E', Dear ~{r. VanDusen~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shal! be submitted .on all logs for copying except experimental logs, velocity surveys and dipmeter surveys- .Many rivers in Alaska and their drainage systems have been c.lassified as important for the spawning or migration of anadromous fish, Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative .Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and C~me. 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 amendede Prior to Hr. Po Ao VanDusen Kuparuk 25647 No. 1A-9 -2- October 9, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field ~ork, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness pre se nt. Very truly yours, Enclosure coz Department of Fish & Game, ~abitat Section w/o encl. Department of Enviro~ental Conservation w/o/encl. ARCO Alaska, Inc. / Post OfficeB~, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 6, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk 1A-9 Dear Sir: Enclosed please find the following: 1. The application for Permit to Drill Kuparuk 1A-9 and a $100.00 check for the application fee. 2. A diagram showing the proposed horizontal and vertical project ions of the wel lbore. 3. An as-built drawing of "A" pad indicating the proposed surface location. 4. A proximity map indicating the relative locations of Kupark wells 1A-4, 1A-6, and 1A-8 (West Sak #12). 5. A determination of maximum pressure to which BOP equipment could be subjected. 6. A diagram and description of the surface hole diverter system. 7. A diagram and description of the BOP equipment. In addition, please note that this well's bottom hole location will not require a Letter of Non-Objection from BP 'Alaska, Inc. or Sohio Alaska Petroleum Company. If you should have any questions, please do not hesitate to contact me at 263-4270. Sincerely yours, P. A. VanDusen District Drilling Engineer PAV:cm Enclosures RECEIVED OCT 0 1981 Al3ska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany O(~ STATE OF ALASKA ~ ALASKA ._ AND GAS CONSERVATION CO MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL IXIX lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC El' REDRILL [] DEVELOPMENTOIL~[~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2, Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360 Anchorage, Alaska 99510 4. Location of well at surface a% &, ~, ~ J ~.~l~j~ or lease name 569' FSL, 487' FWL, Sec 5, T11N, RIOE, UM Kuparuk 25647 At tOp of proposed producing interval OC'T 0 0 ].l~ell number 1320' FNL, 1650' FWL, Sec 8, T11N, RiOE, UN -~'1A-9 At total depth ~aS~ 0il & Gas C0 d. ~.~:.~J~ an~ poo~ 1804' FNL, 1948' FWL, Sec 8, T11N, RIOE, UN Anchor~e~~nRiver Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. ' Kuparuk River 0i 1 Pool 61'GL,66'PD, 100'RBK ADL 25647 ALK 465 12. Bond information (see ~0 AAC 25.025) ' ' Type Statewide Surety and/or number Fed. Ins. Co. 8088-26-27Amount $500,000 13. Distance and direction from nearest town. 14.'Distance to nearest property or lease line 15, Distance to nearest drilling or completed 30 mi NW of Deadhorsemiles (at TD) 1804' feet well @ 1660' TVD 72'feet 16. Proposed depth (MD & TVD) 17, Number of acres in lease, 18. Approximate spud date 7715.' MD/6850' TV D feet 2469 i0/14/81 , 19. If deviated (see 20 AAC 25.050) 120. An{icipated pressures 2625 psig@ 60°F Surface KICK OFF POINT 2400'feet. MAXIMUM HOLE ANGLE 36° °l(see 20 AAC 25.035 (c) (2) 3!33 psig@ 6070 ft, TD ('FVD) 21 , Proposed Casing, Liner and Cementing Program SIZE CASING' AND' LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage datai ' 24,, 16,, 65# H-40 Melded 80' Pad ! Pad 114' I 114" +20(3 CF 13 3/4 10 3/4 45.5# K-55 BTC 2270' Pad , Pad 2300'~ 2300' ~-080 sx AS III + 250 ' I AS 8 3/4 7" 26# K-55 BTc 7685' Pad ~Pad 7715' 1~ 6850' 910 Sx Class G I I 22. Describe proposed program: ARCO Alaska, ]~nc. proposes to drill a Kuparuk River Field, Kuparuk River 0il Pool devel:- opment well to approximately 7715'MD, 6850'TVD. Selected intervals will be logged. A 20" x 2000 psi annuluar diverter will be installed on the 16" conductor while drilling the surface pipe. lit will be tested upon installation and weekly thereafter. Test pres- sure will be 3000 psig. Expected maximum surface pressure will be 2625 psig based on cooling of a gas bubble rising at constant volume. The well will be completed with 3 1/2" 9.2# ,]-55 buttress tubing. Non-freezing fluids will be left on uncemented annuTi thru the permafrost interval. Selected intervals will be Perforated within the Kupar'uk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED , - TITLEDi_gtrict [lrlg FnninPPr DATE 10/6/81 The space below for Commission use CONDITIONS OF APPROVAL · Samples required Mud log required. Directional Survey required I APl number r-]YES ~NO []YES [~.O ~.YES []NOI 50-- O -'L, ~ ~'~o ~ f~ ~ Permit number Approval date ¢ ~ - /S~'L. 10/09/81 I SEE cOVER LETTER FOR OTHER REQUIREMENTS · - ~' by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 "-.:"~:"- :- .... ' ;-'.. ;' :--. --. :.--- :-T-:" '.-- -:-:.: PAD It, NELL NO'-i 9 'PROPOSED:-:- T--:.:-:T--':J'::-::::-: ~ I!/-:;:':-':'~CRL[- · L ..~v. t" ........... ~ "- KUPARUK FIELD, ~NORTH SLOPE,-ALASKAi ..... , ................ . ...... · ---- : ~- :' :-':-:'- :: ' ----':----:; :-:--;-:"t-; :--[-:: ...... -~-i '--:-~ ~- I --t '-'";~ ...................... ~ .............. --.RVERRGE RNGLE! ............ ? .......... L .......... "' I .... TRRGET : :DEP=2218 . j.:i: ...... !_ ' ............... LONER SRNDS TVD=6250'YHD~6973 DEP=2349 - 'BRSE!KUP SRNDS':TVD=6365 TND=TIIS!DEP--.2433 POZNT--TVD~65~7---THD~7315'DEP-~55! ~ .......... --- '::TD i [HRX) i TVD=6850 TPID=T715 DEP=2786 i ......... ! ! WELL A1 Y = 5,971,467.25 ~----~~ i X : 540,'1 78.17 ~ ~ LAT = 7~)°19'58.741'; ,~ ~ ., ~ LONG =_ 149°40'26.679'l ' . X : 540,~78.32 .... ~ ---~-I-_ ~ LAT = 70°19'57.557'' '~ ] ~ ~~~]~~''~ LONG : 149°40' 26'693" ---~ ~l~t -- ~' WELL A3 Y : 5,971,227,31 ' .... ~ x: 54o ~78 5~ . < ~__ ~.~l~ ~ LAT = 70o19, 56. 381" %1~' A~~~ ~~ ~LONG : 149°40'26.707'' '~'--7> ~ WELL A~ Y : 5 , 971,g 06. 83 ~Z ~ X : 540,~78,52 ~l~' ~~~ LAT : 70°19 55.196" ---- LONG = 149040'26.725'' ~ < I ~ '" WELL A5 Y = 5,970,986.86 .~ = ~40,178.61 _ _ ~il'. A~..--~ ~ ~ . ' LAT= 70°19'54.016'' : ~>. ~ ~ LONG = 1 49o40' 26.741" ~ ~l'~-.~' ' ----~ - ~--' (~)~ WELL A6 Y = 5,970,866,70 O' A~ ~ ~ , ..... ~- ~~-~--~~, -I- ~ : X : 540,178.~1 , ,~ ~ ~' ~ 1 LAT : 70o19'52.834'' i ~ I ~ IY--~Ato 1 / LONG = 1 49o40' 26.757" ~O~' A~ ~ ~, ~ ~ WELL A7 Y : 5,970,746.73 -~ .... ~ .............. ~ ,[- ~ I x: 540,~78.55 ~ . ~?~ ~ ' ~ I LAT = 70°19'51.654'' --- --~~,_. - -~~.~~'~ ...... ~ '' ' 'LONG : 1~9°~0'26-781'' ......... ~-~~'' ~--'.~ ~ WELL A8 Y =- 5,970,G26.78 i ~ ~ /' ~l . o ~ X - 540,178 5 'S~ ~ : ' ~ LAT ' > . ~ - '~: , ' LOnG = 149°40'26-798'' ' REC IV o _ 6~A~: t"~ ~oo' OCT ' · .,'.~ ~,r ~, '- .>'~: .- -,[ ,~ .~,. I HEREBY CERTIFY THAT I AN ~_ ,'- . . . .:w~..,.: ..~,.,~ ~.,- . .-. ,~ .... PROPERLY REGISTERED AND LICENSED .... ~ TO PRACTICE LAND SURVEYING IN ' ' ..... "'" ' '- THE STATE OF ALASKA AND THAT ' ' ' -' '~' '~' ~' o /: ' "' .// / ~/~: ............ ~ ............ THIS PLAT REPRESENTS AN AS- / ,~, ~, ~ ..... ;,,.~, .. ~- THAT ALL BINENSIONS AND OTHE~ .~ .... · ..~ .: · .' '..'~ -~..-~.....;'. ,' DETAILS ARE CORRECT, ~S OF: · - ~ ...,. .. .,-..? .--. ...,. . . . ~.. . I I II ~-/~ ii I I I I All~nlic~ichtieid~omp~n~ ~ DATE. D~A~ING NO~TH A~E~ICAN P~ODUClNG DIVISION ALASKA DIST~I~T-- KUPA~UK IIl l iii iii ii ii i i i i I II I III '" ARCO'ALASKA,'INC, .....~ ........... ~ ..... , .... ~ "~ ......... ~" '" :' :'~P ; 'WELL ~NO~ 9! :PRaPBsED T;:'[':;;L.~ ::-' !- ~ .... ' ............. t .... ~ . ~ELB,~T~SL~E~-~RSKR ...... ~ .......... ~, .................. ~ ~ ............ ~ ...... ~ ~ , ~ -- ~ ~ .. .......... ~ ...... ~ ........ ~ .............. : ........~ ......... ~ .......... i .......... ~ ......................... ~ .......... ~ ~ ......... ~ .......... ' ............ .:: ~.ERSTMRN, WHIPSTOCK~. ' INC. ~, ' ~ ............ ~ ~ .......... ~lt 1664' , .! ,. . ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3133 psig from RFT & pressure buildup date. This pressure @ 5970' SS = 6070' TVD will be balanced by 9.92 ppg mud wt. Normal drilling practice calls for a 10.4 ppg wt. prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 150 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2625 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160°F 3133 psi), gas migration to the surface w/o expan_sion, and cooling to 60UF summer cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (.reservoir) Vi = volume initial (reservoir) Pf: pressure final (surface) Tf = temperature final (surface) Vf: volume final (surface) Pi Vi = Pf Vf Ti Tf Since Vi = Vf ie no expansion Pi : Pf Ti Tf Then Pf : .Pi Tf: (314~ psia) (60°F + 460) Ti 160°F = 460) Pf = 2640 psia = 2625 psig Surface Div~' .,r System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" 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. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumst'ances. 16" Conductor . Maintenance & Ooeration ~ 1. Upon initial installation close annular ! · preventer and verify that ball valves I ~ave opened properly. I 2. Close annular preventer and blow air ~__ through diverter lines every 12 hours. · .o ! RNNULGR PRP.VENTOR 9 ) ) L. BL I ND RR,"IS ) £, ( ) < - P I PP' R..-q,"IS 1._ F-] ) 7 (. ( ) C ) - (L" ) L_ PiPE RRHS, t-5/8" 5000 PSI RSRRA BOP STACK/ 1. 16" Bradenhead 2. 16" 2000 PSI x lC" 3000 PSI casing head 3. lC" 3000 PSI tubing head 4. lC" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACCL?IULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DO'JNSTREAH OF THE REGULATOR. 3. OBSERVE TIHE THEN CLOSE ALL UNITS SIHULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REHAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LONER LIMIT IS 45 SECS;;DS CLOSING TItlE AND 1200 PSI RFHAINING PRESSURE. 6. F a '-I ' ,,. ¼, ¢ J ECEiVED' I I ~faska 0ii & Gas Cons. Comaissio~ 6 ~ . ~aska O~i &~a:~ora,e . 13-5/8" BOP STACK TEST FILL BOP STACK Atto MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE,~.IINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN tN LOCK DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. TEST ALL CCHPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MI tlUTE~. CLOSE ,/ALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~,IAINING UNTESTED HANIFOLD VALVES, IF ANY, WITH 300~ PSI UPSTREAm-! OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. - , , OPEN TOP SET OF PIPE RAHS AND CLOSE BOTTC,,I SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. OPEN BOTTOH SET OF PIPE RA,'.1S. BACK OFF RU,I- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO I.!I,;UTES." BLEED TO ,ZERO PSI. OPEN BLIhD RANS AND RECOVER TEST PLUG. MAKE SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POS I TI ON. TESTSTANDPIPE VALVES TO 3000 PSI. TEST KELLY coCKs AND I~;SIDE" BOP TO 3000 PSI WITH KCC;',EY PUt'IP., RECORD TEST INFO~.tATION ON BLO'dOUT PREVENTER TEST FOPJ,1 SIGN AND SEhD" TO DRILLI;;G SUPER- VISOR. PERFORI.I CC~iPL,...,. BOPE TEST ONCE A '~EEK AND FUNCTIONALLY OPERATE BOPE CAILY. ~HECK LIST FOR NEW WELL PERMITS Company Lease& Well No. ITEM APPROVE DATE YES NO REMARKS (1) Fee /' (2> (~ thru (3) Admin ~,t M "~''~''~! (9/thru 11) (4) Casg (~thru20)//c>'~'~g/ (5) BOPE~~ /~--~'~/ ~-(-21 'ihru 24) (6) Add:~~ ~ O~-&! 1 10. 11. 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ....................... 3. Is well located proper distance from property line ......... 4. Is well located proper distance from other wells ....... 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 8. Can permit be approved before ten-day wait ............. Does operator have a bond in force ..................... Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. Is conductor string provided .................. 13. Is enough cement used to circul~t; ;n go~g;;r ~g~ gg~}~g; .... 14. Will cement tie in surface and intermediate or production strings . 15. Will cement cover all known productive horizons ............... ' ' ' 1'6. Will surface casing protect fresh water zones ..~ .................. 17. Will all casing give adequate safety in collapse, tension and burst 18. Is this well to be kicked off from an existing wellbore ........... 19. Is old wellbore abandonment procedure included on 10-403 .......... 20. Is adequate well bore separation proposed ............ , ............ 21. 22. 23. 24. 25. Is a diverter sYstem required ................... Are necessary diagrams of diver;e~ ~ ~0~ e~ip~e~; a;t~c~ed ..ii. Does BOPE have sufficient pressure rating - Test to j2~O~ psig Does the choke manifold comply w/API RP-53 (Feb.78) .............. . Additional requirements .............................................. Additional Remarks: Geology: Eng~ring: HWK~ LCS~'~EW~ WVA ~ JKT~ ~ ~AL/~ ~.-<--~ ~ .~ rev: 0~/10/81 INITIAL i GEO. UNIT!ON/OFF' POOL CLASS STATUS AREA ..NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi ., No 'special'effort has been made to chronologically organize this category of information. .o LVP 00').}{05 VERiFiCATiOi~ LISYI~G PAGg 1 DAT~ ;~i/i1/10 TAPE ~JA~4E ~62260 PRE~IOd~ TAPE ** FiL~ HEADER Flbg ~g :$ERV!C.O01 DATM : MAXi~O~ hEMGTh ; I02~ FI~E 'ffPE PRCVlO!..t$ Fib .... CN RANG S~.'l C 0 !J ~'~ STAT CTRY PR~S: NF]OIT4F UNIT TYPE CATE SIZE CODE 000 000 026 065 000 000 012 065 000 000 008 065 000 000 003 065 O00 000 003 065 000 000 001 065 000 000 012 065 000 000 006 065 000 000 004 065 U~IT TYPE CATE SIZ~ CODg 000 000 O0'l 065 047 ** 047 ** JOY ~ [0707,62260 DIb ~(U~ #1, uOG~.~L., 29-QC'i7-8i : 7204 FT. = 2236 FT. : 10 3/4" .AT 2236" = @ 3/4 IN. = LO SOLIDS NON DISFflRSED : 10.4 i,S/G = 41.0 S = 10.0 : ~.5 C3 = .3,I60 OH~,~ AT 70 DF : 3.540 0~ AT 70 DF = 2.600 ~H~ ~T 70 ~ = 1.600 C}?~ AT 145 DF LIMESTONE PAGg T'~P~ SIZE', ~ 4 0 ,{PEC_~F..~;ATION 86u~Ko. . DEPT NPHi 722!. 00,3 2.603 -W99.25O -999.259 G~ D ~ P *2 I b ~',~. N P~"~ i NCdL 7200.u00 2,547 39.25~ 2194.o00 SFL~J NRAT NPH'I N C i~i b 7100.000 2.32~ ig.~W 00o SFbO NPHI 70o0,00O 12.00S 29.736 2714.000 g~ CALI D NPHI ~.Sg~ 29.932 2008,000 G~ CALk TYP i BEPR CODE 66 66 i APl ~,P! FILL ~1 CbA$8 ~lOO NO. 0 0 0 0 1 32 0 0 I 0 0 0 2 -i6 0 0 0 0 O 0 9 0 0 0 5:? 32 0 0 31 3:2 0 0 68 2 o 0 2~ 3 0 0 ~ ~ 0 0 0 35 I 0 0 3i 92 O o 42 I 0 0 34 93 0 0 -99.188 5P 3.041 D~ -999.250 DR~tO -999,250 FCNb -9 9.188 8,555 3.27O 2.063 2.908 8.867 9,a75 sP 4.828 DT ~.166 £)RHO 2,744 FCNb S,250 5.090 9.1~i 2.7a9 FCNb ENTRY i. lin 0 SIZE PRUCESS SAH.PLE 4 0 1 4 0 4 0 4 0 i 4 0 1 4 0 1 4 0 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 i -I9.578 IbP 94.750 GR -999.250 RHOS -99g.250 -18 633 -16 102 0 552 -27 0 965 : 750 GR 174/R~i0~ .500 .359 !L,D 000 ,,~ ,172,/ .500 .844 IbP , 0 0 0 REPR COD~ 68 ~8 ~8 ~8 ~8 68 2.334 -999.250 -999.250 2.436 1294.000 2.584 -- 2.2~B 108.500 2,525 13 32O 79:063 ..- 2,365 4.565 82.b25 2.430~ DEPT IL/'! NPiit NC~ N C ~'~ L DEfT NPHi NC~L DEPT I b H NPHi NC :'~ b DEPT NPH I DEPT NPH I NCNb NC~b D E P T Ib~-4 NPHI D E P T I LM NP~I NP~'~ DEP T P ~.~ I. O0.),H05 VER[FiCATIU~ LISTI~G OSO0.O00 G~ 25.000 CALl 3072.000 NMA~f 0700.000 GR 1.581 SFhO 43.945 CALX 1827.000 NRAT 6600.U00 1,782 SFbO ~5,605 CALl iU12,000 6590.000 GR 2,539 SFLU -999,250 CAb[ -999,250 NRAf 0400.000 GR 2,430 SF[.U -999.250 CALf -999,250 NRA'~ 6390.000 GR 2,561 SFLU -999,250 CALk -999,250 NRAT ~200.000 GR 3,285 SFLiJ -999,250 CAL£ -999,250 ~RAT 6190.000 GR 2,1~ SPLO -999.250 CALl -~99.250 NRAT &O00,O00 G~ 2,1~3 SFLO '999.250 CALf -999.250 NR~T 5900.000 GR 3,00~ SFBJ -999,250 CALl -999,250 NRA'Z 5800.000 GR 2.2~ SFLO -999,250 CALi 54,531 SP 10,195 DT 9,3i2 DRHO 2.473 FCNL i9~.3i2 SP 2.586 DT 10,008 DRHO 3.648 FC~L 113.875 SP 1.964 Df 11.461 ORHO 3.816 FCNL 5,652 Df -999,250 DRa© -999.250 F~"Nb~ 117.188 SP 3.125. -999.250 -999.250 1!1.375 Se 4.1i3 Df -999'250 ORHO -999.250 FCNb 106.125 SP 4.499 DT -999,250 OReO -999,250 FCNb 107.875 SP 3.432 OT -999.250 OReO -999.250 FCNL 125.312 SP 2.965 -999.250 DRMO -999.250 FCNb 3.102 -999.250 -999.250 FC~L 1~9,000 ~,184 DT '999.250 DRHO '34 406 90:375 1197,000 -19.109 ILD 112 i8~ .~ 509.250 -21.359 lad 76,375 Ga -999.250 -33.312 ill) 104.563 GR -999,250 RHOB -999,250 -25,578 ILi) i13.000 GR -999,250 RH96 -999.250 -29.609 IbD 108.750 GR -999.250 RHOB -999.250 -15,M59 121.375 -999.250 -19.844 i08,375 Ga -999.250 -999.250 -39.344 IbO 109,1a8 GR -999.250 RHOB -999.250 24 063 Ilo,750 -999 · 250 PAG~ 8.055 68.063 2.36'1 1,514 114.875 2,445 1.754 115 312 2:389~ 2.084 -999.250 -999.250 2.389 -999.250 -999.250 2.467 -999.250 -999.250 3.252 -999.250 -999.250 2.06~ -999.250 -999.250 2.086 -999.250 -999.250 3.016 -999.250 -999,250 2.307 -999,250 -999,250 bV~' 00~.i405 ~/ERiFICATiO~ blSTiNG PAGE 5 -999. 250 NaA~ -999,250 FCN~ DEPT 5700,000 GR IbH 2,287 SFbU NPHf -999.250 CAhi NCnb -999,250 ~aT 157.250 SP 2,031 DT -999.250 DRHO -999.250 FCNU DEPT 56o0,000 GR ILN 1,6!2 SF,SJ NPHi -999.250 CASI NCNb -999,250 NRA~ 153,500 ,733 Df -999,250 DEPT 5500,000 GR IL~ i.~03 SFG0 NPHA -999.250 CAGI NCblL -9-99.250 NRA~i~ 154,750 SP t,739 DT '999.250 DRhO -999.250 FCNb DgPT 5400.000 GR Ibg 2,078 SMbU NPHi -999.250 CALi NCNb -999,250 ~RA~ 133,375 SP 2,~93 DT -999,250 DREO -999,250 FCN~ DEPT 5390,000 GR Ib~ 1.972 8Fb9 NP~I -999,250 CALI NCNL -999,250 NRA:~ 98,312 SP 1,870 bT -999,250 ORHO -999,250 FCN5 DEPT 5200.000 GR Ibh 2,i70 8Fbd NP}ii -999.250 CALl NC~.fh -999.250 ~RA'f 85,375 SP 2,238 DT -999,250 DRHO -999,259 FCNb DEFT 5100,0o0 GR IbM 2,398 SFbO NP~I -999,250 CAbg NC~ -999,250 NRA~ 93,625 2,383 PT -9~9.250 DRHO -999,250 DEPT 5000,000 GM ILH 3,729 ~5FLO NP~[~. -~99,250. CALl NC i-.~ b -999 , 250 NRA'r 82.688 3,932 DT -999,250 -999,250 FCMb DEPT 4900,000 GE I Li'~l 2.35 ! S~bd NPH, i -999,250 CAbi NCHh -999,250 k~RAT 73,935 SP 2,238 DT -999,250 DRHO -999,250 FC~b DEIST 4~00,000 GR NOiqi -999.250 CAbI NC~b -999.250 NRAt 75.563 SP 2.51~ UT -999.250 ORHO -999,250 FCNG 90.188 2.352 '999,250 -22,~75 95.188 -999.250-999.250 -20,891 1il,750 -999.250 -999,250 -2!,i25 ~16.000 -999.250 -999.250 -24.094 112.000 '999.250 '999.250 -21,~28 -999,250 -999.250 -22.34~ I04.375 -999.250 -999.250 -24.59~ I04.375 -999,250 -999.250 -25.922 93,i8~ -999,250-99g.250 -24,q06 105,563 -999,250 -999,250 -24.07~ i06.563 -999'250 -999,250 -25.578 109.750 I bD GR I bD GR I bD GR ! kD GR I I h D G R RHOB G~ GR GR 2,117 -999,250 -999.250 1.563 -999.250 -999.250 1.619 -999.250 -999.250 2.100 -999.250 -999.250 2.010 -999.250 -999.250 2.182 -999.250 -999.250 2.445 -999,250 -999'25O 3.575 -999.250 -999.250 2.~30 -999.250 -999'250 2.502 -999.250 -999.250 2.525 -999.250 L V P I L DE,if NP~iI D E ~ T N P ~t I DEP'~ NCnb DEPT DE~T N P;i i NCu~L DEPT NC~b DEgT NPdl NCi~¼ DEPY IL:4 N P H i I L M NP~I 009.H05 VERI[~'iCATiO~>~ -999.259 CA~I -999,250 NRAT 4bO0,O00 GR 2,t57 -999,250 CALl -999,250 4~00,000 2.943 -999,250 CAL£ -999,250 4400,000 GM 5,1~1 8?L!J 32,8~:1 CALl 4300.000 3.566 ]6,670 2270,000 4200.0O0 Ga 3.i62 SFb~ 38,37~ CALl 2150,o00 ~RAT 4100.000 2.910 42,334 1955.000 4000. 000 GR 2.46/ SFLO 39. 355 CaLi 2o80. 000 NRA f 3900,000 Ga 2.625 SFLO 41,35'7 CASI 3B<)O.O00 GR 36,133 CADI 2068,000 NRAT 3700.000 Gx 3.i75 SFbO 40.38I CAb[ 2194.00o NR~f 3 ~ 0 0.00 0 G a -999.250 -999.250 93.563 2,381 -999,250 -999,250 2.895 -999,250 -999,250 82,438 4,234 il,211 3,i25 76.3i2 3,~60 i1,09i 3.312 98,063 3,010 12.672 3.447 98,000 2,693 3.662 8~.438 2,334 12.289 3.492 78.939 2.520 I2.852 3,617 90.312 3.89i 12.148 3,309 75.250 2.916 12,250 3.547 76.625 FCNL 8P DRHO FCN5 SP DT FCNa SP DRHO OT $? SP DRHO SP OT DRHO DT 9.. :~ 250 -999.250 -26.406 111,750 '999.250 '999.250 '27,578 i08.375 '999.250 '999.250 '32.34~ 9~,375 -0,002 100~.500 -39,328 i05,375 0,018 686.500 '32.~25 115.750 0.007 046.900 -33,063 i19.563 0.000 532,500 -30.875 1!8,563 0.035 590.000 -33.023 119.563 0.038 526.500 -35.125 117,375 0.039 592.000 '33,063 116,750 0.040 jSg.uO0 -35.406 GR a~i00 GR RHO~ GR I b D G R i b 0 PAGE -999.250 2.545 -999.250 -999.250 3.055 =999.250 -999.250 5.973 89.875 2,340 3.783 79.688 2.287 3.340 108.b63 2,295 3,080 112.250 2.260 2.502 9'1.625 2.287 2.~30 91.250 2.301 4.945 101.125 2.289 3.748 75.500 2,271 3.07~ LV9 00).HO6 VERiFICATIgi~ 5ISTING PAG~; N P ~i NC.~ 3.400 SFLU 40,381 CALI 1981.000 NHAT 3~00,000 6.945 .~'7.891 CAbI 2128'o00 NRAT 3400.000 6,20'1 SFbO ]8.281 CALl 2004,000 3300.000 40,563 SFLO 24,023 CALX 5o12,000 3200.000 6,582 37.~51 C~Li 19~3,000 3i00.000 G~ 4,797 SFbO 42'87i 201~.000 N~AT 3000.000 G~ I0.820 SFb0 41.O!6 CALl 21~0.000 2900.000 8,06~ SFb0 ~3,066 i959.000 NRA~I 2S00,O00 16.8'75 SFb~ ~2,969 CALI 1975.000 270O.009 11.383 SFL0 39.990 CAlf 1955,000 N~T 2uO0,O00 12,680 SFLO 44.~29 CALl 3.061 12.969 3.568 65.500 6.i29 1i.918 3.402 72.438 5,270 12.438 51,063 32.063 11.531 2.545 56,250 7.121 i~.719 3,~24 61,188 4.672 i0.i56 3,60~ 65.875 9.602 13.820 3.625 73.438 5.531 12,~17 3,705 45,09~ 21.234 10.i95 3.609 49.4~9 15.484 11.305 3.502 38,469 12.689 11.555 3.7S~ DT FCNb DT DT FCNb SP DT FCNb DRHO FC~D ORHO FCNb SP ORHO DT OReO FCND FC~b OT DRMO FCNb ~C~ i20.375 0.025 53i.500 -47.063 125,:188 0,o41 578,000 -57.i56 123.750 0.012 553,000 -81.750 60.781 -0.024 1990,000 -45-625 117,000 0,064 529,000 -50,~75 i23.i88 0,020 534.000 -4a.~25 i13.188 0.048 598,500 -47,938 117,750 0.031 522.000 -61,500 133,500 0,016 522.000 -59 122:750 -0,001 513,000 -6i,563 136.750 0.019 486,000 80,08~ 2.242 '1.~44 76.250 2,281 6,598 81,250 28,453 52,34/ 2,377 7.828 ~0.563 2,309 5.230 67,938 2,238 11.680 70.438 2.260 9,~75 81,563 2.301 17,000 52,531 2,078 11.~30 60,781 2,16~ 13,852 44.844 2,078 LVP O0'R.H05 VBRiFICATiO!~-~ LISTING DEPT 2500.000 GR ILM 10,180 SFb~ NPHi 43,848 CALf NCnb 1573.000 NR~T 53.9~8 SP 9.516 DT 12.438 DR~Q 3.746 FCN~ DEPT 2400.000 GR IBM 7.07~ SCbO NPHf 47'510 CALl NCN$ 1492.000 ~LAT 59.719 S? ~.875 DY 14.56] ORHO 4.004 FCNL D£Pf 2300.000 GR IL~ 12.8!3 SFhO NPMi 43.945 CAbi NCNL i546.o00 N~A~ I2.281 DT I1.789 DRHO 3'732 FCa5 DEPT 2200.000 GR IL~ 9.76u SFLO NP~I 63,525 CALl NCNb 1369,000 NRAT 39.406 SP ~.758 DT 10.219 9RHO 4.750 FCab DEP~ 2151,500 GR ILN 49,063 SFLU NPH~ -999,250 CALI NCNL -999.250 NHAT 44.688 SP 4.863 DT -999.250 DRHO -999.250 FCNb ** FILE ~RAIbER ** FILE N~SE :SERVIC.O0i SERVICE NA~E : DATE ; MAX~U~ LCNGTS : 1024 NEX1~ F~bE NAME : EOF rA~ TRAILER SERVICZ NANE :SERVIC DATE OR~GIN :!070 TAPE i~AME :622~0 COi~TINUATION ~ :01 NEX~ '¥AFC NA~E : COM~E~S :TAPE COMMENTS -51,875 127.375 0.012 442,500 ~43.156 121.750 0.023 ]48.000 -53,844 0,00i 437.000 -11,125 56.375 -0.595 258.750 57.59~ -999,250 -999.250 IbD GR GR RHOB IbD GR PAGC 11.4i4 54.750 2.141 7.523 56.4~8 2.051 14.27~ 52.063 2.104 2000.000 41.719 1.897 I76.375 -999 250 -999:250 LVP 00~.~05 'VERIFIC~TIO~'q blST.li'~G PAG~J 9