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185-222
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-03-18_22214_KRU_3A-06_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22214 KRU 3A-06 50-029-21443-00 Caliper Survey w/ Log Data 18-Mar-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 185-222 T40236 3/25/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.25 09:55:01 -08'00' • LG1.41,o WELL LOG TRANSMITTAL#902887905 To: Alaska Oil and Gas Conservation Comm. February 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100E C I DATA LOGGED Anchorage, Alaska 99501 i•' 3 i t /201CD M K.BENDER FEB 2 3 2011) AOGCC RE: Leak Detect Log with ACX: 3A-06 Run Date: 11/4/2015 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 3A-06 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21443-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-029-21443-00 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 SCEQ Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / , ,/ • S Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, September 11, 2015 3:46 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Kuparuk injector 3A-06 (PTD 185-222) Report of IA pressure rise Attachments: 3A-06 90 day TIO 9-15-15.JPG Follow Up Flag: Follow up Flag Status: Flagged Chris, KRU injector 3A-06 (PTD 185-222) has exhibited a suspect IA pressure increase. When the IA began increasing in pressure it was thought to be correlative to the increase in injection rate and tubing pressure. The IA pressure was bled down multiple times yet the pressure continued to build up, as such the pressure increase can no longer be attributed to rate increase. The well has been shut in and freeze protected. CPAI intends to perform diagnostics to evaluate potential repair options. Upon conclusion of the diagnostics any required notifications or paperwork will be submitted. Attached is a 90 day TIO trend. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. AUG 0 4 2016 Desk Phone (907) 659-7126 SCANNED Pager(907) 659-7000 pgr. 123 ilitWELLS TEAMConocoPhillips roK Problem Well Supv Sent: Wednesdays,June 17, 2015 10:39 AM To: Wallace, Chris D • e Cc: Senden, R. Tyler; .0 .sch . -._r:►alaska.•ov; NSK Problem Well Supv Subject: RE: Kuparuk injector 3A-06 (P ' - 22) Report of IA pressure rise Chris/Guy- Kuparuk injector 3A-06 (PTD 185-222)tubing patch replacement has been co . - ed. The tubing patch was replaced and a successful diagnostic MIT-IA and IA DDT were performed proving integrity betwee me tubing and IA. The 10-404 has been submitted via mail for the patch reset and an electronic copy has been attached to this - ..ail for reference in the meantime. Because the well now displays TxIA integrity, it is CPAI's intention to bring the well online-wader normal injection status. If at any point in time communication is once again suspected diagnostics will be arranged as sc oQas reasonably possible. If you have any questions or disagree with the plan please contact us at your convenience. 1 STATE OF ALASKA RECE�' ED AL r(A OIL AND GAS CONSERVATION CON .3SION• l REPORT OF SUNDRY WELL OPERATIONS JUN 19 2Vis 1.Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other ,, Reset tubing Alter Casing r Pull Tubing r Stimulate- Frac Waiver1. '� a Patch r E Time Extensi�.t,j'` J!', - '— Change Approved Program rOperat Shutdown r Stimulate-Other r Re-enter Suspended Well r 2 Operator Name: ' 4.Well Class Before Work: 5 Permit to Drill Number. _ ConocoPhillips Alaska, Inc Development [ Exploratory r 185-222 3.Address: 6.API Number: Stratigraphic r Service p. P. O. Box 100360,Anchorage,Alaska 99510 50-029-21443-00 7.Property Designation(Lease Number) 8.Well Name and Number: ADL0025632 KRU 3A-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s) N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary. Total Depth measured 7680 feet Plugs(measured) None true vertical 6352 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6819,6822,6840,6894, 6949 true vertical 0 feet (true vertical) 5692, 5694, 5708, 5748, 5790 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 0 0 SURFACE 3376 12 3406 3179 0 0 PRODUCTION 7638 7 7668 6343 0 0 Perforation depth: Measured depth 7144-7220, 7340-7362, 7372-7420, 7440-7450 True Vertical Depth 5939-5998, 6090-6106, 6114-6150,6169-6174 SCANNED ,IU'L 1 `7 201 Tubing(size,grade,MD,and TVD) 2.875, L-80, 7281 MD,6044 TVD Packers&SSSV(type,MD,and TVD) PACKER-WEATHERFORD ER PACKER @ 6818 MD and 5692 TVD PACKER-WEATHERFORD ER PACKER @ 6842 MD and 5709 TVD PACKER-BAKER FHL PACKER W/PBR&6.12' PUP JT @ 6949 MD and 5790 TVD 12.Stimulation or cement squeeze summary N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic r 16.Well Status after work Oil r Gas r WDSPL r Daily Report of Well Operations GSTOR r WIND 17 WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Dusty Freebom/Jan Byrne Email n1617@conocophillips.com Printed Name Dust Freeborn Title Problem Wells Supervisor Signature l ' Phone:659-7126 Date /7. 7,,,6 is- VT-L- s- VTC 7-/g1lc RBDMSN'C JUN 2 5 2015 Form 10-404 Revised 10/2012 Submit Original Only y/ ouov ConocoPhillips ^PI4 6Nflr Alaska .-:Z/ M) P.O. BOX 100360 ' ANCHORAGE,ALASKA 99510-0360 th 17day of June 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Ms. Foerster Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3A-06 PTD 185-222 tubing patch re-set. The previous patch was set with equipment that did not allow for diagnostics to be completed on the failing IA draw down test and therefore the patch was reset as a repair for the failing test. It was also reset with the updated equipment to allow for diagnostics in the event of a future failure. Please call Jan Byrne or myself if you have any questions. Sincerely, 11041,411, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 3A-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/19/14 Existing tubing patch suspected to be TxIA leak point 02/22/14 10-403 Submitted for patch replacement 03/17/15 Lower Weatherford ER packer set and tested. Upper Weatherford ER packer set 03/18/15 Upper Weatherford ER packer tested. MIT-IA passed to 3000 psi. 04/28/15 Reported to AOGCC for continued IA build up 04/30/15 MIT-IA passed to 3000 psi: Failed IA DDT 05/30/15 Unable to drift to patch LDL tool string due to wrong snap latch assembly during install 06/08/15 Communication with AOGCC for submission of 10-404 only for patch replacement 06/11/15 Pulled upper section of tubing patch 06/12/15 Re-set upper section of tubing patch. Passed MIT-IA to 3000 psi. 06/16/15 Passed IA DDT i KUP INJ 3A-06 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska IOC Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) crrrx<A110ip, 500292144300 KUPARUK RIVER UNIT INJ 43.55 4,600.00 7,680.0 ".. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3A-06,3/22/2015 4112 4 PM SSSV:NIPPLE Last WO: 12/12/2008 36.48 10/19/1985 Vertical schematw(actuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ---- -Last Tag: 7,475.0 8/3/2008 Rev Reason:PATCH lehallf 3/22/2015 HANGER;28.6- ill Casing Strings 1 �j .1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 1040 104.0 62.58 H-40 Casing Description OD(in) ID(in) Top(ftKB Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread uar,SURFACE 95/8 8.765 30.7 3,406.4 3,178.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len 0...Grade Top Thread .ns n .h PRODUCTION 7 6.276 30.0 7,668.0 6,342.5 26.00 J-55 Tubing Strings CONDUCTOR;31.0-104.0 a Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(,blit) Grade Top Connection I TUBING 31/2 2.992 28.6 6,967.3 5,804.0 9.30 L-80 EUE NIPPLE;504.3 I4 Completion Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 28.6 28.6 0.05 HANGER FMC Gen 5 Tubing Hanger w/pup 2.992 SURFACE;30.7-3,4064 504.3 504.3 0.25 NIPPLE 3.5"x 2.875"Camco"DS"Nipple 2.875 Acid Wash;31.0 -� is 6,877.4 5,735.9 40.82 GAUGE Weatherford Gauge Mandrel 2.992 I 6,955.0 5,794.6 40.67 SEAL ASSY GBH-22 Seal Assembly&Locator w/2.00'space out 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection PACKER;6,818.0 __ TUBING 1.5"for 115/16 1.625 6,919.6 7,139.6 5,935.7 2.90 L-80 1J 10rnd Intensifier Pump PATCH;6.815.0 i Completion Details GAS LIFT;58271I Nominal ID Top(RKB) Top(ND)(ftKB) Top Incl(') Item Des Com lin) 6,919.6 5,767.8 40.70 XO Reducing X-Over 3.5"x 1.66"Stick out pin 1.660 PACKER;6,8420 :1=1 6,920.5 5,768.5 40.70 XO Enlarging X-over 1.66"x 1.9"Box x Box 1.900 m 7,132.2 5,930.0 39.77 LOCATOR No-Go LOCATOR 1.820 m=r II 7,133.8 5,931.3 39.77 SEAL ASSY SEAL ASSEMBLY 1.820 I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(lb/ft) Grade Top Connection ISO SLEEVE;6,877.4- Stack Packer 31/2 2.992 6,949.1 7,066.0 5,879.1 9.30 L-80 EUE GAUGE;6.8774 imar1418 Completion Details ilig INTENSIFIER TUBING;6,894.0 0 l(11 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) 6,949.1 5,790.2 40.68 PACKER Baker FHL Packer w/PBR 8 6.12'Pup jt 3.000 7,012.2 5,838.1 40.52 NIPPLE Camco"DS"Nipple 2.812 7,0512 5,867.9 40.16 LOCATOR Locator w/2"space out 3.000 7,053.7 5,869.8 40.14 SEAL ASSY 80-40 GBH-22 Seal Assembly WO/Seals 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection Completion Details 3 1/2 2.992 7,042.1 7,281.4 0,044.5 9.30 L-80 8RD MOD SEAL ASSY;6,955.0-, =' 76 PACKER;69451Nominal ID /11 4-1 Top(ftKB) Top(ND)(ftKB)!Top Incl(') Item Des l Com (In) 7,042.1 5,860.9 4025 PACKER BAKER 83-40 FB-1 PACKER 4.000 NIPPLE;7,012.2 i 7,045.4 5,863.4 4022 SBE BAKER SEAL BORE EXTENSION 4.000 • 7,138.6 5,934.9 39.78 BLAST JOINT 2.992 PACKER;7,042.1 7,238.4 6,011.5 39.98 NIPPLE AVA BPL PORTED NIPPLE w/ISO SLEEVE ID 2.31" 2.697 SBE;7545.4 7,253.0 6,022.7 40.02 LOCATOR BAKER 80-32 LOCATOR SUB 2.440 LOCATOR;7.0512 7,254.0 6,023.5 40.02 SEAL ASSY BAKER 80-32 SEAL ASSEMLY 2.440 7,255.0 6,024.3' 40.02 PACKER BAKER MODEL'D'PERMANENT PACKER w/5'SEAL 3250 BORE SEAL ASSY;7,053.7 7,273.7 6,038.6 40.08 NIPPLE CAMCO'0'2.25"NO GO NIPPLE 2.250 I 1 7,280.7 6,043.9 40.10 SOS BAKER SHEAR OUT 2.441 INJECTION;7,093.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) l Top(ND) 'Top Incl PACKER;7,129.0 Top(ftKB) (MKB) _ (') Des Com Run Date ID(in) -� - 6,815.0 5,688.7 41.09 PATCH 'SPACER PIPE W 17.5',SNAP LATCH 24' '3/17/2015 2.000 LOCATOR;7,132.2 ' ELEMENT TO ELEMENT • SEAL ASSY;7.133.8 f_f 6,818.0 5,691.0 41.07 PACKER WEATHERFORD 31/2WIDEPACK LE PACKER :3/17/2015 1.750 PACKER 6,842.0 5,709.1 40.97 PACKER WEATHERFORD 3 1/2 WIDEPACK LE PACKER 3/16/2015 1.810 IPERF;7,144.67,220.0- 6,877.4 5,735.9 40.82 ISO SLEEVE PORTED ISO SLEEVE(OAL=101") 6/16/2012 -' 7,129.0 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3.5" 12/12/2008 2.250 TBG NIPPLE;7,238.3 7,238.3 6,011.5 39.98,I50 SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 ISO SLEEVE;7,238.31 I Perforations&Slots I I Shot LOCATOR;7,253.0 T Dens op D) Bt SEAL ASSY;7,254.0 _ Top(ftKB) Btm(ftKB) (ftKB) (ftKB D) (sh Zone Date ti( Type Corn PACKER;7,255.0 '' 7,144.0 7,220.0 5,939.1 5,997.4 C-1,C-3,C-4, 11/22/1985 12.0 IPERF 120 deg phase;5'Csg 3A-06 Gun I 7,340.0 7,362.0 6,089.3 6,106.1 A-3,3A-06 11/22/1985 4.0 IPERF 90 deg.phase;4"Csg Gun NIPPLE;7,273.7 7,341.0 7,361.0 6,090.0 6,105.3 A-3,3A-06 6/14/2008 6.0 RPERF 21/8"PEJ,+/-45 DEG 1 7,372.0 7,420.0 6,113.8 6,150.6 A-2,3A-06 '6/142008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG SOS;7280.7 Y 7,372.0 7,420.0 6,113.8 6,150.6 A-2,3A-06 1122/1985 4.0 IPERF 90 deg.phase;4"Csg _ Gun IPERF;7,340.0.7,362.0 _ _ 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 6/112008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG RPERF;7,341.0.7,361.0 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 1122/1985 4.0 IPERF 90 deg.phase;4"Csg _ Gun RPERF;7,372.07,420.0 - IPERF;7,372.0.7,420.0 RPERF;7,444.07,450.0, IPERF;7,444.0.7,450.0 PRODUCTION;30.0-7,668.0 KUP INJ 3A-06 ConocoPhillips Alaska,Inc. Cc.acon:lhpl 3A-06.322/2015 4:11:24 PM Vertical schematic(actual) HANGER;28.6— I Stimulations&Treatments IdMin Top Max Btm ( Depth Depth Top(TVD) Bim(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com auu, 31.0 6,845.0 31.0' 5,711.4 Acid Wash 3/15/2009 Tubing Add Wash-60 bbls 7.5%HCL from 6845 CTMD to surface,allowing acid to soak 3 hrs in TBG s before displacing.Displaced TBG w/scale blaster W/45 bbls SSW for every 1000'TBG CONDUCTOR;31.0-104.0 „ Mandrel Inserts St ati NIPPLE;504.3 I on Top((VD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com { 6,827.1 5,697.9 CAMCO MMG 1 1/2 INJ PATC RK 0.000 0.0 8/31/2010 H SURFACE;30.73,406.4 2 7,093.0 5.899.9 CAMCO MMM 11/2 INJ DPHF RKP 0.000 0.0 12/2/2008 Add Wash:31 0 ,6 - I CV Notes:General&Safety End Date Annotation T'l 12/25/2008 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;6,818.0 PATCH;6,815.0 I..! GAS LIFT;6,827.1 i■I EEr[ PACKER;6,842.0 13r- J[�=: ISO SLEEVE;6,877.4- :99 GAUGE;6.8774 !` INTENSIFIER TUBING,6,894.0 --1 I ■ I 41 SEAL ASSY;6.955.0N PACKER;6,949.1 get f NIPPLE;7,012.2 PACKER;7,042.1 .I SBE;7,045.4 -I I LOCATOR;7,051.2 1 'r SEAL ASSY:7,053.7- 6 INJECTION.7,093.0 w. PACKER;7,129.0 LOCATOR;7,132.2 .` SEAL ASSY;7,133.8 IPERF;7,144.0-7,220.0— NIPPLE;7,238.3 ISO SLEEVE;7.238.31 I LOCATOR;7,253.0 SEAL ASSY;7,254.0 PACKER;7,255.0 _. . U NIPPLE;7,273.7 - a SOS;7,280.7- IPERF;7,340.0-7.362.0,, SS RPERF;7,341.0.7,361.0 RPERF;7,372.0-7,420.0 IPERF;7,372.0.7,420.0 RPERF;7,444.0-7,450.0 IPERF;7,4N.0.7.450.0 PRODUCTION;30.0.7.668.0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to jim regq(rDalaska qov AOGCC Inspectors@alaska gov phoebe brooks(rialaska qov chns wallace(0ialaska qov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/ Pad DATE: 06/12/15 OPERATOR REP: Watkins AOGCC REP: N/A Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-06 Type In/ W TVD 5,790' Tubing 1,050 1,050 1,050 1,050 Interval 0 P T D 1852220 Type test P Test psi 1500 Casing 1,250 2,525 2,490 2,475 P/F P Notes: Diagnostic MIT-IA OA 100 100 100 100 Well Type Int TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P.T D Type test Test psi Casing P/F Notes: OA Well Type In/ TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type Int. TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT TEST FORM 2013 xis STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to pm reggtSjalaska qov AOGCC Inspectors]talaska qov phoebe brooks[atalaska goy chris wallace@alaskagov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/ Pad DATE: 06/16/15 OPERATOR REP: Sumerall AOGCC REP: N/A Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-06 Type In/ W TVD 5,790' Tubing 1,100 1,100 1,100 1,100 1,100 1,100 Interval 0 _ P T D 1852220 Type test P Test psi 1500 Casing 873 500 512_ 515 5.17 518 P/F P Notes: Diagnostic DDT-IA OA 25 25 25 25 25 25 Well Type Int TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well _ Type Inj TVD Tubing Interval P T D Type test Test pd_ _Casing Casing - P/F Notes: OA Well Type In) TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) 3A-06 Diagnostic IA-DDT post patch 6-16-15 xis Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, June 17, 2015 10:39 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: RE: Kuparuk injector 3A-06 (PTD 185-222) Report of IA pressure rise Attachments: image001.png; 3A-06 Diagnostic IA-DDT post patch 6-16-15.xls; 3A-06 Diagnostic MIT- IA post patch 6-12-15.xls; 3A-06 90 Day TIO plot.JPG; 3A-06.pdf; 10-404 Packet.pdf Chris/Guy- Kuparuk injector 3A-06 (PTD 185-222) tubing patch replacement has been completed. The tubing patch was replaced and a successful diagnostic MIT-IA and IA DDT were performed proving integrity between the tubing and IA. The 10-404 has been submitted via mail for the patch reset and an electronic copy has been attached to this email for reference in the meantime. Because the well now displays TxIA integrity, it is CPAI's intention to bring the well online under normal injection status. If at any point in time communication is once again suspected diagnostics will be arranged as soon as reasonably possible. If you have any questions or disagree with the plan please contact us at your convenience. Attached is a well bore schematic, diagnostic testing forms, a copy of the 10-404 packet and a 90 day TIO plot. Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 WELLS TEAM conocoPhimps SCANNED JUL 1 6 2015 From:.-N K Problem Well Supv Sent: Tuesday, April 28, 2015 6:05 AM To: Wallace, Chris D (ZOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Kuparuk injector 3 T-06 (PTD 185-222) Report of IA pressure rise Chris, Kuparuk injector 3A-06 (PTD 185-222)was originally reported for1Ap`sure increase on 1/12/14. The well went through a series of diagnostics which culminated in the existing tubing patc k being pulled and replaced (sundry 314- 112). The well was recently brought on injection on 4/24/15 at which time theTA pressure began increasing. Initially the IA pressure increase was suspected to be thermal due to the fluids used during th well work until multiple bleeds and rate injection changes proved otherwise. The well is to be shut in and freeze protected ams soon as reasonably possible. Diagnostics will be scheduled as needed in attempt to identify the pressure source. Once a plan forward has been developed the proper notifications and paperwork will be submitted. A 90 day TIO and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. w U re > >. . . . 0 U) () U) U) U) N W W W W W a Z Z Z Z o ._ Z- Z Z Z u> r; OooO) UJ N- O CD C) ' to Cri co CO CO r a r iL C -- O y O O O O O - w 000oUn VI Cr CD 0 01 co CO z a a) o a) x o w Cd y (_) 0 0 0 a) w r— ornCC) CY CO CO r~ C) a. N ccH in CD Un u) u; .1. 0 0 0 0 0 w CV CV N N N (n (a .7 V' V N N N CD 'V NI. .1 C] JI C, COCO CO CO J O O O O O co 6) co M co A6ap O O O O O O O O O [n co JO U, •r 03 ry I 1 I I I i I I I C C UJ CDV • C ('- ... 7' .CI Cr CC r-- u, . " on on 0 O `--� 1 V N 03 G1 C Z aUl _ _ LL in � c) c N ONi f v : £ Q Q) O7 ti M > M CO a a xa Q- ?;g0_ d CO o o o 2 2 c. 2 W N U N I N S ss � � U) o U/ U W O U, Od1e tom 1_ N C) th IN V m0CC isd in 0 w KUP INJ 3A-06 ConocoPhillips o Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(.I MD(f6KB) Act Btm(ftKB) tkf,,, 500292144300 KUPARUK RIVER UNIT INJ 43.55 4,600.00 7,680.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-06,3/22/20154:11,24 PM SSSV:NIPPLE Last WO. 12/12/2008 36.48 10/19/1985 Vertical schematk(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 7,475.0 8/3/2008 Rev Reason:PATCH lehallf 3/22/2015 HANGER.286- ,AO Casing Strings .,a �� ,ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 104.0 104.0 62.58 H-40 Casing Description Itt] OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ....�,,, ..,�,,,",SURFACE 95/8 8.765 30.7 3,406.4 3,1782 36.00 J-55 BTC Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread /..n �,n,�.��.�PRODUCTION 7 6.276 30.0 7,668.0 6,342.5 26.00 J-55 -- Tubing Strings CONDUCTOR;31.0-104.0--a A Tubing Description 'String Ma...I ID(in) ITop(ftKB) 'Set Depth(Bret Depth(TVD'(...I Wt(Ib/ft) (Grade 'Top Connection I TUBING 31/2 2.992 28.6 6,967311 5,8040 9.301L-80 EUE NIPPLE;5043 Completion Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com (in) 28.6 28.6 0.05 HANGER 'FMC Gen 5 Tubing Hanger w/pup 2.992 SURFACE;90.7J,400.4 J 504.3 504.3 0.25"NIPPLE 3.5"x 2.875"Camco"DS"Nipple 2.875 Aaa wean;31.0`- 6,877.4 5,735.9 40.82"GAUGE 'Weatherford Gauge Mandrel 2.992 II 6,955.0 5,7946 40.67 SEAL ASSY GBH-22 Seal Assembly&Locator w/2.00'space out 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Bet Depth(ft..Set Depth(TVD)(...WlQdft) Grade Top Connection PACKER;6,818.0 .-r TUBING 1.5"for I 115/161 1.6251 6,919.6 7,139.61 5,935.71 2.901 L-80 11J 10 rod Intensifier Pump PATCH;0,815.' Completion Details GAS LIFT;0,827.1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ino/(°) Item Des Com (In) 6,919.6 5,767.8 40.70 XO Reducing X-Over 3.5"x 1.66"Stick out pin 1.660 PACKER;8,8421- ")U(1 6,920.5 5,768.5 40.70 XO Enlarging X-over 1.66"x 1.9"Box x Box 1.900 '112i t 7,132.2 5,930.0 39.77 LOCATOR No-Go LOCATOR 1.820 7,133.8 5,931.3 39.77 SEAL ASSY SEAL ASSEMBLY 1.820 Tubing Description (String Ma...IID(in) ITop"B) Set Depth(k..Set Depth(TVD'I...(Wt(lb/ft) 'Grade 'Top Connection Iso SLEEVE;8.877.4.. Stack Packer 312 2.992 6,949.1 7,066.015.8791 930 L-80 EUE GAUGE;0,877.4 4 Completion Details = Nominal ID INTENSIFIER TUBING;8,894.0 Top(kKB) Top(TVD)(8KB) Top Inoi(°) Item Des Com (in) 'I 6,949.1 5,790.2 40.68 PACKER Baker FHL Packer w/PBR&6.12'Pup jt 3.000 If7,012.2 5,838.1 40.52 NIPPLE Camco"DS"Nipple 2.812 7,051.2 5,867.9 40.16 LOCATOR Locator w/2'space out 3.000' 7,053.7 5,869.8 40.14 SEAL ASSY 80-40 GBH-22 Seal Assembly WO/Seals 3.000 Tubing Description 'String Ma...IID(In) ITop(ftKB) Set Depth(ft..'Set Depth(TVD)(...l Wt(lb/ft) 'Grade 'Top Connection TUBING Original 312 2.992 7,042.1 7.281 4 6,044.519.30 L-80 8RD MOD SEAL ASSY;6,955.0` I Completion Details PACKER;0,949.1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Dee Com (in) 7,042.1 5,860.9 40.25 PACKER BAKER 83-40 FB-1 PACKER 4.000 NIPPLE;7,0122 7,045.4 5,863.4 40.22 SBE BAKER SEAL BORE EXTENSION 4.000 7,138.6 5,934.9 39.78 BLAST JOINT 2.992 • PACKER;7,042.1 7,238.4 6,011.5 39.98 NIPPLE AVA BPL PORTED NIPPLE w/ISO SLEEVE ID 2.31" 2.697 SBE;7,045.4 7,253.0 6,022.7 40.02 LOCATOR BAKER 80-32 LOCATOR SUB 2.440 LOCATOR;7,051.2 7254.0 6,023.5 4002 SEAL ASSY BAKER 80-32 SEAL ASSEMLY 2.440 7,255.0 6,024.3 40.02 PACKER BAKER MODEL'D'PERMANENT PACKER w/5'SEAL 3.250 BORE SEAL ASSY;7,053.7 7,273.7 6,038.6 40.08 NIPPLE CAMCO'D'2.25"NO GO NIPPLE 2250 7,280.7 6,043.9 40.10 SOS BAKER SHEAR OUT 2.441 INJECTION;7,0930 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • Top(TVD) Top Incl PACKER;7,129.0110 Top(ftKB) (ftKB) Dee Com Run Date ID(in) 6,815.0 5,688.7 41.09 PATCH SPACER PIPE W 17.5',SNAP LATCH 24' 3/172015 2.000 ELEMENT TO ELEMENT LOCATOR;7,132.2 6,818.0 5,691.0 41.07 PACKER WEATHERFORD 3 1/2 WIDEPACK LE PACKER 3/17/2015 1.750 SEAL ASSY;7,133.8 PACKER 6,842.0 5,709.1 40.97 PACKER WEATHERFORD 312 WIDEPACK LE PACKER 3/16/2015 1.810 IPERF;7,144.0-7,220.0- 6,877.4 5,735.9 40.82 ISO SLEEVE PORTED ISO SLEEVE(OAL=101") 6/16/2012 7,129.0 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3.5" 12/12/2008 2.250 TBG NIPPLE;7.2383 7.238.3 6,011.5 39.98 ISO SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 ISO SLEEVE:7,238.3, Perforations&Slots Shot Dens LOCATOR;7253.0 Top(TVD) Btm(TVD) (shot:0 SEAL ASSY;7,254.0 -- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PACKER;7,2650 4z.. 7,144.0 7,220.0 5,939.1 5,997.4 C-1,C-3,C-4, 11/22/1985 120 IPERF 120 deg phase;5"Csg .., 3A-06 Gun ,-- 7,340.0 7,362.0 6,089.3 6,106.1 A-3,3A-06 11/22/1985 4.0 IPERF 90 deg.phase;4"Csg Gun NIPPLE;7.273.7-----€> 7,341.0 7,361.0 6,0900 6,105.3 A-3,3A-06 6/14/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG © 7,372.0 7,420.0 6,113.8 6,150.6 A-2,3A-06 6/14/2008 60 RPERF 21/8"PEJ,+1-45 DEG Sos;7,280.7 -- 7,372.0 7,420.0 6,113.8 6,150.6 A-2,3A-06 1122/1985 4.0 IPERF 90 deg.phase;4"Csg Gun IPERF 7,340.0-7,362.0 _ 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 6/11/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG RPERF;7,341 0-7,901.0 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 11/22/1985 4.0 IPERF 90 deg.phase;4"Csg Gun RPERF;7,372.0-7,420.0 IPERF;7,372.0-7,420.0 RPERF;7.444.0-7,450.0 • IPERF;7,444.0-7,450.0 PRODUCTION;30.0-7,008.0 KUP INJ 3A-06 ConocoPhillips frmrRa 3,06,3122/2015 4:11:24 PM Verticalscherneto(actual) HANGER.286— .H i_ Stimulations&Treatments II Min Top Max Ben Depth Depth Top(TVD) Ben(TVD) . ,. F (fiKB) (566) (666) (NKB) Type 31.0 5 711 4 Acid WDate Can y-J�yy aLLLIII 31 0 G.815 0ash 3/152009 Tubing Acid Wash-60 bbls 7.5%HCL from 6845 CTMD to surface,allowing acid to soak 3 hrs in TBG A ,r--",.k,�,,r before displacing.Displaced TBG w/scale blaster W/45 bbls SSW for every 1000'TBG CONDUCTOR;31.0-104.0 J, Mandrel Inserts St NIPPLE;504.3 n on' Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (CK0) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f 6,827.1 5,697.9 CAMCO MMG 1 1/2 INJ PATC RK 0.000 0.0 8/31/2010 H SURFACE:307x.406.4 • 2 7,093.0 5,899.9 CAMCO MMM 11/2 INJ DPHF RKP 0.000 0.0 12/2/2008 Add Wash;31.0 A A CV Notes:General&Safety End Date Annotation 12/25/2008 NOTE View Schematic w/Alaska Schematic9.0 PACKER;4818.0 PATCH:6,8150 `1ii GAS LIFT:8,827.1 P 6,8420 315.r l-lUt l i pTL) - ZZZ Loepp. Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,June 08, 2015 12:20 PM To: NSK Problem Well Supv Cc: Senden, R.Tyler;Wallace, Chris D (DOA); Loepp, Victoria T (DOA) Subject: RE: 3A-06 (PTD# 185-222) Upper patch reset Follow Up Flag: Follow up Flag Status: Flagged Jan, As this is a diagnostic step to determine your leak path go ahead and perform the operation and report results on a standalone 10-404. Just include a cover sheet with an explanation of events and well history. Do not reference the other sundry as it has been closed out. As you mentioned in the phone call the well passes a MIT-IA but IA builds up pressure over time. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED JUL 0 12015 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: NSK Problem Well Supv [mailto_n1617@conocophillips.com] Sent: Monday, June 08, 2015 11:19 AM To: Schwartz, Guy L(DOA) Cc: Senden, R. Tyler Subject: 3A-06 (PTD# 185-222) Upper patch reset Guy, As per our conversation concerning the patch in 3A-06 (PTD#185-222)CPAI intends to pull the upper packer and patch assembly to enable the well bore fluids to be circulated out and install sufficient freeze protect in the IA for further diagnostics. After the well has been circulated out the upper patch assembly will be stung back into the lower packer and reset. Is it acceptable to reset the upper packer and patch assembly using the last sundry(#314-112) and file a 10- 404? Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7126 Pager(907) 659-7000 pgr. 123 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, April 28, 2015 6:05 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: Kuparuk injector 3A-06 (PTD 185-222) Report of IA pressure rise Attachments: 3A-06 90 day TIO trend 4-28-15.MHT; 3A-06 wellbore schematic.pdf Chris, Kuparuk injector 3A-06 (PTD 185-222)was originally reported for IA pressure increase on 1/12/14. The well went through a series of diagnostics which culminated in the existing tubing patch being pulled and replaced (sundry 314- 112). The well was recently brought on injection on 4/24/15 at which time the IA pressure began increasing. Initially the IA pressure increase was suspected to be thermal due to the fluids used during the well work until multiple bleeds and rate injection changes proved otherwise. The well is to be shut in and freeze protected as soon as reasonably possible. Diagnostics will be scheduled as needed in attempt to identify the pressure source. Once a plan forward has been developed the proper notifications and paperwork will be submitted. A 90 day TIO and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor SCANNED APR 2 9 2015 ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] : Wednesday, February 19, 2014 3:32 PM To: NS ' '•lem Well Supv Cc: Senden, R. Subject: [EXTERNAL]' . uparuk injector 3A-06 (PTD 185-222) Report of IA pressure rise Dusty, Looking at the records I see the Sundry 310-4, i ued on December 23, 2010 and the corresponding reports of that work 10-404 dated 15 October 2012 and again Novem. 2012. You should submit a new sundry application 10-403 for the new work, . .. complete the subsequent report 10-404. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 1 Page lofl Well Name Notes'. Start Date Days Mead History End Date Vs114011 i 71 , 1� Annular Communication Surveillance srn-vars Fio-vers zA-06 4r26/2ot5 za:o •303 1800NER 3A-06 4/24/2015 1750 900 850148ER 47NP 3A-06 4/24/2015 1400 800 600 INNER 3A-06 2/4/2014 1999 850 1149 HER -40 2icC— - r -70 2000 -- - -- i a0 111 _g04 tT O 1500 V v ,c 1000 30 —20 500 A . /j` J'/^\\\, 0 _ f 1 A 7 Y 0 Jan-15 Fab-15 Mar.SS 14x-15 May-15 4600 Oi .oa_ -- t 10_ aeae 46m. 000. Jan-t5 445 Mor-t5 'ei-15 May-IS Das mhtml:file://C:\Users\cdwallace\AppData\Local\Microsoft\Windows\Temporary Internet F... 4/28/2015 4 KUP INJ 3A-06 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) 500292144300 KUPARUK RIVER UNIT INJ 43.55 4,600.00 7,680.0 ,-, Comment H2S(ppm) Date Annotation End Data KB-Grd(ft) II-Rig Release Date 3A-06,3/22/2015 4:11:24 PM SSSV:NIPPLE Last WO: 12/12/2008 36.48 10/19/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Data Annotation Last Mod By End Date -- --- -- Last Tag. 7,475.0 8/3/2008 Rev Reason:PATCH lehallf 3/22/2015 HANGER;28,13----•l jir Casing Strings ( EU II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(hKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 1040 104.0 62.58 H-40 Casing Description OD(in) ID(in) Top)ftKB) Set Depth)RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.765 30.7 3,406.4 3,178.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(ND)...Wt/Len(I...Grade "Top Thread III .r PRODUCTION 7 6.276 30.0 7,668.0 6,342.5 26.00 J-55 Tubing Strings CONDUCTOR;31.0-104.0 -• Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 28.6 6,967.3 5,804.0 9.30 L-80 EUE NIPPLE;804.3 LI Completion Details Nominal ID 1 Top(ftKB) Top)TVD)((MB) Top feel() Item Dee Com (In) 28.6 28.6 0.05 HANGER FMC Gen 5 Tubing Hanger w/pup 2.992 SURFACE;30.73,406.4 504.3 504.3 0.25 NIPPLE 3.5"x 2.875"Cameo"DS"Nipple 2.875 Aad Wash;31.0 6,877.4 5,735.9' 40.82 GAUGE Weatherford Gauge Mandrel 2.992 6,955.0 5,794.6 40.67 SEAL ASSY GBH-22 Seal Assembly&Locator w/2.00'space out 3.000 II Tubing Description String Ma...ID lin) Top MKS) Set Depth(ft..Set Depth(ND)(...Wt(16X1) Grade Top Connection PACKER;8,818.0 - X' _ TUBING 1.5"for 1 15/16 1.625 6,919.6 7,139.6 5,935.7 2.90 L-80 1J 10 rod Intensifier Pump PATCH;8,618.0 I� Completion Details • GAS LIFT;6,827.1 Nominal ID Top(ftKB) Top(TV))MKS) Top Mel(°) Item Des Cam (in) e e 6,919.6 5,767.8 40.70 XO Reducing X-Over 3.5"x 1.66"Stick out pin 1.660 PACKER;6,8420 Yin 6,920.5 5,768.5 40.70 XO Enlarging X-over 1.66"x 1.9"Box x Box 1.900 �7(_1 7,132.2 5,930.0 39.77 LOCATOR No-Go LOCATOR 1.820 -e 7,133.8 5,931.3 39.77 SEAL ASSY SEAL ASSEMBLY 1.820 Tubing Description String Ma...ID(in) Top(ftKB) ret Depth(R..Set Depth(TVD)(...Wt OWN) Grade Top Connection -- ISO SLEEVE;0,877.4- Stack Packer 31/2 2.992 6,949.11 7,066.0 5,879.1 9.30 L-80 EUE GAUGE;8,877.41`-5 Completion Details Nominal ID ' INTENSIFIER TUBING;8,894.0 Top MKS) Top(TVD))ftKB) Top Incl(") Item Des Com (in) 6,949.1 5,790.2 40.68 PACKER Baker FHL Packer w/PBR&6.12'Pup jt 3.000 111 7,012.2 5,838.1 40.52 NIPPLE Camco"DS"Nipple 2.812 II7,051.2 5,867.9 40.16 LOCATOR Locator w/2'space out 3.000 7,053.7 5,869.8 40.14 SEAL ASSY 80-40 GBH-22 Seal Assembly WO/Seals ' 3.000 Tubing Description String Ma...ID pn) Top(ftKB) ret Depth(ft..r Set Depth(TVD)(...Wt(Ib/fl) Grade Top Connection 1 TUBING Original 3 1/2 2.992 7,042.11 7,281.4 6,044.5 9.30 L-80 8RD MOD ?°f Completion Details SEAL ASSY;00491 L - ' PACKER;8,949.1 Nominal ID )) tt Top MKS) Top(TVD)(ftKB) Top Incl(°) Item Des Cam (in) i7,042.1 5,860.9 40.25 PACKER BAKER 83-40 FB-1 PACKER 4.000 1 NIPPLE;7,012.2 ' 7,045.4' 5,863.4 40.22 SBE BAKER SEAL BORE EXTENSION 4.000 7,138.6 5,934.9 39.78 BLAST JOINT 2.992 PACKER;7,042.1 .1 I; 7,238.4 6,011.5' 39.98 NIPPLE AVA BPL PORTED NIPPLE w/ISO SLEEVE ID 2.31" 2.697 SBE;7,046.4 I I 7,253.0 6,022.7 40.02-LOCATOR BAKER 80-32 LOCATOR SUB 2.440 LOCATOR;7,051.2 - ' ', 7,254.0 6,023.5 40.02 SEAL ASSY BAKER 80-32 SEAL ASSEMLY 2.440 • 7,255.0 6,024.3 40.02 PACKER BAKER MODEL'D'PERMANENT PACKER w/5'SEAL 3.250 / BORE SEAL ASSY;7,053.7 j 7,273.7 6,038.6 40.08 NIPPLE CAMCO'D'2.25"NO GO NIPPLE 2.250 7.280.7 6.043.9 40.10 SOS BAKER SHEAR OUT 2.441 INJECTION;7,093.0 ie Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl PACKER;7129.0 - Top)hKB) (hKB) 5) Das Com Run Date ID(in) "L.-- 6,815.0 5,688.7 41.09 PATCH SPACER PIPE W 17.5',SNAP LATCH 24' 3/17/2015 2.000 LOCATOR;7,132.2 1.11II ELEMENT TO ELEMENT 6,818.0 5,691.0 41.07 PACKER WEATHERFORD 3 1/2 WIDEPACK LE PACKER 3/17/2015 1.750 SEAL ASSY;7,133.8 PACKER 6,842.0 5,709.1 40.97 PACKER WEATHERFORD 3 1/2 WIDEPACK LE PACKER 3/16/2015 1.810 6,877.4 5,735.9 40.82 ISO SLEEVE PORTED ISO SLEEVE(OAL=101") 6/16/2012 (PERF;7,144.0-7,220.0 7,129.0 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3.5" 12/12/2008 2.250 TBG NIPPLE;7.238.3 7.238 3 6,011.5 39.98 ISO SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 ISO SLEEVE;7.238.31 II Perforations&Slots I Shot Dens LOCATOR;7,253.0 Top( atmITVDI a hotsM SEAL ASSY;7,254.0 Top(ftKB) BM(MB) (ftKB)B) ((KB) Zone Dab t) Type Cam PACKER;7,2551 - 7,144.0 7,220.0 5,939.15,997.4 C-1,C-3,C4, -11/22/1985 12.0 IPERF 120 deg phase;5"Csg 3A-06 Gun • 7,340.0 7,362.0 6,089.3 6,106.1 A-3,3A-06 1122/1985 4.0 IPERF 90 deg.phase;4"Csg I Gun NIPPLE;7,273.7 7,341.0 7,361.0 6,090.0 6,105.3 A-3,3A-06 6/14/2008 6.0 RPERF 2 1/8"PEJ,'./-45 DEG I 7,3720 7,420.0 6,113.8 6,150.6 A-2,3A-06 6/14/2008 6.0 RPERF 21/8"PEJ,+/-45 DEG sos;7.260.7 ■ 7,372.0 7,420.0 6,113.8 6,150.6 A-2,3A-06 1122/1985 40 IPERF 90 deg.phase;4"Csg _ Gun IPERF;7,340.0.7,302.0 _ e, 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 6/11/2008 6.0 RPERF 21/8"PEJ,+/-45 DEG RPERF;7,341.0-7,301.0 r 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 11/22/1985 4.0 IPERF 90 deg.phase;4"Csg Gun RPERF;7,372.0-7,420.0 .-- IPERF;7,372.0-7,420.0 RPERF;7,444.0.7,450.0 - IPERF;7,444.0.7,450.0 PRODUCTION;30.0-7,088.0 • KUP INJ 3A-06 ConocoPhillips Alaska,Inc. 34-06.3/22/2015 4.11'.24 PM Vertical schematic(actual) HANGER;28.0-'FI` Stimulations&Treatments �� Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (MB) (ftKB) (ftKB) (f1Ka) Type Dale Com 31.0 6,845.0 31.0 5,711.4 Acid Wash 3/15/2009 Tubing Acid Wash-60 bbls 7.5%HCL from 6845 CTMD to surface,allowing acid to soak 3 hrs in TBG before displacing.Displaced TBG w/scale blaster W/45 bbls SSW for every 1000'TBG 'i CONDUCTOR;310-104.0_ 111 Mandrel Inserts St NIPPLE:5043 ali N Top(TVD) Valor Latah Port Size TRO Run Top(KKB) (KKB) Make MaMI OD(In) 9ary Type Type (In) (psi) Run Dab Cam � 6,827.1 5,697.9 CAMCO MMD 11/2 IN PATC RK 0.000 0.0 8/31/2010 H SURFACE;30.7J.4K64 2 7,093.0 5,899.9 CAMCO MMM 112 INJ Valve RKP 0.000 0.0 12/2/2008 Add WaM;31.0 CV I Notes:General&Safety End Date Annotation • l 12/25/2008 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;0,818,0 _ 111- �- PATCH;6,81501 ,8150' GAS LIFT;0,827.1 PACKER;6,842.0 .-118- lQl=1 ISO SLEEVE;6,877.4- 'W GAUGE;0.8771 I NNW INTENSIFIER TUBING;6,8940 mirk It SEAL ASSY;6,955.01 PACKER;0,949.1 "I Ll NIPPLE;7,012.2 I PACKER,7,042.1 SBE;7,045.4 LOCATOR;7,051.2 . SEAL ASSY;7,053.7 1 [ INJECTION;7,093.0 L� PACKER;7,129.0 LOCATOR;7.132.2 ■ SEAL ASSY;7,133.8 ; IPERF;7,144.04,220.0-.1- NIPPLE; ,144.0.7,220.0 NIPPLE;7,2383 ISO SLEEVE;7,238.31 • yU• I LOCATOR;7,253.0 a r SEAL ASSY;7,2540 PACKER;7,255.0111 _ i NIPPLE;7,273.7 SOS;7,2807 1t IPERF;7,340.0-7,302.0, RPERF;7,311.0-7,301.0 RIPEPERF;RF;7,372.0.7,420.0, 7,372.0-7,420.0 RPERF; IPERF;7,444.0-7,450.0 PRODUCTION;30.0.7,088.0 ` STATE OF ALASKA AL, ,(A OIL AND GAS CONSERVATION COIV, ..SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed' Abandon r Repair w ell r Rug Perforations r Perforate r Other p' Reset tubing Alter Casing r Pull Tubing r Stimulate- Frac Waiver patch r r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185-222 3.Address: 6.API Number: Stratigraphic r Service r P O. Box 100360,Anchorage,Alaska 99510 50-029-21443-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025632 KRU 3A-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7680 feet Plugs(measured) None true vertical 6352 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6819,6822, 6840, 6894,6949 true vertical 0 feet (true vertical) 5692, 5694, 5708, 5748, 5790 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 0 0 SURFACE 3376 12 3406 3179 0 0 PRODUCTION 7638 7 7668 6343 0 0 Perforation depth: Measured depth: 7144-7220,7340-7362, 7372-7420,7440-7450 E C E D True Vertical Depth: 5939-5998, 6090-6106, 6114-6150,6169-6174 MAR 2 4 2015 Tubing(size,grade,MD,and ND) 2 875, L-80, 7281 MD,6044 TVD o Packers&SSSV(type,MD,and ND) PACKER-WEATHERFORD ER PACKER @ 6818 MD and 5692 ND /'1 A GCC PACKER-WEATHERFORD ER PACKER @ 6842 MD and 5709 TVD PACKER-BAKER FHL PACKER W/PBR&6.12' PUP JT @ 6949 MD and 5790 ND 12.Stimulation or cement squeeze summary.N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: p NNED ;-, "- 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 314-112 Contact DustyFreebom/Jan Byrne Email n1617@conocophillips.com Printed Name Dust Freeborn Title Problem Wells Supervisor Signature Phone:659-7126 Date ZZ Mu2Gg 15— RBDMSik APR - 6 2015 V IA- 4//0//T A 4-7/ .l—-- Form 10-404 Revised 10/2012 Submit Original Only • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 22th day of March 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Ms. Foerster Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3A-06 PTD 185-222 tubing patch. Please call Jan Byrne or myself if you have any questions. Sincerely, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 3A-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/19/14 Existing tubing patch suspected to be TxIA leak point 02/22/14 10-403 Submitted for patch replacement 03/17/15 Lower Weatherford ER packer set and tested. Upper Weatherford ER packer set 03/18/15 Upper Weatherford ER packer tested. MIT-IA passed to 3000 psi. 3A-06 . DESCRIPTION OF WORK COMPLETED SUMMARY ►•- • s KUP INJ 3A-06 ConocoPhillips ' Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Bhn(ftKB) c„....,;vhdbr, 500292144300 KUPARUK RIVER UNIT INJ 43.55 4,600.00 7,680.0 I ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-06,3/22/2015 4:11:24 PM SSSV:NIPPLE Last WO: 12/12/2008 36.48 10/19/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ............ Last Tag: 7,475.0 8/3/2008 Rev Reason:PATCH lehallf 3/22/2015 HANGER;28.6 _1:81 - 11 Cas� g!trines Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread .1CONDUCTOR 16 15.062 31.0 104.0 104.0 62.58 H-40 Gra T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth 3,17 . Wt/Len(L..J-555e BTCop Thread , SURFACE 9 5/8 8.765 30.7 3,406.4 3,178.2 36.00 (TV Casing Description (in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len p...Grade Top Thread ill s PRODUCTION 7 6.276 30.0 7,668.0 6,342.5 26.00 J-55 Tubing Strings CONDUCTOR;31.0-104.0 - Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 28.6 6,967.3 5,804.0 9.30 L-80 EUE NIPPLE;504.3 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 28.6 28.6 0.05 HANGER FMC Gen 5 Tubing Hanger w/pup 2.992 SURFACE;30.7-3,406.4 5043 504.3 0.25'NIPPLE 3.5"x 2.875"Camco"DS"Nipple 2.875 Acid Wash;31.0 A A 6,877.4 5,735.9 40.82 GAUGE Weatherford Gauge Mandrel 2.992 6,955.0 5,794.6 40.67'SEAL ASSY GBH-22 Seal Assembly&Locator w/2.00'space out 3.000 I, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection PACKER;6,818.0 - TUBING 1.5"for 1 15/16 1.625 6,919.6 7,139.6 5,935.7 2.90 L-80 1J 10 rnd Intensifier Pump PATCH:6,615.0 �` Completion Details GAS LIFT;6,827.1 Nominal ID fI Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des _ Corn (in) ie, 6,919.6 5,767.8 40.70 XO Reducing X-Over 3.5"x 1.66"Stick out pin 1.660 PACKER;6,842.0 }-11 rut 6,920.5 5,768.5 40.70 XO Enlarging X-over 1.66"x 1.9"Box x Box 1.900 7,132.2 5,930.0 39.77 LOCATOR No-Go LOCATOR 1.820 I -l['t-t r;�, 7,133.8 5,931.3 39.77 SEAL ASSY SEAL ASSEMBLY 1.820 -, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...'Wt)Ib/ft) Grade Top Connection I '" ISO SLEEVE:6,877.4- '-' Stack Packer 3 1/2 2.992 6,949.1 7,066.0 5,879.1 9.30 L-80 EUE GAUGE;6,877.40 Completion Details Aim. INTENSIFIER TUBING;6,894.0 {(WY 1. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 6,949.1 5,790.2 40.68 PACKER Baker FHL Packer w/PBR&6.12'Pup jt 3.000 , 7,012.2 5,838.1 40.52 NIPPLE Camco"DS"Nipple 2.812 ■ 7,051.2 5,867.9 40.16 LOCATOR Locator w/2'space out 3.000 i! 7,053.7' 5,869.8 40.14 SEAL ASSY 80-40 GBH-22 Seal Assembly WO/Seals 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Original 3 1/2 2.992 7,042.1 7,281.4 6,044.5 9.30 L-80 8RD MOD SEAL ASSY;6,955 0-, ) ''t Completion Details PACKER;6,949.1 I Nominal iD i' 1''I t Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 7,042.1 5,860.9 40.25 PACKER BAKER 83-40 FB-1 PACKER 4.000 NIPPLE;7,012.2 7,045.4 5,863.4 40.22 SBE BAKER SEAL BORE EXTENSION 4.000 7,138.6 5,934.9 39.78 BLAST JOINT 2.992 PACKER;7,042.1 ,; 7,238.4 6,011.5 39.98 NIPPLE AVA BPL PORTED NIPPLE w/ISO SLEEVE ID 2.31" 2.697 SBE;7,045.4 s 7,253.0 6,022.7 40.02 LOCATOR BAKER 80-32 LOCATOR SUB 2.440 LOCATOR;7,051.2 ' I, 7,254.0 6,023.5 40.02 SEAL ASSY BAKER 80-32 SEAL ASSEMLY 2.440 7,255.0 6,024.3 40.02 PACKER BAKER MODEL'D'PERMANENT PACKER w/5'SEAL 3.250 BORE SEAL ASSY;7,053.7 7,273.7 6,038.6 40.08 NIPPLE CAMCO'D' 2.25"NO GO NIPPLE 2.250 7,280.7 6,043.9 40.10 SOS BAKER SHEAR OUT 2.441 INJECTION;7,093.0 ',;/.. Other In Hole(Wireline retrievable plugs,valves, pumps,fish,etc.) Top(ND) Top Incl PACKER;7,129.0 s_ Top(ftKB) (ftKB) (°) Des Com Run Date _ ID(in) 6,815.0 5,688.7 41.09 PATCH SPACER PIPE W 17.5',SNAP LATCH 24' 3/17/2015 2.000 •- ELEMENT TO ELEMENT LOCATOR;7,132.2 6,818.0 5,691.0 41.07 PACKER WEATHERFORD 3 1/2 WIDEPACK LE PACKER 3/17/2015 1.750 SEAL ASSY;7,133.8 : PACKER 6,842.0 5,709.1 40.97 PACKER WEATHERFORD 3 1/2 WIDEPACK LE PACKER 3/16/2015 1.810 _ 6,877.4 5,735.9 40.82 ISO SLEEVE PORTED ISO SLEEVE(OAL=101") 6/16/2012 (PERF;7,144.0-7,220.0 7,129.0 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3.5" 12/12/2008 2.250 i TBG NIPPLE;7,238.37,238.3 6,011.5 39.98 ISO SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 ISO SLEEVE;7,238.3, Perforations&Slots Shot LOCATOR;7,253.0 III. Top(ND) Btm(ND) (shots/f SEAL ASSY;7,254.0 = Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,144.0 7,220.0 5,939.1 5,997.4 C-1,C-3,C-4, 11/22/1985 12.0 IPERF 120 deg phase;5"Csg I PACKER;7,255.03A-06 Gun I 7,340.0 7,362.0 6,089.3 6,106.1 A-3,3A-06 11/22/1985 4.0 (PERF 90 deg.phase;4"Csg Gun NIPPLE;7,273.7 7,341.0 7,361.0' 6,090.0 6,105.3 A-3,3A-06 6/14/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG 7,372.0 7,420.0 6,113.8 6,150.6 A-2,3A-06 6/14/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG SOS;7,280.7 7,372.0. 7,420.0 6,113.8 6,150.6 A-2,3A-06 11/22/1985 4.0 (PERF 90 deg.phase;4"Csg Gun (PERF;7,340.0-7,362.0 7,444.0 7,450.0' 6,169.1 6,173.7 A-1,3A-06 6/11/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG RPERF;7,341.0-7,361.0.�- _ 7,444.0 7,450.0 6,169.1 6,173.7 A-1,3A-06 11/22/1985 4.0 (PERF 90 deg.phase;4"Csg Gun RPERF;7,372.0-7,420.0 (PERF;7,372.0-7,420.0 RPERF;7,444.0-7,450.0 .-_ (PERF;7,444.0-7,450.0 PRODUCTION;30.0-7,668.0 KUP INJ 3A-06 .11 ConocoPhillips Al-i,k<i,hh;. ConocciFRulkps 3A-06,3/22/2015 4:11:24 PM Vertical schematic(actual) ..................................... --- HANGER;28.6 HANGER;28.6 F Stimulations&Treatments I �� I Min Top Max Btm Depth Depth Top(TVD) Btm(ND) 1 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn Luu 31.0 6,845.0 31.0 5,711.4 Acid Wash 3/15/2009 Tubing Acid Wash-60 bbls 7.5%HCL from 6845 CTMD to surface,allowing acid to soak 3 hrs in TBG before displacing.Displaced TBG w/scale blaster • W/45 bbls SSW for every 1000'TBG CONDUCTOR;31.0-104.0 Mandrel Inserts St NIPPLE;504.3 ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 6,827.1 5,697.9 CAMCO MMG 11/2 INJ PATC RK 0.000 0.0 8/31/2010 H SURFACE;30.7-3,406.4 2 7,093.0 5,899.9 CAMCO MMM 1 1/2 INJ Valve RKP 0.000 0.0 12/2/2008 Acid Wash;3,. \-- - CVI II Notes:General&Safety End Date Annotation 6 12/25/20J8 NOTE:View Schematic w/Alaska Schematic9 0 PACKER;6,818.0 _ PATCH;6,815. an-.-. GAS LIFT;6,827.1 0 !t PACKER;6,842.0 7 (= iapr_ .. i ISO SLEEVE;6,877.4 1:11e GAUGE;6,877.4 (` s Alibi INTENSIFIER TUBING;6,894.0 {_ ti T ■ -i [OS SEAL ASSY;6,955.0, PACKER;6,949.1 €1 'iIt NIPPLE;7,012.2 PACKER;7,042.1 : is: SBE;7,045.4 I I LOCATOR;7,051.2 ', SEAL ASSY;7,053.7 INJECTION;7,093.0 ..., I PACKER;7,129.0 — LOCATOR;7,132.2 a SEAL ASSY;7,133.8 I IPERF;7,144.0-7,220.0 S NIPPLE;7,238.3, I ISO SLEEVE;7,238.3 LOCATOR;7,253.0 SEAL ASSY;7,254.0 PACKER;7,255.0 _' I NIPPLE;7,273.7 a SOS;7,280.7 f IPERF;7,340.0-7,362.0 _ _ RPERF;7,341.0-7,361.0 RPERF;7,372.0-7,420.0 _ IPERF;7,372.0-7,420.0 RPERF;7,444.0-7,450.0 -.— IPERF;7,444.0-7,450.0 PRODUCTION;30.0-7,668.0 - Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, March 16, 2015 11:20 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: 3A-06 (PTD 185-222) Date and scope change to sundry 314-112 for tubing patch change out. Attachments: image001.png Chris- As per our conversation regarding the patch replacement on 3A-06 (PTD#185-222) CPAI intends to complete the patch replacement and testing under a date extension and scope change to sundry number 314-112. The original 10-403 was submitted with the intentions to only pull and reset only the upper patch assembly in an attempt to mitigate the slow TxIA communication. Due to the extremely small leak rate CPAI was unable to pin point the exact location of the TxIA communication but due to the history of the upper patch assembly being the failure point it was suspected to be the point of communication. During the replacement process it was discovered that the lower assembly was also not competent and would need to be replaced. The patch replacement and testing process exceeded the 12 month validity of the original 10-403. At the completion of patch replacement and testing the proper paperwork will be submitted for continued injection or further diagnostics. Please let me know if you disagree with this plan or have any questions regarding the change in scope or date extension to sundry number 314-112. Cheers Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. SCANNED MAR 1 8 2015 Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM ConocoPhinips Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 4WELLS TEAM ConocoPhillips 1 �' �\//7,4, '' I hSTATE I a21Kle k1e �e } _ - — --_ 333 1desr Seventh ?.venue P ,. GOVERNOR S}.AN PARNELL Anchorage, Alaska 99501-3572 t ' P � � Main: 907.279.1 433 a . 90/.276.7542 SCANNED Au% 6 6 2014 Dusty Freeborn Problem Well Supervisor q5...—_g„g,. .. I ConocoPhillips Alaska, Inc. ` P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-06 Sundry Number: 314-112 Dear Mr. Freeborn: 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, A /°;e„,/7-,— Cathy P. oerster Chair DATED this ZS day of February, 2014. Encl. STATE OF ALASKA RECEIVED AL�,JKA OIL AND GAS CONSERVATION COMMIS_ A APPLICATION FOR SUNDRY APPROVALS FEB 2 6 2014 20 AAC 25.280 D7�s,�(�212 / 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change App�rgloprr'�9C-Ne Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:TBG patch re-set f' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 185-222 • 3.Address: Stratigraphic r Service r' • 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21443-00. 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P. 3A-06 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025632 - Kuparuk River Field/Kuparuk River Oil Pool * 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7680- 6352 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104' 104' SURFACE 3376 9 5/8 3406' 3179' ! PRODUCTION 7638 7 7668' 6343' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7144-7220,7340-7362,7372-7420,7444-7450• 5939-5998,6090-6106,6114-6150,6169-6174 3.5 L-80 7281 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-3.5"X 2.875"CAMCO"DS"NIPPLE MD=504 TVD=504 ` PACKER-WEATHERFORD ER PACKER MD=6819 TVD=5692' PATCH-SPACER PIPE&SNAP LATCH MD=6822 TVD=5694 PACKER-WEATHERFORD ER PACKER MD=6840 TVD=5708 PACKER-BAKER FHL PACKER W/PBR&6.12'PUP JT MD=6949 TVD=5790 12.Attachments: Description Summary of Proposal (�/ . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Fi' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ rf' GINJ r WAG • Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dusty Freeborn/Jan Byrne Email: N1617@cop.com Printed Name Du Fr Title: Problem Well Supervisor Signature Phone:659-7126 Date 25 Fee, !q Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness R c -Sy-1-‘kt. Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance RBDMSMAY 1 0 2014 Other: �"ref__tG W 1 h- t 5 $t d /1/t / T- f A /.-G ,1 ti i FSC CJ u f/-e.c , ., ./-__,,,. 6i /,3 l d 1,/1j‘,C flvri Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /19 _ 4 0 J APPROVED BY /C� Approved by: ' ' "I�����u✓+"� "'"'.'I' . COMMISSIONER THEICOMMISSION Date: 2 "2 S—` I ) AI.pi VVC�.ygNl d11l�J{IJIVN fVf i :1011111) fI VI 1 !Mg (idle or dNNISub m. p Form 10-403(Revised 10/2+12 U K I (V, NAL �f�� ���''/ Submit Form and Attachments in Duplicate VLA."z/2-7-/i - ,,IL >//y ~/ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 22 January 2014 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 3A-06 (PTD 185-222). The request is for approval to reset the existing upper tubing patch assembly. Please call Jan Byrne or myself at 659- 7126 if you have any questions. Regards, Dusty Freeborn Problem Well Supervisor Name of Recipient Page 2 of 2 02/25/14 ConocoPhillips Alaska,Inc. Kuparuk Well 3A-06 (PTD 185-222) SUNDRY NOTICE 10-403 PATCH REPLACEMENT 02/21/14 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 3A-06 (PTD 185-222) with a replacement tubing patch. On January 1, 2014, the AOGCC was initially notified of suspected TxIA communication. The diagnostic MIT-IA passed but the IA failed a DDT. Due to the slow build up rate the source of IA re-pressurization will be difficult to identify. It is suspected that the leak is from the upper assembly of the patch. The plan is to retrieve the upper assembly of the existing patch and reset a new upper patch assembly. An MIT- IA will be conducted and the well brought back on injection for an extended monitor period to confirm the integrity of the patch. REPAIR PLAN 1. Pull upper assembly of patch over mandrel #1 at 6827' 2. Reset upper assembly of patch. 3. Perform MIT-IA as per AOGCC requirements (0.25 x TVD to packer) 4. Submit 10-404 post-repair. NSK Problem Well Supervisor • KUP 3A-06 1.-- Drifting i[pnpPhjlljps ,;. �awelas ell Attributes Max Angle&MD TD I Wellbore API/UWI Field Name Well Status Incl C) MD(ftKB) Act Btm(MB) Alaska.he. 500292144300 KUPARUK RIVER UNIT__ INJ 43.55 4,600.00 _ 7,680.0 Comment ' H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Conan--3A-06,10A5f10126'28'39AM SSSV:NIPPLE-__ Last WO: 12/12/2008 36.48 10/19/1985 Schematic-Actual _Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: 7,475.0 8/3/2008 Rev Reason:DRILL DATES osborl 10/15/2012 : Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth)TVD)...String Wt...String... String Top Thrd HANGER,29 , 4.?r CONDUCTOR 16 15.062 31.0 104.0 104.0 62.58 H-40 "' Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 1 -,s' SURFACE 95/8 8.765 30.7 3,406.4 3,178.5 36.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 30.0 7,668.0 6,342.5 26.00 J-55 IliTubing Strings Tubing Description String 0... String ID..Top(RKB) Set Depth(f...Set Depth(TAD)... String Wt...String... String Top Thrd I co4Duc70R. TUBING 3 1/2 2.992 28.6 6,967.3 5,804.0 9.30 L-80 EUE 3,-,a Completion Details NIPPLE,504 /116 Top Depth (ND) Top Incl Nomi... ITop(ItKB( (RKB) C) Item Description Comment ID(in) 28.6 28.6 0.26 HANGER FMC Gen 5 Tubing Hanger wlpup 2.992 504.3 504.3 0.25 NIPPLE 3.5"x 2.875"Camco"DS"Nipple 2.875 SURFACE. 31-3,406- - 6,877.4 5,735.9 40.74 GAUGE Weatherford Gauge Mandrel 2.992 And Wash,31 _ Y 6,955.0 5,794.7 40.67 SEAL ASSY GBH-22 Seal Assembly 8 Locator w/2.00'space out 3.000 ��`7S Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PACKER.6,819 -' -` TUBING 1.5"for 1 15/16 1.625 6,919.6 7,139.6 5,935.6 2.90 L-80 1J 10 rnd Intensifier Pump PATCH. LIF y(4 VII N Completion' Details Top Depth j; )TVD) Top Incl Noml... PACKER,Q840 -' 33�V Top(RKB) (RKB) (°) Item Description Comment ID(In) 6,919.6 5,767.8 40.70 XO Reducing X-Over 3.5"x 1.66"Stick out pin 1.660 1 6,920.5 5,768.5 40.70 XO Enlarging X-over 1.66"x 1.9"Box x Box 1.900 7,132.2 5,930.0 39.77 LOCATOR No-Go LOCATOR 1.820 ISO SLEEVE, ,, 7,133.8 5,931.3 39.77 SEAL ASSY SEAL ASSEMBLY 1.820 6,877 •" GAUGE.6.877 Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd INTENSIFIER ___ir Stack Packer 31/2 2.992 6,949.1 7,066.0 I 5,879.1 9.30 L-80 EUE TUBING.6.894 Jtaisr" bompletion Details II Top Depth' (ND) Top Incl Nomi... Top(RKB) (RKB) 11 Item Description Comment ID(In) 6,949.1 5,790.2 40.68 PACKER Baker FHL Packer wIPBR 8 6.12'Pup jt 3.000 7,012.3 5,837.6 39.59 NIPPLE Camco"DS"Nipple 2.812 E.) i--i 7,051.3 5,867.7 39.65 LOCATOR Locator w2'space out 3.000 ` =,., ‘)14' 7,053.7 5,869.6 39.65 SEAL ASSY 80-40 GBH-22 Seal Assembly WO/Seals 3.000 SEAL ASSY, Al, 6955 �V` Tubing Description String 0... String ID...Top(RKB) Set Depth)f...Set Depth(ND)...String Wt. String... String Top Thrd PACKER,6,949 , - -41 iter- V\ l TUBING Original 31/2 2.992 7,042.1 7,281.4 6,044.5 9.30 L-80 8RD MOD &ompletion Details - Top Depth (TVD) Top Incl Nomi... NIPPLE,7,012 Top(ftKB) (RKB) (°) Item Description Comment ID(in) (.,NPI Top 5,860.7 39.63 PACKER BAKER 83-40 FB-1 PACKER 4.000 PACKER,7.042 SN 7,045.4 5,863.2 39.64 SBE BAKER SEAL BORE EXTENSION 4.000 SSE,7045 1; /� 7,138 .6 5,934.9 39.78 BLAST JOINT 2.992 LocAi 1- 7,238.4 6,011.6 40.29 NIPPLE AVA BPL PORTED NIPPLE w/ISO SLEEVE ID 2.31" 2.697 II ,,NN 7,253.0 6,022.8 40.26 LOCATOR BAKER 80-32 LOCATOR SUB 2.440 SEALISEAL ASSY. ; 7,254.0 6,023.6 40.26 ASSY BAKER 80-32 SEAL ASSEMLY 2.440 7,054 • 7,255.0 6,024.4 40.25 PACKER BAKER MODEL'D'PERMANENT PACKER w/5'SEAL BORE 3.250 INJECTION, 7,273.7 6,038.6 40.21 NIPPLE CAMCO'D'2.25"NO GO NIPPLE 2.250 7.093MI a 11 a Wv 7,280.7 6,043.9 40.19ISOS I BAKER SHEAR OUT 12.441 PACKER.7.129 - ` '1.p� Biter In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 N 1V- Top Depth (I A\ (ND) Top Incl LOCATOR, !ii ^ Top(RKB) (ftKB) (°l Description Comment Run Date 'ID(In) 7'1326,819.0 5,691.7 40.79 PACKER WEATHERFORD ER PACKER 9/17/2012 1.750 SEAL ASSY. �� 7'134 'MD 6,821.9 5,693.8 40.79 PATCH SPACER PIPE 8 SNAP LATCH 9/17/2012 1.992 ■i�fit" �14'r/� 6,840.0 5,707.5 40.77 PACKER WEATHERFORD ER PACKER 6/18/2012 1.750 (PERF, . "r K 6,877.4 5,735.9 40.74 ISO SLEEVE PORTED ISO SLEEVE(OAL=101") 6/16/2012 7,144-7,220 L ` at 7,129.0 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3.5"TBG 12/12/2008 2.250 ISO SLEEVE. 11117,238.3 6,011.6 40.29 ISO SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 7,238 NIPPLE.7,238 gis 1.1 Perforations&Slots Shot MI Top(ND) Btm(TVD) Dens LOCATOR._ '-"_ Top(RKB)Btm(RKB) (RKB) (ftKB) Zone Date Ise... Type Comment 7.253 7,144.0 7,220.0 5,939.1 5,997.7 C-1,C-3,C-4, 11/22/1985 12.0 IPERF 120 deg phase;5"Csg Gun SEAL ASSY, _ 3A-06 PACKER.7.255 s{I 7,340.0 7,362.0 6,089.5 6,1062 A-3,3A-06 1122/1985 4.0 IPERF 90 deg.phase;4"Csg Gun In 7,341.0 7,361.0 6,090.3 6,105.5 A-3,3A-06 6/14/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG III 7,372.0 7,420.0 6,113.8 6,150.3 A-2,3A-06 6/14/2008 6.0 RPERF 2 1/8"PEJ,+/-45 DEG NIPPLE,7.274 -- le- 7,372.0 7,420.0 6,113.8 6,150.3 A-2,3A-06 11/22/1985 4.0 IPERF 90 deg.phase;4"Csg Gun III 7,444.0 7,450.0 6,168.9 6,173.6 A-1,3A-06 6/11/2008 6.0 RPERF 21/8"PEJ,+/-45 DEG SOS,7,281 EY 7,444.0 7,450.0 6,168.9 6,173.6 A-1,3A-06 11/22/1985 4.0 IPERF 90 deg.phase;4"Csg Gun IPERF, 7 340.7 36RF2 RPE 7341-7.361 1 RPERF, r,,, 7372 � ...1'el Details 7,37IPER PER 0 Top Depth Top --- ---� --- Port RPERF, III (TVD) Incl OD Valve Latch Sire TRO Run 7.444-7.450 Stn Top(RKB) OMB) 1°) Make Model (in) Sery Type Tile (In) (Psi) Run Date Com... IPERF, 1 6,827.1 5,697.8 40.79 CAMCO MMG 1 12 INJ PATCH RK 0.000 0.0 8/31/2010 7,444-7,450 PRODUCTION, 2 7,093.0 5,899.9 39.71 CAMCO MMM 1 12 INJ DPHFCV RKP 0.000 0.0 12/2/2008 30.7,668 ' il ' TD.7.680 KUP 3A-06 ConocoPhillips 0-8' Alaska.I., cnrnaovrMPps "" KB-Grd(ft) Rig Release Date ... Well Coe .-3A-0s 1015(201262839 AM 36.48 10/19/1985 Stimulations&Treatments v r Bottom._- - --- -- - — — HANGER,29 Min Top Max Btm Top Depth Depth D P I (RKB (R B) (B) I K) Type Date Comment 31.0 6,845.0 31.0 5,711.3 Acid Wash 3/152009 Tubing Acid Wash-60 bbls 7.5%HCL from 6845 , I CTMD to surface,allowing acid to soak 3 hrs in TBG before displacing.Displaced TBG w/scale blaster W/45 bbls SSW for every 1000'TBG CONDUCTOR. at ___ iNotes:General&Safety 31-104Or End Date Annotation 12/25/2008 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE.504 l SURFACE. 31-3,406_ - - Acid Wash,31 ag PACKER,6,819 PATCH,6,822 OAS LIFT, 9 6,827 -f 111 PACKER,6,840 --- ISO SLEEVE, - - GAUGE,6,877 ' ..n.:' INTENSIFIER I TUBING,6,894 '1 'I SEAL ASSY, A Ms 6,955 PACKER.6.949 . min Am as NIPPLE.7.012 PACKER,7,042 --_ SSE.7,045- —,$ /. LOCATOR, ''11 1 7,051 L .f 1; I SEAL ASSY, .1 ' 7,054 INJECTION, :1 7.093 PACKER.7,129 LOCATOR, .: 7,132 SEAL ASSY, 11 7,134ii IPERF, @""" l { 7,144-7,220 @, -_ ISO SLEEVE, 7.238 NIPPLE.7,238 LOCATOR,_. IP' SEAL ASSY, 7,254 PACKER,7,255 _ Ilk NIPPLE,7,274 i•_ I SOS,7,281 - r. IPERF, 7,340-7,362 RPERF, "(l Iain 7,341-7,361 RPERF, RI 7,372-7,420\ IPERF, ( ___. 7,372-7,420 RPERF, 7,4447,450 IPERF, 7,444-7,450 PRODUCTION, 30-7,66 TO,7.680 • • RECEIVED ConocoPhil NOV 062012 Alaska AOGCC P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 November 1, 2012 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission AN A,— ` f 333 West 7 Avenue, Suite 100 r.t�t Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3A-06 (PTD 185 -222) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659 -7224 if you have any questions. (� M P Sincer- y, elly Lyon ConocoPhillips Problem Wells Supervisor Enclosures STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell p' Plug Perforations r Perforate r Other r° Set tubing patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development r Exploratory r _ 185 -222 3. Address: 6 . API Number: rr--�� Stratigraphic r Service 50- 029 - 21443 -00 "°�D� P. 0. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ..„ ADL 256 ALK 2565 3A -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7680 feet Plugs (measured) None true vertical 6352 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 504, 6949 true vertical 0 feet (true vertical) 504, 5790 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 SURFACE 3376 12 3406 3179 PRODUCTION 7638 7 7668 6343 RECEIVED NOV 06201Z AOGCC Perforation depth: Measured depth: 7144 -7220, 7340 -7362, 7372 -7420, 7444 -7450 True Vertical Depth: 5939 - 5998, 6090 - 6106, 6114 - 6150, 6169 - 6174 Tubing (size, grade, MD, and TVD) 3.5", L-80, 7252' MD, 6044 TVD 9( 9 , Packers & SSSV (type, MD, and TVD) NIPPLE - 3.5" X 2.875" CAMCO "DS" NIPPLE @ 504 MD and 504 TVD PACKER - WEATHERFORD ER PACKER @ 6819 MD and 5692 TVD TL (k PATCH - SPACER PIPE & SNAP LATCH @ 6822 MD and 5694 TVD PACKER - WEATHERFORD ER PACKER @ 6840 MD and 5708 TVD ,PACKER - BAKER FHL PACKER W /PBR & 6.12' PUP JT @ 6949 MD and 5790 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 n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic r 1 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r wiN WA GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -440 Contact Kelly Lyons / Brent Rogers Email n1617 @conocophillips.com Printed Name II L ons Title Problem Wells Supervisor Signature Phone: 659 -7224 Date 11/1/12 Form 10 -404 Revised 10/fi .iii t)--) .,� 7 7, Pa-- Submit Original Only • 3A -06 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/18/12ISET WEATHERFORD 2.74" LOWER ER PACKER AT 6841'. 09 /17 /12ISET 21.5' ER UPPER PATCH ASS'Y @ 6820' RKB. MITIA 3000 PSI, PASSED. 10 /11 /12IReturned to injection 10/17/121 Pre- SW MITIA (Passed) to 3010 PSI. 10 /21 /12IState Witnessed (John Crisp) MITIA (Passed) @ 2500 psi. Summary ISet 21' Weatherford retrievable patch. Witnessed MIT passed following patch set. STATE OF ALASKA ALOA OIL AND GAS CONSERVATION COIOSION ' c REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair well r Plug Frrrforations r Ferforate r Other r Install Patch Alter Casing r Pull Tubing ( Stimulate - Frac r Waiver f Time Extension r Change Approved Program ®" Operat. Shutdow n E Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185 - 222 3. Address: 6. API Number: Stratigraphic r Service p P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 21443 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25632 ' 3A -06 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 7680 feet Plugs (measured) None true vertical 6352 feet Junk (measured) None Effective Depth measured 7576 feet Packer (measured) 6820, 6841, 6949, 7042, 7129, 7255 true vertical 6270 feet (true vertical) 5692, 5708, 5790, 5861, 5928, 6024 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 104 104 SURFACE 3376 9.625 3406 3179 PRODUCTION 7638 7 7668 6343 RECEIVED OCT 16 2ij11 Perforation depth: Measured depth: 7144 -7220, 7340 -7362, 7372 -7420, 7444 -7450 True Vertical Depth: 5939 -5998, 6090 -6106, 6114 -6150, 6169 - 6174 4,0000 p JAN 2 8 20 SCANNED Tubin (size, grade, MD, and TVD) 3.5, L -80, 6967 MD, 5804 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6820 MD and 5692 TVD PACKER - WEATHERFORD ER PACKER @ 6841 MD and 5708 TVD PACKER - BAKER FHL PACKER W /PBR & 6.12' PUP JT @ 6949 MD and 5790 TVD PACKER - BAKER FB -1 PACKER @ 7042 MD and 5861 TVD PACKER - BAKER KB PACKER @ 7129 MD and 5928 TVD PACKER - MODEL D PERMANENT PACKER @ 7255 MD and 6024 TVD SSSV - CAMCO 'DS' NIPPLE @ 504 MD and 504 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation 3000 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic r 16. Well Status after work: Oil r Gas '' WDSPL r Daily Report of Well Operations XXX GSTOR WIND ji WAG r GINJ r SUSP 1 SPLUG "" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -440 Contact Tyson Wiese 263 -4250 Email Tyson .M.Wiese @conocophillips.com Printed Name T son Wiese Title Wells Engineer Signature Phone: 263 -4250 Date (b.• ) S —1.raye.‘ Form 10-4 4 Revised 10/20 I8DMS OCT 16 nu .., ) /0 /b /z„. Submit Original Only /0/2" • • 3A -06 Well Work Summary Patch installed 9/17/2012 due to leak in dummy valve at 6827' MD. Leak Detection Log showed bottom of mandrel leaking. �II 3A -06 Well Work Summary DATE SUMMARY • • 6/18/12 SET WEATHERFORD 2.74" LOWER ER PACKER AT 6841'. LOG CORRELATED TO TUBING DETAIL RECORD DATED 12 DEC 2008. 9/17/12 SET 21.5' ER UPPER PATCH ASS'Y @ 6820' RKB. MITIA 3000 PSI, PASSED. COMPLETE. KUP • 3A -06 " • Conoc 0°- Well Attributes Max Angle & MD TD Inc Wellbore APIIUWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) Alaska. 500292144300 KUPARUK RIVER UNIT INJ 43.55 4,600.00 7,680.0 '" Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 12/12/2008 36.48 10/19/1985 Well Confil. - 3A -06 9/18/2012 9'.17.59 AM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: 7,475.0 8/3/2008 Rev Reason: SET PATCH ASSY & ISO SLEEVE ninam 9/18/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 29 j ) . , CONDUCTOR 16 15.062 30.0 104.0 104.0 62.58 H gl ' ;" P Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I SURFACE 95/8 8.765 30.7 3,406.4 3,178.5 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 30.0 7,668.0 6,342.5 26.00 J -55 Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ...Top (RKB) Set Depth (f... Set Depth (TVD) ... ng Wt... String... String Top Thrd 30 TUBING I 31/2 I 2.992 I 28.6 I 6,967.3 I 5,804.0 !String L -80 I EUE NIPPLE, 504 K "»ompletion Details Top Depth (TVD) Top Intl Nomi... Top (ftKB) (RKB) ( °) item Description Comment ID (In) 28.6 28.6 0.26 HANGER FMC Gen 5 Tubing Hanger w /pup 2.992 SURFACE, .� 504.3 504.3 0.25 NIPPLE 3.5" x 2.875" Camco "DS" Nipple 2.875 31 3.108 Acid Wash. 30 6,877.4 5,735.9 40.74 GAUGE Weatherford Gauge Mandrel 2.992 6,955.0 5,794.7 40.67 SEAL ASSY GBH -22 Seal Assembly & Locator w2.00' space out 3.000 PACKER. 6,819 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd PATCH, 8,822 It i 1 TUBING 1.5 "for Intensifier Pump 1 15/16 1.625 6,919.6 7,139.6 5,935.6 2.90 L -80 1J 10 rnd GAS LIFT, 7 6,827 a 1 Completion Details 11 1 Top Depth (TVD) Top Intl Noml... PACKER, 8,840 t- "\ Top (RKB) ("B) ( °) Rem Description Comment ID (In) V ._ 6,919.6 5,767.8 40.70 XO Reducing X-Over 3.5" x 1.66" Stick out pin 1.660 6,920.5 5,768.5 40.70 XO Enlarging X-over 1.66" x 1.9" Box x Box 1.900 ISO SLEEVE, 7,132.2 5,930.0 39.77 LOCATOR No-G0 LOCATOR T 1.820 6,877 Tu 7,133.8 bing Deacri 5,931.3 ption 39.77 String 0. SEAL .. AS ing SY 10 ... SEAL ASSEMBLY 1.820 GAUGE, 6,877 op (RKB) Set Depth (f... Set Depth (TVD) ... . .. String Top Thrd INTENSIFIER Stack Packer l 3 1/2 I Str 2.992 I 6,949.1 7,066.0 I 5,879.1 I String Wt.. 9.30 I String . L - 80 I EUE TUBING, 6,894 Completion Details Top Depth (TVD) Top Intl Nomn.. Top (RKB) (RKB) ( °) Rem Description Comment ID (In) . 6,949.1 5,790.2 40.68 PACKER Baker FHL Packer w/PBR & 6.17 Pup jt 3.000 7,012.3 5,837.6 39.59 NIPPLE Camco "DS" Nipple 2.812 a l 7,051.3 5,867.7 39.65 LOCATOR Locator w/2 space out 3.000 SEAL ASSY, 7,053.7 5,869.6 39.65 SEAL ASSY 80-40 GBH -22 Seal Assembly WO/Seals 3.000 6,955 \ _ U Tubing Description String 0... String ID ... Top (ftKB) Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PACKER, 6,949 ' TUBING Original I 31/2 I 2 I 7042 I Set 7281.4 I 6 I 9 l L -80 I 8RD MOD 1 ' Completion Details Top Depth NIPPLE. 7,012 t (TVD) Top In OMB) Top (ftKB) (RKB) ( °) Rem Description Comment ID (In) ' I_, 7,042.1 5,860.7 39.63 PACKER BAKER 83-40 FB-1 PACKER 4.000 PACKER, 7,042 - - _ 7,045.4 5,863.2 39.64 SBE BAKER SEAL BORE EXTENSION 4.000 LO jI ' 7,138.6 5,934.9 39.78 BLAST JOINT 2.992 7,051 1 • � '� i 7,238.4 6,011.6 40.29 NIPPLE AVA BPL PORTED NIPPLE w/ISO SLEEVE ID 2.31" 2.697 I 1 li 7,253.0 6,022.8 40.26 LOCATOR BAKER 80-32 LOCATOR SUB 2.440 SEAL ASSY, !I � 7,254.0 6,023.6 40.26 SEAL ASSY BAKER 80-32 SEAL ASSEMLY 2.440 7,054 I 1 7,255.0 6,024.4 40.25 PACKER BAKER MODEL 'D' PERMANENT PACKER w /5' SEAL BORE 3.250 INJECTION. 1 1;. 7,273.7 6,038.6 40.21 NIPPLE CAMCO 'D' 2.25" NO GO NIPPLE 2.250 7,093 7,280.7 . 6,043.9 40.19 SOS BAKER SHEAR OUT 2441 PACKER,7,129 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) c f NM Top Depth LOCATOR. Top Inc! 7,132 Top (RKB) (RKB) ( °) Description Comment Run Date ID (In) SEAL ASSY, al 6,819 5,691.7 40.79 PACKER WEATHERFORD ER PACKER 9/17/2012 1.750 7,134 'R lir 6,822 5,693.8 40.79 PATCH SPACER PIPE & SNAP LATCH 9/17/2012 1.992 '!" 6,840 5,707.5 40.77 PACKER WEATHERFORD ER PACKER 6/18/2012 1.750 PERF, 7,14x7,220 - 1 1 1 6,877 5,735.9 40.74 ISO SLEEVE PORTED ISO SLEEVE (OAL=101") 6/16/2012 7,129 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3.5" TBG 12/12/2008 2.250 ISO SLEEVE, 7,238 6,011.6 40.29 ISO SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 7.238 NIPPLE. 7.238 a Perforations & Slots Shot 1 Top (TVD) Bat (TVD) Dens LOCATOR, Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date ( Type Comment 7,253 7,144 7,220 5,939.1 5,997.7 C 1,C 3,C 11/22/1985 12.0 IPERF 120 deg phase; 5" Csg Gun SEAL ASSY, _. 7.254 3A PACKER, 7,255 - 7,340 7,362 6,089.5 6,106.2 A -3, 3A -06 11/22/1985 4.0 IPERF 90 deg. phase; 4" Csg Gun Mandrel Details 1 Top Depth Top Port NIPPLE. 7274 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ft613) (ftKB) 1 Make Model (!n) Sere Type Type 1!n) (psi) Run Date Corn... 1 6,827.1 5,697.8 40.79 CAMCO MMG 1 12 INJ PATCH RK 0.000 0.0 8/31/2010 SOS. 7.281 - ''''. 2 7,093.0 5,899.9 39.71 CAMCO MMM 1 12 INJ DPHFCV RKP 0.000 0.0 12/2/2008 IPERF, 7.340.7.362 RPERF, 7,341 -7,381 - RPERF, 7,372 -7,420 J PERF, 7,372-7,420 RPERF. RPERF, 7.444-7.450 IPERF, PERF, 7.444-7,450 PRODUCTION, D30 30-7.868 rD. 7,ee0 KUP • 3A -06 Lit ConocoPhillips Alaska, Inc ccex,cc* 14lp KB-Grd (ft) Rig Release Date 36.48 10/19/1985 Well Con80. - 3A -06 9/182012 9.17.59 AM Schematic - Actual Perforations & Slots Shot -a te ' HANGER, 29 Top (TVD) Btm (TVD) Dens Top (RKB) Btm (RKB) (CKB) (RKB) Zone Date (oh... Type Comment 7,341 7,361 6,090.3 6,105.5 A -3, 3A -06 6/14/2008 6.0 RPERF 2 1/8" PEJ, +/ -45 DEG 7,372 7,420 6,113.8 6,150.3 A -2, 3A-06 6/14/2008 6.0 RPERF 2 1/8" PEJ, +/_ 45 DEG 7,372 7,420 6,113.8 6,150.3 A -2, 3A-06 11/22/1985 4.0 IPERF 90 deg. phase; 4" Csg Gun coNDU 7,444 7,450 6,168.9 6,173.6 A -1, 3A-06 6/11/2008 6.0 RPERF 2 1/8" PEJ, +1- 45 DEG 3 oa oa 7,444 7,450 6,168.9 6,173.6 A -1, 3A -06 11/22/1985 4.0 IPERF 90 deg. phase; 4" Csg Gun NIPPLE, 504 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (MB) (RKB) (RKB) (RKB) Type Date Comment SURFACE. 30.0 6,845.0 30.0 5,711.3 Add Wash 3/15/2009 Tubing Acid Wash - 60 bbls 7.5% HCL from 6845 31 3.406` - - Acid wash, 30 \ CTMD to surface, allowing acid to soak 3 hrs in TBG before displacing. Displaced TBG w /scale blaster W/45 bbls SSW for every 1000' TBG PACKER, 8,819 Notes: General & Safety PATCH, 6,822. 11 End Date Annotation GAS LIFT, ♦ 12/25/2008 NOTE: View Schematic w/ Alaska Schematic9.0 6,827 1 PACKER. 6.840 1 1 ISO SLEEVE. 1 s• 6.877 GAUGE, 6,877 _.) INTENSIFIER - - -- TUBING, 6,894 - 1 C ■ I .1e SEAL ASSY. , I I 6,955 PACKER, 6,949 1 .1 NIPPLE. 7.012 a PACKER. 7,042 _ 066.7,045- LOCATOR, 1 _[ �'. 7,051 9 1 11 LI 1 .I SEAL ASSY, I ; 7,054 INJECTION, 7,093 PACKER, 7,129 LOCATOR, 7,132 SEAL ASSY. 7,134 i ' E PERF, 7.144 -7,220 , MB ISO SLEEVE, 1.. 7,238 NIPPLE, 7,238 1 1 LOCATOR, 7,253 SEAL ASSY, 7,254 PACKER, 7,255 1 NIPPLE. 7.274 1 i 1 000.7,281 IPERF. 7,340 -7.362 RPERF, 7,341 -7,381 RPERF. 7,372-7,420 IPERF. \ ■ 7,372-7,420 RPERF, RPE4F, 7,444-7.450 IPERF, PERF, . 7.444-7,450 1 PRODUCTION. N. 30-7.668 " TD. 7.880 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 7, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3A -06 Run Date: 1/6/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21443 -00 5 FEB 0120U PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 .0060 Fax: 907 - 273 -3535 klinton.wood @halliburton.com { Date: „ , , S J . Signed: 0-, 120 us. N " 331011 ` • gg SEAN PARNELL, GOVERNOR I ALASKA OIL AATD GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 _ PHONE (907) 279 -1433 FAX (907) 276 -7542 Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. A EV 0E C 7 2UIU P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A -06 Sundry Number: 310 -440 Dear Mr. Rogers: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ? 3 day of December, 2010. Encl. ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED DEC 2 2 2010 December 21, 2010 Alaska Gil & Gas Cons. Commission Anchorage Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount, Enclosed please find the 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 3A -06 (PTD 185 -222). The request is for approval to patch a tubing r leak above the top packer. Please call Martin Walters or myself at 659 -7224 or M J Loveland / Perry Klein at 659- 7043 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments STATE OF ALASKA C& ALASAL AND GAS CONSERVATION COMMISSIO a ho APPLICATION FOR SUNDRY APPROVALS � 20 AAC 25.280 1. Type of Request: Abandon Flug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend Rug Perforations (— Perforate r" Pull Tubing �° Time Extension (° Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing Other:Set tubing patch rt 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185 - 222 3. Address: Stratgraphic r Service fv 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21443 -00• 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r7o 3A -06 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25632 ALK 2565 i Kuparuk River Field/ Kuparuk River Oil Pool 11. PRESENT WELL C ONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): 7680 1 6352 Casing Length Size MD TVD U tB rs ollapse CONDUCTOR 74 16 104' 104' Rd VII U SURFACE 3376 9.625 3406' 3179' 8S on " om mission And nag PRODUCTION 7638 7 7668' 6343' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7144 - 7220, 7340 - 7362, 7372 - 7420, 7444 - 7450 5939 3.5" L - 80 7 252' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) NIPPLE - 3.5" X 2.875" CAMCO "DS" NIPPLE MD= 504 TVD= 504 PACKER - BAKER FHL PACKER W /PBR & 6.12' PUP JT MD= 6949 TVD= 5790 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12128/2010 Oil r Gas WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG (- 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers /Martin Walters Printed Name Brent Rogers Title: Problem Wells Supervisor Signature Phone: 659 -7224 Date 12/21/10 l c Co mmission Use On Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ` Plug Integrity r BOP Test r Mechanical Integrity Test � Location Clearance r Other. �vc���L� 0�` Q 5;11, Q Y-^��� SL's C� `LCD w ( ��- a-�e v's ` � V l �� wLC3. c>� CL, �\ 1 ® rs ►c+ c,_��o v� c� �co t�� �� Subsequent Form Required: APPROVED BY f n , 2-�) 10 Approved by' _ COMMISSIONER THE COMMISSION Date: I B S [ 1 Form 10 -403 Reviseti'OWS DEC 2 3 R I G I N /�l Submit I' D licate ��� /� • ConocoPhillips Alaska, Inc. i Kuparuk Well 3A -06 (PTD 185 -222) SUNDRY NOTICE 10 -403 TUBING REPAIR 12/21/10 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 3A -06 (PTD 185 -222) with a tubing patch. On August 20, 2010, the AOGCC was notified of suspected TxIA communication. Subsequent diagnostics have identified a tubing to IA leak at gaslift mandrel #1 at 6,827' MD. The plan is to set a retrievable patch over the mandrel, conduct an MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Set 3.5" Weatherford retrievable patch over gaslift mandrel at 6,827'. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10 -404 post- repair. NSK Problem Well Supervisor WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 3, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3A -06 Run Date: 11/1/2010 The technical data listed below is being submitted herewith. Please address any problems or j concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029- 21443 -00 .NNW NOV 2 201[? PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 - 3527° Fax: 907 - 273 -3535 klinton.wodd(( lliburtoil:coin �o J Date: Signed: • • WELL LOG TRANSMITTAL PROACTIVE DAAGNmdc SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE: Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 21 -0ct -10 3A -06 1 Report/ EDE 50 -029- 21443 -00 2) NOV (z £ 5 - C 9 C9 ')L c) 3-- Signed: Date . Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL: 2dsanchoragear*.:emorm!eg.com WESSITE : .APA9tv.:remol log. cow. C.\Documents and Settings\Diane Williams \Desktop \Transmit_Conoco.dom ' Memory Multi - Finger Caliper S Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3A -06 Log Date: October 21, 2010 Field: Kuparuk Log No.: HAL 7680 State: Alaska Run No.: 2 API No.: 50- 029 - 21443 -00 Pipet Desc.: 3.5 inch 9.3 lb. L -80 EUE Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 6,870 Ft. (MD) ' Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: ' This caliper data is tied into the GLM @ 6,827 ft. (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage prior ' to running a patch for leak detected @ 6,827 ft. The caliper recordings indicate the 3.5 inch tubing is in good to fair condition, with a maximum recorded wall penetrations of 25% (6,059 ft), and 22% (4,854 ft). No other significant wall penetrations, areas of cross - sectional wall loss or 1. D. restrictions are recorded. ' This is the second PDS caliper log of this well, however a comparison of the 3.5 inch tubing indicates; the previous log (October 23, 2008) was prior to the WO (12/12/2008). This is the first PDS caliper of this 3.5 inch tubing, therefore a comparison plot in not included in this report. ' This summary report is interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: ' Corrosion ( 25 %) it. 190 @ 6,059 Ft. (MD) Corrosion ( 22 %) it. 151 @ 4,854 Ft. (MD) No other significant wall penetrations (> 20 %) are recorded. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross- sectional wall loss (> 11 %) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: ' No significant I.D. restrictions are recorded. Field Engineer: E Regnier Analyst: J. Thompson Witness: J. Condio ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E-mail: PDSCcbmemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 ' V l is S PDS Multifinger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3A -06 Date : October 21, 2010 ' Description : Detail of Caliper Recordings Across Potential Patch Interval Comments Depth Max. I.D. (ins.) 3 -D Loo Image Map j 1ft:170ft ' 2 5 3.5 0 90° 180 270° 0 °1 Min. I.D. (ins.) 2.5 3.5 Nominal I.D. (ins.) ...........................: 2.5 3.5 6790 I 6800 — -- A 213 ' 6810 ' 6820 - Pup A. 231.1 it C;LM (Latch 1 @ 6830 7:00) Pup A 213.3 6840 6850 - I A 214 ' Nominal I.D. (ins.) 2.5 3.5 Min. I.D. (ins.) 2.5 3.5 Comments Depth Max. I.D. (ins.) 3-D Log Image Map 1 ft: 170ft 2.5 3.5 0° 0 90 180° 270° 0° Correlation of Recorded Damage to Borehole Profile ® Pipe 1 3.5 in (52.0'- 6845.6') Well: 3A -06 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Country: USA Survey Date: October 21, 2010 ■ Approx. Tool Deviation . Approx. Borehole Profile 25 842 'i 50 1631 75 2 419 ' 100 3212 v E z s c 125 4004 Q- o a, 150 4793 I I ' 175 5583 200 6375 GLM 2 ' 214 6846 i 0 50 100 i j Damage Profile (% wall) / Tool Deviation (degrees) ' Bottom of Survey = 214 PDS Report Overview clils Body Region Analysis ' Well: 3A -06 Survey Date: October 21, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 ' Country: USA No. of Fingers: 24 Analyst: J. Thompson Tubing: Norn.OD Weight Grade & Thread Norn.ID Nom. Upset Upper len. Lower len. 3.5 in 9.3 ppf L -80 EUE 2.992 in 3.5 in 6.0 in 6.0 in 1 Penetration and Metal Loss (% wall) Damage Profile (% wall) ' IllIllIll penetration body metal loss body M penetration body metal loss body 0 50 100 250 0 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 48 1% 10% 20% 40% 85% 85% Number of joints analysed total = 219 pene. 0 93 124 2 0 0 loss 7 210 2 0 0 0 98 Damage Configuration ( body) � 60 ' 40 148 ' 20 0 isolated general line ring hole / poss 198 pitting corrosion corrosion corrosion ible hole GLM 1 Number of joints damaged total = 75 ' 58 17 0 0 0 Bottom of Survey = 214 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE Well: 3A -06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 21, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upsel Body % Loss I.D. Comments ( % wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 52 0 0.02 7 6 2.93 PUP 1.1 84 0 0.02 8 0 2.92 PUP 1.2 92 0 0.02 9 6 2.94 PUP 1.3 102 0.06 0.02 8 10 2.94 PUP 2 112 0 0.03 11 4 2.93 3 144 ( ) 0.02 8 5 2.93 4 176 0 0.03 13 9 2.93 Shallow pitting. 5 208 0 0.03 11 9 2.95 6 239 0 0.04 14 1 9 2.95 1 Shallow 6tting. Lt. De osits. 7 271 0 0.02 9 4 2.95 8 302 0 0.03 10 5 2.93 9 334 0 0.03 11 9 2.95 10 366 0 0.02 9 6 2.91 11 397 0 0.02 8 6 2.95 12 429 0 0.03 13 6 2.93 Shallow pitting. 13 460 0 0.03 11 1 5 2.95 14 492 0 0.04 14 7 2.95 Shallow corrosion. 14.1 523 0 0 0 0 2.88 Camco DS Ni le 15 525 0 0.04 14 10 2.95 Shallow Pitting. 16 557 0 0.03 11 4 2.93 17 589 0 0.02 7 6 2.94 18 620 0 0.03 10 6 2.94 19 651 t ) 0.02 9 1 6 2.95 20 683 0 0.02 7 5 2.95 21 715 0 0.02 8 5 2.95 22 1 746 0 0.04 14 9 2.91 Shallow pitting. ' 23 778 0 0.02 8 9 2.96 24 810 0 0.03 10 6 2.94 25 842 0 0.02 7 5 2.94 26 874 0 0.03 11 12 2.94 Lt. Deposits. 1 27 905 0 0.03 12 4 2.94 28 937 0 0.02 9 5 2.93 29 1 969 0 0.03 13 6 2.94 Shallow pitting. 30 1001 U 0.02 9 9 2.96 ' 31 1033 0 0.03 12 1 4 2.92 32 1064 U 0.03 13 7 2.95 Shallow pitting. 33 1096 0 0.03 13 7 2.93 Shallow pitting. 34 1128 0 0.03 12 5 2.93 35 1160 0 0.03 13 9 2.97 Shallow 6tting. 36 1192 0.07 0.03 13 8 2.95 Shallow pitting. 37 1222 0 0.02 7 1 4 2.94 38 1254 0 0.03 13 2 2.93 Shallow pitting. 39 1284 0 0.01 6 8 2.95 40 1315 0 0.03 11 7 2.92 41 1347 0 0.03 11 6 2.94 42 1378 0 0.02 8 9 2.96 43 1410 0 0.02 9 6 2.93 44 1 1442 0 0.03 11 1 2 2.94 45 1474 0 0.02 1 9 9 2.96 46 1505 0 1 0.03 1 12 5 2.95 Penetration Body ' Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE Well: 3A -06 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 21, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 47 1537 0 0.03 10 8 2.94 48 1569 0 0.03 12 6 2.92 Tonp Mash. 49 1599 0 0.02 7 5 2.92 50 1631 0 0.02 9 9 2.94 51 1663 0 0.03 13 2 2.95 Shallow pitting. 52 1695 0 0.03 11 5 2.93 53 1726 0 0.02 7 4 2.93 54 1757 0 0.03 13 9 2.95 Shallow pitting. 55 1789 0 0.02 9 7 2.94 ' 56 1819 0 0.03 11 5 2.91 57 1851 0 0.03 13 9 2.96 Shallow corrosion. 58 1883 0 0.02 9 9 2.93 59 1915 0 0.03 13 5 2.93 Shallow pitting. 60 1946 0 0.03 13 9 2.94 Shallow Pitting. 61 1978 0 0.02 9 6 2.94 62 2008 0 0.02 9 8 2.95 63 2040 0 0.03 12 8 2.95 64 2072 0 0.02 7 4 2.91 65 2103 0 0.03 13 8 2.92 Shallow corrosion. 66 1 2135 U 1 0.02 9 9 2.92 67 2167 O 0.03 11 5 2.94 68 2198 0 0.03 13 8 2.93 Shallow pitting. 69 2229 0 0.03 10 4 2.92 70 2261 0 0.03 10 1 4 2.94 71 2293 U 0.04 15 9 2.95 Shallow pitting. 72 2325 0 0.02 9 5 2.93 ' 73 1 2356 0 1 0.03 11 5 2.95 74 2387 0 0.04 16 10 2.93 Shallow pitting. 75 2419 U 0.03 13 4 2.94 Shallow corrosion. 76 2450 0 0.03 10 6 2.91 77 2482 0 0.02 8 1 5 2.93 78 2514 0 0.02 7 4 2.91 79 2546 0 0.03 11 6 2.91 80 1 2578 0 1 0.03 12 6 2.93 ' 81 2610 0 0.03 13 5 2.92 Shallow corrosion. 82 2642 0 0.03 10 7 2.91 83 2673 0 0.04 17 7 2.95 Shallow pitting. Lt. Deposits. 84 2705 0 0.02 7 1 2.94 85 2737 0 0.03 13 4 2.91 Shallow corrosion. ' 86 2769 0 0.04 17 9 2.95 Shallow )ittin . 87 1 2800 0 1 0.02 9 7 2.95 88 2831 0 0.02 9 5 2.93 Lt. Deposits. 89 2863 0 0.02 7 9 2.94 90 2895 (? 0.03 13 I 2.94 Shallow corrosion. 91 2926 o 0.04 14 7 2.91 Shallow pitting. 92 2958 0 0.03 10 4 2.93 93 2990 O 0.03 13 4 2.92 1 Shallow pitting. 94 1 3022 1 1) 1 0.04 15 8 2.95 1 Shallow 6tting. Lt. Deposits. ' 1 95 3053 0 0.03 13 7 2.95 L Shallow pitting. 96 3085 1 0 1 0.03 11 4 2.93 ' Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE Well: 3A -06 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 21, 2010 ' Joint Jt. Depth Pen. Pen, Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 97 3117 0 0.05 19 7 2.95 Shallow corrosion. 98 3149 0 0.03 12 9 2.93 Shallow 6tting. 99 1 3180 0 0.02 7 1 2.94 100 3212 0 0.02 7 4 2.90 101 3244 0 0.02 9 9 2.96 102 3275 0 0.03 11 6 2.93 103 3307 0 0.04 15 7 2.95 Shallow corrosion. 104 3339 0 0.04 16 7 2.94 Shallow pitting. 105 3371 0 0.02 9 5 2.93 106 1 3403 0 1 0.03 11 7 2.93 107 3434 0 0.03 11 4 2.92 108 3466 0 0.02 9 4 2.93 109 3498 0 0.02 9 7 2.93 110 3530 0 0.02 8 5 2.90 111 3.562 0 0.02 8 8 2.94 112 3594 0 0.03 11 1 9 2.94 Lt. Deposits. 113 3625 0 0.03 13 4 2.92 Shallow Pitting. 114 3657 0 0.04 15 5 2.93 Shallow pitting. 115 3689 0 0.03 13 6 2.94 Shallow ittin . 116 3721 0 0.02 7 4 2.90 117 3752 0 0.03 13 8 2.93 Shallow pittin 118 3784 0 0.04 14 8 2.96 Shallow pitting. 119 3816 0 0.03 12 1 8 295 120 3847 0 0.03 11 4 2.93 121 3879 0 0.02 9 4 2.92 122 3910 0 0.04 14 5 2.88 Shallow pitting. 123 3941 0 0.01 6 4 2.90 124 3973 0 0.03 11 7 2.93 125 4004 0 0.03 11 4 2.94 126 4034 0 0.03 12 1 7 2.95 127 4066 0 0.02 8 1 3 2.94 128 1 4098 0 1 0.02 9 5 2.93 129 4129 0 0.03 11 4 2.93 130 4161 0 0.02 9 6 2.94 Lt. Deposits. 131 4193 0 0.02 9 4 2.93 132 4224 0 0.04 15 7 2.96 1 Shallow corrosion. 133 4256 0 0.04 14 7 2.90 Shallow pitting. 134 4286 0 0.04 15 1 8 2.94 Shallow pitting. 135 1 4318 0 1 0.04 14 7 2.95 Shallow pitting. ' 136 4350 t) 1 0.03 13 8 2.94 Shallow pitting. 137 4382 0 0.04 17 7 2.92 Shallow corrosion. 138 4413 0 0.02 9 3 2.91 139 4445 U 0.03 10 8 2.92 140 4477 0 0.04 14 7 2.92 Shallow pitting. 141 4509 0 0.04 14 3 2.96 Shallow pitting. 142 4540 0 0.04 14 8 2.94 Shallow corrosion. 143 4572 0 0.02 9 6 2.95 144 4604 0 0.03 12 8 2.94 145 4636 0 0.02 9 2 2.93 146 4666 0 0.02 9 5 2.93 Penetration Body ' Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf L -80 EUE Well: 3A -06 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 21, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 147 4698 0 0.03 12 3 2.93 148 4730 0 0.03 11 4 2.94 149 4761 0 0.03 12 5 2.91 150 4793 0 0.04 17 7 2.92 Shallow ittin . 151 4824 0 0.06 22 9 2.93 Corrosion. ' 152 4856 0 0.02 9 4 2.94 Lt. Deposits. 153 4888 0 0.03 13 8 2.94 Shallow pitting. 154 4920 0 0.03 10 3 2.92 155 4952 0 0.02 9 3 2.91 ' 156 4982 0 0.03 12 6 2.94 157 1 5014 0 1 0.02 8 2 2.92 158 5046 0 0.02 9 3 2.91 159 5078 0 0.02 8 5 2.92 160 5110 0 0.03 11 3 2.92 161 5142 0 0.03 13 8 2.96 Shallow pitting. 162 5173 U 0.03 13 6 2.95 Shallow pitting. 163 5205 0 0.03 11 1 3 2.92 ' 164 5237 1) 0.03 12 7 2.92 165 5269 0 0.03 12 6 2.93 166 5301 0 0.04 14 7 2.93 Shallow pitting. 167 5332 0 0.04 15 7 2.95 Shallow corrosion. Lt. Deposits. 168 5364 0 0.02 7 6 2.91 169 5394 U 0.03 10 4 2.93 170 5426 0 0.03 11 1 3 2.93 171 5456 0 0.03 12 6 2.94 172 5488 0 0.03 11 7 2.93 ' 173 1 5520 0 1 0.04 14 6 2.94 Shallow pitting. 174 5552 0 0.03 12 4 292 Shallow pitting. 175 5583 0 0.02 7 4 2.93 176 5615 0 0.03 12 4 2.91 ' 177 5647 0 0.03 13 1 3 2.93 Shallow pitting. 178 5678 0 0.04 16 6 2.92 Shallow pitting. 179 5709 0 0.02 7 3 2.94 180 1 5741 0 1 0.02 9 1 2.93 181 5773 0 0.03 12 4 2.94 Lt. Deposits, 182 5804 0 0.02 9 2 2.91 183 5836 0 0.03 11 2 2.89 184 5868 U 0.03 12 1 4 2.93 185 5900 0.03 11 4 2.93 ' 186 5931 0 0.03 13 2.93 Shallow corrosion. 187 1 5963 0 1 0.04 14 6 2.90 Shallow pitting. 188 5995 0 0.02 9 3 2.94 189 6027 0 0.02 9 2 2.93 190 6059 0 0.06 25 11 2.95 Corrosion. 191 6091 0 0.04 14 1 7 2.93 Shallow pitting. 192 6122 0 0.04 16 6 2.93 Shallow corrosion. 193 6154 0 0.04 14 6 2.94 1 Shallow pitting. 194 1 6186 1 0 1 0.02 9 3 2.91 I' 195 1 6217 0 0.02 9 6 2.91 196 1 6249 0 0.02 8 2 2.90 jPenetration Body ' Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE Well: 3A -06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 21, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 197 6281 0 0.02 7 4 2.92 198 6312 0 0.02 9 4 2.93 199 6343 0 0.03 13 1 7 2.90 Shallow Pitting. 200 6375 0 0.03 13 7 2.95 Shallow pitting. ' 201 6407 0 0.03 12 5 293 202 6439 0 0.03 13 3 2.92 Shallow pitting. 203 6470 0 0.04 17 7 2.96 Shallow pitting. 204 6502 0 0.03 10 3 2.93 205 6532 0 0.03 11 6 2.93 ' 206 6564 0 0.02 8 1 3 2.92 207 6596 0 0.04 15 1 8 2.91 Shallow pitting. 208 1 6628 0 0.02 9 3 2.92 209 6659 0 0.02 7 2 2.92 210 6691 0 0.03 13 6 293 Shallow pitfing. 211 6723 0 0.02 7 2 2.92 212 6754 0 0.04 16 6 2.93 Shallow pitting. 213 6785 0 0.02 8 6 2.95 ' 213.1 6817 0 0.02 1 8 1 2.91 PUP 213.2 6827 0 0 0 0 N A GLM 2 Latch @ 7:00 213.3 6836 0 0.02 8 1 2.92 PUP 214 6846 0 0.04 14 3 2.93 Shallow pitting. ' Penetration Body Metal Loss Body ' Page 5 1 � w PDS Report Cross Sections Well: 3A -06 Survey Date: October 21, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 ' Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE Analyst: J. Thompson ' Cross Section for Joint 190 at depth 6059.37 ft Tool speed = 43 Nominal ID = 2.992 ' Nominal OD = 3.500 Remaining wall area = 93 % Tool deviation = 43 " 1 Finger 21 Penetration = 0.064 ins Corrosion 0.06 ins. = 25% Wall Penetration HIGH SIDE = UP Cross Sections g a e 1 P PDS Report Cross Sections ' Well: 3A -06 Survey Date: October 21, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE Analyst: J. Thompson ' Cross Section for Joint 151 at depth 4854.85 ft Tool speed =43 Nominal ID = 2.992 ' Nominal OD = 3.500 Remaining wall area = 94 % Tool deviation = 46 " 1 ' Finger 7 Penetration = 0.056 ins Corrosion 0.05 ins. = 22% Wall Penetration HIGH SIDE = UP 1 Cross Sections page 2 iuM �aNui ' Top Dj Top hcl - fttK B1 i i °i Item m ici tion _fom m ent 28.6 28.6 0.26 HANGER FMC Gen 5 Tubing Hanger wfpup 504.3 544.3 0.25 NIPPLE 3.5" x 2.875" Camoo "D S" Nipple ' 6,877.4 5,735.9 40.74 GAUGE 'Weatherford Gauge Mandrel 6,955.0 5,754.7 40.67 SEALASSY G B H-22 Seal Assembly a Locator ,w2.00' space out ' Tubini C+eicriptton Sting C D... String ID... Top (itt•: Bl set N ti ft.. Set CopIth (TVD)... Sting Wt.. String ... TUBING 1.5 "for 1 15116 1.625 6,919.6 7,135.6 5,935.6 2.90 L-80 Intensifier Pump Completion Details Top Depth Top i Tr Di Top ticl ittl•:Bi ittl-:Bi 1 "1 tbem Dercrl tion O mment 7,132.2 5,930.0 39.77 LOCATOR No -Go LOCATOR ' 7,133.8 5,931.2 39.77 SEALASSY SEALASSEMBLY Tubing Ife rcriptJon String Cora String ID... Top i k: 6.4 Set Ceptli i.t.. Set Cis p 1 i Tv "Co String Wt.. Sting ... Stack. Packer 3 12 2.992 1 6 7,066.0 5,879.1 9.30 L -00 Completion Details Top Depth Top (TVD) Top Incl MI. Bi ittk:Bi i °i Ibam C*+ci tion -:Dmment ' 3 6,943.1 5,790.2 40.68 PACKER Baker FHL Packer k -fPBR a 6.12' Pupjt 7 5 39.59 NIPPLE Came, "DS "Nipple 7,051.3 5,867.7 39.65 LGCATGR Locator w2'space out I 7.053.7 5 39.65 SEALASSY 8040 GBH-22 Seal,-!Issembly WO/Seals Tubing De rorlptlon Sting oc .. I String ID... Top iftK Bi Set C1epU7 ft.. Set Depth fTV Di... Strin�l tr'o't.. string ... TU B I N G Original 3 12 2.592 7,042.1 7,281.4 6,044 9.30 L40 Completion Details Top C+eptti Top M Top hcl 131 Ml 151 i' i Item Cie oci lion _nom m ent 7,042.1 5,860.7 39.63 PACKER BAKER 83.40 FB -1 PACKER 7,045.4 5,863.2 39.64 SBE BAKER SEAL BORE EXTENSION 7,238.4 6,011.6 40.29 NIPPLE AVABPLPO RTE D NIPPLEwfIS0 SLEEVE ID 2.31" 7,253.0 6,022.8 40.26 LOCATOR BAKER 8032 LO CATO R S U B 7,254.0 6,023.6 40.26 SEALASSY BAKER 80-32 SEA,LASSEMLY 7 6,024.4 40.25 PACKER BAKER MODEL'D' PERMANENT PACKER wry' SEALBORE 7,273.7 6,038.6 40.21 NIPPLE CAM CO'D' 2.25' NO GO NIPPLE 7,280.7 6,043.91 40.19 S 01 BAKER SHEAR OUT Other In Hole 4 Wireline retrievable plugs, valves, pum fish, etc.) Top Cloptli Top (TVID) Top Ind ' rtKB'i ittl i °1 CMMrr1 ton Cz-mment 6,875 5 40.74 PACKER 3 "YVEATHERFORD UPPER PACKER TESTOOL (OAL =31'3 8 1 7 ; 129 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL3.5 'TBG 1 ' 7,238 6,011.6 40.29 1 SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9 Perfo rations & dots I - Shot ' Eft Top (TVD) Etn (TV D) Den4 Top f ttKE3 ftti;61 fM.B1 itti•:B1 ::one Its '9h... T I Om 7,144 7,220 5,939.1 5,997.7 C -1, C,1, C-4, 11 /2211985 12.0 IPERF 1 120 deg phase, 5" C 3A-06 7.34+) 7,362 6,089.5 6,106.2 .4-3, 3A -06 112211985 4.0 IPERF 90 deg. phase; 4"C 7,341 7,361 6,090.3 6,105.5 A-3, 3A-06 611472008 6.0 R PE R F 2 118" PEJ, +1- 45 D 7,372 7,420 6,113.8 6,150.3 Ar-2, 3A-06 11/2211985 4.0 IPERF 90 deg. phase; 4:'C 7 7,420 6,113.8 6,150.3 A,2, 3A-06 61142008 6.0 R PE R F 2 1 1 0 ," PEJ, +1- 45 D 7..4441 7,450 6,168.9 6,173.6 A-1, 34-06 11 2211985 4.0 j IPERF j9O deg. phase; 4!'C WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 27, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT Caliper Log: 3A -06 Run Date: 10/21/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21443 -00 NOV T ZO�D MIT Caliper Log 1 Color Log 50- 029 - 21443 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton o Wireline & Perforating " Attn: Klinton Wood `J 06? 6900 Arctic Blvd. 1 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 klinton.wood @hal]Wburton -c rn Date: Signed: Page of Maunder, Thomas E (DOA) From: NSK Problem Well Supv[n1S17@conocophi||ipo.com] Sent: Friday, August 20.201O8:43AM To: Regg. James B(O[)A); Maunder, Thomas E(OOA); Schwartz, Guy L(DC)A) Co: NQK Problem Well 8upv;NSK Well Integrity Pnoj;CPF3 Prod Engro;CPF3 IDS Lead Tenha; Hunter, Lindsey L Subject: 3A~O8(PTO#18S'322) Report OfTx|ACommunication Attachments: 3A-08VVe||boraSchematic.pdf; 3A-08T|[) P|oLpdf Jim/Tom/Guy. Kuparuk injector 3A-06 (PTD# 185-222) is suspected of having TxIA communication based upon pressures observed during routine vve||vvork. Slickline and e-line will be used to diagnose and repair the leak if possible. The well is currently shut in and will be added to the monthly injector report. Attached are avve||bora schematic and AD day T|Oplot. Please contact meot your convenience if you have questions orcomments. Martin , Martin Walters /Brent Rogers Problem Wells Supervisor CononoPhiUipo Alaska Inc. Office 907-059-7224 Cm|| 0O7-843-172D/1Q00 Pager 907-650-7000 #909 NOV ,.w , - - � ll/l5/2AlU Well Name 3A -06 Notes: End Date 8/29/2010 Days 120 Start Date 5/1/2010 Annular Communication Surveillance 3500 WHP 90 IAP OAP 80 3000 WHT 70 2500 • 60 2000 -- SCLL •y � CL 1500 - 40 30 1000 - - 20 500 - — 10 0 0 May -10 Jun -10 Jul -10 Aug -10 so • IDGI 2s —MGI �PWI ° a —SWI 0 15 BLPD r U 2 1000 500 -- — 0 May -10 Jun -10 Jui-10 Aug -10 Date MEMORANDUM To: Jim Regg '~~~g ~Ij zl ~~' P.I. Supervisor (. I FROM: John Crisp Petroleum Inspector • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 12, 2009 SUBJECT: Mechanical Integrity Tests CONpCOPHILLIP5 ALASKA INC 3A-O6 KUPARUK RIV UNIT 3A-06 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,,~~ Comm Well Name: KUPARUK RIV UNIT 3A-06 Insp Num: mitJCr090507150914 Rel Insp Num: API Well Number: 50-029-21443-00-00 Permit Number: 185-222-o Inspector Name: John Crisp Inspection Date: 5/3/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3A-06 Type Inj. W 'I'mo 5790 IA 650 1800 1760 1750 P.T.D Iss222o TypeTest SPT Test psi 1800 OA 455 590 S90 590 Interval INITAL p~ P `' Tubing 2630 2630 2630 2630 Notes: ]bbl pumped for test. No problems witnessed. Shallow packer depth only required 1500 psi for AOGCC. •~ [.•j~~«~}cy,~f~gq ~`~''._ {(~/f~ ~}'/ (~ fry Tuesday, May 12, 2009 Page 1 of 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 LJ ~ - ~ ~~ ~ ~. ~ ~ ~ : , APR ~~. ~ EQs;~ ~~ Oil 0~~ ~c~s i~~s:~, _,~ ~ho~ April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ,, ~ ~ , ~ f~t~, Anchorage, AK 99501 ~~~~~'~~~'~ ' '~' Dear Mr. Maunder: l ~~' 1~ ~ ~_ ~~ ~ u Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K~ Lein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-036 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~i~~~ JAN 2 (~ 2005 REPORT OF SUNDRY WELL OPERATI~a'r & Gas Cons. Commission ~_ . 1. Operations Pertormed: Abandon ^ Repair Well ~ Plug Pertorations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing Q Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnocoPhillipSAlaska, Inc. Development ^ Exploratory ^ 185-222! 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21443-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 32' 3A-06 8. Property Designation: 10. Field/Pool(s): ADL 25632 Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7680' feet true vertical 6352' feet Plugs (measured) Effective Depth measured 7576' feet Junk (measured) true vertical 6270' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 72' 16" 104' 104' SURFACE 3374' 9-5/8" 3406' 3178' PRODUCTION 7636' 7" 7668' 6343' ~ati ~~~ ~~;la t~ ~~ 2~1~ ~~ Perforation depth: Measured depth: 7144'-7220', 7340'-7362', 7372'-7420', 7444'-7450' true vertical depth: 5939'-5998', 6090'-6106', 6114'-6150', 6169'-6174' Tubing (size, grade, and measured depth) 3.5", L-80 @ 7252', 2-7/8" L-80 @ from 7252'-7281', -80 from 6920'-7134' 1.5" L ~ Packers & SSSV (type & measured depth) Baker'FHL' pkr, Baker FB-1 pkr, Baker'D" permanent pkr @ 6947040', 7255 Camco'DS' nipple @ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 837 ~ 900 2800 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 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: 308-431 contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Engineer ` / Signature Phone: 263-4220 Date ! ~~/(~ P red b Sha n All u rek 263-4612 Form 10-404 Revised 04/2006 ~v /• ZQ D~ ~1l Submit Ori ' Onl ~~~ 'may/©~ DATE SUMMARY 3A-06 Well Events Summary 10/24/08 DRIFT TBG W/ 2.80" TO TO~ BPC @ 7238' RKB, IN PROGRESS. 3000 PSI, PASS. PULL CAT SV @ 7274' RKB, DRIFT TBG W/ 12' OF 2.77" TO 7238' RKB. IN PROGRESS. 10/26/08 CALIPER TBG FROM 7270' RKB TO SURFACE. REPLACED DV @ 7093' RKB W/ 1.5" FULL OPEN 5/8" ID HFCV ON RKP FLOW THROUGH LATCH, JOB COMPLETE. 11/24/08 DRIFTED TBG & TAGGED AVA (c7 7283' RKB W/ 2.70" SWAGE, BRUSH & FLUSH TBG FROM 7050' TO 7140' 11/26/08 SET BAKER 35 WL "KB" LOWER STRADDLE PACKER WITH Mi _Fi FnnFNT AT 71 A'. TAKE SBHP SURVEY. RESULTS: 3408.3 PSI AT 7120' RKB AND 3365.2 PSI AT 6970'. 11/30/08 RAN AVA TEST TOOL TO TOP OF KB PACKER @ 7126' SLM, ATTEMPT MITT, FAILED, RAN D&D TEST TOOL TO ABOVE KB PACKER @ 7111' SLM, MITT FAILED, SET CATCHER @ 7126' SLM, PULLED HFCV @ 7093' RKB, IN PROGRESS. 12/01/08 SET DV @ 7093' RKB, PULLED CATCHER SUB @ 7121' SLM, RAN 2.25"AVA SV TO 7124' SLM, PASSED CMIT TO 2500 PSI, IN PROGRESS 12/02/08 SET AVA CATCHER @ 7121' SLM, PULLED DV @ 7093' RKB, SET DPHFCV @ 7093' RKB, PULLED DV @ 6956' RKB, PULLED CATCHER, SET BPV, 1000 PSI UNDER BPV, JOB COMPLETE. 12/25/08 REPLACE 1.5" SOV FROM STA # 1 @ 6827 W/ DV. PULL 2.75" CATCHER SUB. JOB IN PROGRESS. 12/26/08 MITT & MITIA TO 2500 PSI, BOTH PASSED. PULL TEST TOOL @ 6874' RKB. JOB SUSPENDED. WILL RETURN TO SET "DOWN HOLE INTENSIFIER PUMP" AFTER OPS GET WELL READY FOR INJECTION. 01/02/09 DRIFTED TBG W/ 2.85" GAUGE RING AND TAGGED WHAT APPEARS TO BE X- PROFILE @ 6892' RKB. DRIFT TBG W/ 2.823" CENT. AND TAGGED WHAT APPEARS TO BE TOP OF INTENSIFIER @ 6895' RKB. DRIFT TBG W/ 25' X 2.80" DRIFT AND TAGGED BOTTOM OF INTENSIFIER @ 6915' RKB. JOB SUSPENDED (WAITING ON VENDOR FOR MORE RESEARCH TO BE DONE BEFORE SETTING DHIP~. 01/12/09 DRIFTED TBG W/ 2.80" TO 6875' WLM, BRUSH & FLUSH PUMP AREA, SET 2.81" X- LOCK W/ 3" DOWN HOLE INTENSIFIER (cry 6875" WLM, 24'-7" TOTAL LENGTH),,... 10/25/08 PULL BPC & SET BPI (NEW LE) @ 7238' RKB.SET CAT SV @ 7274 B. CMIT TO ConoccaPh~llips Time Log & Summary WeJWiew Web Jteparting Report Well Name: 3A-06 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/9/2008 3:30:00 AM Rig Release: 12/14/2008 3:00:00 AM Time Loys Date From To _ Dur S. Depth E . Depth Phase Code Subcode T Comment 12/08!2008 _ _ 24 hr Summary Moved Nordic Rig 3 from 30-14 to CPF3. 21:00 00:00 3.00 MIRU MOVE MOB P Move Nordic Rig 3 from 30 Pad to CPF 3. 12/09/2008 Cont move rig to 3A Pad. Accepted Nordic 3 Rig @ 3:30 hrs 12-9-08. RU and killed well with 11.4 ppg brine, ND tree, NU and tested BOP's, ulled han er to ri floor. 00:00 02:30 2.50 MIRU MOVE MOB P Cont moving Nordic Rig 3 from CPF 3 to 3A Pad. 9 mile ri move total. 02:30 03:00 0.50 MIRU MOVE OTHR P Load tree in cellar, spot well head e ui ment behind well. 03:00 05:30 2.50 MIRU MOVE PSIT P Move rig over well, berm up cellar, spot tanks and mud shack. Acce ted Nordic Ri 3 at 03:30 AM_ on 12/9/2008. 05:30 09:30 4.00 COMPZ MOVE RURD P Load lubricator on rig, load 290 bbls 11.4 ppg KWF in pits, RU hardline to kill tank, RU lubricator on tree and ull BPV 1 000 si on tubin and IA 25 si on OA load 150 bbls 11.3 brine in pits and blend, adjust surface volume wei ht to 11.4 test hardline to 1,000 si. 09:30 11:30 2.00 COMPZ WELCTL KLWL P Break circ down tubing at 3 bpm maintaining 1,000 psi on choke for 61 bbls (tubing volume to GLM), cunt pumping 184 bbls maintaining 430 psi on tubing, close choke and bullhead 15 bbls down tubing at 2 bpm - 380 psi, open choke and pump 20 bbls to kill tank with 430 psi on tubing, with 11 ppg return fluid, shut down pump, shut in well, blow down hard line. Pumped a total of 329 bbls 11.4 .Monitor well for ressure. 11:30 13:00 1.50 COMPZ WELCTL KLWL P Load 290 bbls 11.5 ppg in pits. Monitor well, on vac. Pumped 25 bbls. 11.4 ppg brine @ 3 BPM w/ 230 si. Lost 6 bbls. well on vac. 13:00 14:00 1.00 COMPZ WELCTL NUND P RD circulatin lines set BPV. 14:00 15:30 1.50 COMPZ WELCTL NUND P ND tree, install blanking plug, ins ect lift threads. 15:30 18:30 3.00 COMPZ WELCTL NUND P NU BOPE. ~~~u 1 G D Time Logs _ Date From To Dur S De th E. De th Ph se Code Subcode T Comment 18:30 22:00 3.50 COMPZ WELCTL ROPE P Field wide phase 2 weather conditions, tested ROPE at 250 psi low, 3,500 psi high, on chart, good test, RD test equipment. Witness of BOP test was waived by AOGCC Rep Jeff Jones at 17:00 hrs on 12/9/08. 22:00 23:30 1.50 COMPZ RPCOM RURD P MU retrievin ool Dull blanking lu ull BPV, MU landing joint and circ hose, BOLD's. 23:30 00:00 0.50 7,053 7,053 COMPZ RPCOM CIRC P Pulled to 145K (includes 35K block weight) and seals pulled free, pulled hanger to rig floor, up weight 90K, 12.5 bbls to fill hole. 12/10/2008 CBU, POOH LD 3 1/2" tubing, PU RIH with FHL packer and PBR on new 3 1/2" tubing to 6,238' MD. 00:00 03:00 3.00 7,053 7,053 COMPZ RPCOM CIRC P CBU at 2 bum for 185 bbl_s, lost total of 47 bbls, monitor well f/ 15 minutes, lost 3 bbls in 15 minutes with well static, diluted 95 bbls from 11.3 ppg to 11.1 ppg and filled trip tank. Rack and tally 3 1/2" tubing. Still in field wide Phase 2 weather conditions. 03:00 07:00 4.00 7,053 4,200 COMPZ RPCOM PULD P POOH LD 3 1/2" tubing from 7053' to 4200'. 07:00 10:30 3.50 4,200 4,200 COMPZ RPCOM OTHR P Load, rack and tally, & drift new 3 1/2" tubin and 'ewel 10:30 11:30 1.00 4,200 4,200 COMPZ RPCOM CIRC P Fluid losses slowed down to less than 1 BPH. Pumped 30 bbls 11.3 ppg brine @ 4 BPM w/220 psi to bring fluid column up to 11.3 ppg. Monitor well. Lossing fluid at Approx. 4-5 BPH. 11:30 16:30 5.00 4,200 0 COMPZ RPCOM PULD P Continued POOH with 3 1/2" tubing, laying down, strapping and removing from i e shed. LD old seal ass . 16:30 17:30 1.00 0 0 COMPZ RPCOM PULD P Clean tools and rig floor. Prep rig and tools for running stacker packer on new 3 1/2" tubin . 17:30 00:00. 6.50 0 6,238 COMPZ RPCOM RCST P PU and RIH with seal assembly (no seals), 2.812" "DS" nipple (with RHC body), FHL packer and PBR on 3 1/2" tubin ,well on trip tank to monitor displacement, to 6,238' md. Fluid loss to date = 73 bbls. 12/11/2008 Cont RIH and locate SBE at 7,045', spot corrosion inhibitor and drop ball/rod, set FHL packer, pressure test 7" csg, shear out PBR, RU slickline and pull ball/rod, RHC plug and locate the 1.92" ID XO in KB packer, rack back 3 stands tbg, set storm packer, ND BOP and tubing head, spear and re-set 7" csg, CO pack-off, NU new tubin head and test, NU BOP's. 00:00 01:00 1.00 6,238 7,030 COMPZ RPCOM RCST P Cont PU RIH with 31/2" tubing from 6,238' to 7.030'. Calculated displacement for string was 23.4 bbls actual dis lacement w I F~~qe ~ of $ Time Lags Date From To Dur S De th E. De th Phase Code Subcode T Comment 01:00 01:30 0.50 7,030 7,041 COMPZ RPCOM OTHR P MU circ hose on jnt #222, ease in hole with charge pump, no-go top of F1 packer 7.5' in on jnt #222, at 7,056' MD with mule shoe at 7,068'. PU 15'. 01:30 02:30 1.00 7,041 7,041 COMPZ RPCOM CIRC P Break circ at 2 bpm - 120 psi, pumped 20 bbls inhibited 11.3 brine and had 11 bbl returns, followed with 60 bbls 11.3 ppg to spot inhibitor at FHL packer depth with no further fluid loss. 02:30 03:00 0.50 7,066 7,066 COMPZ RPCOM PACK P Break off top jnt and drop ball/rod, MU joint, ease in hole and no-go on F1 packer top at 7,056', PU string weight of 85K +2' to position top of PBR at 6,957' and mule shoe at 7,066', pressure up to 2,300 psi, hold 2 minutes and bleed off call for slickline crew. 03:00 04:30 1.50 7,066 7,066 COMPZ RPCOM DHEQ P RU and attempt to test 7" casing at 3,000 psi, valve on mud manifold leaking, RU test pump on IA and pressure up to 3,000 si, test 7" for 30 minutes on chart. Good test. Bled IA to zero, pressured up on tubing to 1,500 psi, pulled to 105K (includes block weight) and sheared out of 04:30 10:30 6.00 COMPZ RPCOM SLKL P LD one joint, MU 8' pup and RU slickline. RIH, pull ball & rod. RIH ull RHC lu .RIH and tag seal bore above KB packer for depth correlation between seal bore and DS nipple. This measurements gives us a total of 188' space out for the 1.5" tubin below the intensifier um housin . RD slickline. 10:30 12:00 1.50 COMPZ RPCOM OTHR P Pulled 4 stands of 3 1/2" tubing standing back in derrick. MU and RIH with 7" storm packer, set @ 30 '. Pressure test storm r 500 si. 12:00 14:00 2.00 COMPZ RPCOM NUND P Bled off OA pressure to 0 psi. ND BOP. 14:00 21:30 7.50 COMPZ RPCOM OTHR P ND tubing head, remove pack-off, RU ands ear 7" cs PU to 60K an reset sli s slack off a roximatel 1"and set emergency slips with 50K up weight on 7" cs ,install new pack-off, cut 6" off to of 7" cs stub NU new tubin head test ack-off to 3,000 si for 10 minutes, ood test. 21:30 00:00 2.50 COMPZ RPCOM NUND P NU 13 5/8" BOP. 12/12/2008 Test breaks on BOP stack, POOH LD storm packer, cont POOH to seal assembly, MU 1.5" 10 rnd IJ tubing, MU intensifier housing and Weatherford gauges, MU GLM with SOV, RIH installing TEC wire clamps on every other cou lin ,install DS ni le at 500', cunt RIH to 6,955'. €~age 3 ~sf 6 s~ Time logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 00:45 0.75 COMPZ RPCOM NUND P Cont NU 13 5/8" BOP. 00:45 01:30 0.75 COMPZ WELCTI BOPE P Set test lu RU and test BOP breaks at 250 low - 3,500 high, good test. RD test equipment, pull test plug. Witness of BOP test was waived by AOGCC Rep Chuck Scheve on 12/11/2008 at 16:40 hrs. 01:30 03:00 1.50 6,885 6,577 COMPZ RPCOM TRIP P MU retrieving tool and RIH 3 stands 3 1/2" DP, engage storm packer and release monitor well ort tri tank for 15 minutes hole took 15 bbls to fill, POOH LD 3 1/2" DP. 03:00 03:30 0.50 6,577 6,577 COMPZ RPCOM OTHR P CO elevators, move pipe in derrick, spot Weatherford spooler on drillers side ri floor. 03:30 06:00 2.50 6,577 880 COMPZ RPCOM PULD P Cont POOH standing back 69 stands 3 1/2" tubing, recording hole fill every 5 stnds. 06:00 06:30 0.50 880 880 COMPZ RPCOM OTHR NP Not taking proper hole fill. Monitor well, static. Check surface equipment, valve on trip tank closed. Open valve weft on vac, hole fill leveled out. 06:30 07:00 0.50 880 0 COMPZ RPCOM PULD P Continue POOH from 880' and LD seals. 07:00 08:00 1.00 0 0 COMPZ RPCOM RCST P Clean rig floor and prep for running completion. Rig up sheave and s ooler for Tech Wire. 08:00 10:00 2.00 0 103 COMPZ RPCOM RCST P Hang seal assy in slips. MU false rotary table. RIH with 1.5" 10 rd IJ tubing space out for distance between KB acker and new PBR. MU 1.5" tubing to down hole injection intensifier housing. MU downhole injection intensifier to seal ass . 10:00 12:00 2.00 103 103 COMPZ RPCOM RCST P MU Weatherford gauges to sensing ports on downhole injection intensifier housin & test OK. 12:00 00:00 12.00 7 6,955 COMPZ RPCOM RCST P MU Camco MMM GLM w/1500 psi casing to tubing SOV 1 jt above downhole injection intensifier. RIH with 3.5" tubing from derrick installing TEC wire clamps over every coupling to 6,955', up weight 85K, down weight 72K, ran a total of 217 Cannon Cross Coupler Clamps and 5 SS Bands. 12/13/2008 Spaced out, spliced Tec Wire through hanger, spotted corrosion inhibitor, landed string, RILD's, RU slickline, pulled isolation sleeve, set test tool, RD slickline, tested tubing and annulus, sheared SOV, set BPV, ND BOP, NU tested tree, dis laced to sea water, freeze rotected well. ~'aga ~ of 6 s~ r1 Time Logs Date From To Dur S. De th E. De th Phase Coe Subcode T Comment 00:00 01:00 1.00 6,955 6,927 COMPZ RPCOM __ HOSO P Pump 1/2 bpm and ease in hole, saw pressure increase 19' in on jnt #217, shut down pump, opened bleeder and ease in hole, no-go'd 30 1/2' in on jnt #217, with upper muleshoe at 6,969', lower mule shoe at 7,139'. LD 3 jnts, PU 28' pups and MU under 'nt #215 for 2' s ace out. 01:00 02:00 1.00 6,927 6,927 COMPZ RPCOM OTHR P Clamped and secured Tec Wire, MU hanger, cut and terminate Tec Wire at hanger, test swagelock fitting in bottom of hanger to 5,000 psi, tested ood. 02:00 03:00 1.00 6,927 6,927 COMPZ RPCOM CIRC P Pump 20 bbls corrosion inhibited brine followed with 60 bbls 11.3 ppg (tubing volume) to spot inhibitor between PBR and GLM, at 2 bpm - 190 si. 03:00 03:30 0.50 6,927 6,967 COMPZ RPCOM OTHR P Circ at 1/2 bpm, ease inhole and verify upper seals entering sealbore, shut down pump, drain stack, land hanger, up weight 85K, down weight 72K, RILD's, upper muleshoe set at 6,967', lower muleshoe set at 7,137', monitoring "A"and "C" sand pressure guages, "C" gauge reading 3,465 psi, "A" guage reading 3,461 si. 03:30 04:30 1.00 6,967 6,967 COMPZ RPCOM DHEQ P Pumped 1/2 bpm at 200 psi to verify gauges working and zones isolated, while pumping the "C" gauge reading was 3,676 psi, the "A" gauge reading was 3,376 psi, shut down pump and bled off, "C" gauge reading dropped to 3,415 psi, the "A"gauge reading dro ed to 3,336 si, ood test. 04:30 07:00 2.50 6,967 6,967 COMPZ RPCOM SLKL P Spot and RU slickline, PJSM, RIH with slickline and pulled iso sleeve, RIH and set u er acker lu at 6,877', pressured up to 300 psi to check lu ,POOH RD slickline. 07:00 09:00 2.00 6,967 6,967 COMPZ RPCOM DHEQ P RU and test tubin to 3000 pSj. Bled off tubing pressure to 2000 psi. Pressure test IA to 3000 si for 30 min and recorded on chart. Bled IA and tubing to 0 psi. Pressure up IA and sheared SOV 1250 si. 09:00 12:30 3.50 6,967 6,967 COMPZ RPCOM NUND P Set BPV. ND BOPE and adaptor and NU tree. 12:30 19:00 6.50 6,967 6,967 COMPZ RPCOM OTHR P Make final connections for Weatherford Gau es. 19:00 21:00 2.00 6,967 6,967 COMPZ RPCOM NUND P NU tree, pull BPV, set test plug, test tree at 250 low - 5,000 high. Good test, ull test lu . 21:00 22:30 1.50 6,967 6,967 COMPZ RPCOM CIRC P Pump 240 bbls corrosion inhibited sea-water down annulus taking 11.3 returns to its at 3 b m, 550 si. Page 5 of ~ r Time Logs ___ Date From To Dur __ S. De th E. De th Phase Code Subcode T Comment 22:30 23:30 1.00 6,967 6,967 COMPZ RPCOM FRZP P Pump 90 bbls diesel down annulus at 2 bpm, 1,050 psi to freeze protect well. 23:30 00:00 0.50 6,967 6,967 COMPZ RPCOM FRZP P Put tubing and annulus in communication to allow diesel to swa ,blow down hardline to kill tank. 12!14/2008 Blow down all circ lines, i nstall BPV, clean pits, secure well and install gauges on tree, prep rig to pull off well, move tanks, noti DSO and ull ri off well, clean cellar box and well site, start movin ri to 1 D Pad. 00:00 02:00 2.00 COMPZ RPCOM FRZP P Cont allow tubing annulus diesel to swap, blow down circ lines, install BPV, install gauges on tree, move tanks and prep to pull rig off well. SITP = 0 si, IA = 0 si, OA = 0 si. 02:00 03:00 1.00 COMPZ RPCOM OTHR P Call DSO, back rig off well, clean out cellar box and well site. Released Nordic Ri 3 at 03:00 hrs on 12/14/2008. P~e~e $ of 6 `,. ~~~, KUP ~ 3A-06 ~OY10GO~1l~~I~i5 ~'~ Well Attributes _ ___ _ Max Angle & MD_ ',TD- _ r3 Yrt ~hC ,~, Wellbore APl/UWI Field NameWell Status 'Prod(Inj Type 'Intl() ~IMD(ftKe) Act Btm (ftKB) - 1 500292144300 KUPARUK RIVER UNIT 'INJ ~SWI 143.55 '. 4,600AO 7,680.0 Comment H25 (ppm) Date 'iAnnotation :End Date ~iKB-Grd (ft) Rig Release Date _wfle conrg .:4@~6.V15(2lg53:32v?P,u SSSV. Nlpple 0 7/1/2008Last WO: 12/12/2008 3648 10/1911985 _ 3.Gt%nadf Actual (Annotation Depth (ftK81 End Date Annotation '~Entl Date Last I ag' 7 475.0 8/3/2008 Rev Reason SHOW GLM #2 OPEN 12/27/2008 Casing. Strings - ~; .-...-- - Casing Description String 0... String ID ... TOp (flK8) Set Depth (f... Sel Depth (TVD) ... String W[... St ng ._ String Top Thrd Tubing Hanger, CONDUCTOR 16 15.062 0.0 104.0 104.0 62.58 H-00 ' - _' ~~ Casing Description String 0... String ID ... Top (flK8) Set Oepth (f... Sat Depth (TVD) ... String Wt... Sing ... iString Top Thrd SURFACE 95/8 8.765 0.0 3406.0 3,178.2 36.00 J-55 __ Casing Description String 0... .String ID ...'Top (ftK8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrtl PRODUCTION 7 6.151 0.0 7,668.0 6,342.5 26.00 J-55 corvoucroR. _ ~ Tubin Strin s o.tw ~. 9 9. - ---- -- ', Tubing Description ',String 0... String ID ...'Top (ftK8) ilSet Depth (f... Set Depth (TVD) ... String Wl... St g .. ~. String Top Thrtl TUBING ~~ 3112 'I 2992 28.6 ~ 6,967.3 5,8040 9.30 L-80 EUE NIPPLE, 506- - - - - _.--___-.-_ -; Completion Details _ SURFACE, _ Top Depth 0-3.406 (TVD) Top Intl Top (ftK B) (kK8) (°) ttam Description Comment __ ID (in) 504.3 504 3 0.251 NIPPLE 3.5" x 2.875' Camco "DS" Nipple - 2.875 cns uFT. 6,877.4 5,735 9' 40.74 GAUGE Weatherford Gauge Mantl rel ~ 2..992 6,82] 6,894.0 5,748.5 40.73 INTENSIFIER BHA, 3" FlDownhole IntensAier for T 26#Csg 1.000 6,955 0 5,794.7 ~ 40.67 SEAL ASSY GBH-22 Seal Assembly & Locator w/2.00'space ou[ 3.000 ` Y Tubiny Descr pM1On Str nq 0.. ',String ID ...TOp (ftKB) (Set Depth (f... (Set Depth (TVD(... (String Wt...lSt g ..String Top Thrd GAUGE 6s7r .-ro: '-' I UBING 1.5" 1 15/16 ~ L625 6.919.6 7,139 6 5,935 6 2 90 L 80 _ 1J 10 rntl _ INrF"s'689a ~ - Completion Details _ _ __ ftKB .. - _~.._ --.. P P ... ". ,.... To(TVDI th ~i ToP Intl Ratluring XO, _ - Top (ttK6) ( I (°) ttem Description Comment _ ID (in) 6'020 ,y 6,919.6 5,767.8 40.70 Reducing XO X-Over 3.5" x 1.66" Slick out pin 1.000 ENargmg XO. _ I __. - _-__ ss21 6,920.5 5,768.5 40.70 Enlarging XO ~X-over 1.66" z 1.9" Box x Box 1.000 7,132.2 5,930.0 39.77 LOCATOR INO-Go LOCATOR 1.820 - :'~ 7,133.8'x, 5,931.3 39.77~SEAL ASSY SEAL ASSEMBLY ~ 1.820 Tubin Dascri hon IStrin O IStrin ID ...To ftKB Set Da th f.. Stack Parker 3 tit 2.992 6949 1 7 066 Q ' i.Set Depth (rVD) . String Wt... ~St g String Top Thrd 9 P 9 9 P l 1 P( 5,879.1 i 9.30 ~ L 80 _-. EUE _ SEAL Asst. --_ ~- Completion Details 6955 ~ ftK81 Top Incl. .... _._.__-_. ..._ - PACKER,6,949- - Top Depth i -'- Top (ftK B) ( (°) Item D cription Comment __ _ ID (in) 6 949.1 ~ 5 790.2 40.68'~i PACKER Baker FHL Packer wIPBR & 6.12' Pup j[ 3000 NIPPLE 7,012 - 7 012.31 5,837.6 39.59 NIPPLE Camco "DS' Nipple w/ RHC Plug - 2.812 7,051.3 i 5,867.7; 39.65 LOCATOR Locator w/2' space out - - - I. 3.000 - 7,053.7 5,869.6 39.65 SEAL ASSY 80-40 GBH-22 Seal Assemby WO/Seals 13.000 PACKER. 7.042-- -- ~~ ~ - - g p g g p( ) Set Da h I -- - SBE 7.045--- _ Tubin Des n lion Stnn O Strin ID .. ITo ftKB Set Depth (i... II Pt (rvo) ~ 9 30 L 80 L 8RD MOD TUBING Ongmal 3 1;2 2.992 7,0421 7.281.4 6 044-5 String Wt... Str ng Stri g Top Thrd LocA?os.. __ ~ -,~ Completion Details - _ _ _.. _ ___ -- ~, _ Top Depth I '~ ,' i (TVD) Top Intl Top (ttK8) (ftKBl (°) ttern Description Comment __ ~ ID (inl SEAL Assv. 7 042.1 5,860.7 39.631 PACKER BAKER 83-40 FB-1 PACKER 4.000 LoSa 7,045.4 ~ 5,863.2 39.64ISBE BAKER SEAL BORE EXTENSION 4.000 7,054.8 5,870.4 39.65 Reducing XO 2.992 IwECTIO"' ____- __-. =`~ 7,238.4 6,011.6 40.29 NIPPLE AVA BPL PORTED NIPPLE wlISO SLEEVE ID 2-31" 2.697 7,093 7 252.2 6,022.2 40.26 Reducing XO 2.875 PACKER, Zt29-- -- 7,253.0 6,022.8 40.26 LOCATOR BAKER 80-32 LOCATOR SUB 2.440 __ 7,254.0 6,023.6 40.26 SEAL ASSY BAKER 80-32 SEAL ASSEMLY 2.440 I LocATOR, _ 7,255.0 6,024.4 40.25 PACKER (BAKER MODEL'D' PERMANENT PACKER w!5' SEAL BORE 3.250 ].132 __-_ - -__ _ 7,273.7 6,038.6 40.21 NIPPLE CAMCO 'D' 2.25" NO GO NIPPLE 2.250 SEAL ASSY, _ Zt 34 - -- 7,280.71 6,043.9 40.191808 BAKEK SHEAR OUT 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) _ - --- Top Depth IPERF, ~ 7,129-NI (ND) Top Intl 714'1-7220 ~ Top (ftK8) (flK B) (°) Description Comment Run D t ID (in) 5,927.5 39.76 PACKER BAKER KB PACKER SET INSIDE ORIGINAL 3 5" TBG 1272/2008 2.250 7,23A.3 6,011.6 40.29 SLEEVE ISO SLEEVE SET IN PORTED NIPPLE 9/5/1997 2.310 SLEEVE 7.238 - ~` ~ ~~ -__-- NIPPLE. 7.238 - Per'fOratlOn$ I Shot Top (TVD) Blm (TVD) Dens To f1K8 Blm (ttK6) (ftK8) (ftK8) Zone Date (sh... Type Comment __ LocATOR. 1 P ( 1 7,220.0 5,939.1 5,9977-C-1 C-3,C-0, 11/22!1985 12 OIPERF 120 tleg phase; 5' Csg Gun 7,144.01 7.2s3. t ..:~ 3A-06 ~ SEAL Assv, 7,340.0 7,362.0 6,089.5 6, 106.2~A-3, 3A-06 11/22/1985 ~' 4.0 IPERF 90 deg. phase; 4' Csg Gun 7294 ':. .' PACKER. 7255 7,341.0 7,381.(7 ~, 6,090.3 6,105.5 A-3, 3A-06 6/14/2008 6.0 RPERF 2 1/8" PEJ.+!-45 DEG I. :_-. -. _.- __° I Mandrel Details iTop Depth Top ~ PoA NIPPLE 7.214 ~ (NDI Intl OD I Valve Latch Sze TRO Run, Stn TOp (ft KB) I (ttK6) '~ (°) Mak Model (in) Serv ~ Type Typa (in) (p ) Run D to Com_m... i 1 6,827.1 5,697.8140.79 CAMCO MMG 1 1/2 INJ 'DMY IRK 0 00 12/25!2008 '39.71 CAMCO MMM 1 1!2 INJ IiOPEN ~I 0 0.0 12!8/2008 I sos.7,ze~~ 2 7,093.0 5,899.9, IPERF. 1,360-7,362 RPERF, aR 7.3dt~736'. ~ ~ T0, 7.6 3A-06 (PTD#185-222) Administra~Approval Cancellation • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, January 05, 2009 10:16 AM `\~~ i'u~~Ze~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay; Fleckenstein, Robert J (DOA); NSK Well Integrity Proj Subject: RE: 3A-06 (PTD#185-222) Administrative Approval Cancellation Attachments: MIT KRU 3A-06 12-26-08.x1s Jim, As per your request, I have attached the form for the post workover MIT's performed on the 3A-06 on 12/26/08. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ,. ,. ~ ~y __ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, January 05, 2009 9:52 AM To: NSK Problem Well Supv Subject: RE: 3A-06 (PTD#185-222) Administrative Approval Cancellation I can take action on this now if you send me the MITT and MITIA performed 12/26; otherwise, I will wait until I receive Inspector's witnessed MiT {whenever it is performed). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, January 03, 2009 3:26 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Edwards, Reid T; NSK Problem Well Supv Subject: 3A-06 (PTD#185-222) Administrative Approval Cancellation Jim/Tom, On 07/28/06, AOGCC granted administrative approval (A10 26.008) to CPAI to continue water only injection in Kuparuk 3A-06 (PTD#185-222) Administra~ Approval Cancellation ~ Page 2 of 2 injector 3A-06 (PTD# 185-222) with known TxIA communication. On 12/14/08, a rig workover was completed which replaced the production tubing and inner casing packoffs in an effort to eliminate the source of communication. The well passed a post workover MITT and MITIA on 12/26/08 and has been returned to injection. ,, CPAI intends to: o Cancel the administrative approval ~ o Return the well to normal status ~ o Remove the well from the "Monthly Failed MIT Report" Attached is an updated 90 TIO plot and wellbore schematic. «3A-06 Wellbore Schematic.pdf» «3A-06 TIO Plot.ppt» / A State witnessed MITIA will be scheduled once injection is stabilized. Please advise and contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~ ~~ /• A I / / 1/ , /'-''~~~~~ 12/17/08 ~•' S~~umberg~r NO. 5005 Schlumberger -DCS 2525 Gambell Street, Suite 400 Com an Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 r~ti •¢ >' p Y~ ATTN: Beth "~~~ '~'~~ ~ u~~ Attn; Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD a 2X-10 11978476 PRODUCTION PROFILE / - ~ • 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE 9 '~- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE r- 11/28/08 1 1 3K-108 12100466 USIT _ 11/23/08 1 1 3K-30 12097433 LDL _ / -" 11!28/08 1 1 30-01 12097434 LDL -(~ 11/29/08 1 1 1E-04 12097436 LDL ~i' 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE ~ 11/27/08 1 1 i H-16 12096581 PRODUCTION PROFILE ~ 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE L - ( 12102/08 1 1 1 G-O6 12096580 INJECTION PROFILE 12!04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06!08 1 1 3F-O1 12086694 PRODUCTION PROFILE - 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE I ~•-+ 12/08/08 1 1 iJ-102 12086701 INJECTION PROFILE ( - 12/14/08 1 1 1 D-07 12114999 USIT 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE "' ~ ~j 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~" v I J ALASSA OIL A1~TD GAS COI~SER'QATIOI~T CO1rII-II5SION Howard Gober Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 ~"'v ~~5' Re: Kuparuk River Field, Kuparuk River Oil Poal, 3A-06 Sundry Number: 308-431 ~~ ~~ - ~ ~~ 2i~~ Dear Mr. Gober: 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, 22 f~ DATED this J day of December, Daniel T. Seamount, Jr. Chair 2008 Encl. ~~1 STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ VClaiver, ^ Other ^ _~ Alter casing ^ Repair well /^ ~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 185-222 ' 3. Address: Stratigraphic ^ Service Q ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21443-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS NO ^~ 3A-O6 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): avel ADL 25632 ' RKB 32' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7680' 6352' 7576' 6270' Casing Length Size MD TVD Burst Collapse CONDUCTOR 72' 16" 104' 104' SURFACE 3374' 9-5/8" 3406' 3178' PRODUCTION 7636' 7" 7668' 6343' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7144'-7220', 7340'-7362', 7372'-7420', 7444'-7450' 5939'-5998', 6090'-6106', 6114'-6150', 6169'-6174' 3.5" & 2-7/8" J-55 & L-80 7 ' & 7281' Packers and SSSV Type: Packers and SSSV MD (ft) ~IaSa Baker'FB-1' pkr, Baker'D' pkr t"m 7042', 7255' ~ Camco 'DS' nipple @ 498' ~ 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for ~j 16. Well Status after proposed work: Commencing Operat December 200 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 ~ WDSPL ^ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Engineer Signature Phone 263-4220 Date „ Z~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~JSO~~S~~ ~"~:~~Z ~~v~ ~~~ '~S~ Subsequent Form Required: 1..~~trl •"~~~ ~~ ~ ~~ ~ ~~~ ~~~~ APPROVED BY l I ~ Approved by: COMMISSIONER THE COMMISSION J Date: ` Form 10-403 Revised 06/2066 ~ ~ `~, { (~ ! ~ Submit in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 25, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3A-06 (PTD 185-222). 3A-06 was drilled and completed as a Kuparuk producer in 1985. The well was converted to an injector in 1988. Historically, injection has been dominantly into the C sand. ConocoPhillips has been investigating ways to get more injection into the A sand while still injecting into the C sand. Several ConocoPhillips personnel along with Weatherford developed a Downhole Injection Intensifier that will help increase A sand injection. The system consists of a downhole pump that boosts pressure for the A sand injection. 3A-06 will be the first test of this technology. The well currently has a tubing leak, so a primary objective of the workover will be to restore ~ tubing integrity by changing out the tubing string. Anew packer will be installed along with the Downhole Injection Intensifier to alleviate any possibility of a packer leak. There is some evidence of a one-way packer leak, but it has not been positively confirmed. Anew packer will be run just in case. The well does pass a combo MIT, so the production casing is good. The installation will also include pressure gauges to monitor C sand and A sand pressures during injection. On the proposed schematic, A sand injection will be through the 1.5" tubing string, and C sand injection will go through the MMM injection mandrel (letter G on the diagram). If you have any questions or require any further information, please contact me at 263-4220. Sincerely, .,~ Howard B. ober Wells Engineer CPAI Drilling and Wells • Ku pa ru k 3A-06 General Workover Procedure Pre-riq Work 1. Apply for Sundry 2. Set KB packer in 3.5" tubing below the C sand injection mandrel. General Workover Procedure Major steps: 1. MIRU Nordic #3 rig. 2. Pull BPV. Kill well with 12.1 ppg formate brine. Reset Bpy~ la ~} 3Soc~ l~~.'' 3. ND tree, NU and test 11" 5M BOP to 250 psi. The well has been shut in since July 14, 2008 and the current tubing pressure is 1400 psi. MASP based on 0.1 psi/ft gradient is 2953 psi. 4. Pull BPV. Pull and lay down 3-1/2" tubing. 5. RIH with FHL packer and PBR on new 3-1/2" L-80 tubing string. Stab into existing PBR and set new packer. 6. RU slickline. Pull ball and rod and RHC plug. Tag seal bore above KB packer for depth correlation. 7. Begin POOH. Set storm packer. ND BOP. Change tubing head to FMC Gen5. NU and test BOP. Pull storm packer. 8. POOH with tubing. 9. MU 1.5" tubing on bottom of seal assembly and downhole injection intensifier. MU gauges and attach TEC wire to outside of tubing. RIH on tubing. 10. Sting 3.5" seal assembly into PBR and 1.5" seal assembly into KB packer seal bore. Run isolation sleeve into downhole injection intensifier housing. Monitor pressure to ensure A and C sands are isolated from each other. 11. Pull up. Load IA with corrosion inhibited brine. Space out and land 3-1/2" tubing. 12. Pull isolation sleeve with slickline. Run the upper packer test tool on slickline. PT tubing to 3000 psi. MIT IA to 3000 psi. 13. ND BOP, NU and test tree. Freeze protect tubing and IA. 14. RU slickline. Pull upper packer test tool. Set downhole injection intensifier pump. Set BPV. 15. RDMO Nordic 3. Post-Rig Work: 1. Pull BPV. 2. RU slickline. Recover formate brine. Ensure IA is loaded with corrosion inhibited fluid or diesel. Pull upper packer test tool. Replace SOV with DV. Set downhole injection intensifier pump. 4. Modify S-riser if necessary. 5. Return to injection. ~~~~~~~h~~~~~ ~ ~1 Well Attributes 1""' Welllwre aPnUWI Fleld Name Well status Proaln) Wen (ype ' / ° 500292144300 KUPARUK RIVER UNIT INJ ~ ._____________._.._ _...._.. Comment H2S Date Annotation End Date IPPmI ~~- _ . SSSV: Nipple 0 7/1/2008 jLast WO: 9/511997 ~ ~~ ~ .,_ ,~~ .. ,... ... ;,.3i _ - _ Annotation Depth (RKB) End Date Annotation ~!..~ ;t Tag: 7.475.0 8/3/2008 Rev Reason: UPDATE AVA BPL ID SIZE Casing Strings CONDUCTO , J ~ ~ ~ I R ~ . NIPPLE, 7,001 3A-06 11'J MD (Neal TG (max( (h.. 43.55 4,600.00 7,680.0 10/16YZ008 Casing Description String OD ~ String ID Pn) i lin) Top (RKB) Set Depth (RKB) Set Depth (TVD) (RKB) StNng Wt (Ibc/R) String Grade String Top Thrd CONDUCTOR 16 15.062 0.0 104.0 104.0 62.58 H-40 SURFACE 95/8 8.765 0.0 3,406.0 3,178.2 36.00 J-55 PRODUCTION 7 6.151 0.0 7,668.0 6,342.5 26.00 J-55 Other In Hole (All Jewelry: Tubing Run 8. Retrievable, Fish, etc.) Top (RKB) , ep ~epm (1VD1 (RKB) Top Inel (°) Description Comment Run Date ID lin) 498.0 498.0 0.25 NIPPLE Camco'DS' Nipple NO GO 9/5[1997 2.812 6,956.0 5,795.5 40.67 GAS LIFT CAMCOIMMMII.S/DMY/RK!// Comment: STA 1 9/11/1997 2.920 7,001.0 5,828.9 39.57 NIPPLE Camco 1M Nipple 9/511997 2.812 7,042.0 5,860.6 39.63 PACKER Baker'FB-1' PACKER 915/1997 4.000 7,045.0 5,862.9 39.64 SBE Baker SBE 9/5/1997 4.000 7,093.0 5,899.9 39.71 INJECTION CAMCO/MMMI1.5/DMY/RIVI/ Comment: STA 2 9/11/1997 2.920 7,238.0 6,011.4 40.29 NIPPLE AVA BPL PORTED NIPPLE 1 9/611997 2.697 7,238.0 6,011.4 40.29 SLEEVE J AVA 2.75" BPC (NEW STYLE) 8111/2008 2.310 7,255.0 6,024.3 40.25 PACKER Baker'D' PACKER 9/511997 3.250 7,274.0 6,038.8 40.21 NIPPLE Camco'D' Landin® Nipple NO GO 915/1997 2.250 7,281.0 6,044.2 40.19 SOS Camco 9/5/1997 2.441 7,281.0 6,044.2 40.19 TTL 91811997 2.441 tes: General & Safety • Well: 3A-06 API: 50-029-21443-00 Y IC3~P~lip5 Field: Kuparuk PTD: 185-222 2008 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3'/z' EUE 8rd BPV: 3" FMC ISA Model: FMC Gen3 Converted to Gen 5 this workover CONDUCTOR 16", 62.58 ppf, H-40 SURFACE CASING 9-5/8", 36 ppf, J-55 PRODUCTION CASING 7", 26 ppf, J-55 TUBING 3'/2', 9.3 ppf, L-80, 8rd EUE Mod, 0' - 7252' (new this workover) 2-7/8", 6.5 ppf, L-80, EUE Srd Mod, 7252' - 7281' (existing) 1.5", L-80, IJ 10rd, 7030'-8015' (new this workover) PERFS 7144' - 7220', C sand 7340' - 7362', A sand 7372' - 7420', A sand 7444' - 7450', A sand H NEW COMPLETION A: Landing Nipple: 2.875" DS profile +/-500' MD B: Gas Lift Mandrel; No. MD TVD TYPE 1 6940 5783 1-1/2" MMM C: Weatherford Downhole Injection Intensifier pump with 2.813" X nipple in top. 1.5" tubing extending out the bottom PBR, stack packer, and poorboy overshot @ 7030' RKB E: Nipple: 3'/2' with 2.813" DS profile F: Packer: FB-1 packer and seal bore extension (exisiting) G: Injection Mandrel: MMM (existing) with 5/8" ID injection valve H: Packer: 2-7/8" KB Packer with seal bore on top 1: Injection sleeve: AVA Nipple with BPI sleeve installed (existing) J: Packer: Model D packer F: Nipple: 2-7/8" with 2.25" D profile Last Tag: 08/03/06 Tag Depth: 8070' RKB Fill: 45' rathole TD: 8550' RKB Last Updated: 24-Nov-08 Updated by: HBG • • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907) 245-8952 1 ] Caliper Report 26-0ct-08 3A-06 1 Report/EDE 50-029-21443-00 2] Caliper Report 23~Octr08 1 R-14 1 Report /EDE t~sS-cS-t I ~~5, C~ZC cuss =2~~ - l~-~6 Signed Print Name: ~,~~~t ~.~~ Nl~c_-~.c 10 50-029-21386-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL: via,,~~~3.~i77?3~°iC~:?°i;'ivf`-i~'J~.+r,~fT, WEBSITE:'~'r•PP;/,:i,2Yi:Ci'?/~v:a.CL~'i3 ~ C:\pa,.uments and Settings\Owner\Desktop\Transmit_Conoco.doc `1 r L~ I~ • • Memory Multi-Finger Caliper S Log Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 3A-06 Log Date: October 26, 2008 Field: Kuparuk Log No.: 6252 State: Alaska Run No.: 1 API No.: 50-029-21443-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 8RD MOD Top Log Intvl: Surtace Pipet Use: Tubing Bot. Log Intvl: 7,258 Ft. (MD) ' Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ' This caliper data is tied into the 3.5" `HES'X-Nipple @ 7,424' (Drill's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage prior ' to Pre-RWO operations. The caliper recordings indicate the 3.5" tubing is in good condition, with the exception of a 34°~ wall penetration in joint 39 (1,234'). No other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded. The comparative severity of the isolated pit in joint 39 (1,234.4') with the condition of the rest of the 3.5" tubing and the proximity of the damage to the location of the tubing hole (1,236'} reported in the Nitrogen Video LDL (8/25/2003) suggests the two events are the same. A 3-D log plot of the caliper recordings across this interval is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pitting (34%) Jt. 39 @ 1,234 Ft. (MD) No other significant wall penetrations (> 19%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 5%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: D. Cain Analyst: M. Lawrence Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) ar (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~ memorylog.com Prudhoe Bay Fieid Office Phone: (907) 659-2307 Fax; (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot ~, .~_. ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3A-06 Date : October 26, 2008 Description : Detail of Caliper Recordings Across Area Nitrogen Video Log Indicated Tubing Hole • • Correlation of Recorded Damage to Borehole Profile ' Pipe 1 3.5 in (7.5' - 7251.7) Well: 3A-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: October 26, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 12 780 1551 2326 3099 p 3867 s Q Ql 4642 5416 6183 GLM 1 6972 INJ M 2 232.5 7252 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 232.5 1 25 50 f ;, a \~; 75 100 v z 125 Y C_ O 150 175 200 f- r "2'15 • • PDS Report Overview ~~ SW Body Region Analysis Well: 3A-06 Survey Date: October 26, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°!o wall) ~ penetration body ~: metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 8$% 85% Number of ~oints anal sed total = 244 pene. 2 195 46 1 0 0 loss 105 139 0 0 0 0 Damage Configuration (body ) 20 10 0 isolated general Gne ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 24 19 2 3 0 0 Damage Profile (% wall) ~ penetration body ;r metal loss body 0 50 100 n ('IM 1 INJ M 2 Bottom of Survey = 232.5 Analysis Overview page 2 • i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD MOD Well: 3A-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 26, 2008 Joint No. Jt. Depth (Ft.) I'c~n. 111>sc~t Um.j Pen. Body (Ins.) I'c•n. °,4, ~I~•t,,l I oss `;'~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 7 u 0.01 4 I 2.96 PUP 1 12 a 0.02 `~ t 2.91 1.1 43 t1 0.02 Es I 2.9 PUN 1.2 51 a 0.03 1 ~ 2.90 PUP 2 59 U 0.01 5 I 2.92 3 89 U 0.01 -3 I 2.91 4 120 I) .01 (~ I 2.91 5 150 I I 0.02 ~~ ~ ~ .92 6 181 ll 0.01 4 I 2.92 7 212 ~I 0.01 6 1 2.92 8 241 i ~ 0.02 ~~ 1 2.92 9 2 72 n 0.03 111 _' 2.92 10 303 ~ ~ 0.02 `> I 2.91 11 333 ~ I 0.01 ~ 2.91 12 364 ~ ~ 0.02 7 i ~ 2.92 13 395 t) 0.02 i ~~ 2.92 14 426 a 0.02 9 tl 2.92 15 456 ~ ~ 0.01 6 I 2.92 15.1 487 t~ 0.03 1O 5 2.97 PUP 15.2 492 ~ ~ 0 t I ~ ~ 2.81 'DS' N' le NO GO 15.3 494 a 0.01 z u 2.89 PUP 16 500 ~) 0.01 4 I 2.92 17 531 U 0.04 14 1 2.93 Shallow ittin . 18 562 ~ ~ 0.02 £3 3 2.93 1 593 ~ ~ 0.0 <~ I 2.90 20 624 ~I 0.02 7 ! i 2.91 21 655 a 0.01 r., I 2.92 22 686 U 0.01 5 ~~ 2.91 23 717 U 0.02 ~ u 2.91 24 749 (1 0.02 ~) i~ 2.92 25 780 U 0.03 11 ~ 2.92 26 811 l1 0.01 5 ~ 2.90 27 842 U 0.02 £i _' 2.91 28 873 ~ I 0.02 7 i ~ 2.92 29 904 ~ I 0.02 £3 I 2.92 30 934 ~ ~ 0.01 ~t ~' 2.91 31 964 U 0.02 ~~ 1 2.91 32 995 t~ 0.02 ~i I 2.91 33 1025 I~ 0.03 1c) I 2.92 34 1056 U 0.01 5 2.91 35 1087 ~~ 0.02 £~ I 2.93 36 1116 l~ 0.02 ~> _' 2.92 37 1147 ~) 0.02 ~~ I 2.91 38 1177 a 0.02 ') I 2.92 39 1208 t) 0.09 i4 ! 2.91 Isolated Pittin . 40 1239 ii 0.03 1lJ 1 2.93 41 1270 ~~ 0.02 ~) I 2.92 42 1302 ~ I 0.02 £3 ? 2.92 43 1333 n 0.01 (~ 2.91 44 1364 ~ ! 0.03 I . 2.92 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD MOD Well: 3A-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 26, 2008 Joint No. Jt. Depth (Ft.) Ncn. UhsF~l (In,.) Pen. Body (Ins.) I'~~n. °i~> ~~1c~tal I rya ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 45 1395 U 0.02 9 _' 2.92 46 1426 ~) 0.03 l n 2.92 47 1457 ~) 0.02 - 2.91 48 1488 a 0.02 is 2.92 49 1520 ~) 0.02 ~ ~ 2.92 50 1551 i) 0.01 -1 2.92 51 1582 ~) 0.02 ti 2.91 52 1613 ~) 0.01 4 2.92 53 1644 11 0.01 ~i ' 2. 54 1676 1) 0.02 tf _' 2.92 55 1707 U 0.01 G ? 2.91 56 1739 O 0.02 1 2.93 57 1769 ~ ~ 0.02 ') _' 2.92 58 1800 ~ ~ 0.02 7 2.94 59 1831 I) 0.03 1 1 2.9 60 1862 ~) 0.02 t9 _' 2.94 61 1893 ~) 0.02 8 1 2.95 62 1924 ~) 0 01 ~ 1 2.92 63 1956 t) 0.01 5 ~' 2.93 64 1987 a 0.01 4 2.9 65 2018 1) 0.02 9 2.91 66 2049 a 0.03 1O I .93 67 2080 a 0.03 1l) I 2.91 68 211 1 ~) 0.03 1 u I 2.94 69 2142 )) 0.02 ~> _' 2.9 70 2173 ~~ 0.03 11 _' 2.92 71 2205 ~) 0.03 I I I 2.92 72 2234 a 0.02 tf I 2.91 73 2263 U 0.02 t3 2.94 74 2294 O 0.02 ~~ 2.90 75 2326 c) 0.02 t3 I 2.95 76 2356 ~) 0.03 1 I I 2.92 77 2387 ~) 0.02 £3 I 2.92 78 2418 ~ ~ 0.02 ~ I 2.96 79 2449 ~) 0.01 5 1 2.91 80 2480 U 0.03 11 )1 2.91 81 2511 O .01 ~ 1 2.92 82 2 541 1) 0.02 F9 ~) 2.92 83 2572 1) 0.01 b 1 2.91 84 2603 ~t 0.02 7 ~ 2.94 85 2634 ~) 0.01 -1 I 2.91 86 2665 U 0.03 I ; I 2.91 Shallow ittin . 87 2696 ~) 0.03 11 2.93 88 2 72 6 u 0.02 £3 I 2.91 89 2758 a 0.02 ~) ~ 2.91 90 2789 ~) 0.01 2 I 2.94 91 2820 ~~ 003 I i Z 2.91 Shallow ittin . 92 2851 ~ i 0.03 l U I 2.91 93 2882 0.02 7 f 2.92 94 2912 0.01 Z ~ 2.92 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD MOD Well: 3A-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 26, 2008 Joint No. Jt. Depth (Ft.) I'~~n. LII~E~t (ln~.) Pen. Body (Ins.) P~~n. `;4, M~~lal Irris `%, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2943 a 0.03 11 1 2.90 96 2974 c i 0.02 8 2.93 97 3004 U 0.01 4 I 2.93 98 3036 t~ 0.02 2.89 99 3068 O 0.02 t3 I 2. 2 100 3099 U 0.03 13 ' 2.9 Line shallow corrosi n. 101 3129 t) 0.02 - 2.93 102 159 (J 0.00 I 2.91 103 3189 U 0.02 '~ 2.91 104 3220 t~ 0.02 7 1 .91 105 3252 t~ 0.03 1 ~ ~' 2.9 Shallow ittin . 106 3283 it 0.03 13 2.93 Shallow ittin . 107 3313 (~ 0.03 10 2.91 108 3344 t ~ 0.03 t U 2. 2 109 3375 n 0.02 t3 I 2.92 110 3404 ~ ~ 0.0 ~) ~' 2.91 111 3435 a 0.03 I (1 <' 2.91 112 3465 U 0.02 t3 ' 2.92 113 3497 (~ 0.02 t3 I 2.92 114 3528 it 0.03 I1 2.91 115 3560 a 0.02 ti 2.91 116 3590 l ~ 0.02 ~ ~ 2.91 117 3622 t~ 0.02 ~~ U 2.91 118 3653 () 0.02 ~ ? 2.91 Lt. De osits. 119 3683 a 0.01 5 I 2.93 120 3715 i~ 0.02 ~3 I 2.92 121 3745 t? 0.01 Z 2.91 122 3775 t i 0.02 8 ~ 2.93 123 3806 U 0.03 1 "3 ' 2.92 Sh Ilow ittin . 124 3838 i~ 0.02 ti I 2.94 125 3867 (I 0.03 13 _' 2.93 Shallow ittin . 126 3898 (~ 0.03 I ~' ~' 2.91 127 3930 U 0.01 4 1 2.91 128 3961 tt 0.02 9 ~' 2.92 129 3991 i) 0.01 5 ~' 2.90 130 4023 U 0.04 14 2.90 Line shallow corrosion. 131 4054 a 0.02 i Z 2.92 132 4084 0 0.02 £3 2.93 133 4116 0 0.0 f3 ..' .92 134 4146 0 0.01 ~ _' 2.91 135 4178 t~ 0.01 (~ ~ 2.94 136 4208 (1 0.02 ~i ~ 2.91 137 4239 t> 0.02 8 ? 2.91 138 4270 t~ 0.01 U ' 2.92 139 4300 U 0.03 111 3 2.91 Lt. De osi 140 4332 i ~ 0.02 7 I 2.92 141 4363 U 0.02 8 ' 2.92 142 4393 (~ 0.03 1 Z Z 2.90 143 442 5 0.02 I 2.94 144 4454 0.02 ~ ' 2.91 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD MOD Well: 3A-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 26, 2008 Joint No. Jt. Depth (Ft.) P~•n. Ul,s,~l (Ins.) Pen. Body (Ins.) Pen. %, Mel,il Ices Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4485 t~ 0.01 Z I 2.91 146 4516 (~ 0.02 ~) I 2.91 147 4549 c ~ 0.02 7 ~ 2.94 148 4579 !~ 0.02 7 t~ 2.92 149 4610 ! I 0.01 ~ ! I 2.94 150 4642 ! ~ 0.03 1 t ~ ~ 2.91 151 467 !) 0. 2 9 ~' 2.90 152 4703 a 0.01 4 ~ 2.91 153 4734 U 0.02 ~) U .90 154 4765 a 0.02 ti 2.92 155 4795 !~ 0. 4 15 ~ 2.91 Shallow ittin Lt. De sits. 156 4827 t~ 0.02 ~~ I 2.92 157 4858 t) 0.01 5 2.91 158 4889 a 0.02 9 _' 2.91 159 4920 t! 0.02 t3 •] 2.90 160 4951 U 0.02 '~ I 2.94 161 4981 (1 0.03 1 U I 2.90 162 5013 t~ 0.0 t9 2.91 163 5044 (~ 0.03 I U 2.91 164 5076 t> 0.02 t3 _' 2.91 165 5106 a 0.02 '~ ~~ 2.92 166 513 7 ! I 0.02 ~) 2.90 167 5169 ! 1 0.03 I 1 2.91 168 5200 ! ~ 0.00 1 t ~ 2.91 169 52 31 ~) .01 6 1 2.91 170 5262 (~ 0.02 t3 2.92 171 5292 U 0.02 ~) 2.91 172 5324 !) 0.03 1 ~' _' 2.94 173 5354 U 0.02 i 2.91 174 5384 l) 0.02 ~ ? 2.91 175 5416 0 0.02 ti _' 2.91 176 5447 U 0.02 t3 _' 2.92 177 5478 ! ~ 0.03 1 l I I 2.93 178 5508 ! I 0.04 1 2.91 Shallow ittin . 179 5537 a 0.01 t, I 2.90 180 5569 ! I 0.01 ~ .' 2.90 181 5599 a 0.04 I -t _' 2.89 Shallow ittin . 182 5630 ! ! 0.01 -1 2.90 183 5661 t > 0.01 E~ ~ 2.90 184 5692 t) 0.01 ~' 2.91 185 5722 a 0.02 ~1 2.89 186 5753 U 0.03 It) ~ 2.90 187 5783 t! 0.04 1(, .91 Shallow ittin . 188 5812 (I 0.02 ~~ _' 2.90 189 5843 t ~ 0.01 S I 2.91 190 5875 t I 0.03 1 1 2.91 191 5906 ! ~ 0.01 5 ! ~ 2.93 192 5937 t? 0.01 6 _' 2.91 193 5965 !~ 0.03 11 ~ 2. 9 194 5997 ! ~ 0.03 1 l) ~ 2.93 _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD MOD Well: 3A-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 26, 2008 Joint No. Jt. Depth (Ft.) I'~~n. UI>«~t (In..) Pen. Body (Ins.) I'c>n. °~~ ~k~i,~l I<~cs .~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 195 602 9 t 1 0.0 7 ~ 2.91 196 6059 t l 0.03 1 1 I 2.90 197 6090 U 0.04 1 ~ 2.91 Shallow ittin . 198 6122 U 0.03 11 2 2.90 199 6153 !) 0.02 8 2.88 Lt. De osits. 200 6183 ! 1 0.01 b 1 2.93 201 6213 U 0.02 7 2.91 202 6243 a 0.02 9 2.90 203 6274 ~~ 0.02 ~) 2.91 204 6306 !) 0.02 8 I 2.91 205 633 !i 0.04 14 ~' 2.90 Shallow ittin . 206 6368 t i 0.05 I ~? 2.92 Line shallow corrosion. 207 6399 U 0.03 I.S ~ 2.90 Shallow ittin . 208 6429 a 0.02 ~~ I 2.91 209 6459 !! 0.02 ti _' 2.90 210 6490 ! ? 0.02 ~ ! ~ ~ 2.90 211 6521 ! i 0.02 - 2.91 212 6550 !i 0.02 ~~ 2.89 213 6581 ! ~ 0.01 <1 2.91 214 6612 t) 0.01 2.92 215 6643 U 0.01 b _' 2.90 216 6674 U 0.02 2.89 217 6705 U 0.02 9 ~ 2.90 218 6736 (~ 0.02 7 I 2.91 219 6768 !~ 0.03 13 ' 2.91 low ittin . 220 6799 ! ~ 0.02 ti i 2.93 221 6829 !~ 0.03 I 2.91 Shallow ittin . 222 6862 U 0.05 1 ~) ? 2.92 Shallow ittin Lt. De sits. 2 3 6891 ! ~ .02 ~~ ? 2.90 224 6922 i~ 0.03 13 1 2.87 Shallow corrosion. Lt De osits. 224.1 695 U 0.03 I? 1 2.93 PUP 224.2 6959 t~ 0 !I u N A GLM 1 Latch ®1:30 224.3 6966 a 0.03 I u ' 2.89 P P 225 6972 t) 0.04 14 _' 2.91 Shallow ittin . 25.1 7004 l) 0 0 U N A W-Ni le 226 7006 U 0.03 1 ~' 2.92 226.1 7036 !1 0 t1 U N A Baker'FB-1' Packer 226.2 7043 ~) 0 t) !i N A SBE 2 7 7055 !) 0.02 ~ I 2.93 227.1 7087 !~ 0.03 11 1 2.93 PUP 227.2 7093 ti 0 0 t) N A In'. Mdrl 2 Latch ~ 6:30 227.3 7102 a 0.03 1l) 1 2.92 PUP Lt De sits. 228 7108 tt 0.03 11 1 2.92 229 7138 !! 0.01 Z tt 2.94 Blast oint. 230 7158 !i 0.01 2 t~ 2.94 Blast oint. 231 7178 a 0.01 2 t! 2.92 Blast oint. 232 7198 U 0.01 3 U 2.94 Blast oint. 232.1 7218 ti 0.02 f3 c) 2.93 PUP Blast oint. 232.2 7228 0.02 t~ I 2.89 PUP Blast oint. 232.3 7238 0 ! ~ ~ ~ N A AVA BPC Sleeve on AVA BPL Ported Ni le _ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD MOD Well: 3A-06 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 26, 2008 Joint Jt. Depth I'c•n. Pen. f'c•n. ~1~•t.~l Min. Damage Profile No. (Ft) UI>~~~i Body % Ic~ss LD• Comments (%wall) Iln~.) (Ins.) `iii (Ins.) 0 50 100 232.4 7241 ~ ~ 0.03 I 1 U 2.89 PUP Shallow c rro ion 232.5 7252 i~ 0 0 U N A 3.5" x 2.875" Cross-Over _ Penetration Body Metal Loss Body Page 6 ~~ PDS Report Cross Sections Well: 3A-06 Survey Date: October 26, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 "Dubin 3.5 ins 9.3 f -55 8RD MOD Analyst: M. Lawrence Cross Section for Joint 39 at depth 1234.433 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 Tool deviation = 7 ° Finger 19 Penetration = 0.086 ins Isolated Pitting 0.09 ins = 34% Wall Penetration HIGH SIDE = UP s Cross Sections page 1 GolnocoPhillips Alaska, Inc. KRU 3A-06 3A-O6 API: 500292144300 Well T INJ An le TS: 40 de 7142 NIP (498-499 SSSV Type: Nipple Orig COm letion: 10/19/1985 Angle @ TD: 39 deg @ 7680 , OD:3.500) Annular Fluid: Last W/O: 9/5/1997 Rev Reason: Set SLEEVE Reference L Ref Lo Date: Last U ate: 3/28/2008 Last Ta : 7393' SLM TD: 7680 ftK6 Last Ta Date: 11/26/2007 Max Hole An le: 44 d 4600 TUBING (o-7z5z, Casin Strin -ALL STRI NGS OD:3.500, Descri tion Size To Bottom TVD Wt Grade Thread ID:z.ss2) CONDUCTOR 16.000 0 104 104 62.58 H-40 SUR. CASING 9.625 0 3406 3178 36.00 J-55 PROD. CASING 7.000 0 7668 6343 26.00 J-55 Tubin Strin -TUBING Size To Bottom ND Wt Grade Thread Gas Lin ,r,~~p,,,,,my 3.500 0 7252 6022 9.30 J-55 8RD MOD vaMe 1 2.875 7252 7281 6044 6.50 L-80 EUE-ABM (ss56-ss57, oD:s o1s) Perforations Summa . Interval TVD Zone Status Ft SPF Date T e Comment 7144 - 7220 5939 - 5997 ~ C-3 C-1 76 12 11122/1985 IPERF 120 de hase~ 5" C Gun 7340 - 7362 6089 - 6106 A-3 22 4 11/22/1985 IPERF 90 de hase~ 4" Cs Gun 7372 - 7420 6114 - 6151 A-2 48 4 11/22/1985 IPERF 90 d hase• 4" Cs Gun 7444 - 7450 6169 - 6174 A-1 6 4 11/22/1985 IPERF 90 de hase; 4" Cs Gun Gas Lift M andrelsNalves St MD ND Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt PKR i 1 6956 5795 Camco MMM DMY 1.5 RK 0.000 0 9!11/1997 (7oaz-7oa3, 151) OD:6 In's ction MandrelsNalves . ~ St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 2 7093 5900 Camco MMM DMY 1.5 RK 0.000 0 9/11/1997 Other lu s ui .etc. -COMPLETION SBE De th ND T e Desori tion ID (7oa5-7046, OD:3 500) 498 498 NIP Camco'OS' Ni le NO GO 2.812 . 7001 5830 NIP Camco'W' Ni le 2.812 7042 5861 PKR Baker'FB-1' 4.000 7045 5863 SBE Baker 4.000 7238 6011 NIP AVA BPL PORTED NIPPLE 2.750 Injection i ndrellDUmmy 7238 6011 SLEEVE AVA BPC SLEEVE; Set 3/11/2008 2.310 vaNe2 7255 6024 PKR Baker 'D' 3.250 (7°e3-7°s4, 7274 6039 NIP Camco'D' Landin Ni le NO GO 2.250 OD 6 018, 72s1 so4a rn 2.441 Pert 7281 6044 SOS Camco 2.441 (717220) Gener al Note s Dete Note 1/13/200 NOTE: WAIVERED WELL: T x IA ANNULAR COMMUNICATION 8/25/2003 NOTE: TBG HOLE 1236' ON NITROGEN VIDEO LOG LDL SLEEVE (7238-7239, OD:2.750) I ' PKR (7255-7256, OD:6.151) NIP ' (72747275, OD:2.875) TUBING (7252-7281, OD:2.875, ID'2441) SOS ~ (7281-7282, Pert (7340.7362) Perf (7372-7420) Pert (7444-7450) ><3~i11'ul1~IJ~FaI _~r NO. 4759 Schlumberger -DCS 2525 Gambell Street, Suite 400 ATTN Beth AK 99503-2838 ~,,~ ~ ~~~ ~~~~ Well Job # Log Description ~. ;' L ' ~ i , a ~ ~ 4 i. ~, ~, ' _._ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 't00 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 iG-14 11964620 INJECTION PROFILE - -- r°; ~"-(c,~ a ~~,~~~E'rp~/ 06/13/08 1 1 3A-16 11964621 LDL '' '" , i~ c ,f ~• F= ~ ~ } 06/14/08 1 1 1 B-14 12061702 LDL ~`=? ?-!-- •?i ~:r "," ~'_ '" 06/15/08 1 1 2N-327 12061704 PRODUCTION PROFILE v=,)~>`"'--• ~r°"-^'=~ ,'j' ,~-°° ~- 06/17/08 1 1 1 B-04 12061705 INJECTION PROFILE , •-'"- o~ ~~ ~ ..., -~'_ :>-°"- +~+',~.~-• ~:aAr1 06/18/08 1 1 2D-05 11964625 INJECTION PROFILE/LDLa ^-~- -.-~ )-., ~'a ^.:9-;~f~, 06/18/08 1 1 1 E-12 11964628 G LS `C~ ' ;? ~-~;9 ~J ! ; ,~ q'. '~ `~' d' 06/20/08 1 1 3A-06 12061708 INJECTION PROFILE •` -• /' ~`~~~' ~: 06/21/08 1 1 2A-OS 11964629 INJECTION PROFILE d~,k~:~ ~~;~ `"zg;~" /~~,~~ `-v~~,~ 06/21/08 1 1 1 L-11 11964630 PRODUCTION PROFILE d" =" --, ~=;'~""' ' 06/23/08 1 1 ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~i L.IJ - V_7 `l I" 10 t1J7V) OLam wiui%,JJGu 1Y1111 t - v pG1 C111J z_".VL"t ragco 1 Vl J Maunder, Thomas E DOA From: NSK Problem Well Supv [n1617 @conocophillips.com) Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TxIA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MAOP %1YP AA # 2C -07 7" 26 ppf K -55 4980 3000 60% AIO 28.007 2G -03 7" 26 ppf J -55 4980 3000 60% AIO 28.014 3A -06 7" 26 ppf J -55 4980 3000 60% AIO 28.008 3A -11 7" 26 ppf J -55 4980 3000 60% AIO 28.022 3A -14 7" 26 ppf J -55 4980 3000 60 %. AIO 26.026 3H -09 7" 26 ppf J -55 4980 3000 60% AIO 28.009 3N -12 7" 26 ppf J -55 4980 3000 60% NA 3N -13 7" 26 ppf J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TxIA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 26.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TAA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 Pager 907 - 659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4:41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 213.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 11/9/2010 t.v -vim kt I" 10 T1J7v) vi.aw w YVi A1V z -".v 1Z z. vi i The AIO 26.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPAI to manage the pressure differently? Jim Regg AOGCC I 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 26.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 /,v -w �r i L 1 ow i .I7v) O uuc wuucaxu 1vn i vri Pvi ruv /.i3.v i - r a ,c vi J Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 213.014. What is CPAI using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Friday, May 16, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G -03 (PTD 1841390) State witnessed MITOA per AID 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 213.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xis>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 11/9/2010 MEM RAND M O U To: Jim Regg ~' ~ ,r, ~ .. { ? j ;"~, ~ P.I. Supervisor ~~` ` ~ ~~ ~ ERONt: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 03, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-06 KUPARLZt RIV UNIT 3A-06 Src: Inspector NON-CONFIDENTIAL ~ ~~~~ ~~~ Reviewed By: P.I. Suprv,~ }g;-~- Comm Well Name: KUPARUK RN UNIT 3A-O6 Insp Num: mitCS071 130075122 Rel Insp Num: API Well Number• so-o29-21443-00-0o Permit Number: 185-222-0 Inspector Name: Chuck Scheve Inspection Date: i 1%292007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ sA-o6 jTypeInj. ~ N ~ TVD ~ 5861 "'! IA_ Ioso 'I use ~ llso ItBO ~ - -- 1852220 ~ SPT P.T. TypeTest I ~, Test psi ~ 1500 f~ OA 150 ~ 1850 ~ 1820 1810 ~ Interval REQVAR p~F P ~ Tllhing ~ 1050 1180 0 ~ 1180 Notes: MITOA ~~~~~ ~~c ~ ~ 2aa~ Monday, December 03, 2007 Page 1 of 1 MEMORANDUM To~ Jim Regg ~'~' _ P.I. Supervisor ~ ~ <~~ cfi ` ~ ~ ~ ~'~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska OiI and Gas Conservation Commission DATE: Monday, December 03, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-06 KUPARUK RIV UNIT 3A-06 Src: Inspector NON-CONFIDENTIAL ~~+ ~~~~ Reviewed By: P.I. Suprv` `~= Comm Well Name: KUPARUK RN UNIT 3A-06 Insp Num: mitCS071130074515 Rel Insp Num: API Well Number: 50-029-21443-00-00 Permit Number: 185-222-0 Inspector Name: Chuck Scheve Inspection Date: 11/292007 Packer Depth Pretest Initial 15 Min. 30 Min. 4S Min. 60 Min. Well ~ 3A-06 Type Inj. ~ N ~ T~7D ~ ~ 5861 it IA ~ 1400 3000 i 2940 I 2920 j ~~~ P.T. ~ Is522 p Test , SPT ~ Test psi '~ 1500 r QA 1400 3000 C ~' I ~ 2940 2920 ~ I I Interval REQVAR P~' P _ TQbI g 150 ~ 0 _ I50 ~ 150 I NOteS: OMIT T x IA.`~A plug was set in the tubing tail below the packer, the IA was pressured up to 3000 psi with the tuging pressure tracking the IA. ~;~ DEC ~. ~ 2fl0? Monday, December 03, 2007 Page 1 of 1 Œ 04/05/07 Sc~lunl~IPue.p RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Oil & Gas Cons. Commission 1\ 1..007 Anchorage cAN"e.o t>. t> R 1," ~d~ UTe... l"ð~-~ Field: Kuparuk Weill Job# Log Description Date BL Color CD 2M.12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1 H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H-02 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331' N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . • ®S~e~S'e~~~~Y®d~ ~.+® s7s~~®dd • FRANK h!. r1AURKOWSKI, GOVERNOR 333 W. T° AVENUE. SUITE t 00 ANCHORAGE, ALASKA 9950?-3539 PHONE (907a 279-1433 cy~ rg07; 276-7542 AD1i~IIVI5TIZ~TIVE APPR®VAL ti®. AID 28.008 ~Ir. Jerry Dethlefs Problem V6'ell Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 9910-0360 RE: KRU 3A-06 (PTD I8~-222) Request for Administrative Approval Dear Mr. Dethlefs: ~:a~!l~~ ,SAN ~ ~ 200 On stay 28, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area Injection Order `'AIO" 2,B to allow continued water injection in service well Kuparuk River Unit `-KRU" 3A-06. The Alaska Oil and Gas Conservation Commission ("Commission"j GRANTS CPAI's request for WATER ONLY service, as detailed below-. 3A-06 was originally reported to have tubing x inner annulus "T x IA" pressure communication in July ?003. An attempt was made to restore mechanics! integrity by placing a patch over the leak, however pressure communication remained. Diagnostic testing determined that the IA pressure communication is likely due to a leak at the packer as well as in the tubing and that a rig workover is necessary to repair the well. CPAI has elected not to perform corrective action on 3A-06 to restore full integrity. The Commission finds that, based upon reported results of CPAI diagnostic procedures, 3A- 06 exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity and will not result in an increased risk of movement of fluids outside the injection zone. Where freshwater is not affected, 20 A.AC 2~.4~0 gives the Commission authority to approve less stringent w-eil integrity and operation requirements. Per Rule 9 of AIO 2B, the Commission hereby grants CPAI's request for administrative approval to continue water injection in KRU l H-07 on the following conditions: 1. Injection is limited to WATER ONLY; v ~'iSTRATi~"E ~PPRO~L A(O NO 2B.008 AD. tI~ Lune 2 i. ?006 Pave Z of 2 2. CPAI shall monitor and record tubing. inner annulus and outer annulus tT1rO) pressures and injection rate daily; 3. CP~.I shall submit to the Commission a monthly report of well pressures and injection rates including any pressure bleed events; ~. CPAI shall perform an Combined Mechanical Integrity Test (CHIT) of the tubing and inner annulus (T x IA} every two years; 3. CPAI shall perform an MIT-OA every two years; b. CPAI shall immediately shut in the well and notify the Commission upon any measurable change in the wells mechanical condition; and 7. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 8. The ~1IT anniversary date is January 3, 2006. As provided in A5 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 far rehearing is considered timely if it is received by x:30 P1~1 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. :~ person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONi~ at N Alaska and dated June 21, 2046. The Alaska Oit and Gas Conservation Commission T. Seamount, Jr. ,~ ,,; /F ~',~f y 'v~r~Il~idi ``~''" ~'~ Cathy Pr`. Foerster Commissioner Commissioner MEMORAND'UM TO: FROM: Jim Regg ~ J/ I }).I. Supervisor i--Ç¿i'¿î 14 O~;J Jeff Jones Petroleum Inspector Well Name: KUPARUK RIV UNIT 3A-06 Insp Num: mitJJ060104084849 Rei Insp Num State of Alaska AlaslŒ Oil and Gas Conservation Commission DATE: Wednesday, January 04, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC 3A-06 KUPARUK RIV UNIT 3A-06 Src: Inspector ;NON-CONFIDENTIAL API Well Number 50-029-21443-00-00 Permit Number: 185-222-0 ) <v C/J--~ \Cb~ Rcviewed By: P.I. Suprv ~2-- Comm Inspector Name: Jetl' Jones Inspection Date: 1/3/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 ,Min. ''"w;ïi."r..·-3"A:.-ö6----Typ;i~i:"T·"N· TVD ·--"T·--"""S"Š"6-i---"·""--· IA '----¡"4"¿O·---··-"·-··"·-";09·Ö··.."-···-·r-·-..··"3080 3070 3070 ......".~""_,_,,_,..__,_...~. ,." .. _~" '...." "'"' .'".._" ... _~,~. ...._.._".. __,,_.. _....,_.__.__"..,...._.____._____......______..._._.......".,_....__..______..~,_"...._..__..,. ,. __._'m_"'_'..,.._.~.."..._,,_.,~...~.. _""..w.".....,,_.. .."'..."...._,,'...,_.. ..,,_, ,'"'' .P.T. 1852220 TypeTest SPT Test 1465.25 OA 0 0 0 0 0 Tubing 3090 .....'.-'--- ~.._" ...~" ,,~.~....." ,_... -........... .",,-,,- - .J!I!~ryªl"...~_~_~~~.~..._........._..PIE.......... p _._._~~.""--,.,,,.,,..~--_..._-,.._.__._----_._.__.._.._.-_..__.-.....__.._...~_.- 1450 Notes Sundry #303-373. 1.2 BBLS diesel pumped. 1 well house inspected; no exceptions noted. Wednesday. January 04, 2006 S(;ANN!EID cUHtJ 1 1 2005 3010 3010 30lO 60 Min. ".. .... ,,_,4..". ,."...,~, .. ..~,... ......",..._",.",-"......,_..,"....... ."..._".'-----.",."._",,"'",. Page I of 1 ) ) .¡¡t.':J~¡i~;~;[~~:;;;;\~;~[:¡::,. ......... .. + <. .. . . . . [¡¡¡¡¡::.: :·:·:~¡:¡¡:;¡:¡:¡;j¡¡¡¡f¡.. ConocoP'bJJhps . Ala$k.a~ Jnc~. .. ~ ..... ..",':¡;¡: ... :3A-06' . .. .. I API: 500292144300 , SSSV Type: Nipple II ~~1 ~ ~ TUBING --~~~--o (0-7252, ~ ~ 00:3.500, i ~ ID.2.992) ~ ) I~ ~ ~ ~ ~ ~ ~~~ :):.:. ~ ..... ~ . ':.: .. ~ ~ ..... ) ~ ~ , ~ SSE· ~------ (7045-7046, ~ 00:3.500) ~ 10J'''00 ---- !~, 0U ~ndrellDummy ~ -.:{::: Valve 2 ~ ':::¡:: . (7093-7094, ~ ~... 00:6.0 18) ~ ~ ._~ -)- =t -~- i-rp¡-1 ~ \.):':..:::::¡ ~ I ¡ I (7255-~~ --~~'.il~::;¡¡ ~ 00:6.151) ~~¡ ~ ¡ ) ~ ~-~ ~ ~ ~ --µ ~ ~ ~ ---~- _.,~ ---=..-!!..- ~ -+ NIP (498-499, 00:3.500) Gas Lift mdrellDummy Valve 1 (6956-6957, 00:6.018) PKR (7042-7043, 00:6.151) Pelf (7144-7220) SLEEVE-O -- (7238-7239, 00:2.750) NIF--- (7274-7275, 00:2.875', TUBING (7252-7281 00:2.875 10:2.441, SO~ (7281-7282, 00:2875) Perf (7340-7362) Perf (7372-7420) Perf (7444- 7450) II .-_..,-"'_._.~.__._-----~---- I I ~ II II ! . .. .. ! . ~ =-~= ~t= -~- ~ j Top Bottom TVD Wt Grade Thread 0 104 104 62.58 H-L~- 0 3406 3178 36.00 J-5,5 0 7668 6343 26,00 J-5;5 TVD Wt Grade Thread 6022 9.30 J-55 8F:D MOD 6044 6.50 L-80 EUE-ABM KRU Well Type: INJ Orig 10/19/1985 Completion: Last W /0: 9/5/1997 Ref Log Date: TO: 7680 ftKB Max Hole Angle: 44 deg @ 4600 Annular Fluid: Reference Log: Last Tag: 7443 Last Tag Date: 7/23/2003 ¡ Casing String - ALL STRINGS ! Description CONDUCTOR SUR. CASING PROD. CASING ·T.ubipg·$tring:~..T.U.BING:.·..:··········"·· Size Top 3.500 0 2,875 7252 : Perforations Summary Interval TVD 7144 - 7220 5939 - 5997 7340 - 7362 6089 - 6106 7372 - 7420 6114 - 6151 7444 - 7450 6169 - 6174 . Gas Lift MandrëlsNålvës St MD TVD Man Man Type Mfr 1 6956 5795 Cameo Injëctión Mandre1sNalves.· ... St MD TVD Man Man Type Mfr 2 7093 5900 Cameo MMM : Other (plugs, eQuip., etc.) - JEWELRY Depth TVD Type 498 498 NIP 7001 5830 NIP 7042 5861 PKR 7045 5863 SBE 7238 6011 SLEEVE-O 7238 6011 NIP 7255 6024 PKR 7274 6039 NIP 7281 6044 TTL 7281 6044 Size 16.000 9,625 7,000 Bottom 7252 7281 Zone C-4,C-3,C-1 A-3 A-2 A-1 Slatus Ft SPF Date Type 76 12 11/22/1985 IPERF 22 4 11/22/1985 IPERF 48 4 11/22/1985 IPERF 6 4 11/22/1985 IPERF VOD Latch V Mfr V Type DMY V Mfr V Type DMY MMM 1.5 RK 0,000 VOD Latch Port 1.5 RK 0.000 Descripti~ Cameo 'OS' Nipple NO GO Cameo 'W' Nipple Baker 'FB-1' Baker AVA BPC SLEEVE; Seton 1/26/04 AVA BPL PORTED NIPPLE Baker '0' Cameo '0' Landing Nipple NO GO 3A-06 An~@ TS: 40 deg.Jâ) 7142 Angle @ TO: 39 deg @ 7680 Rev Reason: Pull Plug, Set BPC Last Update: 1/29/2004 Comment 120 deg phase; 5" Csg Gun 90 deg. phase; 4" Csg Gun 90 deg..:...~se; 4" Csg Gun 90 d~g,,:,2.b_~se; 4" Csg Gun Port -Date Run 9/11/1997 Vlv Cmnt TRO o TR 0 Date Run L~lli1997 Vlv Cmnt ID 2.812 2.812 4.000 4.000 2.310 2.750 3.250 2.250 2.441 2.441 Date Note 11/13/2002 WAIVERED WELL: T x IA ANNULAR COMMUNICATION 8/25/2003 TBG HOLE @ 1236' ON NITROGEN VIDEO LOG LDL --.-------.--"----- ----_.~-_._------,--_.-..,.---...,.....--_._. ----..----....---.--. ~ { MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: JimRegg ~¡ \ 1'2e:/M' DATE: January 19, 2004 P.I. Supervisor. ( SUBJECT: Mechanical Integrity Test Conoco/Phillips Kuparuk River Unit KRU 3A-06 FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL V P P Type Test Interval M= Annulus Monitoring 1= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details Tbg. patch set @ 1200'. TBG & IA pressure tracked while test performed. ~TOA passed MIT 12-26-03. .- ptA..k.~ (,tfl Su£ceç5k--t .bC{5e& {)Y\.. ~; (t:Û ~ iti j 103 ::J73(Z-- (/&;104- M.I.T.ls performed: 1 Number of Failures: Q Total Time during tests: 2 hours Attachments: cc: ~.'(r-'(-.' \~ I^\\¡t^\\¡~;;:.'-'lï.'.. Ij ,lilll\\i f)¡ Cì r¡ê~O~å ",!>vf'~~~ô~&;;.Q.. 0dh to? 'iJJ LUJt u MIT report form 5/12/00 L.G. 2004-0119_MIT _KRU_3A-06-.ic.xls 1/20J2004 f ( VIC File Review Date: December 17, 2003 Subject: CPA I KRU Well3A-06 PTD#: 185-222 403-303-373 Orders: AlO 2B I ~~ Tom Maunder, P.E. ~ Reviewers: Initiating Action: Application for Waiver to Continue Injection with T x IA Communication Review Summary 1. This well was drilled in October 1985. 2. Nothing remarkable is reported for either hole section and both casing strings were run and cemented successfully. Cement is not reported to surface on the surface casing, but no top job was performed. 3. There is no report of the well being Arctic Paked, although it is stated in the permit application that the OA would be after disposing of drilling waste. 4. It is reported that a CBL was run 11/05/85. I have performed the MIT II spreadsheet calculation and sufficient cement was pumped. I was not able to locate the bond log in the log files. John Boyd performed a MIT Part II in January 1988. His calculations are correct and he notes that "Adequate bonding appears above the perfs". 5. The well was fracture stimulated in December 1985 prior to being placed into production. No problems were reported. 6. In October 1987, a 403 was submitted proposing to convert the well to water injection service. 7. There is a report of the initial witnessed MIT, 11/14/88. 8. In August 1993, the well was refraced. 9. The well was worked over in September 1997. There is a 404-work report in the file, but it there is no 403. 10. The well passed an unwitnessed MIT after the workover. John Crisp witnessed a successful MIT on July 21,2001. 11. On 7/1/03, Problem Wells reported that the well failed a MIT IA and had been freeze protected and SI. 12. In early September, CPAI submitted a 403 (303-262) to repair the communication problem with a tubing patch. Initial indications were that the patch was successful, however the well failed a witnessed MIT in early November. CP AI requested to keep the well in service pending further repaIrs. 13. CP AI has determined that further patching is not appropriate and in the latest sundry has proposed to keep the well in water only service, submit the monthly monitoring information and perform a MIT-IA every 2 years. Review Conclusions: .-' .. . . ',' '-'-.'" DEC" ~ ~ 2003 ( .:' I.'" ""'J';"': I ,I , . " .., ." . " I \~, \..".. ~'.' , ."'-" ~ '- ~ ¡.. '~ 'I ( , 1. No problems were reported drilling any hole section or cementing any casing, It is not clear if the surface casing was cemented to surface. 2. A bond log was run in the 7" casing and an MIT II analysis was performed in January 1988. Based on the volume pumped, more than sufficient cement was pumped, The bond log was not in the log file. According to the 1988 MIT II, "Adequate bonding appears above the perfs". 3. CP AI reported potential T x IA communication July 1, 2003 and proposed to keep the well in water service while performing diagnostics. Their request was granted. According to CP AI, the well will pass a MITIA when SI, however communication is evident when the well is operating. 4. CP AI obtained permission to perform repairs that have not proven successful. It appears that a major workover is necessary to return the well to full integrity. 5, CP AI has proposed to keep this well in WATER ONLY service, add this well to the monthly monitoring list and perform a MIT-IA every 2 years. These are the standard conditions that have been applied to wells with similar leaks. Recommendation 1, I recommend approval of CPAI' s request. (' ( y ConocoPh i iii pS Alaska P,O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 12, 2003 Mr, Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 3A-06 (PTD 1852220). The request regards continued injection with a failed MIT. Please call Nina Woods or MJ Loveland 659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachments RECEIVED DEC 1 6 2003 Alaska Oil & Gas Cons Camm' , . ISSIon Anchorage OR'G1~'At- " (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~ A1J¡- q(J /~(n 20 AAC 25.280 /v ,,1 ~ 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 01 Annular Disp. 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4, Current Well Class: 5, Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 185-222 3. Address: Stratigraphic 0 Service 0 6, API Number: P, 0, Box 100360 50-029-21443-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 73' 3A-06 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): 7680' 6352' Casing Length Size MD TVD Burst Collapse CONDUCTOR 104' 16" 104' 104 SUR. CASING 3333' 9-5/8" 3406' 3178 3520 2020 PROD, CASING 7595' 7" 7668' 6343 4980 4320 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7144-7220', 7340-7362', 7372-7420', 7444-7450' 5939-5997', 6089-6106', 6114-6151', 6169-6174' 2-7/8" L-80 7281' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'FB-1'; BAKER'D' pkr= 7042'; 7255' SSSV= NIP SSSV= 498' 12. Attachments: Description Summary of Proposal 0 13, Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15, Well Status after proposed work: Commencing Operations: Immediately Oil 0 Gas 0 Plugged D Abandoned 0 16, Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact: MJ Loveland/Nina woods @ 659-7224 Printed Name d~r~~h'~~ Title: Problem Well Supervisor Signature Phone 659-7043 Date /~/.t~~ / ¿) Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 303-373 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test D Location Clearance LRECEIVED Other: \.N ~ -n:.Q t::> ~ \... ~\ \ ~"- \"'- ',; \C!: \>C ~'I ~ 0 ~ ~ 1\'1 ~ ~ ç. ~ ~~ lfiOO3 k \ -- 0.-.. d. '1 'r L' c.. \ <è. . 1 d .a Oil & Gas Cons. Commission Subsequent Form Required: "O "'C'L R(IIIS Bft DEe Anchorage Original Signed By .. sarah Palin BY ORDER OF /' Z117lrJ~ Approved by: COMMISSIONER THE COMMISSION Date: . I I ./ Form 10-403 Revised .?(200;3..~ . ,"':", .' 1"1 r: It" ~1) ], ð))on1> O. R, f G I N A L ""~:\:..;,:"\'.. ~- '..:..:.....:..1 VI!:.\!¿¡ cl' J. £.\1 U.JJ I SUBMIT IN DUPLICATE (' ( ConocoPhillips Alaska, Inc. Kuparuk Well 3A-06 (PTD 1852220) SUNDRY NOTICE 10-403 VARIANCE REQUEST 12/12/03 The purpose of this Sundry Notice variance request is for approval to continue water-only injection with a failed MIT. DS 3A-06 is a water injection well that was reported to show signs of T x IA communication in July 2003. Diagnostics found a tubing leak at 1200' MD, which was patched with AOGCC approval. The well continued to show communication problems, of which re-sets of th~atch did not fi~. The well will pass a 3000-psi MIT with the well is shut-in, but fails with the well flowing, Draw down tests also fail. A small leak in the pac~er is suspected in addition to the known leak in the tubing. A workover will be required to fully repair the well. ~ MITs are proposed as the chief method to verify the casing continues to have integrity, As long as an MIT will pass it will demonstrate competent casing to the packer. Should the casing MIT fail, a tubing plug will be run for a combination MIT (CMIT T x IA). The following page details diagnostics that have been done to investigate the communication problem. The following Action Plan is proposed to support the variance request for continued injection: ACTION PLAN 1. Well will be used for water inj~ction only (no gas or MI allowed); 2. Perform MIT-IA every 2-years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4, Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 12/12/03 ( CONOCOPHILLIPS ALASKA, INC.( 3A-O6 Injection Well Diagnostic History !.'.-Date: ":..1- ""~,' ">:"':":"", ',::"~....",:::,:,.,, ":,,",,'Com'ment:,:'.:....,,.,:,,~::, ":".',:..:.-;"....:.."'/:~".'~"".,:,:,:. .',:>-::..:..;'".::.:1 ; jlNSTALLED BPI @ 72381 RKB, 2.25" CA-2 BLANKING PLUG @ 72741 RKB, CMIT 2500 PSI, GOOD, ¡ ¡ 12J5/20031DRAW DOWN TEST FAILED. WELL LEFT SI. . !'" ,.,." M ...... ,.. .".., '. "'l pu [CËÖ' EcT~ÎPŠE"'PAfc~r'@""122 3"'ËLrvCc" M'î f"sTIce Ë"S~rFO L'w ï TH 'p[ÜG"Ä T '7061" ï' (A bov'e" top 'pä'ëï< e r y:"' : I 12J4/20031DRAWDOWN TEST FAILED. IN PROGRESS, i \-,_.._...._.~-;' ~ ' , , ._,.._-~-_.~--~ . !MIT-IA to 3000 psi, passed, BUR failed,T/l/O = 1050/100010. InitiallA FL @ SF. Pumped 3 bbls of diesel. ¡down the IA to pressure up to 3000 psi, IA lost 40 psi in first 15 minutes and 0 psi in second 15 minutes. For: ¡ la total loss of 40 psi during 30 minute test. Bled IA back to 500 psi and monitored for 10 minutes. lAP! 111~~003'inc~asedbacku t0750~~n9 m~~~ ~a~re~s~res; 105q~5~~~~~~-~,-~~--~-~---~-j :~._'---,. State witnessed MIT-IA, failed with a LLR of 7 gpm @ 2300 psi. T/I/O = 1800/1200/100, InitiallA FL near i surface, Pumped >1 bbl to pressure IA up to 2000 psi. IA slowly increased in pressure up to 2300 psi, then ¡ steadily maintained an injection rate of 7 gpm @ 2300 psi for approximetly 10 minutes. (Until out of Diesel.) ¡ Shut down and monitored pressures. IA fell off at a rate of 100 psi per minute to 1920 psi where it stabilized! and maintained pressure. Bled IA down to 820 psi and monitored for 15 minutes, After 15 minutes the IA ¡ 11/1/2003 increased to 980 psi. Final pressures; 1800/1200/100 """" .".,., """,'""",-,..'.'... MIf:ì;(p'âšs'ecr'(posi' 'pâictl" šet)',""'f¡i/ð'~'21'Óöï1§ÒöïÒ" "fñii ¡ãr'IA" î=C(§),'s'þ :""Fi urn"ped'¿':§ 'bb'ís"of 'Õfesefdown""ïÄ'l to pressure up IA with diesel to 2600 psi. IA lost 50 psi in first 15 minutes of test, and 0 psi in second 15 ! .191~ 9 (?Q 0 3 ~ll)~!~~:£<?L~^lo t é!L I 0 ~,~"2L?9~,,,EêL~~E!n^g_?'Q"^E!l..^ i n ~!~"1~.~,t:£JD,,~,,Lp.r~.ê~,~E~~,;."^gJ,9 0 Lt?QQ¿Q;-^-^,""~~_^,M~"_^_^~~..w,~",-~,~^J . ET ECLIPSE PATCH IN 3,5" TUBING IN TWO RUNS, PATCH COVERS 12261 -12461, MIN ID OF I 1 0/28/2003; PATCH: 1,75", TOP OF PATCH IS AT 12231, WELL LEFT SHUT IN. I 'W"-~___"M'M+M"'M~~~.__""W^WM~~W.~,,~w.m"...,w,_~..,~-,,~.""~W._.',""W'","."w....,.,^_.~.."MW_..W._M".W.W._'.',",,^,^~"^."..."..W""..w._.._^".,^-^~..w.,~,^-_w",^"-'._-~~",,_.~,,.".WMW,~W^--^~'~"-'^_~_.WN^'__""'_"~"_W'~~'~'-"^~'M'^..."w~.,,^w-.wm..,^__..._¡ 10/2~/?Oq~¡.P~II~~patch.......,.,...,........... .,......, ... "......' "... '..'. ,. . ¡ ,MITIA failed, T/I/O=2200/190010, Attempted to pressure up IA with tri-plex & diesel, IA pressured up to !! 12200 psi and pumped away @ 2200 psi for 15 minutes, shutdown pump, IA pressure fell off to 1900 psi in 2 ll1 0/12/2q03! ~i':1~t.~~,. Final.T/I(O=2?00/190010 ." . . . :LRS Attempted to bleed the IA to prep for an MITIA. Initial T/I/O = 2240/1900/50. Bled IA to 1600psi, started' !to get fluid returns. Shutln, IA pressured back to 1900psi. Bled once more down to 1500psi with all fluid [ 10/11/2003~returns. SI and pressure rose to 1900psi. RDMO, ¡ !ELEMENT SET AT 1243,31, CORRELATED TO TUBING TALLY DEPTHS, TIED IN TO D NIPPLE AT 4981.! . ~LEAK IS 61 FROM BOTTOM OF 23RD FULL JOINT COLLAR BELOW DS NIPPLE (AKA 61 ABOVE 25TH ¡ ~ 10/8/2003~COLLAR BELOW DS NIPPLE). OVERPULLED 800 LB TO FREE BOrrOM OF SETTING ROD FROM! ~...~/?4/~.Oq.3~Pf\ICH (?.,7~~"..9D) .T°J4q9IRK~. NO P~OBLEMS;. PU_LLED.?~~.1~" \I'J-1.~()ÇK.~1 I.NJ. V~V @70011, ,...I 9/3/2003 R e ce i v ed 1 Q -4P 3_§~..~9!Y~!- 30~~^:,g^~N?Nf~?LP'~~ç,blQ"9,w!~~_tl;l.ÞJÐ"9"w_M"""",,wN"'-~_'__M~"'^~_~"M~W~~WM~_"_~W_"MM~_'~W^"~"M__WWW"~"'~^"~~~~'MM"'M'; NITROGEN VIDEO LOG. IDENTIFIED TUBING LEAK @ 12361 VLM. LOCATED TOWARDS THE ' 8/2 5/2 0 0 3 !?',QI!9 ~..9£'M~Q!.~I_^~Q_QT,,~..~ R .!:~~!5§"l~§~I~~J^§.Q:~w_"""'M"",^W^W^w",~~""-,"^w"'Mw_-",,,-W""^"-'W,^,^W^W^~WM"W""_M"_~^"'M'~""',^W,~MWM...^~.~,^W~"~.....".,"...i ¡PULLED 2,75" BPC @ 72381 RKB; SET 2.75" BIP PLUG @ 72381 RKB & PULLED SAME; PERFORMED 1 iCMITIA TO 2200 PSI, HELD FOR 30 MIN/PASSED; FOUND LEAK IN TBG BETWEEN 4751 - 35231 WLM, ¡ 8/21/2003 SET 2,75" BPC @ 72381 RKB. j """"""""""""""""'."""""".""""".."""""""""""",."",'",.,.,..".,.,..,.,..".,..,.,.,.........."..,'..,..,....,..".,.,...".",."""""""""""""""""""""""'.""""'""........... .,..',.'....,...,..,'...,.,.,.",....."..-....",..,."..'.........'".""".""""""."""""."".",-",.,....",.......,..,.,.,.,.,.,.,."".""..""."""""""""""""""""""N,""""""""""""..,.""",..".".",.,' UNABLE TO ESTABLISH IA INJECTION RATE, PRSSURE IA TO 3000 PSI, IA DROPPED DOWN TO i 7/23/20032000 PSI IN 3 MIN 15 SEC, ',,',,"'..'.'..'."""'.." ","'""",,""",,"'.. '... ""'."',,, '..... . .'" . ,MITIA - failed, T/I/O = 1550/1600/100 start pressuring up IA with diesel, IA would not pressure up beyond ¡ ~2350 psi, shut down pump and IA pressure dropped to 1600 psi in 6 minutes. Establish LLR of approx 8-9 ; .' ., I L'^"""N..l!'!!~Q,9-~lg.E!!!",.^~....,.g,~,?..Qw"e.~!^~,^~W~^"~'WM_W^"'.._"W........M'.^W^~'..w,.w^w.w.,w..w....._^"",^w....,^"w',.,..".....w..W""",^W^'M',~"'M".w.'""""~_..".wM'....w,"'.MWM,^.....W.,,w^""'.W^'...'M~...,....w.W^",'."w....,'.W""""MW.,,,w,"~',,',.,w.",.^...W.WM""'^W,".."~~W"W',W"'^'M"^"'"^",,,"'m.,,~w,,......w"w""",.."".....,..J (' ConocoPhillips Alaska, Inc. NIP (498-499 , 00:3,500) TUBING (0-7252, 00:3,500, 10:2,992) PKR (7042-7043, 00:6,151) SBE (7045-7046, 00:3,500) Perf (7144-7220) SLEEVE-C (7238-7239, 00:2.750) PKR (7255-7256, 00:6,151) PLUG (7274-7275, 00:2,250) TUBING (7252-7281, 00:2,875, 10:2,441) Perf (7340-7362) Perf (7372-7420) Perf (7444-7450) 3A-o6 ( KRU INJ 10/19/1985 9/5/1997 Reference L : Last Ta : 7443 Last Ta Date: 7/23/2003 Casin Strin . ALL STRINGS Descri tion CONDUCTOR SUR. CASING PROD. CASING Tubin Strin . TUBING Size To 3.500 0 2.875 7252 Perforations Summa Interval TVD 7144 - 7220 5939 - 5997 7340 - 7362 6089 - 6106 7372 - 7420 6114 - 6151 7444 - 7450 6169 - 6174 Gas Lift MandrelslValves St MD TVD Man Man Type Mfr 1 6956 5795 Cameo In'ection MandrelsIValves St MD TVD Man Man Type Mfr Cameo MMM Ui , etc. . JEWELRY T e NIP NIP PKR SBE NIP SLEEVE-C PKR PLUG NIP TTL SOS V Type VOD Latch Port TRO DMY 1.5 RK 0.000 0 V Type VOD Latch Port TRO DMY 1.5 RK 0.000 0 Descri tion Ref L TVD 104 3178 6343 Size 16.000 9.625 7.000 Bottom 104 3406 7668 To 0 0 0 Wt 9.30 6.50 Zone C-4 C-3 C-1 A-3 A-2 A-1 Status Ft SPF Date T e 76 12 11/22/1985 IPERF 22 4 11í2?J1985 IPERF 48 4 11/22/1985 IPERF 6 4 11'22/1985 IPERF V Mfr MMM VMfr Cameo 'OS' Ni Ie NO GO Cameo 'W' Ni Ie Baker 'FB-1' Baker AVA BPL PORTED NIPPLE AVA BPI SLEEVE' Set on 12/5/2003 Baker '0' 2.25" CA-2 PLUG set 12/5/2003 Cameo '0' Landin Ni Ie NO GO Cameo 3A-O6 Last U date: Wt 62.58 36.00 26.00 Grade H-40 J-5S J-5S Thread Date Vlv Run Cmnt 9/11/1997 Date Vlv Run Cmnt 9/11/1997 ID 2.812 2.812 4.000 4.000 2.750 2.310 3,250 0.000 2.250 2.441 2.441 3A-06 Failed MIT Sundry #303-262 Subject: 3A-06 Failed MIT Sundry #303-262 Date: Sun, 02 Nov 2003 07:39:12 -0900 From: NSK Problem Well Supv <n1617@conocophillips.com> To: tom_maundcr~admin.state.ak.us, jim_regg~admin.state.ak.us CC: chuck_scheve@admin.state.ak.us, n1617 <rtl 617~conocophillips.com> Tom, Jim, On July 1, 2003, 3A-06 Failed a MIT IA and was reported to the AOGCC. The well was left SI at that time. Subsequent diagnostics found a hole in the tubing at 1236' ConocoPhillips applied for and received approval to patch the leak with Sundry Notice #303-262. A 20' retrievable patch was set Oct 28, 2003 and passed a pre state witnessed MITIA with no pressure bleed off on Oct 29, 2003. Shortly after passing the MITIA the well was returned to injection service and a State Witnessed MITIA was schedule. State Inspector, Chuck Scheve, witnessed the MITIA Nov 1, 2003, and it failed miserably with a leak rate of 7 gpm @ 2300 psi. We are speculating that patch partially failed after the well was brought on line and warmed up to normal operating temperature. Chuck Scheve gave verbal approval 11/1/03 to leave the well on-line over the weekend until approval from town could be obtained. This well passed a CMIT to 2200 psi on 8/21/03 (using the D&D hole finder as a plug for pressure testing against), therefore we are relatively confident that the leak is in the tubing and most likely the patch. The plan forward is to run a leak detect log above and below the patch while pumping down the IA. The leak was originally identified by a Video log, if a large enough leak rate for a normal LDL cannot be obtained then we will pursue re running a video log or pulling the patch and starting over. A 10-404 (subsequent to the patch) has not been filed (pending the possibility of pulling the patch for troubleshooting). Attached are copies of the 2 MITIA forms for your review, however they have not been sent to Bob Fleckenstein for entry in your database as he already has the failed MITIA data from July 1. ConocoPhillips request approval to leave the well on-line until troubleshooting operations can be performed. We will schedule the work to be completed as soon as possible, hopefully to be finished before the end of November/beginning of December. Let me know if you have any question or require additional information. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3A-06 MIT ll-01-03.xls) (See attached file: 3A-06 MIT 10-29-03.xls) [~3A-06 MIT 11-01,-03.xls 3A-06 MIT 11-01-03.xls ] Name:Type: EXCEL File (application/msexcel)]'1 ~,Rc,~o.....ding: base64 1 of 2 11/3/2003 11'10 AM 3A-06 Failed MIT Sundry #303-262 [~3A-06 MIT 10-29-03.xls Name: 3A-06 MIT 10-29-03.xls Type: EXCEL File (application/msexcel)] Encoding: base64 2 of 2 11/3/2003 11:10 AM ( MEMORANDUM ~': State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich , Commissioner . SUBJECT: Mechanical Integrity Test THRU: Jim Regg .~ JI/Zè/'ä.3 Conoco Phillips P.I. Supervisor N 11 3A-O6 KRU FROM: Chuck Scheve Petroleum Inspector NON. CONFIDENTIAL DATE: November 1 , 2003 Packer Depth Pretest Initial 5 Min. 30 Min. Well 3A-06 Type Inj. S TV.D. 5861 Tubing 1800 1800 1800 1800 Interval 0 P.TD. 185-222 Type test P Test psi 1465 Casing 1200 2300 1900 P/F F Notes: Post tubing patch Well Type Inj. TVD. Tubing Interval P.TD. Type test Test psi Casi ng P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. TVD. Tubing Interval P.TD. Type test Test psi Casi ng P/F Notes: Well Type Inj. TVD. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: / Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to the Conoco Phillips 3A-06 Well in the KRU to wItness the post tubing patch MIT. This well has tubing by inner annulus communication with a leak in the tubing located at 1236'. A patch had been set in the tubing in an attempt to repair the leak. The test pump was rigged up on the annulus and an injection rate of aprox .25 bbl per minute at 2300 psi was established. When the pump was blocked in the pressure declined rapidly ftom 2300 psi to 1900 psi in less than 5 minutes. M.LT.ls performed: 1 Attachments: Number of Failures: 1 Total Time during tests: 2 hour cc: ~:':::f("'A~~~Qe,r,",~ ¡(-~Eo~)) q¡ 1 2', 0, O?( (~~{f'\\~'t10~r;;.;~..," U - \Lø ¿¡; ..1 - ~~ MIT report form 5/12/00 LG. 2003-1101 MIT KRU 3A-O6 cs.xls - - - - 11/20/2003 i, 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: ConocoPhillips Alaska Inc. Kuparuk/KRU/3A 11/01/03 Sauvageau / Brake Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. WellJ3A-06 Type Inj J Sp J T.V.D. J5861 J Tubing J 1800J 1800J 1800J J lntervalJ oF P.T.D. I1852220 TypeTest Test psiI 1500 I Casing I 12001 23001 19201 J P/F Notes: State Witnessed Post Patch MITIA. Pressure fell off 100 psi per minute down to 1920 in 5 Tin and stablized, bled IA to 800 icreased to 920 in 15 minutes P.T.D. I Type Test Test psi 1500 Casing P/F Notes: P.T.D.I Notes: Type Test Test psi 1500 Casing IntervalIP/F P.T.D.I Notes: I Typelnj I I T'V'D' I ITubing Type Test Test psi 1500 Casing IntervalIP/F P.T.D.I Notes: Type Test T.V.D. IntervalIP/F 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 O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-110 I_M IT_K RU_3A-06.xls 11/3/2003 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: ConocoPhillips Alaska Inc. Kuparuk/KRU/3A 1 O/29/O3 Arend / Brake Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.11852220I ITypeTestP I Test psiI 15oo I Casing I 15001 26001 25501 25501 P/F Notes: Pre State Witnessed Post patch MITIA P.T.D.I Notes: Type Test Test psi 1500 Casing I°. P.T.D.I Notes: Type Test Test psi 1500 Casing Interval)p/F P.T.D.I Notes: Type Test Test psi 1500 Casing IntervalIP/F P.T.D.I Notes: Type Test Test psi 1500 Casing Interval]p/F IntervalIP/F 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 O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-1029_MIT_KRU_3A-06.xIs 11/3/2003 Re: Failed MITIA KRU well 3A-06i (PTD# 1852220) Subject: Re: Failed MITIA KRU well 3A-06i (PTD# 1852220) Date: Wed, 03 Sep 2003 12'48:02 -0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: jim_regg~admin.state.ak.us Jim, FYI, PPCo submitted a sundry to install a patch in this well to return tubing integrity. I have forwarded it for approval. Tom NSK Problem Well Supv wrote: Tom/Jim - Today (7/01/03) the DHD crew tested KRU Water Injector 3A-06i (PTD# 1852220) and the MITIA failed. The' well was SI and freeze protected at 20:50 on July 1st, 2003. Initial test pressures were (T/I/O) 1550/1600/100psi. The IA pressured to a maximum of 2350psi. (Typical diagnostic test pressures on the IA are 3000psi.) The triplex pump was shut down and the IA pressure dropped to 1600psi in 6 minutes. A liquid leak rate was established of approximately 8-9 gpm @ 2350 psi. This WI had previously passed a State Witnessed MITIA to 3090psi on 7/21/03. Our plan forward is to determine the leak path, set plugs, and running leak detect logs as needed. Once a definitive leak has been identified, we will inform you of the repair mechanism along with submitting the appropriate 10-403 form pending a patch repair. We will report this well on the Monthly Failed MIT report until the problem is resolved. Please call if you have any questions, Thanks. Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 To:m Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 ofl 9/3/2003 4:19 PM ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice request for Phillips Alaska, Inc., well 3A-06. The Sundry request is fo:r approval to set a patch across an identified leak in the tubing. Also attached are the discussion/action plan and a well schematic. Please call Nina Woods or :me at 907-659-7224 if you have any questions. Sincerely, ConocoPhillips PrOblem Well Supervisor Attachments ~CANNE~ SEP 0 9 2003 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 Suspend r~ Operation Shutdown r'-] Repair well [-~ Plug Perforations r-~ Pull Tubing [] Perforate New Pool Perforate E~ Variance Stimulate [-~ Time Extension Re-enter Suspended Well Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development ~] Exploratory [] Stratigraphic [~] ,~ervice r~ I 5 . Permit to Dr.~mber: 185-222 ~ 6. APl Number: 50-029-21443-00 7. KB Elevation (ft): RKB 73' 8. Property Designation: Kuparuk River Unit 9. Well Name and Number: 3A-06 10. Field/Pool(s): Kuparuk Oil Pool 11. Total depth MD (ft): 7680' Casing PRESENT WELL CONDITION SUMMARY CONDUCTOR Effective Depth MD (ft): SUR. CASING PROD. CASING Perforation Depth MD ft): Total Depth TVD (ft): 6352' Length 104' 3333' 7595' Size 16" 9-5/8" Effective Depth TVD (ft): MD 104' 1! 7144-7220', 7340-7362', 7372-7420', 7444-7450 Packers and SSSV Type: pkr= BAKER 'FB-I' ' BAKER 'D' SSSV= NIP Perforation Depth TVD (fi): 3406' Plugs (measured): 7668' 5939-5997', 6089-6106', 6114-6151', 6169-6174' Packers and SSSV MD (ft) pkr= 7042' · 7255' SSSV= 498' 'rVD Junk (measured): 12. Attachments: Description Summary of Proposal [~] Detailed Operations Program [~ BOP Sketch 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Date: Burst Collapse 104 3178 3520 2020 6343 4980 4320 Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" L-80 7281' Service r-~ Plugged [] Abandoned WINJ [] WDSPL r-'"J 13. Well Class after proposed work: Exploratory E~ Development r-1 15. Well Status after proposed work: oil I-1 Gas I--] WAG GINJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Lo,~d / ~ /r+/~///~~~ Commission Use Only Signature Contact: Title: Phone 659-7224 MJ Loveland/Nina woods @ 659-7224 Problem Well Supervisor Date ~'/~//~ ~ Conditions of approval: Notify Commission so that a representative may witness ISundry Number:..?~::3,~ _ ,~ Plug Integrity D BOP Test ~ Mechanical Integrity Test Location Clearance Other: Subsequent Form Required: Approved by: ~ Form 10-403 Revised 2/2003 · COMMISSIONER BY ORDER OF THE COMMISSION SUBMIT IN DUPLICATE RSOIIs ConocoPhillips Alaska, Inc. Kuparuk Well 3A-06 (PTD 1852220) SUNDRY NOTICE 10-403 TUBING REPAIR 08/31/2003 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kupamk Well 3A-06 with a tubing patch. On July 1, 2003 the AOGCC was notified of a failed MIT. Subsequent diagnostics show a hole in the tubing at 1236' MD. Pending the results of a tubing caliper, the plan is to patch the tubing with a 20' permanent patch. Following a successful MIT, the well will be returned to normal water injection. Should the caliper indicate inadequate tubing for patching, the AOGCC will be notified and an alternative plan discussed. REPAIR PLAN 1. Caliper the Tubing 2. Set 20' 3.5" permanent patch from -1226-1246' MD. 3. MIT as per AoGcc requirements (0.25 x TVD to packer) 4. Submit 10-404 post repair .ConOCoPhilliPs Alaska, Inc. NiP (498-499, ~ 0D:3.500) NIF (7001-7002, 0D:3.500) PKR (7O42-7O43, 0D:6.151) SBE (7O45-7046, 0D:3.500) KRU 3A-06 3A-06 · .. APl:1500292144300 SSSV Type:I Nipple Annular Fluid:I Reference Log:l Last Tag: 7461 Last Tag Date: 9/23/2001 casing String- ALL STRINGS Well Type:I INJ Orig 110/19/1985 Completion:I Last W/O: 19/5/1997 I Ref Log Date:I TD:17680 ftKB Max Hole Angle:144 deg (~ 4600 Angle @ TS: Angle @ TD: Rev Reason: Last Update: 40 de~]@ 7142 39 deg @ 7680 Sleeve Open, waivered well 7/5/2003 Description I Size Top I Bottom I TVD t Wt IGradel Thread CONDUCTOR 16.000 0 104 I 104 162.581 H-40 I SUR. CASING 9.625 0 3406 I 3178 136.001 J-55 I PROD. CASING 7.000 0 7668 I 6343 I26'00 I J-55 I Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 7252 6022 I 9.30 I J-55 I 8RDMOD 2.875 7252 7281 6044 I 6.50 I L-80 I EUE-ABM Petf~Yati~h:~::summ'a~. ::..:..:.'... :;:.:'=...'":~:;. ';.?.. '..': · .' ..:: .','..?.'..'; :::.!!~...! ':: :~.:'.:..:~.:....::: .::':::.' .:; ."%:: ':..:.': ~.: .':?.:.;; ~.' ~... '~:. ~.: ':. i ;'.:.;...;:...?.;::.'~'.;':!"..'.:~;! '?.!~..:'. '~..... '.i .; Interval TVD I" Z~ne I Status I F 7144-7220 5939- 5997 F-4,c-3,C-ll 17. 7340-7362 6089-6106 ! A-3 I I 2 7372-7420 6114-6151 / A-2 I I4 7444-7450 6169-6174 / A-1 I I ~ t'ISPFI 'Dat~ ! type I Comment ~ { 12 111/22/1985~ IPERF 1120 deg phase; 5" Csg Gun -) I 4 111/22/1985~ IPERF 190d89. phase; 4" Csg Gun 3 I 4 111/22/1985~ IPERF 19o deg. phaseL4" Csg Gun ; I 4 111/22/19851 IPERF 190 deg. phase; 4" CSgGU.n Vlv Cmnt Vlv Cmnt Perf (7144-7220) SLEEVE-O (7238-7239, 0D:2.750) PKR (7255-7256, 0D:6.151) NIP Camco 'DS' Nipple NO GO NIP Camco 'W' Nipple PKR Baker 'FB-I' Description 2.812 2.812 4.OOO 4.OOO 2.750 2.310 3.25O 2.250 2.441 SBE Baker NIP AVA BPL PORTED NIPPLE SLEEVE-O AVA BPC SLEEVE; Set on 6/1/99 PKR Baker 'D' NIP Camco 'D' Landing Nipple NO GO TTL SOS Camco 2.441 !G.~.~:6~i:l'Nb.te~'.:.::.i .!':': .. ?:':':i:::i:':::. :::.!!',:. ':.i: ":~::;:~.!'; '?:.::i' !! ..!! ~!';:"::i::.::;:.'i :~;:. ::..: ,.. :..' ':" "' '~::.:.::;'.;;:!:::' :'i.::.!~ '?:.:i. ::.!i:'::: :' ::."..':.:';:'i:;.?.',.:.:'.::.i :;:..:..~!...i:.;..~6.¥. ::: ! . ?. f:::.:i::;:.!~/',???~ ;?!.: '.:.:: ' .' Date /Note 11/13/200~ WAIVERED WELL: T x IA ANNULAR COMMUNICATION NIP (7274-7275, OD:2.875) TUBING (7252-7281, 0D:2,875, ID:2.441) Perf (734~7362) Pe~ (7372-7420) Per~ (7444-7450) Failed MITIA KRU well 3A-06i (PTD# 1852220) Subject: Failed MITIA KRU well 3A-06i (PTD# 1852220) Date: Tue, 1 Jul 2003 21:44:19-0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: tom_maundcr~admin.stat¢.ak.us, jim_regg@admin.state.ak.us Tom/Jim - , Today (7/01/03) the DHD crew tested KRU Water Injector 3A-06i (PTD# 1852220) and the MITIA failed. The well was SI and freeze protected at 20:50 on July 1st, 2003. Initial test pressures were (T/I/O) 1550/1600/100psi. The IA pressured to a maximum of 2350psi. (Typical diagnostic test pressures on the IA are 3000psi.) The triplex pump was shut down and the IA pressure dropped to 1600psi in 6 minutes. A liquid leak rate was established of approximately 8-9 gpm @ 2350 psi. This WI had previously passed a State Witnessed MITIA to 3090psi on 7/21/03. Our plan forward is to determine the leak path, set plugs, and running leak detect logs as needed. Once a definitive leak has been identified, we will inform you of the repair mechanism along with submitting the appropriate 10-403 form pending a patch repair. We will report this well on the Monthly Failed MIT report until the problem is resolved. Please call if you have any questions, Thanks. Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 1 ofl SCANt~EE'.~' ~U~ 0 ~ 2003 7/22/2003 5:27 PM MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 21, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder t. Phillips Alaska P.i. Supervisor ~.Co4'}~,~ 3A Pad FROM: John Crisp ~:~'~ ' '~ '~-.~'~\"~ ~'~ "\~(3~- 3A-02,04,06,07,10 GKA Petroleum Inspector Kuparuk River Field NON.- CONFIDENTIAL Packer ,Depth Pretest Initial 15 Min., 30 Min,. , '~ W~il :~-m I T~pe'.j.I 'S i~.V-D, i r'~0 ITu="~i .~,, I' ~1 ~o0, I ~ I'=e"=l 4 p..T.O.l,~S52050,1Typet~i ,''P' ITestpsiI '~45S lc"sinai 2f,00 I ~ I 332O 1,3300.1 Pn: I _P Notes: ' wa~i "3A-04 'iType~-I' ' S i T-~-D. I ~77 I'Tu~j I' 295ol ~ol 2°~°1 ~o I~nte~a~i"4:" P.T..O,! iSS2070'lT,~petesti P .' IT~P~I ~'~,.lCa~.~l ~2,S0.1 ~S0 I !~0 I i940 I P~FIE , ,wa'l 3A-06 i Typelnj. I S I T.v.D. I 5SS~ '1 T"bingl 2~75'l 2S001 2S001 2,6~, I~.te~l 4 p.T.D:I ~%o IT~'testl , P, IT=~I ~'~ I~n01 '~o.~0 ! ~ ! ,:~ I ~0 .I P~: .I ,, Welli, 3A-07 p.T.D.I ~~ W~,l! 3A-10 P;T.D.I 1852370 l~.e'nJ-i 'S i~.V-O, i ~' I~u~"~l ~00 I~''1 =~0' i ~0 I'~1 4: l-i'YPeteSt! P ITestpsil ~.~S0 I Ca~nol 40751 ~ ! ~820'1 ~e201 P/F I E' ,nJ.I s I T:V.9. i ~ I ~u~ I '~000 I ~0 '1' ~ I ~0 I,.~e--ail 4 '~Ypetestl P.I Testpsil 1477'1 Caang.I 1500 I .2050 I 2,o2o ,I 2020 I. P/F I E Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioac~ve Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Worko~r O= Other (describe in no~es) Test's Details These wells passed the Standard Annulus Pressure tests. 2 annulus pressures were high considering they were bled down the previous day. 5 MIT's no failues wimessed. M.I.T.'s performed: 5__ Attachments: Number of Failures: 0 Total Time during tests: 3 HRS. ,,cc,-. MIT report form 5/12/00 L.G. MIT KRU 3Aa 7-21-01jc.xls 7/23/01 ~ C~ STATE OF ALASKA ~ A~S~ OIL AND GAS CO~SERVA~ON COMMISSION ~ Mec~ni~l Inte~ T~ ~ LLm) OPERATOR: .... ARCO Alaskc~ thC. FIELD/UNIT / PAD: Kuparuk/3A DATE: 9/11/97 .. ........ ~. ........... ,, ............. ~. .... ,~.,..~ .... ,,,.~-:.~.::~.,, ~,,~,~, ...... ~,: ........ ..:.~,,~.,~,~J~.,,~,,~! ,~.~,,,,,, ...... ~,~??,: :,, ~,.,~, ....... ,~ .~., .... ~, ~,.~.~ ............ ~.:.!,~,..~...~ ~,...~!, .... !~'j''''' Wo~O~r compiete ~10~7. MIT PeffO~ed by Haiiibu~on .......... ~OMMENTS: COMMENTS: COMMENTS: KI:LI:I V I:U Aladm Oil & Gas Cons. Cammmien TBG. INd. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTfNG TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRE~{~f~, D[ C ~. 9 2002 R = rNTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL GLYCOL SALT WATER Jl DRILUNG MUD _. OTHER Grad. . 0.00 0.00 · WELLTEST: Initial __ 4- Year Work:over X · Other Dislribu~: orig - Well File c- Operator c - Databese c - Trip R~t Fil~ c - Inspector OPERATOR REP SIGNATURE: Eric Zuspan ,~,¢_./¢,,,.~,.~ AOGCC REP SrGNATURE: 3A-O6 MIT.xls {Rev 9i17/96) SENT BY :.~CO Ai_~SKA 7g~ ;11-27-97 ; 8'18A[~1 ; KPS/WELLS/CNST/PROJ'-' 907 276 7542;# 1/ 4 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 26, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3{)01 Porcupine Drive Anchorage, Alaska 99501 Subject: 3A-06 (Permit No. 85-222) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3A-06. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development ORIGINAL WSI/skad STATE OF ALASKA ~" ALASK~ OIL AND GAS CONSERVATION C~,,',/IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 Classification of Service Well Water Injection 7. Permit Number 85-222 8. APl Number 50-029-21443 _. Location of well at surface 599' FSL, 768' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1341' FNL, 3420' FEL, Sec. 18, T12N, R9E, UM At total depth 1565' FNL, 3679' FEL, Sec. 18, T12N, R9E, UM 12. 17. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3A-06 11. Field and Pool 22. Kuparuk River Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Rig RKB 32' I ADL 25632, ALK 2565 Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 10/13/85 i 10/18/95 ! 9/5/97 ! N/A MSLI Two Total Depth (MD+TVD) ! 18. Plug B~Ck Depth (Mb+TVD)i19. Directional Surveyj2b. Depth where sssv' Set~:l'. Thickness of Permafrost 7680 6351 Pr] 7576 6270 FT~ []Yes I~No j N/A MD! 1550' Type Electric or Other Logs Run 23. CASING SIZE VVT. PER FT. GRADE CASING, LINER AND CEMENTING RECORD SE-I-I-lNG DEPTH j HOL¢:'"I TOP BO-FrOM j SIZE I CEMENTING RECORD Surf. ~04' I '24" 1175 sxAS ~ Surf. 3406' j__!__2:2,511 _[1.._0_00 SX _A__S_ !.1! & 3_7_0_ _SX_ C!a_s_ _S G Surf. 7668' i 8.5" 1300 sx Class G & 175 sx AS I __ 1__6" 62.5# H-40 9-5/8" i 36.0# J-55 ....... -?" ......26.0# J-55 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) AMOUNT PULLED MD 7144'-7220' 12 spf 7340'-7362' 7372'-7420' 7444'-7450' 4 spf TVD MD TVD 25. TUBING RECORD SiZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7281' 7042', 7255' 26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. Date First Production Date of Test ;Hours Tested Flow TubingiCasing Pressure Press. 28. PRODUCTION TEST iMeth'0d of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR I OIL-BBL 'TE--S--T-__P-_-E RI° D; l .............. CALCULATED · j OIL-BBL _>4-HOUR RATE j GAS-MCF WATER-BBL GAS-MCF WATER-BBL CORE DATA CHOKE SIZE j GAS-O~L RATIO OIL GRAVITY-APl (CORE) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A REEE VED S~_~' 2_9 1997 Gas Cons. 6emCSS' ~c~0rage ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark?-`.. 30. "-'" Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. .,. , , , N/A Annulus left open - freeze protected with diesel. 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Prepared By Name/Number: Sharon AIIsup-Drake/263-4612 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: I, no cores taken, indicate 'none'. RECF_IV :D ~.~,_ :-- 1997 Alaska 0il & Gas Cons. C0rrcrCs~- :Anchorage Form 10-407 Rev. 07-01-80 Date: 9/12/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3A-06 RIG:NORDIC WELL ID: 998781 TYPE: AFC:--998781 AFC EST/UL:$ 498M/ 673M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: WI: 0% SECURITY:0 API NUMBER: 50-029-21443-00 START C0MP:08/28/97 FINAL:09/05/97 08/27/97 (D1) TD: 0' ( SUPV: RLM 0~ DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG 1Y TO 3A Attempt rig move from 1Y pad to 3A pad. Stuck in 1Y access road. Moving rig from 1Y pad to 3A pad. 32,435 CUM:$ 32,435 ETD:$ 0 EFC:$ 530,435 Date: 9/12/97 ARCO ALASKA INC. WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS WELL:3A-06 RIG:NORDIC 41 s -.Oij,& . as Cons. WI: 0 % --~CURITY: WELL ID: 998781 TYPE: AFC:--998781 AFC EST/UL:$ 498M/ 673M STATE:ALASKA API NUMBER: 50-029-21443-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:08/28/97 FINAL:09/05/97 08/28/97 (C2) TD: 0' PB: 7576' SUPV:RLM DAILY:$ 08/29/97 (C3) TD: 7680' PB: 7576' SUPV:RLM/MC DAILY:$ 08/30/97 (C4) TD: 7680' PB: 7576' SUPV: RLM/MC DAILY: $ 08/31/97 (C5) TD: 7680' PB: 7576' SUPV:RLM/MC DAILY:$ 09/01/97 (C6) TD: 7680' PB: 7576' SUPV:RLM/MC DAILY:$ 09/02/97 (C7) TD: 7576' PB: 7576' SUPV:DLW DAILY'$ 09/03/97 (C8) TD: 7576' PB: 7576' SUPV: DLW DAILY: $ 09/04/97 (C9) TD: 7576' PB: 7576' SUPV:DLW DAILY:$ PREPARING TO DISPLACE W/S MW: 0.0 Laying plywood and moving rig from 1Y pad to 3A pad. 31,415 CUM:$ 63,850 ETD:$ 0 EFC:$ 561,850 PULLING TUBING MW: 0.0 Accepted rig @ 02:00. Pump kill weight mud through tubing displacing through choke to kill well. ND tree, NU BOPE. Test BOPE. 39,835 CUM'$ 103,685 ETD:$ 0 EFC:$ 601,685 LAY DOWN FISH MW: 0.0 Contine test BOPE to 250/350© psi. RIH with fishing BHA %1. Spear and latch fish. Packer pulled loose. 44,298 CUM-$ 147,983 ETD:$ 0 EFC:$ 645,983 POOH WITH FISH %3 MW: 0.0 POOH with fishing BHA and fish %1. RIH w/fishing BHA %2. Tag and latch fish @ 7125'. POOH with fish %2. RIH w/fishing BHA %3. Tag and latch fish @ 7248'. 35,169 CUM-$ 183,152 ETD'$ 0 EFC $ 681,152 FISH MW: 0.0 POOH fishing BHA and fish %3. RIH w/fishing BHA %4. Mill packer from 7257' to 7260' Push packer to 7343'. RIH with fishing BHA %5. Chase fish (packer) from 7343' to 7496' 45,649 CUM:$ 228,801 ETD:$ 0 EFC:$ 726,801 RIH W/3.5" X 7" FB-1 PKR MW:10.8 LSND Continue to push fish (packer and tail pipe assy) to 7496'. Latch onto fish. POOH w/fish. Clean out from 7516' to 7576' PBTD. Run 5.85" gauge ring and junk basket to 7350' Recover packer rubber. 39,557 CUM:$ 268,358 ETD:$ 0 EFC:$ 766,358 RIH W/3.5" DP TO FISH OUT MW:10.8 LSND RIH w/2-7/8" x 7" Baker Pkr and tail pipe assembly. Set pkr top @ 7254' RIH with 3.5" x 7" Baker pkr assembly. Set pkr @ 7050' 76,134 CUM:$ 344,492 ETD:$ 0 EFC:$ 842,492 RUNNING 3.5" COMPLETION MW:10.8 LSND RIH with 3.5" DP. Tag fish @ 7020'. POOH with recovered fish and Baker running tools. Tag Baker packer @ 7054'. 32,148 CUM-$ 376,640 ETD-$ 0 EFC:$ 874, 640 Date- 9/12/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/05/97 (Cl0) TD: 7576' PB: 7576' SUPV:DLW DAILY:$ 09/06/97 (Cll) TD: 7576' PB: 7576' SUPV:DLW DAILY:$ MOVE RIG MW: 8.6 SW Run completion using 3.5" completion string. N/D BOPE, N/U tree. Test seals and packoff, OK. 63,535 CUM:$ 440,175 ETD:$ 0 EFC:$ 938,175 RELEASED RIG MW: 8.6 SW Pump diesel for freeze protection. Secure well, pull off well and clean up around cellar. Release rig for turn key rig move. Released rig @ 0830 hrs. 9/6/97. 14,582 CUM:$ 454,757 ETD:$ 0 EFC:$ 952,757 End of WellSummary for We11:998781 ARCO Alaska, Inc. Post Office L..x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 8, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ¢5- z.~_z. 3A-06 Stimulate ~?---74, 3H-04 Stimulate ~-q ~ 3N- 16 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED OCT 1 199 Alas~ 0il .& Gas Cons. ~omm~ssio~ /~ch0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C :' ' STATE OF ALASKA '- AL~_.,A OIL AND GAS CONSERVATION COMMISb,,..N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 599' FSL, 768' FEL, SEC.7, T12N, R93, UM At top of productive interval 1341' FNL, 3420' FEL, $EC.18, T12N, At effective depth 1522' FNL, 3628' FEL, SEC.18, T12N, At total depth 1565' FNL~ 3679' FEL~ SEC.18, T12N, 12. Present well condition summary Total Depth: measured true vertical R9E, UM R93, UM R93, UM 7680' 6351 ' feet Plugs (measured) feet None Effective depth: measured 7 5 7 6' true vertical 6 2 70' Casing Length Size Structural Conductor 75' 1 6" Surface 3377' 9 5/8" Intermediate Production 76 3 9' 7" Liner Perforation depth: measured 7144'-7220', true vertical 5939'-5997', feet Junk (measured) feet None RKB 73' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-06 9. Permit number/Approval Number 8§-222 10. APl number 50-029-21 443 00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool cemented Measured depth True vertical depth 175 Sx AS II 1 04' 1 04' 1100 Sx AS III & 3406' 31 78' 370 Sx Class G 300 Sx Class G & 7668' 6343' 175 Sx AS I 7340'-7362', 7372'-7420', 6089'-61 06', 6114'-6151', 7444'-7450' 6169'-61 74' Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 @ 7278' Packers and SSSV (type and measured depth) SSSV: Baker FVL @ 1804', PACKERS: Baker FHL @ 7059', Baker FB-1 @ 7251' RECEIVED 13. Stimulation or cement squeeze summary A SAND FRACTURE TREATMENT ON INJECTOR Intervals treated (measured) 7340'-7362', 7372'-7420', 7444'-7450' Treatment description including volumes used and final pressure SEE A'I-I-ACHED WELL SERVICE REPORT SUMMARY 0 CT 1 2 1995 Alaska 0il .& Sas Cons. C0mmiss 0 ui 0raga 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 53O 2OOO 0 0 780 1400 Tubing Pressure 2730 2730 16. Status of well classification as: Oil B Gas Suspended Service WATER INJECTOR 17. I hereby-,,certify that the foregoing is. true and correct to the best of my knowledge. Signed~~ J' ~ Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 Date (0 '"'~' ~'- ? ..~ SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 08/18/93 TO 08/18/93 CPF-3 - DS-3A 3A-06 08/t8/93 INJECTOR GSW DATAFRAC W/ DOWELL. PUMPED 1SLK WTR BD @ 40 BPM, 3 SLK WTR PI/SI'S @ 20 BPM, 1 NON XL GSW PI/SI @ 20 BPM, & 2 XLINKED GSW YF140D MINIFRAC'S @ 20 BPM. DATA AS FOLLOWS: STAGE VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC BD 150 6300 2650 2650 0.88 1175 PI/SI #1 25 4035 2650 2650 0.88 75 PI/SI ~2 25 4028 2710 2710 0.89 8 PI/SI ~3 25 4088 2770 2770 0.90 8 PI/SI ~4 25 4115 2875 2750 0.91 0 MINIFRAC gl 182 4390 3000 .... 0.94 80 MINIFRAC %2 162 4518 3125 2850 0.96 83 SMART FE= 56% FROM TYPE CURVE & 50% FROM CLOSURE TIME. CUT PAD BY 20 BBLS. RECEIVED O(;T 1 ~ 199~ Alaska Oil & Gas Cons. Commissio,~ Anchorage ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 3A-06 Hydraulic fracture DATE CONTRACTOR j KEY PERSON KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/CC# - SCA# 998129 - 80529 !FIELD COST EST. ACCUMULATED COST 8/17/93 1 PBTD (RKB) 7576' DOWELL / Yokum LAST TAG (RKB) - DATE 7483' - 6/14/93 Ii . $127,778 SSSV TYPE / STATUS BAKER FVL - In service $135,974 TIME LOG ENTRY 0530 IM1RU Dowell frac equipment and hot oil.pump. Hold safety meeting with all personnel 21. 0915 QC fluids and sand. PT lines to 9500~. Set trips at 860(~. SI WHP 1100~, 7" csg. 3000, 10" csg. 0~. Start pumping operations. PRF~SURE VOL. TFAVlP. BREAKDOWN (slick water) 40 bpm [ 6340 150 95° 1st PUMP IN (slick water) 20bpm } 4035 ] 25 I 93° 2nd PUM? IN (slick water) 20bpm ] 4028 [ 25 ]93° KUPARUK PETROLEUM ENGINEERING 3rd PUMP IN (slick water) 20bpmI 4088 I 25 194° BREAKDOWN FLUSH (non- XL gel water wi 5% diesel) 7" CSG. ISIP 3460 2650 92° } 3470 ] 3000 I' I , Fluid effecicncy = 50 to 56%. Adjust pad to 10 bbls w/o x-link, and 20 bbls with, total =30 bbls. Reset trips to 7200 psi. . BFCFIVF [X{CI'IECKTIHSBLOCKIFSUMM RY IS CONTIHUED ON BACK iX{ COMPLETE{ { "-I~C~I~IPLETE Report m"~! mp~! .C.,. Estr O CT 1 2 199 62 [ 93° 20bpm [ 4390 2nd DATA FRAC (non-XL OW) 20bpm ] 4640 '1 FLUSH (non-XL GW) 20bpmI 4518 I Stand by to analyze data frac. 1010 1020 1032 1045 1056 1108 1150 1006 62 .[ FLUSH (non-XL GW) 3598 ] 3125 1st DATA FRAC (non-XL GW) 3475 [ 2770 3488 2710 I 3415 ] 2650 REMARKS CONTINUED: 1300 STAGE pre-pad pad 2 ppa 4 ppa 6 ppa 8 ppa 10 ppa 12 ppa 14 ppa Flush Flush Flush 1335 [PUMP FRAC (w/5% diesel) Delay-XL Delay-XL Delay-XL Delay-XL Delay-XL Delay-XL Dela) Delay-XL Non-XL GW Slick diesel 7"CSG. 3214 3228 3580 3571 _ 3525 3530 3530 3534 3530 3525 3530 3530 TEMP PROP. 94° 94° 93° 16X20 90° 12\18 93° 12\18 93° 12\18 93° 93° 93° 93© 93° 90° ¸ 12\18 I2\18 12\18 10" CSG. 65O 700 750 800 Reduce Rates 85O 1340 Shut down pumps. Entire frac pumped. 103,0364t pumped. RDMO. SUMMARY Pumped job as designed to completion. Total fluids pumped was 1231bbls. w/103,036g propant. iWell never screened out. 1800~ left in the tubing. 101,5804t in the formation. i SERVICE COMPANY '$124,2i2':' II ACCUM. TOTP~L ' · $124,21-2 VECO PUMP & VAC TRUCK $t,200 $1,200 PEAK TRUCKING $300 $300 H.E.S. $2,596 LITTLE RED SERVICES $1,688 $1,688 PETREDAT $5,000 $378 $127,778 Signed: ~. ~. £s/rada Diesel 150 bbl. TOTAL FIELD ESTIMATE ~ ,, $978 $135,974 STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: -Development X Exploratory _ Stratigraphic Service ~/ 4. Location of well at surface 599' FSL, 768' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1341' FNL, 3420' FEL, Sec. 18, T12N, At effective depth 1522' FNL, 3628' FEL, Sec. 18, T12N, At total depth 1565' FNL, 3679' FEL, Sec. 18, T12N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 7 6 8 0' true vertical 6 351 ' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 73' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-06 9. Permit num,ber/approvaJ ~ber ~5-222 / 7-7~ I10. APl number 5o-029-2144~ 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 5 7 6' true vertical 6270' feet Junk (measured) feet Casing Length Size Structural Conductor 7 5' 1 6" Surface 33 77' 9 5/8" Intermediate Production 763 9' 7" Liner Perforation depth: measured true vertical Cemented Measured depth 175 Sx AS II 1 0 4' 1000 Sx AS III & 3406' 370 Sx Class "G" 300 Sx Class "G" & 7668' 175 SxAS I 7144'-7220', 7340'-7362', 7372'-7420', 5939'-5997', 6089'-6106', 6114'-6151', Tubing (size, grade, and measured depth) 3 1/2", J-55, 7278' MD-RKB Packers and SSSV (type and measured depth) SSSV: Baker FVL 1804', Packer: True vertical depth 104' 3178' 6343' 7444'-7450' MD 6169'-6174' TVD Baker FHL 7059', FB-1 7251' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re_oreseqtative Daily Averaoe Production or Injection Data .... : "- '" Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 638 354 1054 1440 100 Subsequent to operation 455 450 1800 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations f~ Oil __ Gas Suspended . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form '10-404 Rr~v 06/1~5/88 / Service Water In!ection SUBMIT IN DUPLICATE ARCO Ala~' '.ilnc. ~ Status well l P.T. or TP Choke # I SI Zonel PSI Bean ~ir I!/~o ~1 I1~ p~ ,~!1!!/~. i !~!1!!//~ ! ,~. ~'.~ /~, V' i I ! ~.1 ! Time Drillsite '~ " Production Well-Status Temp Last H2SI CSG Pressure PSI J Gas OF WC% IPPMI 7;' I 10" Tempi Orillsite,.J~lorning Report CPF '-~ "' Gas Lift Status Inj. Rate Meter Total MSCFD Shut-In Hrs JReasonl i I /! Status i.- - !WelllGI, PW · i lnject. Pressure PSI tlTern~ Choke i # orSW [7onei AlloWable Actuall oF Bean SWI Total PWI Total Inje. ction Well Status Shut-In CSG Pressure PSII Meter [ Injection Rate 7" '. 10" I Total i MMSCFDiHrs. Reason k,;~¢J~ BBLS/Day//g)~,~ . ~! ~ Total Heater Prod ! Test ! Prod Test [ Temp.' IGas PSI Run Time Chemicals Type i Gal/Day Headers ~ Production j Water Injection i Gas Injection i Gas Lift t Drain J Tank: Meoh/Diesel iPressure ' J ,¢¢~ ~.-~ i J i ! , / 1-8: ! Level i Temp. ,!Temperaturei. ,; Jl j9-16://~.~..//£:/?;/¢~' 7~ Comments ~ Operater's Signature 3A 024{05/27/87) ARCO Alat inc. · aate //";~ !-F'~ Time ._~c..//:)~ Or,lis,re _~)~r Drillsite Morning Report CPF ~ ; Status i Production Well Slatus Gas Lstt Status Shut-In ;WelliP.T. or i TP Chokei Temp I Last ~H2Si CSG Pressure PSI : Gas ' InI. Rate ~ i # i SI :7'one~, PSI , Bean t OF i wC°/° ,iPPMI 7" 10" .. Temp 'Meter Total; M.SCFO Hrs Reason,. i Status i Injection Well Status Shut-In Well iGI. PW! Inject. Pressure PSI hrernl:x Choke CSG Pressure PSII Meter, Inlechon Rate ~¢ !orSW:Zonel AIIowaOle !Actuall °F : Bean 7" 10" Total : BBLS/Day MMSCFD;Hrs. Reason ' :~ ' ~W & ~,t_~_f) ~/.,~!~,b /,>/ 5on /o ~¢~7-&'"_ !o.,q?o' .. SWl Total / ''*-'~: -'7 3 _~ PWI Total To, , j / 7:3 3i , Drillsite i CoiITemperature °F Heater ', Prod Test · outi /~¢ -- Cod Pressure PSI ' Bath ' Blanket I Prod Test Temp.. Gas PSII Run Time ¢5' Chemicals Type i Gal/Day I Headers Production :~ Water Injection ~ Gas Injection Gas Lift j DrainC_f¢-~;.') Tank: Meoh/Oiesel IPressure J i ~ i ' ¢'~ ~a ~ I ! /~../'_.~ ~) ~1-8:/IQ ~ Level I Temp. 'Temperature ; /°Sc ' '~ ~2' , ' ' ¢5° i9-16:/70 ~d Comments ~o~'nlS ~ '~ O0 Operater's Signature_~4,~ ~;~ 3A.024(05/27/873 I~te: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1988 Transmittal #: 7094 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-8 Kuparuk Well Pressure Report(Otis) 12-23-88 Static 1G-16 Kuparuk Well Pressure Report(Otis) 2-8-88 Static 'C' Sand I ~ 3H-9 Data Frac Pressures 1-15-88 ~) BHP Data Worksheet 1-3-88 #94225 3A-15 Kuparuk Well Pressure Report(Otis) 1-15-88 Static 'A' Sand 3A-15 Kuparuk Well Pressure Report(Otis) 1-15-88 Static 'C' Sand HAPPY VALENTINE'S DAY Receipt Acknowledged: DISTRIBUTION: D & M State of Alaska Chevron Mobil SAPC Unocal ARCO Alaska. Inc. ~s a Subs~o~ary o! AllanlicRichlieldCompany ~-"~' STATE OF ALASKA - ALAb,,,,. ,.)IL AND GAS CONSERVATION COk..~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska: ];nc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 599' FSL, 768' FEL, Sec. 7, T12N, RgE, UM At top of productive interval 1341' FNL, 3420' FEL, Sec. 18, T12N, R9E, UM At effective depth 1522' FNL, 3628' FEL, Sec. 18, T12N, R9E, UM At total depth 1565' FNL, 3679' FEL, Sec. 18, T12N, R9E, 11. Present well condition summary 5. Datum elevation (DF or KB) RKB 73' 6, Unit or Property name Kuparuk River Unit 7. Well number 3A-06 8. Permit number 85-222 9. APl number 50-- 029-21443 10. Pool UM feet 7576' Kuparuk River Oil Pool R CF. iV D Total depth: 7680' measured 6351 ' feet true vertical feet measured 7576 ' feet true vertical 6270' feet Effective depth: Casing Length Size Structural Conductor 75' 16" Surface 3377' 9-5/8" Intermediate Production 7639' 7" Liner Perforation depth: measured Plugs (measured) O"'"r 0 9 Junk (measured) Alaska 0il & Gas Cons. Commissior~ Anchorage Cemented Measured depth True Vertical depth 175 Sx AS II 1000 Sx A.S. III 370 Sx Class "G" 300 Sx Class "G" 175 Sx AS I 104' 104' 3406' 3178' 7668' 6343' 7144-7220, 7340-7362, 7372-7420, 7444-7450' MD true vertical 5939-5997, 6089-6106, 6114-6151, 6169-6174' TVD Tubing (size, grade and measured depth) 3-1/2" J-55 7278' MD-RKB Packers and SSSV (type and measured depth) SSSV: Baker FVL 1804' Packer' Baker FHL 7059' FB-1 7251' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Convert to water injection. 13. Estimated date for commencing operation December, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct tot~e best of my knowledge Signed ~ ~,(./ ~ ~~ Title /j,/,~., (/)/~"~-'7..~~ -~ Commission Use Only Date "~ 0 (,,¢ ~ ? Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ?' ~ -,', -~- :. Commissioner Approval No. by order of the commission Date/O --k'"-~) 7 Form 10-403 Rev 12-1-85 Submit in triplicate~ '-~ .... " STATE OF ALASKA '-' " ALASK~ (J~L AND GAS CONSERVATION L,,.,,v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well REVISED Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 85'222 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21443 4. Location of well at surface 9. Unit or Lease Name 599' FSL, 768' FEL, Sec. 7, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1341' FNL, 3420' FEL, Sec.18, T12N, R9E, UM 3A-6 At Total Depth 11. Field and Pool 1565' FNL, 3679' FEL, Sec.18, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/13/85 10/18/85 10/19/85*J N/A feet MSLI 1 , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7680'MD,6351 'TVD 7576'MD,6270'TVD YES [~ NO [] ; 1814 feet MDI 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, 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 104' 24" 175 sx AS II 9-5/8" 36.0# J-55 Surf 3406' 12-1/4" 1000 sx AS Ill & 370 sx Class G 7" 26.0# J-55 Surf 7668' 8-1/2" 300 sx Class G & 175 sx 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) 7444' - 7450' 3-1/2" 7288' 7068' & 7260' 7392' - 7420' w/4 spf, 90° phasing 7340' - 7362' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7144' - 7220' w/12 spf, 120° phasing See Addendum attac.ed to Well Completion Repot :, dated 3/31/86. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRoDuCTION FOR OI L-BBL GAS-MCF WA-I:ER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Alaska Oil & Gas Cons. *NOTE: Tubing was run and the well perforated 11/23/85. Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GRUi/WC05 Submit in duplicate(~ 29. Z: . . 30. -. GEOLOG, IC MARI~:R'5' ' .. "' ~:0RMATION 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 C 7142' 5937' N/A Base kuparuk C 7221'' 5997' Top Kuparuk A 7327' 6078' Base Kuparuk A .... 7473, 6190, --. 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing i~'irue and correct to the best Of mY knowledge . Signed ~,f);~f~.f)-~ .-~~'. Title Associate Engir~eer Date ~-~'~-~7 -- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska. In' Post Office 8ox 100360 Anchorage, AlasKa 99510-0360 Telepl~one 907 276 1215 DATE 04-03-86 TRANSMITTAL # 5622 RETURN TO: ARCO ALASKA, INC. ATT~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage- AK 99510-0360 Transmitted herewith arethe following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET's or CBL's: One * of each '~iA- 14 12-03-85 ~ 1E-24 02-21-85 - ~ 1E-24 02-23-85 '~IQ, 1 04-16-85 '~iQ-10 01-28-85 ~2E-10 01-14-85 '~ 2E-11 01-13-85 ~2E-12 01-13-85 '' 2H-9 12-06-85 '~2W-15 02-11-85 ~3A-5 11-03-85 ~3A-6 11-03-85 ~3A-8 11-04-85 ~3F-8 11-14-85 Run #2 7050-7732 Run #1 6390-6964 Run #2 6400-7000 Run #1 0695-4476 Run #1 5346-7359 Run #1 4710-6500 Run-#1 6050-8250 Run #1 5390-7522 Run #1 6000-8016 Run #2 6488-8062 Run #1 6771-8518 Run #1 6086-7545 Run #1 5186-7006 Run #1 5410-6885 NSK C!erk*bi r. EC E D ~ ~ Oi: & ~ C~, Commissio- ~---~-' STATE OF ALASKA ~ ALASKA V~L AND GAS CONSERVATION C~J~wMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~Xx GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-222 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21443 4. Location of well at surface 9. Unit or Lease Name 599' FSL, 768' FEL, Sec.7, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1341' FNL, 3420' FEL, Sec.18, T12N, RgE, UM 3A-6 At Total Depth 11. Field and Pool 1565' FNL, 3679' FEL, Sec.18, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKBI ADL 25632 ALK 2565 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116- No. of Completions 10/13/85 10/1 8/85 10/19/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD} 18.PIugBackDepth(MD+l-VD} 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 7680'MD,6351 'TVD 7576'MD,6270'TVD YES E~x NO []I 1814 feet MD 1550' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, CET, 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 104' 24" 175 sx AS II 9-5/8" 36.0# J-55 Surf 3406' 12-1/4" 1000 sx AS Ill & 370 sk Class G 7" 26.0# J-55 Surf 7668' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7444' - 7450' 3-1/2" 7288' 7068' & 7260' 7392' - 7420' W/4 spf, 90° phasing 7340' - 7362' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7144' - 7220' w/12 spf, 120° phasing See attached Addendum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO 1986 Form 10-407 NOTE: Tubing was run and the well perforated 11/23/85. GRU1/WC05 ' Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base kuparuk C Top Kuparuk A Bas~ Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7142' 7221' 7327' 7473' TRUE VERT. DEPTH 5937' 5997' 6078' 6190' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and t'ime of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer D te Z-Z/-$b INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 2:3: 'Attaehed'!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 jection, Gas Inject!on, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/05/s5 12/16/85 3A-6 Rn CET log f/7576'-6086'. Rn GCT gyro f/7502'-surf. Frac well w/total of 244 bbls diesel, 672# 100 mesh & 4166# 20/40 sand w/avg rate of 5 BPM, 2700 psi. RECEIVED APR 0 ~ 1986 Alaska Oil & Gas C~ns. ~,u,,,.,.;,s,~r, Drilling ~uperintendent / D~te ARCO Alaska, Inc. Post Office Box' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-6 Dear Mr. Chatterton- Enclosed is a Well Completion Report for the subject well. have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L21 Enclosure If you ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ,~?-- STATE OF ALASKA .- ~'-- ALASK, _ _ AND GAS CONSERVATION C ~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-222 3. Address 8. APl Number ? :~,f ~ 029-21443 P. O. Box 100360, Anchorage, AK 99510-0360 iT ~.'~ !C ! ~,,,3-? 50- 4. Location of well at surface 9. Unit or Lease Name 599' FSL, 768' FEL, Sec.7, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval ~,'" 2-', ~ 10. Well Number 1341' FNL, 3420' FEL, Sec.18, T12N, RgE, UM 3A-6 ~"~ 0il & G.~s (;:;;'is. 6o;~i',-',.i~si0~ At Total Depth r~,~*~* 1 1. Field and Pool 1565' FNL, 3679' FEL, Sec.18, T12N, R9E, UM L.~,--" ...... ,.,¢~ '~: .... '~'-~u~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 10/13/85 10/18/85 10/19/85* N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD~TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7680'MD,6351 'TVD 7576 'MD ,6270 'TVD YES I-~X NO [] 1814 feet MDI 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, 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 104' 24" 175 sx AS II 9-5/8" 36.0# J-55 Surf 3406' 12-1/4" 1000 sx AS Ill & 370 s: Class G 7" 26.0# J-55 Surf 7668' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7444' - 7450' 3-1/2" 7288' 7068' & 7260' 7392' - 7420' w/4 spf, 90° phasing 7340' - 7362' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7144' - 7220' w/12 spf, 120° phasing N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . Form 10-407 * NOTE: Tubing was run and the well perforated 11/23/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE TEMP3/WC57 Submit in duplicate ; ,-:-:i:: ~ ;:,-'?: ;, '~ ~:~- ?~'::; .... -,:; .:~:~ ~:3:~ :..,.-.: ~-::-:.~_.-:: :,~:~ :~:.:~:.!-..?.~.:~?~.. :.::. ~. :;c::~;~-:. :..-:::-~ ,,:: ;~::. :~:-:. ,¥ -.- -:- .... ~..~ : ....... ~! "¥~ :-'- -G'EO£OGIC MARKERS: /, ~ ~.;~:' .~ : ~: ::~:.:::'": - :":-':~:;~ ~'.'~-"T~-:? '::.'~ 3' ~,: :~,; '~;- ::-'FORMATION TEST, S'" .... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ; Top Kuparuk C 7142: 5937' N/A Base kuparuk C 7221' 5997' -Top Kuparuk A , 7327' 6078' Base Kuparuk A 7473' .6190' · 't, .. 31. LIST OF ATTACHMENTS Well History (completion details), Addendum (dated 12/11/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~_)~/~__~ Title Associate Engineer Date Signed // INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water dispOsal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location, of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' if no cores taken, indicate "none". Form 10-407 ARCO' Oil and .Gas Company Daily Well History-Final Report · Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" Should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFEAK0294 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 11/22/85 11/23/85 Date and depth as of 8:00 a.m. Accounting cost center code JCounty or Parish IState North Slope Borough Alaska ILease or Unit I Well no. ADL 25632 3A-6 JTitle Completion API 50-029-21443 JA.R.Co. W.I. Fetal number of wells (active or inactive, on thisI ~ost center prior to plugging and 56.24% ~bandonment of this well 11/22/85 ! 0001 hrs. Complete record for each day reported 7" @ 7668' 7576' PBTD, RIH w/5" perf guns 10.1 ppg NaC1 Brine Accept ri~ @ 0001 hrs, 11/22/85. ND tree, NU &tst BOPE. Schl, perf w/4" gum, 4 SPF, 90° phasing f/7444'-7450', 7392'-7420' & 7340'-7362'. RU 7" @ 7668' 7576' PBTD, RR Diesel Perf w/5" gun, 12 SPF 120° phasing f/7144'-7220'. Make 6-1/8" gage ring/JB rn to 7240', POOH. RIH & set FB-1 pkr @ 7251' WLM. Rn 228 jts, 3½", 9.3#, J-55 8RD EUE tbg & 3 jts, 3½" BTC tbg w/SSSV @ 1814', FHL pkr @ 7068', FB-1 pkr @ 7260', "D" Nipple @ 7277' & TT @ 7288'. Tst tbg, ann & tree; OK. Displ well w/diesel. Set BPV. RR @ 0730 hrs, 11/23/85. C L4 Old TD New TD Released rig Date 0730 hrs. Classifications (oil, gas, etc.) Oil I PB Depth IKind of rig 11/23/85 I Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7576' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected correct Signature /,~ For form preparation and di~ribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 11/05/85 3A-6 Rn CET log f/7576'-6086' . Rn GCT gyro f/7502'-surf. Drilling0 Superintendent Date ARCO Alaska, Inc. Post Office Bo.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 1'7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-6 Dear Mr. Chatterton- Enclosed are the Well Completion Report and the subject well. The tubing details will well has been completed. If you have any questions, please call me Sincerely, Gruber Associate Engineer JG/tw GRU12/L142 Enclosures gyroscopic survey for be submitted when the at 263-4944. £C£1v D ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ .-- STATE OF ALASKA ALASK, _ _, AND GAS CONSERVATION C ~IISSION WELL COMPLETIO# OR RECOMI LETION REPORT A#D 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~IX ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-222 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21443 4. Location of well at surface 9. Unit or Lease Name 599' FSL, 768' FEL, Sec.7, T12N, RgE, UN '~ Kuparuk River Unit At Top Producing Interval I VERIFIED ~ 10. Well Number 1341' FNL, 3420' FEL, Sec.18, T12N, RgE, UM Surf. 3A-6 At Total Depth ! ~' H'~L 11. Field and Pool 1565' FNL, 3679' FEL, Sec.18, T12N, R9E, UM · Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKB : ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116- No. of Completions 1 0/13/85 1 0/1 8/85 10/19/85 N/A feet MSLI N/A '1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7680'ND,6351 'TVD 7576'HD,6270'TVD YES [~X NO [] N/A feet MD 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/$P/SFL, FDC/CNL, Cal, CRT, 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 104' 24" 175 sx AS II 9-5/8" 36.0# J-55 Surf 3406' 12-1/4" 1000 sx AS III & 370 s: Class G 7" 26.0# J-55 Surf 7668' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A , ,, · , 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.t~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~-~ Form 10-407 TEMP2/WC62 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _ .. · Include interval tested, pressure data, all fluids recovered and gravity, NAME MEAS. DEPTH TRUE VERT. DEPTH - GOR, and time of each phase- , 5937 ' N/A Top Kuparuk C 7142'.. Base kuparUk C 7221'-- 5997' 7327 ' 6078' Top Kuparuk A Base Kuparuk A 7473' -' 6190' . 31. LIST OF ATTACHMENTS Well History- Cvroseonie Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my kpowledge //~ ~ ~_, Title Ass°¢iate Engineer Date Signed 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 sh'ow the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no. ~Title AFE AK0294 I Drill Parker 141 API 50-029-21443 State Alaska Well no. 3A-6 Operator IA.fi. Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 10/13/85 Iotal number of wells (active or inactive) on this~ Dst center prior Io plugging and I bandonment of this well our Prior status if a W.O. 1130 hrs. Date and depth as of 8:00 a.m. 10/19/85 thru 10/21/85 Complete record for each day reported 7" @ 7668' 7576' PBTD, 7680' TD RR Wt. 10, PV 15, YP, 11, PH 9.0, WL 7.0, Sol 12 Fin'short trip, POOH to log. RU Schl, log w/DIL/SFL/SP/CAL/GR/FI)C/CNL to 7604' (WLM). Log out w/DIL/GR/SP/SFL f/7604'-3406', FDC/CNL f/7604'-6900', CAL f/7604'-6000', RD Schl. C&C hole, short trip; OK, POOH, LDDP. Chg rams to 7", tst to 3000#; OK. RU, rn 176 jts 7", 26#, J-55, HFERW, BTC, FS @ 7668', FC @ 7576'. C&C f/mud, RU Dowell, tst Ins to 3500#. M&P 60 bbl spacer, followed by 300 sx CL "G" cmt w/3% KCL, + 0.8% D127, + .25% D13, + .2% D46, @ 15.8 ppg. Bmp plg w/3500#; flts held OK. CIP @ 1700 hrs, 10-19-85. ND BOPE, s~-~[ps, make cut on csg, install packoff. NU tree, tst to 3500#; OK. Pmp 50 bbls diesel into ann, pmp out cellar, RR @ 2100 hrs, 10-19-85. · Old TD New TD 7680' TD 7667' PBTD Released rig Date 2100 hrs. Classifications (oil, gas, etc.) Oil Flowing Producing method Potential test data PB Depth 10/19/85Kind of rg Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date ?.. r .cDr re.ete(:t-~ · .,.-~,~, ~t LJ~,~ ~ './ ~.,¥ Al',sk~ Oil & Gn.~ P, nn~ Cnmmi.q.qio~ The above is correct /~ I",,~h~mi~a. Signatu re I Date I Title ~' ~'~ ~ vi J ,~ ~ ~.~ ~ ~_~)~ ~--~-~*--=~--~--~ I 1/-/~'~' I Drillin~ Superintendent For form preparation and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial ReicH" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Fie~d Kuparuk River Auth. or W.O. no. AFE AK0294 Parker 141 ARCO Alaska, Inc. ICounty. parish or borough North Slope Borough Lease or Unit ADL 25632 Title Drill AP1 50-029-21443 State Alaska IWell no. 3A-6 IARCO W.I. Prior status if a W.O. Operator Spudded or W.O. begun Spudded IDate IHour 10/13/85 Date and depth as of 8:00 a.m. lO/12/85 thru 10/14/85 10/15/85 10/16/85 10/17/85 10/18/85 Complete record for each day reported 1130 hrs. 56.24% 16" @ 104' 2119', (2029'), DD Wt. 9.4, PV 18, YP 24, PH 9.5, WL 16.2, Sol 8 Accept ri~ @ 0645 hrs, 10/13/85. NU diverter sys. Spud well @ 1130 hfs, 10/13/85. Drl, DD & surv 12~' hole to 2119'. 1713', 5.5°, 870.2W, 1712.64 TVD, 10.51VS, 3.65S, 10.!3W 1930', 12.4°, S9.5W, 1926.79 TVD, 44.49 VS, 18.21S, 41.14W 16" @ 104' 3426', (1307'), RU to rn 9-5/8" csg Wt. 9.2, PV 12, YP 13, PH 10.0, WL 16.0, Sol 7 Drl, DD & surv 12¼" hole to 3426', 10 std short trip, circ hi-vis sweep, TOH to rn csg. 2168', 18.5°, 849.2W, 2156.08 TVD, 107.67 VS, 55.09S, 92.57W 2638', 29°, 858.4W, 2587.83 TVD, 288.45 VS, 162.00S, 238.83W 2976', 41.5°, S56.4W, 2863.36 TVD, 483.07 VS, 267.128, 402.61W 3100', 43.5°, S61W, 2954.77 TVD, 566.80 VS, 310.638, 474.17W 9-5/8" @ 3406' 3465', (39'), Turbine drlg Wt. 8.7, PV 5, YP 6, PH 11, WL 22.6, Sol 4 Rn 86 its, 9-5/8", 36#, J-55 HF/ERW BTC csg w/FC @ 3327', FS @ 3406'. Cmt w/1000 sx AS III, followed by 370 sx C1 "G" w/2% CaCi9 & .2% D-46. Displ using rig pmps, bump plug w/2000 psi. CIP @ 1345 hfs, 10/15/85. ND diverter sys. NU & tst BOPE to 3000 psi. TIH, DO flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Turbine drl to 3465'. 9-5/8" @ 3406' 6050', (2585'), Turbine drlg Wt. 9.4, PV 11, YP 7, PH 9.5, WL 12.8, Sol 8.5 Turbine drl to 6050'. 3535', 43.3°, 857.5W, 3270.83 TVD, 865.51VS, 463.42S, 730.99W 4607', 43.9°, S56.9N, 4049.58 TVD, 1602.17 VS, 864.248, 1349.11W 5581', 42.4°, 853.5W, 4759.39 TVD, 2268.37 VS, 1245.908, 1895.91W 9-5/8" @ 3406' 7600', (1550'), Short trip f/E logs Wt. 10, PV 14, YP 14, PH 9.5, WL 5.9, Sol 11 Turbine drl to 7000', raise mud wt to 10.0 ppg while drlg, POOH, LD turbine. TIH w/new BHA, drl to 7600', cond mud, 25 std short trip. 6082', 42.8°, 848.7W, 5128.17 TVD, 2605.22 VS, 1458.79S, 2159.79W 6585', 41.9°, S45.4W, 5499.91 TVD, 2938.32 VS, 1689.50S, 2407.73W 6925', 40.7°, S45.9W, 5755.33 TVD, 3157.88 VS, 1846.50S, 2568.19W 7279', 40.3°, S47W, 6024.51TVD, 3383.46 VS, 2004.908, 2734.81W 7560', 38.7°, S52.9W, 6241.33 TVD, 3560.53 VS, 2119.85S, 2871.57W The above is correct For form ~reparat~on and distl~buti~'~,- -- see Procedures Manual, SectiOn 10, Drilling, Pages 86 and 87. IDate /4/~'~' I Title Drilling Superintendent I I I I ~UB.$URFACE DIRECTIONAL 8URVEY [~UIDANCE ~]ONTINUOUS [~OOL Company , Well Name Field/Location ATLANTIC RICHFIELD COMPAq, Y .3A-6 (59_9.'FSL~ 7,68,'FEL~ S7~ Ti~}]~ R9E KUPAR,UK1 NORTH SLOpE~ ~LASKA jq~ Reference No. 70966 Logo=ed By; HALFACRE RECEIVED Oat.....~e 18-NOVEMBER-85 Computed CUDNEY Anchoraga GCT DIRECTIDNAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3~-6 KUP~RUK NORTH SLOPE,.~LASKA SURVEY DATE: 03-NOV-~5 ENGINEER: HALFACRE METHODS OF COMPUTATION TOOL LOCATION: T~NGENTIAL- AVER&GED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DIST. PROJECTED ONT~ ~ T~RGET ~ZIMUTH DF SOUTH 57 DEG 34 MIN WEST ARCO ALASKa, INC. 3A-6 KUPARUK NORTH SLOPE~ALASKA COMPUTATION INTERPOLATED VALUES FOR MEASURED YETRuE SUB-SEA RTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -73.00 100.00 100.00 27.00 200.00 200.00 127.00 300.00 300.00 227.00 400.00 400.00 327.00 500.00 500.00 427.00 600.00 600,00 527.00 700.00 699.99 626.99 800.00 799.99 726.99 900,00 899,99 826,99 1000,00 999,99 926,99 1100,00 1099,99 1026,99 1200,00 1199,99 1126,99 1300,00 1299,99 1226,99 1400.00 1399.99 1326.99 1500.00 1499.99 1426.99 1600.00 1599.98 1526.98 1700.00 1699.79 1626.79 1800.00 1799,05 1726.05 1900.00 1897.75 1824.75 2000.00 1995.34 1922.34 2100.00 2091.69 2018.69 2200.00 2186.77 2113.77 2300,00 2280,54 2207,54 2400.00 2373.15 2300.15 2500.00 2464.68 2391.68 2600.00 2554.20 2481.20 2700.00 2641.09 2568.09 2800.00 2724.87 2651.87 2900,00 2805.14 2732.14 3000,00 2881,27 2808.27 3100.00 2954,42 2881.42 3200,00 3027.45 2954.45 3300.00 3100.39 3027.39 3400,00 3172.97 3099.97 3500.00 3245.84 3172.84 3600.00 3318.89 3245.89 3700.00 3391.97 3318.97 3800.00 3464.99 3391.99 3900.00 3538.08 3465.08 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 0 0 N 0 0 E 0 10 S 11 19 W 0 3 S 75 59 E 0 3 S 61 31 E 0 8 S 12 58 E 0 15 S 17 33 W 0 21 S 26 41 W 0 21 S 30 43 W 016 S 40 OW 012 S 8 47 W DATE: 15-NOV-85 EVEN 100 FEET VERTICAL DOGL SECTION SEVE FEET DEG/ 0.00 0.05 0.19 0.07 0.11 0.34 0.82 1.39 1.86 2.20 0 10 S 23 49 W 2, 0 8 S 78 33 W 2. 0 9 N 23 22 W 2, 0 13 N 15 0 E 2. 0 13 N 23 13 E 2. 0 11 N 16 28 E 2, I 22 S 57 18 W 2. 5 17 S 66 6 W 8. 8 7 S 63 42 W 20. 10 53 S 56 46 W 36. 14 6 S 51 37 W 16 56 S 49 26 W 19 3 S 52 17 W 21 23 S 53 40 W 22 47 S 53 50 W 24 55 S 54 25 W 28 0 S 55 42 W 31 18 S 56 38 W 34 46 S 57 26 W 38 26 S 58 11 W 42 15 S 58 31 W 43 9 S 58 50 W 43 3 S 59 5 W 43 25 S 58 49 W 43 17 S 58 50 W 43 16 S 58 38 W '43 2 S 58 32 W 43 5 S 58 18 W 43 2 S 58 4 W 42 56 S 57 49 W 57. 84. 115. 149. 187 · 227. 272 · 321. 376. 435. 500. 568. 636. 705. 774. 842. 910. 979. 1047. 1115. 43 69 78 61 29 05 50 35 22 22 94 37 13 75 40 58 07 51 O8 68 47 64 94 32 10 57 85 10 43 66 PAGE DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE OF MEASURED DEPTH EG RECTANGULAR COORDINATES HORIZ. RITY NORTH/SOUTH EAST/WEST DIST. 100 FEET FEET FEET 0.00 0.00 N 0.00 E 0.00 0,33 0.14 S 0.03 E 0.15 0,32 0.35 S 0.00 E 0.35 0.22 0,33 S 0,13 E 0.35 0.29 0.45 S 0,16 E 0.48 0.23 0.83 S 0.13 E 0,84 0.26 1.38 S 0,09 W 1.38 0,06 1,96 S 0.40 W 2,00 0,10 2.38 S 0,69 W .2,48 0.05 2.77 S 0.84 W 2,90 0,14 3,09 S 0,92 W 3,23 0,16 3,27 S 1,11 W 3.45 0,19 3.16 S 1.2'9 W 3.41 0,10 2.84 S 1.29 W 3.12 0,05 2,47 S 1,15 W 2,72 0.25 2.15 S 1,06 W 2,40 3.60 2,46 S 1,40 W 2.83 3.53 4.95 S 6.75 W 8.37 3.31 9.78 S 17.74 W 20,26 3.64 18.32 S 31.27 W 36.24 3.17 30.79 S 49.08 W 57.94 3.29 48.38 S 69.22 W 84.45 2.29 67.76 S 93.35 W 115.35 1,46 88.67 S 121.08 W 150.08 1.24 110,93 S 151,54 W 187.80 2.75 134.58 S 184.12 W 228.06 2.93 160.12 S 220.61 W 272.59 3.52 187.54 S 261.76 W 322.01 3.49 217.28 S 307.51 W 376.53 3.68 243.98 S 357.99 W 436.06 2.72 282.99 S 413.15 W 500.77 0.39 318.41 S 471.40 W 568.86 0.27 353.63 S 529.95 W 637.10 0.64 388.82 S 588.60 W 705.43 0.64 424.44 S 647.45 W 774.18 0.78 460.08 S 705.94 W 842.63 0.21 495.63 S 764.25 W 910.89 0.35 531.37 S 822.40 W 979.13 0.31 567.37 S 880.47 W 1047.45 0.22 603.61 S 938.30 W 1115.$8 73.00 FT DEPARTURE AZIMUTH DEG MIN N 0 0 E' S 10 55 E S 0 4 E S 21 24 E S 19 39 S 8 39 S '3 52 W S 11 37 W S 16 8 W S 16 53 W S 16 30 W S 18 48 W S 22 11 W S 24 28 W S 24 58 W S 26 1T W S 29 41 W S 53 44 W S 61 8 W S 59 37 W S 57 53 W S 55 2 W S 54 1W S 53 47 W S 53 47" S 53 50 S 54 1 w S 54 22 W S 54 45 W S 55 10 W S 55 35 W S 55 57 W S 56 17 W S 56 33 W S 56 45 W S 56 54 W S 57 2 W S 57 7 W S 57 1Z W S 57 14 W ARCO ~L~SKA, INC. 3A-6 KUPARUK NORTH SLOPE~AL,&SKA COMPUTATION DATE: 15-NOV-85 PAGE DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATIDN: ENGINEER: HALFACRE 73.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COOROINATES HORIZ. DEP&RTURE SECTION SEVERITY NOR.TH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET gEG MIN 4000,00 3611.41 3538,41 42 47 4100.00 3684,74 3611,74 42 50 4200,00 3758,04 3685,04 42 56 4300,00 3831,15 3758.15 43 6 4400.00 3903.96 3830.96 43 23 4500,00 3976,54 3903,54 43 30 4600,00 4049,11 3976.11 43 33 4700,00 4121,70 4048.70 43 ZO 4800.00 4194.52 4121.52 43 0 4900,00 4267,71 4194,71 42 53 5000,00 4340,83 4267,83 43 4 5100,00 4414,04 4341,04 42 48 5200,00 4487,51 4414.51 .42 34 5300.00 4561.23 4488.23 42 20 5400.00 4635.52 4562.52 41 50 5500.00 4709.93 4636.93 42 1 5600.00 4784.08 4711.08 42 4 5700.00 4858.46 4785.46 41 58 5800.00 4932.87 4859.87 42 0 5900.00 5007,11 4934,11 42 9 6000.00 5081.18 5008.18 42 16 6100.00 5155.07 5082.07 42 32 6200.00 5228.69 5155.69 42 22 6300.00 5302.67 5229.67 41 57 6400.00 5377.25 5304.25 41 39 6500.00 5451.87 5378.87 41 45 6600.00 5526°56 5453.56 41 37 6700,00 5601,43 5528,43 41 31 6800.00 5676.38 5603.38 41 9 6900.00 5752.02 5679.02 40 43 7000.00 5827.85 5754.85 40 38 7100,.00 5904.07 5831.07 39 43 7200.00 5981.18 5908.18 39 52 7300.00 6057.67 5984.67 40 9 7400.00 6134,21 6061,21 39 55 7500.00 6211.27 6138.27 39 11 7600,00 6288,76 6215.76 39 12 7680.00 6350.74 6277.74 39 12 S 57 33 W 1183.66 S 57 34 W 1251.64 S 57 42 W 1319.67 S 57 50 W 1387.89 S 57 46 W 1456.44 S 57 44 W 1525.23 S 57 25 W 1594.03 S 56 59 W 1662.81 S 56 26 W 1731.33 S 55 54 W 1799.45 S 55 19 W 1867.63 S 55 7 W 1935.70 S 54 54 W 2003.46 S 54 36 W 2070.95 S 5.3 54 W 2137.78 S 52 46 W 2204.40 S 51 45 W 2271.20 S 51 17 W 2337.67 S 50 48 W 2404.06 S 50 I4 W 2470.54 S 49 34 W 2537.13 S 48 58 W 2603.80 S 48 37 W 2670.69 S 48 56 W 2737.15 S 47 50 W 2802.96 S 46 51 W 2868.45 S 45 44 W 2933.67 S 44 3 W 2998.35 S 43 11 W 3062.52 S 43 8 W 3125.93 S 43 3 W 3189.04 S 46 32 W 3252.03 S 48 43 W 3314.86 S 48 31 W 3378.47 S 48 45 W 3442.08 S 49 53 W 3505.08 S 49 58 W 3567.74 S 49 58 W 3617.87 0,25 0,15 0.38 0,27 0,15 0,41 0,29 0.41 0.77 0,53 0.38 0.32 0.39 0.49 0.88 0.96 0.50 0.65 0.42 0.31 0.48 0.61 0.67 1.28 1.00 0.38 1.19 0.89 1.66 0.32 0.53 3.73 1.01 0.26 0.21 4.02 0.00 O.OO 639.94 S 995.77 W 1183.67 S 57 16 W 676.44 S 1053.13 W 1251.66 S 57 17 W 712.86 S 1110.58 W 1319.68 S 57 18 W 749.22 S 1168.31 W 1387.90 S 57 19 W 785.74 S 1t26.32 W 1456.45 S 57 21 "x 822,44 S 1284,50 W 1525,24 S 57 22 859.31 S 1342.59 W 1594.04 S 57 22 w 8'96.54 S 1400.43 W 1662.82 S 57 22 W 934.14 S 1457.72 W 1731.34 S 57 20 W 972.05 S 1514.34 W 1799.47 S 57 18 W 1010.65 S 1570.59 W 1867.66 S 57 14 W 1049.52 S 1626.54 W 1935.75 S 57 10 W 1088,39 S 1682.12 W 2003,53 S 5'7 5 W 1127.41 S 1737.28 W 2071.04 S 57 1 W 1166.46 S ]1791.56 W 2137.91 S 56 56' W 1206.32 S 1845.26 W 2204.58 S 56 49 W 1247.45 S 1898.26 W 2271,46 S 56 41 W 1289,03 S 1950,60 W 2338,04 S 56 32 W 1331.03 S 2002.57 W 2404.56 S 55 23 W 1373.64 S 2054.26 W 2471.21 S 56 13 W 1416.88 S 2105,68 W 2538.00 S 56 3 W 1460,85 S 2156,74 W 2604,92 S 55 53 W 1505.40 S 2207.69 W 2672.10 S 55 42 W 1549.89 S 2258.15 W 2738.87 S 55 32 W 1593.94 S 2308.13 W 2805.02 S 55 22 " 1639.15 5' 2356.99 W 2870.93 S 55 11 ) 1685.01 S 2405.14 W 2935.66 S 54 59 1731.99 S 2451.91 W 3001.94 S 54 45 W 1780.11 S 2497.37 W 3066.86 S 54 31 W 1827.67 S 2542.27 W 3131.06 S 54 17 W 1875.30 S 2586.78 W 3195.02 S 54 3 W 1921.61 S 2631.98 W 3258.82 S 53 52 W 1964.04 S 2679.46 W 3322.19 S 53 45 W 2006.67 S 2727.74 W 3386.34 S 53 39 W 2049.08 S 2776.15 W 3450.47 S 53 34 W 2090.90 S 2824.23 W 3513.99 S 53 29 W 2131.56 S 2872.63 W 3577.09 S 53 25 W 2164.09 S 2911.36 W 3627.57 S 53 22 W ARCO ~LASKA, INC. 3A-6 KUP4RUK NORTH SLOPE~ALASKA COMPUTATION DATE: 15-NOV-85 PAGE DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGUL4R COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -73.00 0 0 1000.00 999.99 926.99 0 10 2000.00 1995.34 1922.34 14 6 3000.00 2881.27 2808.27 42 15, 4000,00 3611.41 3538,41 42 47 5000.00 4340.83 4267.83 43 4 6000,00 5081.18 5008.18 42 16 7000.00 5827.85 5754.85 40 38 7680.00 6350.'74 6277.74 39 12 N 0 0 E 0.00 S 23 49 W 2.43 S 51 37 W 57.94 $ 58 31 w 500.47 S 57 33 W 1183.66 S 55 19 W 1867.63 S 49 34 W 2537.13 $ 43 3 W 3189.04 S 49 58 W 3617.87 0.00 0.14 3.17 2.72 0.25 0.38 0.48 0.53 0.00 0'.00 N 0.00 E 0.00 N 0 0 E 3.09 S 0.92 W 3.23 S 16 30 W 30.79 S 49.08 W 57.94 S 57 53 W 282.99 S 413.15 W 500.77 S 5.5 35 W 639.94 S 995.77 W 1183.67 S 57 16 1010.65 S 1570.59 W 1867.66 S 57 14 1416.88 S 2105.68 W 2538.00 S 56 3 W 1875.30 S 2586.78 W 3195.02 S 54 3 W 2164.09 S 2911.36 W 3627.57 S 53 22 W ARCO ALASKA~ INC. 3A-6 KUPARUK NORTH SLOPE~ALASKA COMPUTATION INTERPOLATED VALUES FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -73.00 73.00 73.00 0.00 173.00 173.00 100.00 273.00 273.00 ZO0.O0 373.00 373.00 300.00 473.00 473.00 400.00 573.00 573.00 500.00 673.01 673.00 600.00 773.01 773.00 700.00 873.01 873.00 800.00 973.01 973.00 900.00 1073.01 1073.00 1000.00 1173.01 1173.00 1100.00 1273.01 1273.00 1200.00 1373.01 1373.00 1300.00 1473.01 1473.00 1400.00 1573.01 1573.00 1500.00 1673.12 1673.00 1600.00 1773.69 1773.00 1700.00 1874.83 1873.00 1800.00 1977.00 1973,00 1900.00 2080.49 2073.00 2000,00 2185.45 2173.00 2100,00 2291.90 2273.00 2200.00 2399.84 2373.00 2300.00 2509.19 2473.00 2400.00 2621.36 2573.00 2500.00 2737.63 2673.00 2600.00 2859.34 2773.00 2700.00 2988.80 2873.00 2800.00 3125.46 2973.00 2900.00 3262,.36 3073.00 3000.00 3400.04 3173.00 3100.00 3537.24 3273.00 3200.00 3674.04 3373.00 3300.00 3810.96 3473.00 3400.00 3947.65 3573.00 3500.00 4083.98 3673.00 3600.00 4220.44 3773.00 3700.00 4357.43 3873.00 3800.00 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 0 0 N 0 0 E 0 10 S 22 45 E 0 4 S 3 25 E 0 4 N 85 20 E 0 6 S 13 11 E 0 15 S 9 21 W 0 21 S 23 21 W 0 22 S 30 26 W 0 15 ,S 38 18 W 0 13 S 11 51 W 0 10 S 14 50 W 0 8 S 61 43 W 0 8 N 37 5 W 0 12 N 8 12 E 013 N 21 8 E 0 10 N 1 22 E 0 34 S 43 53 W 414 S 66 8 W 7 40 S 66 33 W 9 55 S 56 14 W 13 26 S 53 40 W 16 19 S 48 29 W 18 44 S 52 2 W Z1 16 S 53 35 W 22 47 S 53 50 W 25 11 S 54 32 W 28 41 S 56 0 W 32 39 S 56 50 W 36 55 S 57 56 W 41 57 S 58 29 W 43 7 S 58 55 W 43 10 S 58 59 W 43 17 S 58 50 W 43 4 S 58 39 W 43 3 S 58 22 W 43 2 S 58 Z W 42 49 S 57 41 W 42 52 S 57 33 W 42 59 S 57 45 W 43 18 S 57 47 W DATE: 15-NOV-85 PAGE 4 DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: 73.00 FT ENGINEER: HALFACRE EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECT~N SECTION SEVERITY NORTH/ FEET DEG/IO0 FEE GULAR COORDINATES SOUTH EAST/WEST T FEET HORIZ. DIST. FEET DEPARTURE AZIMUTH DEG MIN 0.00 0,00 O. 0.01 0.47 O. 0.18 0,32 O, 0,09 0.15 O. 0.09 0.21 O. 0,25 0.28 O, 0.67 0.09 1. 1.25 0.40 !. 1.74 0.10 Z. 2.13 0.14 2. O0 N 0.00 E 06 S 0.02 E 33 S 0.01 W 32 S 0.10 E 40 S 0.14 E 71 S 0,15 E 22 S O,OZ W 82 S 0.32 W 28 S 0.61 W 67 S 0.82 W 0.00 N 0 0 E 0,06 S 20 58 E 0.33 S 1 20 W 0.34 S 16 33, E 0.43 S 19 47 0.72 S 12 8 1.Z2 S 0 57 W 1.85 S 9 53 W Z.36 S 14 54 W 2.79 S 17 9 W 2,37 0,12 2.63 0.17 2.79 O, 19 2.69 0,16 2,38 0.10 2.10 0,12 2.07 2.20 6,15 3,68 16.64 2.28 31.68 3.99 3.02 S 0,89 W 3.24 S 1,05 W 3.22 S 1,26 W 2,94 S 1,31 W 2.56 S 1.19 W 2,23 S 1,OT W 2.20 S 1.06 W 4.04 S 4.71 W 8.29 S 14.45 W 15.82 S 27,48 W 3,15 S 16 26 W 3.41 S 17 57 W 3.46 S 21 18 W 3,22 S 24 5 W 2.82 S 2~ 53 W 2,47 S 25 39 W 2.44 S 25 41 W 6.21 S 49 22 W 16.66 S 60 8 W 31.71 S 50 4 W 52.48 3.81 27. 78.85 3.56 44. 110.45 2.31 64. 146.81 1.57 86. 187.33 1.23 110. 231.46 2.98 136. 282,20 3,55 165. 341.46 3,59 198. 410.78 3.?6 235. 492.92 3,50 279. 48 S 44.72 W 71 S 65.02 W 88 S 89.64 W 92 S 118.71 W 90 S 151.49 W 84 S 187.28 W 80 S 229.00 W 49 S 278.44 W 83 S 336.84 W 05 S 406.70 W 52.49 S 58 26 W 78,91 S 55 29 W 110.65 S 54 6 W 147.13 S 53 47 W 187.74 S 53 47 231.95 S 53 50 282.72 S 54 5 w 341.95 S 54 30 W 411.19 S 55 0 W 493.23 S 55 32 W 586.04 0.25 679.51 0.81 774.13 0.64 868.04 0.44 961.38 0.17 1054.91 0.36 1148.09 0.25 1240.75 0.26 1333.61 0.23 1427.22 0.05 327.41 S 486.30 W 375.49 S 566.49 W 424.46 S 647.48 W 473.32 S 727.70 W 522.07 S 807.32 W 571.33 S 886.82 W 620.90 S 965.72 W 670.60 S 1043.94 W 720.30 S 1122.37 W 770.17 S 1201.59 W 586.25 679,64 774.20 868.08 961.41 1054.93 1148.10 1240.77 1333.62 1427.23 S 56 2 W S 56 27 W S 56 45 W S 55 57 W S 57 6 W S 57 1Z W S 57 15 W S 57 17 W S 57 18 W S 57 20 W COMPUTATION DATE: 15-NOV-85 PAGE 5 ARCO ALASKA, INC. KUPARUK NORTH SLOPE,ALASKA gATE OF SURVEY: 93-NOV'-85 KELLY BUSHING ELEVATION: ENGINEER: HA'LF~CRE 73.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4495,11 3973,00 3900,00 43 30 4632.97 4073,00 4000.00 43 29 4770,52 4173,00 4100.00 43 13 4907.22 4273.00 4200.00 42 52 5043,99 4373.00 4300,00 42 57 5180,30 447.3.00 4400.00 42 37 5315,91 4573,00 4500,00 42 13 5450,32 4673,00 4600,00 41 57 5585.07 4773,00 4.700.00 42 6 5719.57 4873.00 4800.00 41 58 5854,01 497.3,00 4900,00 42 2 5988,95 5073.00 5000,00 42 16 6124,37 5173,00 5100,00 42 38 6259.96 5273.00 5200.00 42 20 6394,31 5373.00 5300.00 41 39 6528,33 5473,00 5400,00 41 40 6662,04 5573.00 5500,00 41 28 '6795.51 5673.00 5600.00 41 12 6927,68 5773,00 5700.00 40 42 7059.42 5873.00 5800.00 40 18 7189.35 5973.00 5900.00 39 46 7320.06 6073.00 6000.00 40 6 7450,51 6173.00 6100.00 39 36 7579.66 6273.00 6200.00 39 12 7680.00 6350.74 6277.74 39 12 DEG MIN FEET DEG/IO0 FEET FEE'T FEET DEG MIN S 57 44 W 1521.$6 0.36 820.64 S 1281.65 W I521.87 S 57 22 W S 57 18 W 1616.75 0.57 871.55 S i361.73 ~ 1616.76 S 57 22 W S 56 36 W 1711,20 1.01 923.03 S 1440,92 W 1711.21 S 57 21 W $ 55 52 W 1804.37 0.64 974.80 S 1518.41 W 1804.39 S 57 17 W S 55 13 W 1897.61 0.25 1027.75 S 1595.24 W 1897.65 S 57 12 'h S 54 58 W 1990.15 0.60 1080.73 S 1671.22 W 1990.21 S 57 6 $ 54 32 W 2081.64 0.83 1133.62 S 1746.01 W 2081.74 S 57 0 w S 53 22 W 2171.29 0.74 1186.37 S 1818.70 W 2171.44 S 56 52 W S 51 51 W 2261.24 0.52 1241.27 S 1890.40 W 2261.49 S 56 42 W S 51 1Z W 2350.69 0.63 1297.23 S 1960.B1 W 2351.08 S 56 30 W S 50 27 W 2439.94 0.5'7 1353.96 S 2030,52 W 2440.54 S 56 18 W S 49 39 W 2529.77 0.52 1412.07 S 2100.02 W 2530.61 S 56 4 W S 48 52 W 2620.12 0.45 1471.69 S 2169.18 W 2621.30 S 55 50 W S 48 33 W 2710.58 0.63 1532.16 S 2237.94 W 2712.17 S 55 36 W S 47 55 W 2799.23 1.10 1591.40 S 2305.33 W 2801.27 S 55 22 W S 46 39 W 2886.97 0.78 1652.06 S 2370.74 W 2889.59 S 55 7 W S 44 39 W 2973.85 1.21 1714.00 S 2434.32 W 2977.20 S 54 51 W S 43 9 W 3059.66 1.69 1777.96 S 2495.35 W 3063.97 S 54 31 W S 43 4 W 3143.42 0.14 1840,86 S 2554.61 W 3148.78 S 54 13 W S 44 29 W 3226.51 3.25 1903.33 S 2613.37 W 3233.01 S 53 56 W S 48 45 W 3308.12 1.08 1959.5~ S 2674.33 W 3315.40 S 53 46 W S 48 41 W 3391.24 0.87 2015.23 S 2737.44 W 3399.22 S 53 38 W S 48 53 W 3474.04 1.22 2070,40 S 2800.47 W 3482.70 S 53 31 W S 49 53 W 3554.99 0.00 2123.29 S 2862.78 W 3564.25 S 53 26 W S 49 58 W 3617.87 0.00 2164.09 S '2911.36 W 3627.57 S 53 22 '~ ; ALASKA, INC. 3A-6 KUPARUK NORTH SLOPE,ALASKA M~RKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION D~TE: 15-NOV-B5 INTERPOLATED VALUES FOR CHOSEN HORIZONS ORIGIN: 599' MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 7142.00 5936.50 5863.50 7221.00 59g?.27 5924.27 7327.00 6078.31 6005.31 7473.00 6190.36 6117.36 7576.00 6270.16 6197.16 7680.00 6350.74 6.277.74 PAGE 6 DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: 73.00 ENGINEER: H~LF~CRE SU FSL,768' FEL, RECTA NORT RFACE LOCATION SEC 7,T12N,Rg5,UM NGULAR COORDINATES H/SOUTH EAST/WEST 1939.63 S 2651.68 W 1972.95 S 2689.59 W 2018.18 S 2740.80 W 2079.79 S 2811.27 W 2121.80 S 2861.01 W 2164.09,S 2911.36 W FT COMPUTATION DATE: IS-NOV-85 PAGE 7 ARCO ALASKA, INC. DATE OF SURVEY: 03-NOV-85 3A-6 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 oRIGIN: 599' FSL,768' FE SURFACE LOCATION ~T L,SEC 7,T12N,RgE,UM MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SE.~ RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD 7142.00 5936.50 5863.50 7221.00 5997.27 5924.27 7327.00 6078.31 6005.31 7473.00 6190.36 5117.36 7576.00 6270.16 6197.16 7680.00 6350.74 6277.74 1939.63 S 2651.58 W 1972.95 S 2689.59 W 2018.18 S 2740.80 W 2079.79 S 2811,27 W 2121.80 S 2861.01 W 2164,09 S 2911.36 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET 9EG MIN 7680.00 6350.74 6277.74 3627.57 S 53 22 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A-6 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 00~070966 · ~ WELL NAME: 3A-6 SURFACE LOCATION: 599' FSL, 768' FEL, S7, T12N, R9E, UM -2000 -!000 0 0 000 2000 ~000 -.~--~-..~..~-.~-~--.-~-:...~-~ ..-~-..~-.~..¢ .... ~-.~-.-4.--~-- ..~-.~.-.~---~ .... .~-.~--~-;--~ .-~-~-.~..~.~-~...-~-~-.-~.~- --~.4--~--.4- -~.-~-~---~-~.-.~--.~-~--~ ..... ~.-.~-~.-~...~.-~--~---?-~ ...... ?.~---~-..~... -~-~.--~-~... 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OPERATOR, WELL flAME AND ~U~BER Reports and Materials to be received by: //-- 12 -~._~ ......... ~Date ,, Required Date Received Remarks Samples / Core Chips .......... - - Cor~ 'Description Registered Survey Plat Inclination Survey ............... Drill Stem Test Reports ..... L.FJ.04 ARCO Alaska, Inc. Post Office B~,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-13-85 TRANSMITTAL NO: 5440 ETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS. CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 -JINSMITTED HEP~L%~ITH ARE ~CEIPT AND RETURN NAL PRINTS/ $CHL/ OPEN 3C-2 . ~" -- DIL/SFL-GR ~-~ %,~ DIL/SFL-GR ~",,, DEN/NEU ~. ~2",- DEN/NEU < ~5"-' DEN/NEU ' ~2 "-- DEN/NEU ~.~ CYBERLOOK ~6, \ ~5" DiL/SFL-GR - k~ '~ 2" DIL/SFL-GR ~ ~" DEN/NEU ? ~2" DEN/NEU ~-2~ DEN/NEU CYBE EL OOK THE FOLLOWING ITE~IS. PLEASE ONE SIGNED COPY OF THIS TRANSMITTAL HOLE/ ONE PORO POkO RAW RAW DIL/SFL '~5''~ DEN/NEU 2''~ DEN/NEU 5 '~ DEN / NEU ~'~2 ~ DEN/NEU CYBERLOOK ~"/- DIL/SFL-GR ~'~2''''~' DIL/SFL-GR "~,~"" DEN/NEU '~2- ~' DEN/~NEU '~5" ~ DEN/NEU -~2" -~ DEN/NEU ?;CYME RL OOK -- ~'Q P~'~T LOG ~-~ PORO PORO RAW RAW PORO PORO RAW' ~iPT ACKNOWLEDGED: URRIER ~ON d*BL DRiLLING*BL OF EACH 09-15-85 RUN '~1 09-15-85 RUR ~1 09-15-85 RUN #1 09-15-85 RUN ~1 09-15-85 RUN ~1 09-15-85 RUN $1 09-15-~5 RUN ~1 PORO PORO RA~ RAW 10-18-85 RUN !0-18-85 RUN 10-18-85 RUN 10~18-85 RUN 10-18-85 kUN 10-18-85 RUN 10-!8-85 RUN 10-11-85 kUN $1 10-11-85 RUN $1 10-11-85 RUN ~1 10-11-85 RUN ~1 10-11-85 RUN ~1 10-11-85 RUN ~1 .10-11-85 RUN ~1 09-21-85 09-21-85 09'-21-85 09-21-85 09-21-85 09-21-85 09-22-85 09-21-85 DISTRIBUTION: W. PASHER RUN ~l }~UN #1 RUN ~1 XUN ~1 RUN ~1 RUN #1 kUN ~1 RUN ~1 DA TH: STAT ACKNOWLEDGE · L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL*BL 3858-7622 3858-7622 3858-7596 3858-7596 3858-7596 3858-7596 6750-7550 3412-7596 3412-7596 6900-7570 6900-7570 6900-7570 6900-7570 6950-7547 3972-8648 3972-8648 7900-8622 7900-8622 7900-8622 7900-8622 8100-8550 3852-8461 3852-8461 7000-8436 7000-8436 7000-8436 7000-8436 7750-~330 ~ , ...... SOHIO /SE UNION ~AULT/ANO*FILMS ARCO Alaska. Inc. JS a Su~bsJdiarv ARCO Alaska, Inc. /--~ Post Office E 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 1i-07-~5 TicANSHITTAL NO: 5431 :TURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-illLB P.O. BOX 100360 ANCHORAGE, AK 99510 ~SMITTED JCEIPT AND ~EN HQLE LIS TAPES 37T-8 / 10-16-85 fO--7~/' 10-09-85 3M-5~ 10-20-85 3F_4 ?-"' 10-13- 85 3d-16~''~ 09-29-85 3d- 15'"' 10-08- 85 3~- 14 .---~ i 0-15- 85 ~A-/~-j 10-24-85 SA- 6 -~'"' 10-18-85 ~-5~'''' 10-11-85 HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONL.' SIGNED COPY OF THIS TRANSMITTAL. PLUS LISTING/ SCHL/ ONE COPY OF EACH RUN RUN % 1 .0-7585. O~do17 ~-5--g~e-~- / ~'~P- '"/,~-~ RUN RUN fl RUN ~1 RUN %1 RUN t~1 RUN i 1 RUN ~1 1748 1994 3030 3692 3816 4050 !948 3410 3952 · 0-6900. .5-6851. . O- 7864. · 0-8425· · 0-7269. · 0-7 617. · 5- 8 6 8 3. CEIPT ACKNOWLEDGED: AE CURRIER' EVRON M DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK J..P+ATHME LL ARCO Alaska. Inc. i$ a SubslOtary o! Atiant}cRichlleldComl:)any ARCO Alaska, Inc. ~..~, Post Office B 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the October monthly reports 1B-1 (workover) 3A-7 3C-15 3J-6 2A-8 3A-8 3F-3 3J-7 2D-12 (workover) 3C-6 3F-4 3J-8 3A-5 3C-13 3F-5 4-21 3A-6 3C-14 3F-6 4-22 If you have any questions, Sincerely, . Gruber Associate Engineer please JG/tw GRU12/L80 Enclosures for call me the following wells: 9-24 L2-3 9-36 L2-13 16-17 L3-5 16-18 L3-11 18-6 (workover) at 263-4944. RECEIVED Alaska Oil & ~as C0r~s. C(:,mm!ssJ0n Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany . ~---.. STATE OF ALASKA '-"- ALASKA C._ AND GAS CONSERVATION CO~...,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~(i~-I Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-222 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21443 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 599' FSL, 768' FEL, Sec.7, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 25632 ALK 2565 10. Well No. 3A-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. October , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1130 hrs, 10/13/85. Drld 12-1/4" hole to 3426'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7600'. Ran logs. Cont'd dr19 8-1/2" hole to 7680'TD (10/18/85). Ran, cmtd, & tstd 7" csg. PBTD = 7576'. Secured well & RR ~ 2100 hrs~ 10/19/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16"~ 62.5#/ft, H-40~ weld conductor set ~ 104'. Cmtd w/175 sx AS II. 9-5/8", 36.0~/ft, J-55, BTC csg w/shoe ~ 3406'. Cmtd w/lO00 sx AS I!1 & 370 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7668'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/76047 - 3406' FDC/CNL f/7604' - 69007 Cal f/76047 - 60007 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED Naska 0il & (~as Cons. Cnrnm!ss?j~ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. rqoT[--Report~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 TENP2/NR22 Submit in duplicate MEMORANOUM TO: THRU: FROM: State of Alaska ALASKA OIL Aim GAS CONSERVATION COMMISSION C, V/~h~erton DATE: October 22, 1985 Lonn~e C. SmirCh Commissioner -~. Bobby D. Foster Petroleum Inspector TELEPHONE NO: SU BJ ECT: BOPE test ARCO - KRU - 3A-6 Permit #85-222 Kuparuk River Field Tuesday, October 15, 1985: The BOPE test began at 5:30 PM and was ~°~clu~ed a~ 8:~0"PM~ A~the attached BOPE test report shows, there was one failure which was repaired before I departed the location. In summary, I witnessed the BOPE test on ARCO's 3A-6. Attachment 02-00IA(Rev. 10/79) O&G #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Location.: Sec 7 T/~..~__~~ M U ~~asing Set @...~ _~,~ ft. Drilling C°ntractor.~_~.~.~ Rig #/~) Representative Mud Systems Trip Tank Pit Gauge ~,~ Flow Monitor Gas Detectors Visual Audio BOPE Stack . Annular Preventer / Pipe Rams Blind Rams Choke Line Valves H.C.R. ValVe Kill Line Valves Check Valve Test Pressure Test Results: Failures Pressure After ClosUre. /.~0 psig Pump incr. clos. pres. 200 psig ~ mind, sec. Full Charge Pressure Attained: , ~. mi~7 sec. Controls: Master Remote ~g~Blinds switch cover Kelly and Floor Safety Valves Upper Kelly' / Test Pressure ~~ ~ Lower Kelly ~ Test Pressure Ball Type J Test Pressure Inside BOp /' Test Pressure Choke Manifold ~$ Test Pressure~~ No. Valves No. flanges Adjustable Chokes Hydrauically operated choke / Test T~e ~ hrs. Repair or Replacement of failed equipment to be made within --- day~ and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor September 18, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-6 ARCO Alaska, Inc. Permit No. 85-222 Sur. Loc. 599:FSL, 768'FEL, Sec. 7, T12N, R9E, bM_. Btmhole Loc. !296'FNL, 1049'~L, Sec. 18, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chattert°n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-6 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3A-6, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on September 25, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JFB/tw PD/L168 Enclosures RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany la. Type of work. ~'"'- STATE OF ALASKA ~ ALASKA O,L AND GAS CONSERVATION CO~¥,,vIISSION PERMIT TO DRILL 20 AAC 25.005~ DRILL [;~]X lb. Typeofwell EXPLORATORY [] SERVICE [] STRATIGR~I~II~,.' ' '"~ [] DEEPEN [] DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 599' FSL, 768' FEL, Sec.7, T12N, RDE, UM At top of proposed producing interval 1174' FNL, 1240' FWL, Sec.18, T12N, RDE, UM At total depth 1296' FNL, 1049' FWL, Sec.18, T12N, RDE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-6 11. Field and pool Kuparuk River Fie.Id Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. EKD 73', PAD 40.8' I ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company ~..., ~. ,:-.; . ,;~',.:~i IFil':~ Type Statewide Surety and/or number #8088-26-27 3:~''/~p~lnt $500,000 30 mi. NW of Deadhorse miles 3984 feet I-5 well 25' @ surface feet 16. Proposed depth (MD & TVD) - 17. Number of acres in lease 18. Approximate spud date 7535' MD, 6274' TVD feet 2560 09/25/85 19. If deviated (see 20AAC25.050) 120. Anticipated pressures 2654 psig@ 80°F Surface KICK OFF POINT 1500 feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) 3051 psig@ c~c)2R_ ft. TD (TVD) 21 SIZE Hole Casing Weight 24" 16" 62.5# ' 12-1/4"I 9-5/8" 36.0# 8-1/2" 17" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 / Weld !-55/HF-ElIW BTC -55/HF-EIW BTC Proposed Casing, Liner and Cementing Program SETTING DEPTH Length 3339' MD TOP 80' 32' I I 7504' 32' I I I 31' I TVD 32' 112~ 32' 31' MD BOTTOM TVD 112' 3371'I 3133' I 7535'1 6274' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 730 sx CS III & 370 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7535' MD (6274' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2654 psi. Pressure calculations are based on virgin reservoir. pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A-6 will be 25' away from 3A-5 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby ce$,dl~ that the foregoing is true and correct to the best of my knowledge SIGNED ////,~ Z/~,~ TITLE Regional Drilling Engr. The spa r~C ion use/F CONDITIONS OF APPROVAL Samples required []YES J~NO Permit number DATE APPROVED BY Form 10-401 Mud log required I Directional Survey required I APl number E~YES J~]NO [ ~-YES I-INO I 5o- - '/v 0~.~"- ~ Approval date /~~ SEE COVER LETTERFOROTHERREQUIREMENTS ~~ ( ,COMMISSIONER DATE Septembe~ 18, 1985 ~~~~~ ~~~ by orderofthe Commission (JFB) PD/PD168 Submit in triplicate PERMIT TO DRILL 3A-6 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED o ]98§ Alaska Oil & Gas Cons. Commission A~cho~a§e .~--:-KUPARUK-FIELD.' NORTH SLOPE ALASKA .... T~ ..................... · ................................................................................... ...... ..................... . ................................ ~ ...... . . _ . ............ KOP:-- .T_VD= l_500-&TIdD= 150{3 DEP=O .......... ~- ........ ,3 BASE- PERMAFROST- TVD=I 553 TMD=I 55;3- DEP=I ' -- ................................................ ............. 21 ..... BUILD 3 DEO ....... .- - - PER 1 O0 FT ....... ~'~ ......... TOP W SAK--SNDS TVD=265:3 TI"lD=2738' DEP=387 ........... c: ........ £0C TVD=2754 1MD--2868 D£P--470-. '- -< -- CSG PT TVD=3133 TMD~3371--DEP--799 ................... '-- . _-~ ............................. . ._ - ...... . __ .: . ._..~ _~._Z~40002 ..................... . ' -~ ...... K-5 TVD---4~88:_T~D=_51 67 DEP=197'9 .............................. . ....... ......... ._ _5000__ __ "- . .............. ZZ_-.~ _ _ . '. . -:---:~----:-'-' AVERAGE ANGLE--- -- --:--::- :: ......... 41 -- DEG 3 ~--M I N ........ ' ' - : -: - - .............. - --'~ ' D TVD=5923 T/~=7070 DEP=-3229 . , - ' .............. . ~ fZONE A TVD=6013'-TMD=7180 DEP-3307 - ---~-' ...... - ....... ;-'-; ~ -: __-_-_-.__: - tAlaska-Oit-&-Gas-Cons. CbTi~iSsio[D -(LOG PT) . TVD-6274 TlflD=7535 'DEP= . . - .... . .... ,__, .... =_.. : .......... . ' _ ...... . ...... =~ . _ _- . - . _ ....... ?-: ....... = ............................. _ .- ....... ............ _. __ . .. _ . ...........-. Z I 1000 1000 _ 2000 _ ~0oo.' HORIZONTAL, pROJECTION SCALE 1;IN. ? 1000 FEET ARCO ^LAsKA~ I''~'.' ' ~ ..... KUPARUK FIELD~aO~TH~SLOPE, ALASKA EASTMAN 4000 WHIPSTOCK. INC, iWEST-EAST ~000 2000 ! 1000 ~ I TD LOCAl' I ON, 12~' FNL. 1049' FWL SEC. 18. l'12N. RgE , : i I,AROET CENTER TVD-6068 l,HD-7262 DEP-3355 SOUI,H 1799: ~ESf~ 2832~ . S 57 3355' 1000 SURF6CE LOOATION,~ 599' FSL, ~68' FEL SEC. ?. f l2N. RgE TARGET :LOCATION., 1200' FNL. 1200' FWL SEC. !8. T!RN. RgE , OEO 34 MI N W' (TO TARGET) :~-'":=:':- :,1-!1 O0 ? :--:' '~-,1 000 i' ::.--: 9¢~'3 ...... 800.~ ~ -- -=-, 700 .... - ~-,,600 500 ..... ---:-; ~ '~ : . '.,-::-7---,: ................ ~ ....... ; . ' ' , ~--_ :--.;__ j _- _L--;- ~ ---:_-~-,~--. - i ~ ;--' -'--i -~ - : ---': -: -- :---,J----- ' .......... ~ - ~ _:_; ...... : i---,.--'_.--i ...... L' ''~ ' -' : ' ~ ' ' : ' - -: :: :-,-.-~.---~ ..... ---: ......... : ..... ARCO AL'AStrA. 400 ' I- -; .... : ..... ,-:~-!-:-! :--:--; ,--:-::-:-; .... -= ~ .... ''-PAD 3A, WELL NO~ 5-6-7-8 PROPOSED .... .,_ ~' _ - ........... ::- _.-Z~_ KUP^RUK- FIELD, 'NORTH ~L~PE';- AK-;'; . _ '_-T_ :-;-'i~- "-~--~ ; ~'::~.':~_::~':7~_: :'~:~:-'-~ - -~.- "-- ' ..... i _ . ~ ....... : ~' ~ ..... .......................... --., : :, ::,"'. : ....... EASTHAN~ ~H~PSTOCK, ']NC'. Z;O0-~-'~ ...... -~ ~ ........ , --- ., --. ,__ ~. ; , :- -~ - . )~J~, NOTE: WELL~PATHS EXTEND BEYOND . , - ...... . ..... ~ : THIS VIEWING WINDDW ; ; ! . 1277 ......... i 1455 ........... -- 154.0 -- - : 2888 . , . ..... -: -:, 2T7 '- 227 --' : . , . - :11-77 · ! 555. . : · KUPARUK RIVER UNIT 20" DIVEJ~TER SCHEMATIC DE S CR I P T I ON I. 16 · C~CTOR. 2. TANI<O STARTER lEAD. · 5. TANKO SAVER SUB. 4, TANI,(O LOWER QUICK-C~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/t0' OUTLETS, // 7. !0" NCR BALL VALVES W/lO' DIVERTER LINES. VALVES OPEN AUTOMATICALLY UPON CLOSURE A~AR PREVENTER. 8. 20" 2000 PSI Ah, tIJLAR PREVENTER. MAI NTENANCE & OPERATI ON 2 I kECEiVED SE? i o I. UP-C~ INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES -' HAVE OPENED PROPERLY, 2. CLOSE AI~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS, CLOSE ANI'~ULAR PREVENTER IN THE EVENT 'THAT AN Ih, FLUX OF WELLBORE · FLUIDS OR GAS IS DETECTED. IF NECESSARY., MAh~ALLY OVERRIDE AI~ CLOSE APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN ~ELL UNDER ANY CIRCUMSTANCES. Alaska Oil & Gas Cons. cOmmission Anchorage 6 DIAGRAM #~ .I,T,3-5/8" :5000 PSI RSRRA BC~ STACK. I. 16' - 2000 PSI TAlg<~ STARTING ~E. AD 2. II' - ~E)C) PSI CASING ~E. AD 3. I1' - ~ PSI X 15-5/8' - 5000 PSI SPACER SPCX2L 4. 15-5/8' - 5000 PSI PIPE RA~ 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/C~;KE AND KILL LIhES 6. I~-~/B' - 5000 PSI DOL~ RA~ W/PIPE RA~ ON TQm. ?. 1~-5/8' - 5000 PSI A~ · ACC~ATC~. CAPACITY TEST I. CHECX A~ FILL ACCL~T~I~ RF~OIR TO PRC~ LEVEL WI~ ~~IC ~UID. 2. ~ ~T A~T~ ~ IS ~ ~I WI~ 5. ~ TI~, T~ ~ ~ ~ITS S~T~~Y 4. ~~ ~ ~ ~T, ~ A~T~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ ~2~ ~I ~INI~ 5 4 3 2 .! . CEiVED S£P 1 0198, Alaska Oil & Gas Coils.. 6ommission Anchorage II I 13-5/8" BOP STACX TEST 1. FILL BCP STACK AhD C~ ~ANIFO_D WITH ARCTIC 2. ~ ~T ~ L~ ~ ~ IN ~Y ~RA~. ~T ~T WI~ ~I~ ~ ~ ~ IN L~ LI~ V~VES ~~ TO ~ STA~ · ~. ~~ ~ TO ~~ ~ ~~ ~ 5~I ~ ~ F~ ~0 ~IN. 5. ~ ~ P~ ~ ~AL LI~ V~VES. ~ T~ PIPE ~ ~ ~ V~VES '~ TEST TO 2~ PSI ~~~AS IN ST~ ?. ~I~ TESTI~ ALL~ES, LI~S, WI~ A ~ PSI L~ ~ ~ PSI ~I~ T~5T ~S ~ ~ ~T ~LY ~. ~ T~ PI~ R~ ~ ~ BO~ PI~ ~ST B~ PIPE R~ TO ~ ~I ~ ~ ~I. ~ ~~ PIPE ~, ~ ~ ~I~ ~ ~ TEST TO ~i. ~. ~~ TEST I~~T~ ~ ~~ P~ ~ST I~. ~~ ~~E ~E ~ST ~'"lt~ II II II 0,084001 REV. 2 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG 0 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany 6;1 6'.5 4:3~...~ ft[S[~tV ~ 2- 3- 7 8 _ NOTES CjCRDINATES ARE A.S.P, ZONE 4 7- SECTION ~.~NE DISTANCES ARE TRUE. HOR!ZONTAL POSITIONS BAOED CN THE D.S.-OA WEST & 3AMID PER LH0 ~ ASSOC. 4. VERTICAL POSITION BASED CN 3A EAST & '8- 3A MID PER LHO B ASSOC. 5.C.G. ELEVATIONS iNTERPOLATED FROM CED- RlXX- 5020 rev. ~ 9 oF ~ ~ ~ ~1t ..~.?. ~ ..~ ~ ~o- ~,,~~,,,,,,~..~..- ~ .... .... .? . 13- AS BUILT CONDUCTORS I- 16' Y=5,g96,860.05 LAT= 70°2~+'09.520'' X= 507,712.01 LONG= 149°56' lS.020" 4?8' ESL, 736' FEL, 36.8' OG, ~,0.8 PAD Y=5,996,884. ]7 LAT: ?0°7/,' 09. 758" X= 507,705.57 LONG= lz, O°56' !z,.207'' 503' FSL, ?~+3' FEL, 36.8 Y=5,996,908.32 LAT-- 70o2~.' O..~. ]95'' x: 507,699.06 LONG= 1:,.)056' [~. 527' ;SL, 749'FEL, 36.7 OG, 40.8 PAD Y=5,996,932.72 LAT= 70°24' 10.235'' X= 507,692.55 LONG= 149°56'14.58/" 551' FSL, 756' FEL, 35.7 ¥=5,996,956.61 LAT= lO° X= 507,686.21 LONG= 575 FSL, 762'~EL, 36.50G 0 Y=5,996,980.84 LAT: 70 24'10.709" X= 507,679.66 LONG- 149°56 14.963" 599 FSL, 768' FEL, 36.50G, ~0.8 PaD Y=5,9~7,004.90 LAT- 70°24']0.gq5 X= 507,673.26 LONG= 149o56 15.151" 623 FSL, 774'FEL, 36.50G, ~ .1 P~g Y=5,997,029.03 LA[= 70°d~' [ x= 507,666.81 6~7 FSL, 781' Y=5,997,101.24 X= 507,6~7.70 720 FSL, 800m Y=5,997,125.66 X= 5.~ ,640.89 /44 ~}L, 806! Y=5,997,149.8~ X= 507,634.46 766 FSL, 813 Y:5,997,173.97 X= 507,627.96 792 FSL, 819 Y=5,997,198.08 X= 507,62[.48 817' FSL, 825 Y=5,997,222.29 OG, ~0.8 PaD 24' 10.470" 9°56, 14.773', , qO.9 PAD HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ., LI~C_CNSED TO PRACTICE LAND SURVEYIN$ IN THE ~ITATE OF ALASKA, THAT TH~S PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL 14- DETAILS ARE CORRECT AS OF AUGUST 14,1985 x= 507,615.0 LONG= I~9°55 [6.~5:" 8~+1' FSL, 832 FEL, 35.8 OG, 15- Y-5,997,2~6 4~ LAT= 70°2~' 13, ~22" reLOCATED IN PROTRACTED SEC. 7,Z 12N. R.9~ ~r I ~r~ ' ' ~ " I i ~)~ i '~ I ~1 AEkEIVEU x: 5o7.~o8.~5 ~o,~= t~¢~6'~.o~.~'' ! I~ V~/I < I I / ~, ~L, ~3~'~L, ~.6 o~..~.~ ~I i~~~1 ' I ' ~1~10~5- Y=S,991.270.55 LAr: 70024'1~.S~,," I ' ....... -'-- .... TH~S SUrf I / I r,,s so, I nil CONDUCTOR AS- ' ~ ~-~ ~ h 1 ""'"' ..... ' '""'~ ~ ..... J LONG: 169°56 t5.33:~" FEL, 36.~ OG, 40.9 tAT= 70°2~'11.893'' LONG: 149o56 15.896" FEL, 36.3 OG, ~1.7 PAD LAT= 70°26' i2.136" LONG= 149°56 16.095" F£L, 36.30G, cl.6 LAT= 70°24'12.371'' LONG: 149056 16.283" FEL, 36.2 OG, 4~ PAD LA~= 70°24'1 .509" LONG= 1~9°56 16.,,~$" FEL, 36.10G, 41.3 LAT= 70°2~' 12.8&6'' LONG= 1~g°56 FEL, 36.0 OG, cl.O LAT= 70°24' !3.]8~'' CHECK LIST FOR NEW WELL PERMITS Company ....... Lease & Well No. ITEM APPROVE DATE /' / , (1) Fee </L~ /:. ,,,, ,,: ~,> J :(2 thru 8 ('9 thru -12), :,, lO. #:ff _ q.//,/.,v: (10 and 12~) z 12, (13 thru 21) (22 t~¥u 26) 13. 14. .15. 16. 17. 18. 19. 20. 21. YES NO ,, _ 1 Is the permit fee tached . at ........................................... -.. / 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 poe 6. Is well to be deviated and is wellbore plat included., 7. Is operator the only affected party ........ ' .......... .~ . 8. Can permit be approved before ten-day wait .......................... 22. 23. 24. 25. 26. 27. Does operator have a bond in force eeeeeleeeeeeeeeeeeeeeeeeeeeeeeeeee ~ ~"' Is a conservation order needed ...................................... Is administrative approval needed. .................................. · .~,. Is the lea number appropriate ' '~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ...... Will surface casing protect fresh water zones ..::1:::..:.1::1:1:..1 Will all caSing give adequate safety in collapse, tension.and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ' ~.~..~.®...~.~....~........®.®........® Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS Additional Remarks: O HO Geology: Engi~eerin~: WVA~ ~T~ ~"~' H~:~ 1/fi// rev: 03/13/85 6.011 INITIAi~ 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. 5VP 010.~()2 VE~IFICAq~InN. I.,IS.I'NG'T PAGE 1 SL' ,VICE N.A~E :EDTT CONTIN.~A~ION ~ :Ol ** T~P~ HEADER SERVICE NAM~2~ :EDIT Da~E 5/10/~2 CONT~N[.iATION ~ :01 COMMENTS :LIbRaRY TAPE EOF ,~AXI~0~ LE ~GTH : m I L E T ¥ P W PREVIO[~$ FTh~ : 1024 ** INFORMATION RECORD5 ~* CN : A~CU ALASKA WN ~ 3A-6 WN : KUPA~UK TOWN: 12~! ~ECT~ COUN: ~ORTN ~LDP~ STAT: CTn¥~ TNC, PRES: F *]NTT UNIT TYPE 000 000 000 OOO 000 000 000 000 000 TYPE 0o0 CATE 000 000 000 000 000 000 000 000 000 CATE 0oo SIZE 016 0O4 008 OO2 004 002 012 006 0O4 SIZE 001 ~,~' 065 065 065 065 065 065 O65 065 065 CODE 065 *************************************************************************************** , AbASKA COMPUTING CENTER C~pAN~ = AT6ANTIC ~ICHFIE6~ CD~PANY WELL = 3 = KUPAHUK STATE = ALASKA 9,625" [~ 3406' .. BIT SIZE "' ~.5" TO 7600' X;,C POhY~ER lO,O LB/G RM = 4,540 ~ 7~.,0 DF 5,9 C.~ R~ ~T BMT m ~,4~t DF ~A?RTX SANDSTOWE [,,Vr* o10.~07 VE~I~'iF'Aq"InM L~STI~,~G PAGE HOLE CORP, ECT~O~ = CALIPER T '" AS ~,)i,)T ~t~N O~P~t.i SHIFTED - OVERbAYS FI~BD PRINT8 : *~*** ********************************************************************************* * SCM~{!'I41AEI~.GER [uOGS INCb{{D~;D WI'TI4 ?HIS Mt~,GNETIC TAPE: n{.{A[, I~!OUCTIO~! SPHERYCAS[,,Y FOCUSED }jOG (DI[,) , ~'C~N ) * CO~P~NSATE!') NE;IITPON E,,JJG * DATA AVAiY.,At4bV'., 6,900' '1"0 7,570' , ** DATA FO~AT RECORD ~NTR¥ BLO:CK$ TYPE SiZE REPR COD~ ENTRY 2 I 6~ 0 4 bVP OlO.WO? VEPlFICAT![ON L.T. 'T . $. I~G PAGE, 4 8 4 7~ 9 4 65 160 ~66 hOG PE Cb~BS:MO.D NO. FT O0 ~00 O0 g 0 : ~ OH~M O0 0 2O Ol O~~~ 20 0 0 OH~M 2O a4 0 0 q ,V O0 ~:~0 Ol ~ 0 ~ CAPZ O0 ~0 Ol 0 oo o ~N 0,0 0 4 g/C3 02 0 0 C/C~ Ol 0 0 ~ O0 ~20 01 0 0 O0 000 O0 0 0 4 P~ O0 890 O0 0 0 4 ~P$ O0 3]0 3! 0 '0 ~ CPS O0 330 30 0 0 4 .ITN 6O 68 68 gO0000000, 000000:00:~ 68 68 68 6:8 68 00000000000000 DEPT SP R':HOB NPHI DE. PT SP RHOB ~UT SP NPHI ~p RHOB VPNI ~P 9EPT Sp RHOB 7617.~000 . 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