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186-186
Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409813Q-0950-029-21674-00910313102Kuparuk RiverPlug Setting RecordField- Final13-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 3-Sep-21 0 12 2V-11 50-029-21311-00 907373122 Kuparuk River Multi Finger Caliper Field & Processed 4-Sep-21 0 13 2V-11 50-029-21311-00 907365411 Kuparuk River Plug Setting Record Field- Final 2-Sep-21 0 14 2V-13 50-029-21293-00 907373111 Kuparuk River Plug Setting Record Field- Final 7-Sep-21 0 15 3A-08 50-029-21445-00 907327765 Kuparuk River Packer Setting Record Field- Final 13-Aug-21 0 16 3C-17 50-029-23389-00 907330662 Kuparuk River Multi Finger Caliper Field & Processed 15-Aug-21 0 17 3H-01 50-103-20084-00 907344061 Kuparuk River Plug Setting Record Field- Final 24-Aug-21 0 18 3H-01 50-103-20084-00 907344061 Kuparuk River String Shot Record Field- Final 24-Aug-21 0 19 3H-01 50-103-20084-00 907344061 Kuparuk River Tubing Punch Record Field- Final 24-Aug-21 0 110 3H-14B 50-103-20092-02 907358282 Kuparuk River Multi Finger Caliper Field & Processed 29-Aug-21 0 111 3Q-09 50-029-21674-00 907349862 Kuparuk River Multi Finger Caliper Field & Processed 25-Aug-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϭϴϲϭϴϲϬ Ͳ^Ğƚ͗ϯϱϳϭϵBy Abby Bell at 10:25 am, Sep 23, 2021 Originated:Delivered to:2-Jun-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-09 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 06/02/2021 PTD: 1861860 E-Set: 35194 • • pT.!> l BZ —!g Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday,June 28,2016 9:46 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Kuparuk's Producer 3Q-09(PTD#186-186)Cancellation of internal IAxOA waiver with SCP of the OA. Follow Up Flag: Follow up Flag Status: Flagged Victoria- Kuparuk's Producer 3Q-09(PTD#186-186)has been internally waivered for IAxOA communication. On 2/8/15 a RWO was completed replacing the tubing string. The well has not shown indications of IAxOA since the RWO has been completed and therefore no longer shows SCP of the OA. The well is now classified as"Normal"and there is no longer justification to maintain the IAxOA communication waiver. Please let me know if you have any questions or concerns. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 WELLS TEAM co"oc° 'ps SCANNED FEB 0 62017 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(clalaska.aov; AOGCC.Insoectors(&alaska.Aov; phoebe.brooksnalaska.aov chris.wallace(8lalaska.aov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Alpine/CRU/CD1 DATE: 06/21/16 OPERATOR REP: Duffy AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD1-38 Type Inj. N ND 6,990' Tubing 830 250 260 265 265 265 Interval 0 P.T.D.202-003 Type test S Test psi 1747.5 Casing 885 300 325 325 325 325 P/F P Notes:Diagnostic CDDT-TxIA OA 800 800 800 800 800 800 Well Type Inj. TVD TubingInterval P.T.D. Type test Test psi Casing P/F Notes:Diagnostic IA DDT OA Well Type Inj, ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND 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=Industrial Wastewater R=Interval Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey O=Other(describe in notes) W=Water 0=Differential Temperature Test Form 10-426(Revised 11/2012) CD1-38 CDDT-TxIA.xis • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(8talaska.aov AOGCC.Insoectors(8alaska.00v phoebe.brooksbalaska.aov chris.wallaceealaska.aov OPERATOR: Conoc oPhiliips Alaska,Inc FIELD/UNIT/PAD: Alpine/CRU/CD1 DATE: 06/20/16 OPERATOR REP: Wertman AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD1-38 Type Inj. N ND 6,990' Tubing 1,900 3,005 2,972 2,958 Interval O P.T.D.202-003 Type test S Test psi 1747.5 Casing 1,900 3,073 3,042 3,029 P/F P Notes:Diagnostic CMIT-TxIA OA 780 839 839 839 Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Diagnostic IA DDT OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND 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=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) CD1-38 CMIT-TxlA As RECEIVED STATE OF ALASKA ' AL. A OIL AND GAS CONSERVATION COh, ..iSION MAR 0 5 2015 REPORT OF SUNDRY WELL OPERATIONS ®OGCC 1 Operations Performed Abandon r Repair well r- Rug Perforations r Perforate r Other �-` Alter Casing r Pull Tubing r' Stimulate-Frac r Waiver 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 J' Exploratory r 186-186 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21674-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25512 KRU 3Q-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary. Total Depth measured 7990 feet Plugs(measured) 7365 true vertical 6696 feet Junk(measured) 7580, 7587, 7800 Effective Depth measured 7612 feet Packer(measured) 7195, 7321 true vertical 6381 feet (true vertical) 6035,6139 Casing Length Size MD TVD Burst Collapse Conductor 77 16" 115' 115' Surface 4245 9.625" 4282' 3739 Production 7846 7" 7881' 6605' Perforation depth: Measured depth: 7508'-7530',7535'-7570' SCANNED wl n h, zf _1,; True Vertical Depth. 6294'-6312,6317'-6346' Tubing(size,grade,MD,and TVD) 3.5, L-80, 7460 MD,6254 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7195 MD and 6035 TVD PACKER-BAKER FHL RETRIEVABLE PACKER @ 7321 MD and 6139 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil P Gas r WDSPL r Daily Report of Well Operations XXX 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.O Exempt 314-540 Contact Janelle Nesvold Cal 263-4641 Email Janelle.R.Nesvoldconocophillips.com Printed Name Janelle Nesvold Title Sr. Wells Engineer Signature Phone:263-4641 Date 3/Li/i. w-1- 3/I9P RBDMSk MAR - 6 2015 �/" Form 10-404 Revised 10/2012 Submit Original Only KUP PROD 3Q-09 COnoCoPhillip5 illA Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status 'Inc!(°) MD(ftKB) Act Btm(ftKB) ,....0,;,,,,,, pr. 500292167400 KUPARUK RIVER UNIT PROD 43.00 4,300.00 7,990.0 ".. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 30-09,31420158:39:47 AM SSSV:NONE 130 12/22/2014 Last WO: 2/1/2015 42.51 1/4/1987 Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,488.0 2/16/2015 Rev Reason:WORKOVER,GLV C/O,PULLED smsmith 1/8/2015 HANGER;34.0... a-,,.,.I PLUG/CATCHER/RHC I -Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 1150 62.50 H-40 WELDED `; Casing Description OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 37.0 4,282.4 3,739.3 36.00 J-55 BTC fai Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread PRODUCTION 7 6.276 35.0 7,880.5 6,604.6 26.00 J-55 BTC ® Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;38.0-115.0 .. TUBING-WO-2015 31/2 2.992 34.0 7,306.8 6,127.2 9.30 L-80 EUE 8rd Mod Completion Details Nominal ID GAS LIFT;2,700.3 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 34.0 34.0 0.02 HANGER CAMERON TUBING HANGER 3.500 III II 7,164.7 6,010.6 35.05 LOCATOR GBH-22 LOCATOR SUB 2.992 7,165.7 6,011.4 35.05 SEAL ASSY 80-40 SEAL ASSEMBLY 3.000 GAS LIFT,4,158.9 - 7,172.4 6,016.9 34.98 PBR BAKER 80-40 PBR 3.000 11 7,195.1 6,035.5 34.78 PACKER BAKER 4782 FHL RETRIEVABLE PACKER 2.992 I 7,245.9 6,077.2 34.82 NIPPLE CAMCO DS NIPPLE 2.813 7,294.3 6,117.0 34.92 LOCATOR GBH-22 LOCATOR SUB 3.000 7,295.3 6,117.8 34.92 SEAL ASSY 800 SEAL ASSEMBLY 3.000 SURFACE:37.0-4,282.4• • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Sot Depth(TVD)(...WI(lb/ft) Grade Top Connection TUBING WO-2006 31/2 2.992 7,299.0 7,459.6 6,253.7 9.30 L-80 8rd EUE • Completion Details GAS LIFT;5,3334 1Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel(°) Item Des Com (in) 7,299.0 6,120.8' 34.93 PBR CAMCO PBR 3.000 7,320.6 6,138.5 34.71 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 I 7,365.1 6,175.2 34.24 NIPPLE CAMCO'D'NIPPLE 2.750 GAS LIFT;6,163.1 7,459.1 6,253.2 33.69 WLEG WIRELINE ENRY GUIDE 2.960 • $ Other In Mole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (1 Des Corn Run Date ID(in) GAS LIFT;6.773.4 i 7,278.0 6,103.6 34.89 CUT TUBING CUT TUBING WITH 2 3/8 CHEMCUT USING 1/5/2015 III STRINGSHOT IOf 7,580.0 6,354.0 33.54 FISH OLD PACKER ASSEMBLY 11/23/2006 0.000 II 7,587.0 6,359.8 33.54 FISH Milled PACKER MILLED PACKER FROM ORIGINAL 11/26/2006 2.347 GAS LIFT;7,107.9 a COMPLETION MILLED&PUSHED TO BOTTOM 11/26/2006 III 7,800.0 6,537.5 33.45 FISH Packoff DMY DANIEL'S PACKOFF DUMMY lost 5/10/2006 5/10/2006 LOCATOR:7,164.7 Perforations&Slots SEAL ASSY:7,165.7 Dens PBR;7,1724c* Shot Top(TVD) Bim(TVD) (shots/i Top(ftKB) Btm(ftKB) (ftKB) MKS) Zone Date t) Type Com_ PACKER;7,195.1 7,508.0 7,530.0 6,294.0 6,312.3 C-0,A-2,3Q- 8/25/1991 6.0 APERF 2 1/8"EnerJet,Zero deg in 09 phasing a7,535.0 7,542.0 6,316.5 6,322.3 A-1,3Q-09 6/22/2007 5.0 APERF 2.5"Power Spiral EnerJet a -est.36.6"pen,0.38" hole a 7,542.0 7,570.0 6,322.3 6,345.6 A-1,30-09 2/27/1987 4.0 IPERF 4"HSC Csg Gun,120 deg phasing Cement Squeezes CUT TUBING,7,278B I Top(TVD) Bim(TVD) Top OMB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 7,454.0 7,456.0 6,249.0 6,250.7 Cement Squeeze 2/28/1987 LOCATOR;7,294.3 y Mandrel Inserts SEAL ASSY:7295.3 i i k Sl on PBR;7,299.0 Top(ND) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery _ Type Type (in) (psi) Run Date Com PACKER,7,320.6 1 2,700.3 2,508.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,269.0 2/16/2015 _ -... 2 4,158.9 3,648.7 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,270.0 2/16/2015 NIPPLE:7,365.1 3 5,333.4 4,540.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,267.0 2/15/2015 ii. 4 6,163.2 5,201.6 CAMCO MMG 11/2 GAS LIFT OV RKP 0.250 0.0 2/15/2015 DCR- 1 I II 5 6,773.5 5,693.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/7/2015 WLEG;7,459.1 al 6 7,107.9 5,964.2 CAMCO "MMG 11/2 GAS LIFT DMY 'RK " 0.000 0.0 2/7/2015 Notes:General&Safety End Date Annotation _ 5/14/1995 NOTE:WAIVERED WELL:IA x OA COMMUNICATOIN APERF;7,508.0-7,530.0- _ 7/26/2006 NOTE:WORKOVER 2/25/2015 NOTE:WORKOVER APERF;7,535.0-7,542.0- IPERF;7,542 0-7,570.0- 0-.I FISH;7,587.0 -. FISH;7,580.0 FISH;7,800.0 PRODUCTION,35.0-7,880.5 ` 3Q-09 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 5/26/2014 (WC) : MIT-OA (PASSED)TO 1820 PSI, TIFL (FAILED) DUE TO IA FL INFLOW AND IA PSI INCREASE DURING MONITOR. 6/8/2014 BRUSH n' FLUSH TBG DOWN TO 7365' RKB; RAN HOLEFINDER DOWN TO 7344' RKB (GOOD TT TO 1150 PSI); LOST HOLEFINDER @ 200'WHILE POOH. IN PROGRESS. 6/9/2014 RECOVER HOLEFINDER @ 221' SLM; SET 2.75" CAT SV @ 7365' RKB. REPLACED 1/4" OV @ 5792' RKB. PRESSURE UP TBG TO 1800 PSI WHILE DHD CONDUCTED SI-TIFL (FAILED). IN PROGRESS (AWAITING PATH FORWARD). 7/16/2014 LOG BASELINE TEMP/SPIN TO CAT SV @ 7365' RKB, HAVE LRS MITT TO 2500#, WORK W/ DHD TO ESTABLISH INFLOW BUT DATA WAS INCONCLUSIVE, HAVE LRS ATTEMPT TO CMIT-TxIA TO 2500# WHILE LOGGING UP TO SURFACE W/TEMP/SPIN, NO ANOMALIES FOUND, R/D TO MOVE TO NEXT JOB LITTLE RED ESTABLISHED LLR OF 1.4 GPM PUMPING DOWN IA TAKING RETURNS TO FORMATION. JOB DONE. 7/17/2014 (AC EVAL) : CMIT-T X IA (FAILED) TO 2500 PSI DUE TO A LLR OF 5.32 GPM. MIT-T (PASSED)TO 2500 PSI. 7/21/2014 PULLED 2.75" CAT SV& SET 2.75" CA-PLUG @ 7365' RKB. TESTED TBG 2500 PSI AGAINST PLUG. SET CATCHER @ 7327' SLM. IN PROGRESS. 7/22/2014 PULLED OV @ 5792' RKB; PULLED GLVs © 4575' &2931' RKB & SET DVs. LOADED TBG & IA W/220 BBLS DSL. SET DV @ 5792' RKB. MIT TBG TO 2500 PSI ( PASS) READY FOR E/L. 7/26/2014 HOISTED PDS LEAK DETECT FROM SURFACE TO 7365'. TOOK STOP COUNTS AROUND THE PACKER(7321')AND GLM (7249'). LEAK SIGNATURE SEEN AT 7,268, BELOW GLM#5. DATA SENT IN FOR PROCESSING. JOB COMPLETE. 8/15/2014 (PRE-RWO): T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), FT LDS (ALL FUNCTIONED PROPERLY) 9/3/2014 (SEC): T DDT FAILED DUE TO PRESSURE INCREASE DURING MONITOR. 9/5/2014 (SEC): T& IA DDT-IN PROGRESS. RE-ENERGIZE IC PO. 11/28/2014 ATTEMPTED PULL EQ PRONG © 7340' SLM, 7365' RKB. RAN 2.5" BAILER TO PLUG @ 7365' RKB. IN PROGRESS. 11/29/2014 PULLED AVA CATCHER; PULLED CA-2 PLUG @ 7365' RKB. TAGGED @ 7493' SLM. MEASURED BHP @ 7500' RKB: 3384 PSI. COMPLETE. 1/3/2015 LOGGED SBHPS @ 7475' RKB, TEMP = 156degf, PRESS = 3411#, GRADIENT STOP @ 7354' RKB, TEMP = 154degf, PRESS = 3376#, LRS LOADED WELL W/90 BBLS OF SEAWATER & 30 BBLS OF DIESEL FOR FREEZE PROTECT JOB IN PROGRESS. 1/4/2015 SET 2.75" CA-2 IN NIPPLE @ 7365' RKB, DEPLOYED 8' CATCHER SUB & PULL RK-DGLV FROM ST#5 @ 7249' RKB, FIRED STRING SHOT FROM 7278' -7286' RKB....JOB IN PROGRESS. 1/5/2015 CUT TBG W/2-3/8" CHEMCUT @ 7282' RKB...JOB DONE. POST RIG WELL WORK 2/15/2015 PULLED RHC PLUG @ 7246' RKB; REPLACE SOV W/OV @ 6163' RKB; REPLACED DV W/GLV @ 5333' RKB. IN PROGRESS. 2/16/2015 PULLED DV'S AND SET GLV'S 4158' & 2700' RKB (TEST TBG TO 2000 PSI); BAIL SAND & PULLED CATCHER @ 7357' RKB; PULLED PRONG FROM CA-2 PLUG @ 7365' RKB. IN PROGRESS. 2/17/2015 PULLED CA-2 PLUG @ 7365' RKB. TAGGED @ 7488' SLM, EST. 51' FILL. MEASURED BHP @ 7511' RKB: 3485 PSI. COMPLETE. ConocoPhiflips Time Log & Summary Wellv/ew Web Reporting Report Well Name: 30-09 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 2/3/2015 9:00:00 AM Rig Release: 2/8/2015 1:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/01/2015 24 hr Summary Rig Released form 1C-04 at 0800 HRS. Continue prep rig and location for move to 3Q-09. Rig down Handy berm, and tanks. Rig down lines. Prep pits. Standby for Peak Trucks. 08:00 18:00 10.00 0 0 MIRU MOVE WAIT T Rig Released from 1C-04 at 0800 HRS. Standby for Truck availability form Peak. Prep location and rig for move. RD berming around pits, cuttings tank, and cellar. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Continue to standby for Truck availability form Peak. Remove berming around satellite office. Move cuttings tank, parts house, and mud shack. 02/02/2015 Move shop, satellite office, pits, and rig sub from 1C pad to 3Q pad. Rig sub arrived on 3Q pad at 23:30 hours. 00:00 03:00 3.00 0 0 MIRU MOVE WAIT T Continue to standby for Truck availability form Peak. Disconnect power to the shop and electrical shack. Clean and service the rig. 03:00 05:00 2.00 0 0 MIRU MOVE MOB P PJSM with rig crew and Peak. Warm up the rig moving system. Load shop onto truck. Jack up the pits and pull pits away from the sub. Jack up satellite office and hook up truck. Stage shop and satellite camp towards the entrance of the pad and wait for field crew change to start moving them from 1C pad to 3Q pad. 05:00 06:30 1.50 0 0 MIRU MOVE MOB P PJSM. Lay down the derrick and pull off well 1C-04 06:30 08:00 1.50 0 0 MIRU MOVE WAIT T Wait for truck to move the pits. Hook up the Jeep to the pits and stage at 1C pad entrance. 08:00 16:30 8.50 0 0 MIRU MOVE MOB P Mobilize shop, satellite office, and pits to 3Q pad. Mobilize rig sub to 3Q pad at 08:30 hours 16:30 18:00 1.50 0 0 MIRU MOVE WAIT P Stop at 3C access road for STP change out. 18:00 23:30 5.50 0 0 MIRU MOVE MOB P Move sub from 3C access road to 3Q pad. 23:30 00:00 0.50 0 0 MIRU MOVE MOB P Rig sub arrived on 3Q pad. Place DSA in the cellar Page 1 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/03/2015 24 hr Summary MIRU over 30-09. Raise derrick and pin A-Legs,spot and center over well Spot pit module in place. Rig accepted at 09:00. Rig up and lubricate out BPV. Rig up squeeze manifold and hard line; PT lines to 3000 psi. Bleed off gas cap, SITP=0, SICP=0. Circulate 284 bbls of 10.7 ppg brine at 2 bpm; ICP 85 psi, FCP 246 psi. Monitor well, observe gas breaking out. Circulate hole volume at 3 bpm 380 psi. Observe well, static. Set BPV and test to 1000 psi. N/D tree and adapter. N/U BOPE. • 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Hang tree in the cellar and position sub on the pad with the wind at the back in preparation to raise the derrick. Level matting boards around cellar and lay herculite. 01:00 02:00 1.00 0 0 MIRU MOVE MOB P Raise the derrick and pin the A-legs. 02:00 04:30 2.50 0 0 MIRU MOVE MOB P Spot and center rig over well 30-09. Put rig mats under sub and lay down herculite. Level and set the sub down. 04:30 09:00 4.50 0 0 MIRU MOVE MOB P Move pit into place, lay herculite,set cuttings tank, level and set pit. 09:00 11:00 2.00 0 0 MIRU MOVE RURD P Rig accepted at 09:00. Prep pits to take on fluie. Bridle down and secure floor. 11:00 13:00 2.00 MIRU WELCTL MPSP P R/U lubricator. PT to 3000 psi. Lubricate BPV. IA=850 psi,Tubing =700 psi, OA= 140 psi. 13:00 14:30 1.50 MIRU WELCTL RURD P R/U squeeze manifold to kill well. R/U hardline 14:30 17:30 3.00 MIRU WELCTL KLWL P PJSM PT lines to 3000 psi. Bleed off gas cap. Tubing and IA pressure =0 psi. Circulate 284 bbls at 2 bpm; ICP 85 psi, FCP 246 psi. Good 10.7 ppg brine returned to surface. 17:30 18:00 0.50 MIRU WELCTL OWFF P Monitor well. no flow; observe gas breaking out of fluid. 18:00 20:00 2.00 MIRU WELCTL CIRC P Circulate hole volume at 3 bpm 380 psi. 20:00 20:30 0.50 MIRU WELCTL OWFF P Monitor well, static. 20:30 21:00 0.50 MIRU WHDBO MPSP P Set BPV and test to 1000 psi. 21:00 23:00 2.00 MIRU WHDBO NUND P N/D tree and adapter. Function test LDS, inspect hanger threads. Threads in poor quality. 23:00 00:00 1.00 MIRU WHDBO NUND P N/U BOPE; install DSA,stack and riser. 02/04/2015 Continue to N/U 13-5/8"BOPE with 2-7/8"x 5"VBR's in upper and lower cavity. Fill stack. R/U and test BOPE 250/3000 psi. Pull BPV. M/U spear and engage tubing hanger. Pull hanger to the floor PUW 80K. Reverse circulate hole clean staging pumps up to 4 bpm 820 psi. POOH with 3-1/2"decompletion to 5,374'. Service TD and drawworks. Continue to POOH with 3-1/2"decompletion to surface. R/D GBR. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P Continue to N/U 13-5/8"BOPE with 2-7/8"x 5"VBR's in top and bottom cavity. 02:30 04:30 2.00 0 0 MIRU WHDBO RURD P Fill Stack. R/U test equipment. Page2of6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 09:30 5.00 0 0 MIRU WHDBO BOPE P Test BOPE's to 250/3500 psi. State's right to witness test waived by Johnnie Hill. 1)Blind rams; Chokes 1,2, 3, 16; Rig floor kill, outer test spool, IBOP- pass 2) Blind Rams; Chokes 4, 5, 6; HCR Kill, Inner test spool, Manual IBOP- pass 3) Blind rams; Chokes 7,8,9; manual kill, inner test spool, HT38 TIW- pass 4)Super choke and Manual Choke- pass 5) Blind Rams; Chokes 10, 11; Manual Kill, inner test spool, HT38 Dart-pass 6)Blind rams; Chokes 12, 13, 15; Manual Kill-Pass 7)3-1/2"TJ Annular; Choke 14; Manual Kill, 8rd TIW-pass 8)3-1/2"TJ UPR; Choke HCR; Manual Kill, 8rd TIW-Pass 9)3-1/2"TJ UPR, Manual Choke, Manual Kill, 8rd TIW-pass 10)3-1/2"TJ LPR; 8rd TIW Accumulator test-Starting pressure 3000 psi, final pressure 1700 psi. First 200psi recharge 16 seconds; Total recharge 92 seconds. 5 N2 bottles at 1965 psi 09:30 10:30 1.00 0 0 MIRU WHDBO RURD P Blow down choke and kill lines. R/D testing equipment 10:30 11:00 0.50 0 0 MIRU WHDBO MPSP P Pull BPV 11:00 11:30 0.50 0 0 COMPZ RPCOM RURD P R/U GBR pipe handling equipment. C/O Elevators. 11:30 12:00 0.50 7,282 7,282 COMPZ RPCOM PULL P Make up Baker Spear. Engage tubing hanger. BOLDS 12:00 12:30 0.50 7,282 7,250 COMPZ RPCOM PULL P Pull Hanger to rig floor. PUW 80K, SOW 68K. LID Spear and hanger. 12:30 15:00 2.50 7,250 7,250 COMPZ RPCOM CIRC P R/U and Reverse circulate hole volume staging pumps up from 2 bpm(258 psi)to 4 bpm (820 psi) Monitor well,static.B/D lines. 15:00 17:30 2.50 7,250 5,374 COMPZ RPCOM PULL P POOH with 3-1/2"decompletion to 5,374'. PUW 65K, SOW 60K. 17:30 18:00 0.50 5,374 5,374 COMPZ RPCOM SVRG P Daily service of TD and drawworks 18:00 23:30 5.50 5,374 0 COMPZ RPCOM PULL P Continue POOH with 3-1/2"decomp to surface. Pitting observed on collars from joint 223-227 and last GLM (7083'to 7256')-pictures in well file. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P R/D GBR equipment. Clean and clear rig floor. Page 3 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/05/2015 24 hr summary Clean and clear rig floor. Install wear ring. M/U BHA#2 Baker Overshot. Single in the hole from 212'to 7,217'. Slip and cut drilling line. Obtain SPR's, establish parameters PUW 130K, SOW 110K. Slack of to 7,269'(N7 RKB)with 10K WOB. Pick up, no drag observed. Rotate down at 25 rpm's, 0.5 bpm to 7,272'. Continue to slack off to 7,275'with 15K WOB. Pick up with 20-30K drag. Observe seals exit SBE. Slack off at 2 bpm and observe seals enter SBE. Pick up and circulate 1.5 times annular volume. Monitor well. POOH with BHA#2 to 212'. 00:00 00:30 0.50 0 0 COMPZ RPCOM RURD P Continue to clean and clear rig floor. 00:30 01:00 0.50 0 0 COMPZ RPCOM SVRG P Inspect and service top drive. 01:00 01:30 0.50 0 0 COMPZ WELLPF OTHR P Install wear ring. 01:30 04:00 2.50 0 212 COMPZ WELLPF BHAH P M/U BHA#2 Baker Overshot. 04:00 04:15 0.25 212 212 COMPZ WELLPF SFTY P Well Control drill with DC in annular preventer 04:15 15:00 10.75 212 7,217 COMPZ WELLPF PULD P Single in the hole with drill pipe from 212'to 7,217'. PUW130K, SOW 110K. 15:00 15:30 0.50 7,217 7,217 COMPZ WELLPF SVRG P PJSM Daily service and inspection of top drive, crown and drawwoks. 15:30 17:30 2.00 7,217 7,217 COMPZ WELLPF SLPC P PJSM Slip and cut drilling line. 17:30 18:00 0.50 7,217 7,258 COMPZ WELLPF FISH P Obtain SPR's. Establish parameters: PUW 130K/SOW 110K, ROT 115K. Free torque 3800 ft-lbs at 25 rpms. Slack off to 7,269'(N7 RKB),stack 10K on fish. Pick up; no drag observed. Rotate down at 25 rpm's,0,5 bpm to 7,272'. Shut down rotary and slack off to 7,275'with 15K WOB. Pick up and observe 20K of drag increasing to 30K prior to falling off. Slack off while pumping 2 bpm and observe pressure increase as seals engage SBE. Pick up out of SBE to 7,258'. 18:00 20:00 2.00 7,258 7,258 COMPZ WELLPF CIRC P Circulate annular volume x 1.5 at 4 bpm 700 psi. Observe gas break out at bottoms up. Monitor well for 10 minutes, static. 20:00 00:00 4.00 7,258 212 COMPZ WELLPF TRIP P POOH with BHA#2 to 212'. Monitor hole at BHA. 02/06/2015 L/D BHA#2; cut joint and seals recovered. P/U BHA#3 cleanout assembly; 3-1/2"mule shoe with 6-1/8" string mill. RIH to 7,260',establish parameters PUW 135k, SOW 110K. Establish circulation at 3bpm and wash down to 7,293;tag top of PBR; pick up and slack off to 7,307'tag bottom of PBR. Circulate hole clean. Monitor well,static. POOH laying down drill pipe. L/D BHA#3. Pull wear ring. R/U and RIH with 3-1/2" completion as per detail to 4070'. 00:00 01:00 1.00 212 0 COMPZ WELLPF BHAH P L/D BHA#2 overshot with cut joint and seals. 01:00 01:30 0.50 0 0 COMPZ WELLPF SVRG P Daily inspection and service top drive. 01:30 03:00 1.50 0 235 COMPZ WELLPF BHAH P M/U BHA#3 3-1/2"Mule shoe and string Mills. Page 4of6I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 05:30 2.50 235 7,285 COMPZ WELLPF TRIP P RIH with BHA#3 to 7,260'. Establish parameters PUW 135K, SOW 110K. Establish circulation at 3 bpm 460 psi. Slack off and tag top of PBR at 7293'(N7 RKB),WOB 5K. Pick up and turn 1/4 turn,slack off and engage PBR down to 7,307'(14' PBR assembly). Stage pumps up to 4 bpm to clean out PBR. Pick up to 7,285'. 05:30 06:30 1.00 7,285 7,285 COMPZ WELLPF CIRC P Circulate annular volume, stage pumps up to 7 bpm 1880 psi. Monitor well, static. 06:30 13:00 6.50 7,285 235 COMPZ WELLPF PULD P POOH with cleanout assembly, laying down drill pipe. 13:00 14:00 1.00 235 0 COMPZ WELLPF BHAH P L/D BHA#3 clean out assembly 14:00 17:30 3.50 0 0 COMPZ RPCOM RURD P Pull wear ring. Clean and clear rig floor. R/U GBR equipment and prepr to run 3-1/2"completion. 17:30 00:00 6.50 0 4,070 COMPZ RPCOM PUTB P RIH with 3-1/2 Gas Lift completion as per detaril to 4070'. 02/07/2015 Continue to RIH with 3-1/2"completion to 7,290'; PUW/SOW 80/73K. M/U head pin. Establish circulation; slack off and observe seals enter PBR. No-Go at 7,306.5'. Pick up out of seals. Displace well to 8.5 ppg seawater. Spot corrosion inhibited seawater(1%Conqor 303A). Space out 1'from no-go. Set FHL packer; pressure up to 2800 psi. Test FHL packer to 1500 psi-good. Shear out PBR. Space out 7'from no-go. Land hanger, RILDS. MIT-T to 3000 psi-good. MIT-IA to 2500 psi-good. Shear out SOV. Monitor well, static. Set BPV and test. N/D BOPE, N/U tree. Test tree and void 250/5000-good. Pull BPV. Freeze protect well. Set BPV, secure well. 00:00 05:30 5.50 4,070 7,285 COMPZ RPCOM PUTB P Continue to RIH with 3-1/2" completion as per detail to 7,290' PUW 80K SOW 73K. M/U head pin. Establish circulation.at 0.5 bpm. Slack off and observe seals enter PBR. Space out 1'. Plck up to 7,285'. 05:30 07:00 1.50 7,285 7,285 COMPZ RPCOM DISP P Displace hole from 10.7 ppg brine to 8.5 ppg seawater; pump 10.7 ppg high viscostiy spacer followed by 8.5 ppg seawater at 4.5 bpm 900 psi. 07:00 09:00 2.00 7,285 7,285 COMPZ RPCOM CRIH P Spot 190 bbls corrosion inhibited seawater(1%Conqor 303A)in the IA; 5 bpm 650 psi. 09:00 10:00 1.00 7,306 7,306 COMPZ RPCOM PACK P Slack off to space out 1'from no-go. Set FHL packer; pressure up to 2800 psi and hold for 5 minutes. Bleed to 500 psi, pressure up on IA to test FHL packer to 1500 psi-good. 10:00 11:00 1.00 7,306 7,306 COMPZ RPCOM THGR P Shear out of PBR. Slack off and tag no-go. Space out and land hanger. RILDS. 11:00 13:00 2.00 7,306 7,306 COMPZ RPCOM PRTS P MIT-T to 3000 psi for 15 minutes- pass. Bleed to 1500 psi. MIT-IA to 2500 for 30 minutes-pass. Bleed pressure from tubing and shear out SOV. 13:00 13:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor well,static. Page 5 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 0 0 COMPZ WHDBO MPSP P Set BPV and test from below to 1000 psi-good 14:30 18:00 3.50 0 0 COMPZ WHDBO NUND P N/D BOPE. Install dart in BPV. N/U tree. 18:00 20:00 2.00 0 0 COMPZ WHDBO PRTS P Test tree and void 250/5000 psi- good. 20:00 21:00 1.00 0 0 COMPZ WHDBO MPSP P Pull BPV. R/U to freeze protect. 21:00 23:00 2.00 0 0 COMPZ WHDBO FRZP P Freeze protect well to 1800'MD; 2bpm 850 psi. Allow to U-Tube. 23:00 00:00 1.00 0 0 COMPZ WHDBO MPSP P Set BPV, secure well. 02/08/2015 Secure Tree and cellar. Ensure all valves and gauges installed. Shut in Presures-TBG -0 PSI, ANN-0 PSI. OA=0 PSI. Rig Released at 0100 HRS 00:00 01:00 1.00 0 0 DEMOB MOVE RURD P Secure well and cellar. Install guages. Rig Released at 01:00 Page 6 of 6 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) X Two-Sided RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGES: '~' / NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: ~'~ - (at the time of scanning) SCANNED BY: ~BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: PAGES: Quality Checked (done) Rev1 NOTScanned,wpd • .✓ . ConocoPhillips • Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount i is ka Usi & Alaska Oil and Gas Commission 0; CCMS• ) I SS1 333 West 7 Avenue, Suite 1 "�L�' OR Anchorage, AK 99501 r I Commissioner Dan Seamount: 3 0 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 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 corrosion inhibitor /sealant was pumped 10/18, 10/19 and, 10/21, 2011. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • f ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field' Date 10/26/11 2L, 3K, 3M & 3Q PAD Corrosion Initial top of Vol. of Cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A 12" N/A 5.95 10/21/2011 3M -03A 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 3Q -03 50029222210000 1911260 SF N/A 18" N/A 3.45 10/19/2011 30-07 50029216820000 1861940 SF N/A 17" N/A 4.68 10/21/2011 3Q -08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 3Q -09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 • • ~ ~ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2009 . ,4'~`e~+,,,.4J f~ 1i'' ,s ~~~~te' ;r./*~ ~ -!~~ ~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ a~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16th, 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 I~lein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Sur~ace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/18/09 3H, 318 3Q PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top o date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27:' NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 • 7/16/2009 3H-24 501032023500 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 1911260 SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6,8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/90/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6f26/2009 6 6/30/2009 /~ ~~~~~~~~ Schlumberger -DCS 2525 Gambeli Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # /, ~~ -- ~.~~~~ AU G ~ _~ 2D~8 Log Description Company: Alaska Oii & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 08/06/08 1 A-22 12097412 G LS ~ - ~ (p 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23!08 1 1 1A-22 12097413 PROD PROFILE - ~ 07/23/08 1 1 1A-28 11996647 PROD PROFILE ~/ 07/24/08 1 1 1A-25 11996648 PROD PROFILE i - 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE 07/26/08 1 1 1 E-112 12080408 INJECTION PROFILE 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE 07/28/08 1 1 3J-10 12097408 SBHP SURVEY 07/20/08 1 1 3M-28 12097411 SBHP SURVEY C - Q ( 07/21/08 1 1 1 L-15 11982443 PROD PROFILE 07/06/08 1 1 30-08A 12080407 SBHP SURVEY Z~°- i~~ - l93 ~ lp'~-(o 07/26/08 1 1 30-09 12080406 SBHP SURVEY - /(® °~-(~~ 07/26/08 1 1 1 L-24 11978468 PRODUCTION PROFILE 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE ~ ~ ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -pY 07!31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 1H-~-`. `jj 12100434 INJECTION PROFILE U2C ~ '~ {0 08/03/08 1 1 UGNU DS2-OBI 11996650 TEMPERATURE LOG ~ 07/27/08 1 1 2X-14 12100432 LDL L ~ 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08/04/08 1 1 iH-09 12100436 INJECTION PROFILE U 08/05/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~~ 1. Operations Performed: . . RECEIVED STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Ala ~ I EJ OilS. . . An.Hiorage Time Extension 'D JUL 2 3 Z007 n Abandon D Alter Casing D Repair Well D Pull Tubing D Operat. ShutdownD Re-enter Suspended Well D Plug Perforations D Stimulate D Waiver D Perforate New Pool D Perforate [] / Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 34' 4. Well Class Before Work: Development [] / Stratigraphic D 5. Permit to Drill Number: 186-1861 - 6. API Number: 50-029-21674-00 / Exploratory D D Service 9. Well Name and Number: 3Q-09 / 8. Property Designation: ADL 25512:ALK 2553 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool / Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 7990' / feet true vertical 6696' / feet measured 7612' feet true vertical 6381' feet Length Size MD 80' 16" 115' 4258' 9-5/8" 4282' 7846' 7" 7880' Plugs (measured) Junk (measured) 7587', 7800' TVD Burst Collapse 115' 3739' 6604' Measured depth: 7508'-7530', 7535'-7542', 7542'-7570' true vertical depth: 6294'-6312',6316'-6322', 6322'-6346' S'CANNED AUG 0 3 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7460' MD. Packers & SSSV (type & measured depth) Baker FHL retrie. Pkr @ 7321' Cameo 'OS' nipple @ 483' 12. Stimulation or cement squeeze summary: RBDMS 8Fl AUG 0 1 2007 Intervals treated (measured) not applicable 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 930 842 . Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casin Pressure 2203 796 1975 816 15. Well Class after work: Exploratory D Development [] Service D Tubin Pressure 210 204 Daily Report of Well Operations _X 16. Well Status after work: Oil[] GasD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature WAGD GINJD WINJD WDSPL D Sundry Number or N/A if C.O. Exempt: none John Peirce @ 265-6471 John Peirce Title Phone: 265-6471 Wells Group Engine~~te 7/1'1 /dl Pre are b Sharon AlIsu -Drake 263-4612 lJ?lJ) ,.¿S 7. "'/.Þ7-t>7 ~7~~Ø7 \NAL . 3Q-09 Well Events Summary . DATE Summary 5/5/07 DRIFT WITH 2.5" x 11' DUMMY GUN TO 7569' RKB, NO RESTRICTIONS ENCOUNTERED. 5/18/07 RE- ENERGIZE IC PO 'P' SEAL, BLED OA FOR BUR. 6/22/07 PERFORATED 7535' - 7542',5 SPF GUN: 2 1/2" POWER SPIRAL ENERJET, 36.6" PENETRATION, 0.39" ENTRANCE HOL PROCEDURE COMPLETED . . ConocoPhillips Alaska, Inc. KRU 3Q-09 ~ TUBING (0-7460, SSSV Tvoe: NIPPLE Oria ComDletion: 1/4/1987 Anale @ TD: 33 dea @ 7990 00:3.500, Annular Fluid: Last W/O: 11/26/2006 Rev Reason: GLV CIO, PULL 10:2.992) PLUG Reference Loo: 34' RKB Ref Loo Date: Last Untiate: 5/12/2007 Last Taa: 7612 TD: 7990 ftKB 4300 Description Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4282 3739 36.00 J-55 Size Too Bottom TVD Wt Grade Thread .......... 1 6254 1 9.30 1 L.80....... Interval TVD Zone Status Ft SPF Date TYDe Comment 7508 - 7530 6294 - 6312 C-4,A-2 22 6 8/25/1991 IPERF 2 118" Ener Jet. Zero deg 1 Dhasina 7542 - 7570 6322 - 6346 A-1 28 4 2/27/1987 IPERF 4" HSC Csg Gun, 120 deg 1111\111111111" . Int~rval' Date Tyoe Comment 7454 - 7456 2/28/1987 Saueeze Perf III.... St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run VI v Mfr Cmnt 1 2931 2690 CAMCO MMG GLV 1.5 RK 0.188 1264 12/1/2006 2 4575 3954 CAMCO MMG GLV 1.5 RK 0.188 1266 12/1/2006 3 5792 4905 CAMCO MMG GLV 1.5 RK 0.188 1262 12/1/2006 4 6662 5604 CAMCO MMG OV 1.5 RK 0.250 0 11/30/200€ 5 7249 6080 CAMCO MMG DMY 1.5 RKP 0.000 0 11/30/200€ 2J Deoth Tvoe '~~~:~·jlll..II..III".III_..I.".I.awl~~· TVD Descriotion ID 483 483 NIP CAMCO 'OS' NIPPLE 2.812 7299 6121 PBR LOCATOR SEAL ASSEMBLY STABBED INTO PBR 3.000 7321 6139 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 7365 6175 NIP CAMCO '0' NIPPLE 2.750 Deoth Descriotion Comment 7587 Milled PACKER MILLED PACKER FROM ORIGINAL COMPLETION MILLED & PUSHED TO BOTTOM 11/2612006 7800 Packoff DMY DANIEL'S PACKOFF DUMMY lost 5/10/2006 SIMI.fllll.f Date 1 Note / 5/14/19951 NOTE: WAIVERED WELL: IA x OA COMMUNICATOIN 7 Perf - - (7508-7530) - - - - - - PROO. - CASING - - (0-7880, - - 00:7.000, -...... - ~ Wt:26.oo) - - Perf - - (7542-7570) - - - - ........... .. m _..~ - - - - - - - - mm__.. ..--..-.. Packotl OMY ~~ (7800-7801. 00:1.000) as DOS. ommlssíl 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other Aotfibrage Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 186-186/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21674-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 34' 3Q-09 8. Property Designation: 10. Field/Pool(s): ADL 25512, ALK 2553 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7990' feet true vertical 6696' feet Plugs (measured) Effective Depth measured 7612' feet Junk (measured) 7587', 7800' true vertical 6381' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 115' 115' SUR. CASING 4258' 9-5/8" 4282' 3739' PROD. CASING 7846' 7" 7880' 6604' Perforation depth: Measured depth: 7508'-7530', 7542'-7570' true vertical depth: 6294'-6312',6322'-6346' SCANNEr) DEC -; "i 20f1S ' ~ ''"'' ',...!. 1.'-' Tubing (size, grade, and measured depth) 3.5" , L-80, 7460' MD. Packers & SSSV (type & measured depth) Baker FHL retriev. Pkr 7321' Cameo 'OS' nipple @ 483' 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-Mef Water-Bbl Casina Pressure Tubina Pressure Prior to well operation SI Subsequent to operation 1189 1646 916 -- 210 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPL D 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: C,"!oct ~:er~'6H172 Printed Name Gary Eller ~ L Title Wells Group Engineer \¿J~\ O~ Signature Phone Date ~\.. Prenared bv Sharon AlIsu"-D"'k'" 263-4612 -~ . . . RECEIVED STATE OF ALASKA . 0 ALASKA Oil AND GAS CONSERVATION COMMISSION E C 0 7 2006 REPORT OF SUNDRY WELL OPERA TIONSlaska Oil & Gee n Form 10-404 Revised 04/2004 ORIGINAL RBDMS 8Ft DEC 1 1 2005 Submit Onglnal Only ConocJP'hilIi ps We/Mew Web Reporting Time Log Summary RU circulating lines to tree, T-in return line to cuttings tank. Install shaker screens. Bring in 3-1/2" test joint and landing joint. RU Eckel tongs & air sli s. 20:00 21:00 1.00 MIRU WELCT OTHR P Pick up BPV lubricator, pull BPV, lay down lubricator. 21:00 00:00 3.00 MIRU WELCT CIRC P Take on 9.6 ppg brine to pits and PT lines to tree to 2000 si. 11/12/2006 00: 00 02:00 2.00 MIRU WELCT CIRC P PJSM. Pump 25 bbls down IA up tubing @ 3 bpm 280 psi. Pump 60 bbls down tubing up IA @ 4 bpm 440 si. Ri u and set BPV. 02:00 09:30 7.50 MIRU WELCT NUND P ND tree and hang in cellar. NU BOP stack 11" 5000 si. Wash out stack. 09:30 14:00 4.50 MIRU WELCT BOPE P Perform BOP test to 250/3500 psi. Pressure test annular to 250/2500 psi. BOP test waived by AOGCC (Jeff Jones) at 06:00 on 11/12/06. Pull BPV. 14:00 15:00 1.00 P Make up landing joint. Pull CIW han er to ri floor, u wei ht 95K. 15:00 17:00 2.00 P Circulate long way @ 5 bpm 440 psi, pumped total of 260 bbls, good 9.6 brine returns durin circulation. 17:00 21:00 4.00 COMPZ RPCOI\ PULD P Lay down hanger, pup joint, and one single joint. POOH w/ production string, standing tubing back in derrick. Up weight 95K down weight 80K, and block wei ht 30K. 21:00 00:00 3.00 COMPZ RPCOt\, OTHR P Load and strap 3.5" PH-6 work string in pipe shed. Had diffcultly due to heav snow build u on PH-6. 11/13/2006 00:00 03:00 3.00 RPCOI\ OTHR P Finish loading and strapping PH-6 in i e shed. 03:00 05:00 2.00 RPCOI\ PULD P Make up PBR retrieving tool BHA on PH-6 work string. BHA is as follows: 4.75" PBR retrieval tool/ 4.75" Bumper Sub/4.75" Fishing Jars/ Three 4.75" Drill Collars/ Crossover to PH-6. 05:00 13:00 8.00 RPCOI\ TRIP P RIH w/ PBR retrieving tool BHA on PH-6 work strin to 7250' MD. 13:00 13:30 0.50 CASIN( CIRC P Circulate drill pipe volume @ 4 BPM 530 si. 13:30 14:00 0.50 RPCOt\, PACK P Tag top of packer assembly @ 7239' MD. Release packer by rotating pipe to ri ht. Some as brake out. Circulate bottoms up @ 5 bpm 1220 psi. Monitor well 30 minutes. Well static. 15:30 20:00 4.50 P POOH w/ BHA standing back PH-6. 20:00 22:00 2.00 P On surface with packer assembly. Some metal marks on OD of poor boy overshot barrel. Lay down overshot and redress with tattle tale ins. 22:00 23:00 1.00 P Make up dressing mill BHA. 6" hollow mill shoe/5.75" extension/5.75" wash over basket! 4.75" x 2.375" internal mill/ crossover / two junk baskets/ 4.75" bit sub/4.75" bumper sub/4.75" bumper sub/4.75" fishing jars/ three drill collars/ crossover to PH-6 total len th BHA is 138.54'. 23:00 00:00 1.00 0 1,075 COMPZ P RIH w/ mill BHA on PH-6 work string. 11/14/200600:00 03:00 3.00 1,075 7,359 COMPZ P Continue in hole with dress off mill for 2 7/8" tubing stub @ 7359' MD. Tag stub 7359'. 03:00 05:30 2.50 7,359 WASH P Mill on 2 7/8" tbg stub from 7359' to 7360'. 4-1/2 BPM 780 psi. Circulate gas out of well 8 BPM 2350 psi. Up w1120K down wt 95K. 107 ROT. Millin 3.5 BPM, 300 si, 55 RPM 05:30 08:30 3.00 COMPZ FISH CIRC P Mill plugging off. Pulled up hole 60' to 7300' attempt to clean out. Circulated hole clean + pumped sweep @ 7 BPM 4000 si. 08:30 12:00 3.50 PULL P POOH standing back workstring, LD BHA. Clean out frac sand ( Carbolite) metal shavings and chunks of metal. Also recovered what appears to be twisted piece of 2-7/8" stub - 7" long in mill. 12:00 15:00 3.00 COMPZ FISH TRIP X MU new BHA, run back in hole. BHA is as follows: 6" Mill Shoe/5.75" x 16' Extension/ 5.75" Washover basket! Internal mill/4.75" Crossover/4.75" Junk basket! 4.75" Bit Sub/4.75" Bumper Sub/ 4.75" Oil Jars/ Six Drill Collars/ Crossover to PH-6. 15:00 19:00 4.00 COMPZ FISH TRIP X RIH w/ mill and washover basket on PH-6 to 7364' MD 19:00 23:00 4.00 COMPZ FISH WASH X Wash over 27/8" tubing stub @ 7364' MD. Reverse circulating @ 5.5 bpm 1100 psi. Up/Down weights 125K1100K. Made four feet initially to 7368' MD with little difficulty. Last two hours little or no hole made, may have wore out mill. Blow down to drive. 23:00 00:00 1.00 7,368 6,421 TRIP X POOH w/ washover assembly stand in back PH-6. 11/15/2006 00:00 02:30 2.50 6,421 0 TRIP X Continue out hole with washover assembl standin back PH-6. On surface with BHA, inspect mill assembly, one cup full of metal debris in junk baskets, mill worn on the lip of mill, marks internally indicate we were over tubing stub. Lay down BHA. Make up shortened washover mill assembl . 04:00 08:00 4.00 0 7,368 COMPZ FISH TRIP X RIH w/ shortened washover mill assembly: 6" Hollow mill shoe/ 5' Extension/ Washover Basket! Internal flat bottom junk Milll Two Junk Basketsl Bit Sub/ Bumper Sub/ Oil Jarsl Six Drill Collars/ Crossover to 7365' MD. 08:00 11:00 3.00 7,368 COMPZ FISH MILL X Up wt 125K, dwn wt 100K, ROT wt 110K. While pumping at 7.5 BPM w/1550 psi..Milled from 7365' to 7366' (1'), started hanging up and dragging on pick up. Worked up and down while rotating and broke up trash along side mill. Continued milling down to 7371'. Milled 6' total and 2-1/2' of stub. 11:00 12:30 1.50 COMPZ FISH CIRC X Pumped hi vise sweep to clean hole. Recovered more Carbolite, shavings and a few small metal ieces. 12:30 18:00 5.50 COMPZ FISH TRIP X POH standing back workstring. Break down BHA and clean out junk baskets and 4' washpipe. Recovered 5 pieces of milled and twisted pieces of 2-7/8" tubing from the stub. Clean up rig floor and re for next run. 18:00 21:00 3.00 COMPZ FISH PULD X Extension with cage arrived from Baker shop in Prudhoe. Make up clean out BHA. 6" Hollow Mill Shoe/ Extension with cagel Wash pipe extension/ Washover basket! Two junk baskets/ Bit Sub/ Bumper Sub/ Oil Jars/ Six Drill Collarsl Pump out sub/ Crossover to PH-6 21:00 00:00 3.00 0 7,330 FISH TRIP X RIH wI washover assembly on work strin . 11/16/2006 00:00 00:30 0.50 7,330 FISH TRIP X Continue in hole with washover assembl . 00:30 03:30 3.00 7,370 7,377 FISH MILL X Tag up @ 7370'MD. Up weight 125K, down weight 100K. ROT weight 105K. While pumping @ 6 bpm 850 psi. Milled from 7370' to 7377' MD. Worked pipe upldown while rotating, not dragging or making much beyond 7377'MD. 03:30 04:30 1.00 COMPZ FISH CIRC X ND down top drive, rig up reverse circulating equipment. Reverse circulate bottoms up @ 6.5 bpm 1330 psi, not much coming across shakers, small amount of sand. Rig down circulating equipment, rig up top drive, tag up @ 7377'MD. Start milling while circulating @ 8 bpm, not makin hole, shut down. 05:00 09:00 4.00 TRIP X POOH wI wash over assembly standin back work strin . 09:00 11:00 2.00 WOOR X Broke out wash pipe and junk baskets. Retrieved 7' of 2-7/8" pup jt. (originally 10') and misc. Pup full of metal chunks on the inside. Pieces of tubing in junk baskets. Discussed options with Engineering Team for plan forward. Decide that the probability of pulling the 2.25" plug in the packer tailpipe is low, we decided to go ahead and pull the packer to ensure a competent completion. Will run a washover shoe next to clean out around the OEJ barrel. 11:00 15:00 4.00 COMPZ FISH TRIP X MU BHA, 6"x5"Rotary Shoe, 15' Extension, wI junk baskets, bumper sub and hydralic jars, w/6 drill collars. RIH on PH-6 workstrin . 15:00 21:30 6.50 7,377 7,780 COMPZ FISH MILL X Tagged top of fish at 7377'. Established circulation 7 BPM w/11 00 psi. Start washing over junk and OEJ barrel. Up weight 130K, Down weight 100K ROT 115K wash over OEJ barrel to 7780' MD. Suspect mill is worn out, no hole made last two hours. 21:30 23:30 2.00 7,780 COMPZ FISH CIRC X Displace hole with 11.5 ppg brine @ 5 BPM 500 psi. ND top drive, monitor well, static. 23:30 00:00 0.50 7,380 6,329 FISH TRIP X POOH w/ washover assembly standin back PH-6 11/17/200600:00 02:30 2.50 6,329 0 FISH TRIP X Continue OOH wI mill assembly standin back PH-6. 02:30 04:30 2.00 FISH PULD X On surface with assembly, lay down BHA and check tools, only two quarts full of small metal pieces in junk baskets. Make up flat bottom junk mill assembly. 6.125" Junk Mill/ Two Junk Baskets/ Bit Sub/ Bumper Subl Oil Jarl Drill Jars/Crossover to PH-6. 04:30 07:30 3.00 0 7,377 FISH TRIP X RIH wI Junk mill assembly on PH-6 work strin to 7377'MD to ta u . 07:30 11:00 3.50 7,377 7,380 FISH MILL X MU top drv, commence mill remainder 27/8 pup to barrel assy on OEJ. Mill 7377 - 7380 ft. Cease milling, no further progress. Note 400 psi loss at standpipe, troubleshoot surface equip, OK. Prepare POH for possible washout. WOM 5K, RPM 60, SPP 1300 psi /6 bpm, Up 130, Dn 100, Rot 115. POOH w/flat bottom mill asslembly standing back workstring. No washout found. 15:30 17:30 2.00 PULD X Lay down flat mill assembly, check junk baskets for debris, two quarts full of small pieces metal debris, nothing larger than a quarter. Make up washover assembly. 6" Hollow mill shoe/15' of extension/ Washover basket! Crossover/ Two junk basketsl Bit Sub/ Bumper Sub/ Oil Jar/ Drill Collarsl Pump out Sub/ Crossover to PH-6. 17:30 21:30 4.00 0 7,381 FISH TRIP X TIH w/ washover BHA on PH-6 work strin . 21:30 23:30 2.00 7,381 7,395 FISH MILL X Make up top drive. Tag top of fish @ 7381' MD. Washover OEJ @ 6.5 BPM 1090 psi. Up weight 125K down weight 100K ROT 11 OK. Made two feet first hour, then fell through tight spot, wash down to 7395' MD, tagged top of OEJ guide, worked pipe through this area several times, a ear to be clear. 23:30 00:00 0.50 FISH CIRC X Circulate sweep, small amount of metal debris across shakers. 11/18/200600:00 03:30 3.50 7,395 0 FISH TRIP X POOH w/ wash over assembly standin back work strin . 03:30 05:00 1.50 0 0 FISH PULD X Lay down washover assembly, check junk baskets for debris, junk baskets full of frac sand and small metal pieces, half a bucket full. Make up overshot assembly to fish Cameo OEJ @ 7380' MD. 5.75" Overshot with 4.75" grapple/ Top extension/ Bumper Sub/ Oil Jar/ Six Drill Collars/ Pump out Subl Crossover to PH-6. 05:00 09:00 4.00 0 7,380 TRIP X RIH w/ Overshot assembly on work strin to 7380' MD. 09:00 12:30 3.50 7,380 FISH X Pumping 2 BPM @ 180 psi. Up w1. 125K Dwn wt. 100K. Tagged top of fish @ 7380'. Worked 4-3/4" overshot over OEJ barrel 3'. PU to shear OEJ but it would not shear at expected 30K over continue and sheared packer @ 195K or 70K over. PU 30', lowered back down 6' and stacked out. Monitor well and had 10 bbl gain, 400 psi. SI, notified AOGCC and town en ineer. Sheared out pump out sub and established circulation. Pumped 1.5 BPM w/1200 psi thru 3/4 choke. Pumped out gas trapped under packer. Shut In monitor well. DP 126 psi. 290 ann. Brought w1 up from 11.4 to 11.6 ppg, circulated around, Shut In monitor well DP 100 psi 210 ann. After recieving load of brine w1 up to 11.8 circulate around. 18:00 22:30 4.50 COMPZ FISH CIRC X Finish weighting up brine from 11.6 ppg to 11.8 ppg. Circulate 11.8" ppg brine @ 3 BPM 1550 psi on DP 1425 psi on IA. Still circulate out some gas through 3/4 choke. Shut in choke to monitor well. Both DP and IA pressure at 1480 psi, monitor pressure 15 minutes, appears packer is packed-off and holding pressure, pressure remained at 1480 psi. Open choke and bleed pressure to zero, shut choke, monitor pressure, both DP and IA ressure built u to 290 si. 22:30 00:00 1.50 COMPZ FISH CIRC X Called town engineer to discuss plan forward. Decide to weight brine to 12.0 ppg and viscosified so heavier weights can be obtained. Called DSE to verify if su ortin in'ector are shut in. 11/19/2006 00:00 11:30 11.50 COMPZ FISH CIRC X Continue to weight up KWF to 12.0 ppg. Weight up brine in pits to 12.0 ppg, remove crude from pits, viscosify 12.0 ppg brine in pits to aid in weighting up KWF to 13.1 ppg. Continue to circulate at min. rate to kee from freezin at to drive. 11:30 17:30 6.00 COMPZ WELCT KLWL X PJSM, prepare equip for well kill, commence pump 13.1 ppg brine through closed BOPE / 3/4 choke. ICP 820 psi, 510 psi at choke.Cont circ BU X 3, FCP 320 psi, 475 psi at choke. Cease pumping, bleed DP / ann to "0" psi. Flow check, open BOPE, cont flow check 10 min. Fluid column static. Approx 55 bbls loss durin kill 0 s. 17:30 20:00 2.50 COMPZ WELCT CIRC X Begin circ wellbore through open BOPE while re-cip string. Confirm PKR free. Cont circ / re-cip string. Up 125, Dn 90. No gain I loss. Circulate bottoms u 2b m 360 si. 20:00 21:00 1.00 COMPZ WELCT CIRC X Brake down top drive, monitor well 30 mins, static. Lay down work joint and one sin Ie, chan e out elevators. 21:00 00:00 3.00 7,362 5,458 COMPZ FISH TRIP X POOH wI packer assembly, up weight 125K, OOH slowly to prevent swabbing with packer. Minimal loses while tri in out of hole. Continue OOH wI Cameo HRP-1 packer assembly @ 600-700 fph to prevent swabbing. Minimal fluid losses durin tri out of hole. 06:30 11:00 4.50 0 PULD X Flow check, handle BHA, break out fish 10 shot assy, lay dn same. Fish = (outer bbl) OEJ complete. "Slick stick" I PKR left in well. 11:00 15:30 4.50 P PJSM, RU I prepare for BOP test. Pull wear ring, flush stack. Install test plug. Test all components to include kill line I valves, choke mnfld, floor valves, standpipe to pumps, 250 I 3500 psi. Perform time I volume I press test accumulator. Witness waived Mr Chuck Scheve AOGCC. 15:30 17:00 1.50 COMPZ FISH PULD X Make up overshot BHA. 5.75" dual grapple overshot! Top extensionl Top subl Bumper sub/Oil jar/Nine drill collarsl Pump out subl Crossover to PH-6. 17:00 21:00 4.00 0 7,384 FISH TRIP X RIH wI overshot BHA on PH-6 work strin to 7384' MD. 21:00 23:00 2.00 7,384 7,482 FISH PULL X Get upldown weight, 130K up 93K down. Engage fish @ 7384' MD. Work packer down hole to 7482' MD to verify engagement. Showing 15K over string weight. Brake down top drive, monitor well, static. 23:00 00:00 1.00 7,482 7,365 COMPZ FISH TRIP X POOH wI packer assembly to 7365' MD, swabbing badly, almost a barrel gain per single joint. Work pipe in/out of hole for one hour to wear out packer element, no im rovement. 11/21/2006 00:00 01:00 1.00 7,365 COMPZ FISH PULL X Continue to work pipe upldown another 30 minutes, no improvement, still swabbing. Shut down and monitor well. Gains in trip tank continue to rise, close annular, monitor pressure. DP pressure 90 psi CP 160 psi. Called AOGCC 01:00 06:30 5.50 COMPZ WELCT CIRC X PJSM. Prepare for well kill. Start pumping 1.5 hole volume of 13.1 ppg brine through closed annular @ 2 BPM 550 psi on DP 250 psi CPo Stop pumping, bleed off DP/CP, check for flow. Wellbore static. 06:30 13:00 6.50 COMPZ FISH TRIP X PJSM, release PKR, POH for BHA. slow going to avoid swabbing. No gain I loss. 13:00 15:00 2.00 COMPZ FISH PULD X Handle BHA, lay dn over-Shot assy. Place new BHA to ri floor. 15:00 16:30 1.50 COMPZ X PJSM, RU I Test BOP upper rams, followin use as er AOGCC re S. 11/21/2006 16:30 17:30 1.00 COMPZ~ FISH PULD X PJSM, MU BHA: burn shoe, burn shoe, wash pipe ext, x-over, 2 junk baskets, bit sub, bumper sub, oil jar, 9 drill collars, PO sub, xo sub. RIH. 17:30 20:30 3.00 COMPZr FISH TRIP X Flow check, follow BHA with PH6 workstring. 20:30 22:30 2.00 COMPZr FISH TRIP X Cut Drill Line 22:30 00:00 1.50 7,456 COMPZr FISH MILL X Tag up at 7429' rkb. Start milling and work down to 7456' rkb. 11/22/2006 00:00 02:00 2.00 COMPZr FISH MILL X Packer stopped moving downhole at 7456' rkb. Begin mill packer with burn-over shoe and mill up packer elements. 02:00 09:30 7.50 7,456 7,458 COMPZr FISH MILL X Continue to mill over packer. Make 2' to 7458' rkb. No further progress, change parameters, multiple attempts made. Max torque limits reached PH6 DP. 09:30 13:00 3.50 COMPZI FISH TRIP X PJSM, prepare POH for BHA. POH to BHA, no gain /Ioss. 13:00 14:30 1.50 COMPZI FISH X Flow check, handle BHA, inspect inspect inner barrel over-shot, contact made 2 ft into over-shot. MU addtnl 4 ft extension, Re-run burn shoe. RIH same to DP. Discuss torque limit on PH-6 connection with Hyril rep. Increase max torque limit to 9000 ft-Ibs 14:30 15:30 1.00 COMPZI RIGMN SVRG X Service rig. 15:30 19:30 4.00 COMPZI FISH TRIP X Flow check, PJSM, RIH 3 1/2 PH6 DP 19:30 20:00 0.50 COMPZI FISH TRIP X Tag top of Packer at 7459' rkb. ICP= 530 psi at 46 spm 20:00 00:00 4.00 7,459 7,460 COMPZI FISH MILL X Milling on packer. 11/23/2006 00:00 21:00 21.00 7,459 COMPZI FISH MILL X Milling packer from 7459' - 7465' rkb 21:00 21:30 0.50 COMPZr FISH TRIP X Burn-over shoe appears to be wore out. Pump bottoms up at 5 bpm. 21:30 00:00 2.50 COMPZr FISH TOH to change out burn over shoe 11/24/2006 00:00 02:00 2.00 COMPZr FISH TRIP X TOH with milling BHA. 02:00 02:30 0.50 COMPZr FISH PULD X Inspect burn over shoe. Cutting faces and buttons were worn down on bottom of shoe, but not on inside. Marks indicate that packer was swallowed 2.5', even though workstring on surface shown 6'. Appears packer is moving downhole while milling 02:30 04:00 1.50 COMPZr FISH PULD X Empty junk baskets. Recovered metal shavings and small springs. MU new burn over shoe on same BHA and TIH. 11/24/2006 04:00 07:30 3.50 COMPZ~ FISH TRIP X Flow check at BHA, PJSM, follow BHA with 3 1/2 DP to tag at 7465 ft. 07:30 18:30 11.00 COMPZ~ FISH FISH X Commence burn over PKR, spinning at times, slowing progress. Cont burn over PKR, vary parameters, 7465- 7468 18:30 19:30 1.00 COMPZ~ FISH FISH X Packer starts moving downhole. Push packer down to 7587' rkb. Bottom perf at 7570' rkb. Decide to leave packer on bottom of well. 19:30 21:30 2.00 COMPZ~ FISH CIRC X Pump 3 bottoms up, fluid looks good. 21:30 22:00 0.50 COMPZ~ FISH OTHR X Flow check well. Well is static 22:00 00:00 2.00 COMPZr FISH TRIP X POOH with milling assembly PH-6 workstrinQ layinQ down singles. 11/25/2006 00:00 07:00 7.00 6,350 0 COMPZr FISH TRIP X TOH laying down milling workstring 3 1/2 PH6 for completion. No gain I loss. 07:00 09:00 2.00 0 COMPZI FISH PULD X Flow check at BHA, handle BHA, lay dn same. Break out mill assy, lay dn same. 09:00 12:30 3.50 COMPZI RPCm RURD P Clear / clean floor. RU for 3 1/2 completion. 12:30 17:30 5.00 COMPZI RPCm RCST P PJSM, commence RIH 3 1/2 completion BHA as per program, torque all conn's to spec, follow BHA with 3 1/2 tbQ 17:30 18:00 0.50 COMPZI RPCm CIRC P Solids buildup at packer causing backflow through tubing. circulate bottoms up, clean mess on floor. 18:00 23:00 5.00 COMPZI RPCm RCST P Flow check, resume RIH 3 1/2 tbg. 23:00 23:00 0.00 COMPZI RPCOt\, RCST P Finish running 3-1/2" completion 23:00 00:00 1.00 COMPZI RPCOt\, SLKL P RU slickline 11/26/2006 00:00 03:00 3.00 COMPZI RPCOt\, SLKL P Tag D nipple at 7362' SLM. Set CA2 I pluQ in D nipple. 03:00 04:00 1.00 COMPZr RPCOt\, PACK P Pressure up tubing to 3000 psi and set packer at 7320 ft. 04:00 04:30 0.50 COMPZr RPCOt\, HOSO P Shear out PBR with 3000 Ib overpull. Flow check. Space out for tbg hgr and two ft out PBR. 04:30 08:00 3.50 COMPZr RPCOt\, CIRC P PJSM, Reverse circulate out 13.1# brine from well with Seawater, 4 bpm 1000 psi. Brine to storage. Bleed, well static. Spot corrosion inhibitor to annulus. Flow check. Well balanced. 08:00 10:30 2.50 COMPZr RPCOt\, DHEQ P Sting into PBR /Iand hgr. Test tbg 2500 psi / 30 min. Bleed tbg to 1500 psi, test 3 1/2 X 7 annulus to 2500 psi / 30 min. All tests successful. No re-tests. Bleed tbg to 0 psi, note DCR valve shear I open at 250 psi tbg press. releasing ann press. Circ, verify fully open. Rig dn I clear floor, RU I set CIW two wa check. 11:00 14:00 3.00 P PJSM, ND BOPE for tree install. 14:00 16:00 2.00 P PJSM, NU prod tree. 16:00 17:00 1.00 P PJSM, remove CIW two way check 17:00 21:00 4.00 P PJSM, RU, begin freeze protect well. Pump 90 bbls of diesel for freeze protection down tubing, let U-tube. Leavin diesel 2500' in tubin and IA. 21:00 21:30 0.50 P Set BPV 21:30 00:00 2.50 P Finish cleaning pits. Release Rig Note: 172 bbls workover fluids lost to erfs durin workover. . . KRU 3Q-09 ConocoPhiUips Alaska, ¡Inc. ~ TUBING API: 500292167400 Well TVDe: PROD Anole@TS: 34 dea@7506 (0-7460, SSSV TVDe: NIPPLE Oria Completion: 1/4/1987 Anole @ TO: 33 dea @ 7990 00:3.500, Annular Fluid: Last W/O: 11/26/2006 Rev Reason: WORKOVER 10:2.992) Reference Loa: 34' RKB Ref Loa Date: Last Ucdate: 11/30/2006 Last Tao: 7612 TO: 7990 ftKB Description Size Top Bottom TVD wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4282 3739 36.00 J-55 PROD. CASIN 26.00 J-55 I Size I TOD Bottom TVD wt Grade I Thread I Interval TVD Zone Status Ft SPF Date Type Comment 7508 - 7530 6294 - 6312 C-4,A-2 22 6 8/25/1991 IPERF 2 1/8" Ener Jet, Zero deg I phasino 7542 - 7570 6322 - 6346 A-1 28 4 2/27/1987 IPERF 4" HSC Csg Gun, 120 deg . Date TVDe Comment I St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 2931 2690 CAMCO MMG DMY 1.5 RK 0.000 0 11/261200 2 4575 3954 CAMCO MMG DMY 1.5 RK 0.000 0 11/26/200 3 5792 4905 CAMCO MMG DMY 1.5 RK 0.000 0 11/26/200 4 6662 5604 CAMCO MMG DMY 1.5 RK 0.000 0 11/26/200 5 7249 6080 CAMCO MMG SOY 1.5 RKP 0.000 0 11/26/2ºº DeDth TVD TVDe DescriDtion ID 483 483 NIP CAMCO 'OS' NIPPLE 2.812 7299 6121 PBR LOCATOR SEAL ASSEMBLY STABBED INTO PBR 3.000 7321 6139 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 7365 6175 NIP CAMCO '0' NIPPLE w/RHC PLUG w/CR LOCK 2.750 7460 6254 WLEG 2.960 Depth Description Comment 7587 Milled PACKER MILLED PACKER FROM ORIGINAL COMPLETION MILLED & PUSHED TO BOTTOM 11/26/2006 Date Note 5/14/19951 WAIVER ED WELL: IA x OA COMMUNICATOIN Perf - c-- (7508-7530) - f-- - f-- - c-- PROO. f-- CASING - c-- «(1.7880, - f-- 00:7.000, - c-- Wt:26.oo) - c-- Perf - f-- (7542-7570) - c-- - c-- - f-- - f-- - c-- - c-- - f-- - f-- Packoff OMY , (7800-7801, 00: 1.000) . . Gary Eller Wells Engineer Drilling & Wells ConoC6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 September 8, 2006 RECEIVED SEP 1 1 2006 Alaska Oil & Gas Cons. Commission Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3Q-09 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover of Kuparuk well 3Q-09. If you have any questions regarding this matter, please contact me at 263-4172. SCANNED SEP 1 4 2006 JGE/skad ( ¡ til?- ('bro . . RECEIVED SEP 1 1 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION Cons. Commission Other Andbårage Time Extension D D Repair Well 0 Pull Tubing 0 Operat ShutdownD Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 34' 8. Property Designation: ADL 25512: ALK 2553 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Exploratory D Service D Re-enter Suspended Well 5. Permit to Drill Number: 186-1861 6. API Number: 50-029-21674-00 9. Well Name and Number: 3Q-09 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7990' feet true vertical 6696' feet measured 7612' feet true vertical 6381' feet Length Size MD 80' 16" 115' 4258' 9-5/8" 4282' 7846' 7" 7880' Plugs (measured) Junk (measured) 7431' 7800' TVD Burst Collapse 115' 3739' 6604' Measured depth: 7508'-7530', 7542'-7570' true vertical depth: 6294'-6312',6322'-6346' Tubing (size, grade, and measured depth) 3.5" 12-7/8", L-80, 7357' 17443' MD. Packers & SSSV (type & measured depth) Baker FHL retriev. Pkr, Cameo HRP-1-SP pkr@ 7251' /7413' Cameo 'DB' nipple @ 477' 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-Mef Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 . Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the fore oing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Signature Title Phone Wells Group Engine~~te " I ~I ~~ Pre ared b haron AlIsu -Drake 263-4612 ORIGINAL RBDMS BFL SEP 1 :1 2006 I b~I\7 ÃÞ 9·/~.1:# Submit Original Only A-..9/tJI1P6 . ConocoPhillips Alaska, Inc. . KRU X}-09 3Q-09 API: 500292167400 Well Tvoe: PROD Anole (â) TS: 34 dea (â) 7506 TUBING SSSV Type: NIPPLE Orig 1/4/1987 Angle @ TD: 33 deg @ 7990 (0-7357, Comnletion: OD:3.500, Annular Fluid: Last W/O: 8/2/2006 Rev Reason: WORKOVER, Pull ID:2.992) RHC clue Reference Loa: 34' RKB Ref Loa Date: Last UDdate: 8/812006 Last Taa: 7612 TD: 7990 ftKB ~e: 1/21/2006 Max Hole Anale: 43 dea (â) 4300 - ALL STRINGS Descrintion Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4282 3739 36.00 J-55 PROD. CASING 7.000 0 7880 6604 26.00 J-55 Tubino Strino - TUBING Size I Too I Bottom I TVD Wt Grade I Thread 3.500 I 0 I 7357 I 6169 9.30 L-80 I EUE8RD 2.875 I 7352 I 7443 I 6240 6.50 L-80 I EUE8RD Peñorations Summarv Interval TVD Zone Status Ft SPF Date Type Comment 7508 - 7530 6294 - 6312 C-4,A-2 22 6 8/25/1991 IPERF 21/8" EnerJet, Zero deg chasinG 7542 - 7570 6322 - 6346 A-1 28 4 2/27/1987 IPERF 4" HSC Csg Gun, 120 deg chasinG Stimulations & Treatments Interval I Date Type Comment 7454 - 7456 I 2/28/1987 I Saueeze Perf Note on HandOver Form; Tested to 2000 nsi Gas lift MandrelsNalyes St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2926 2686 CAMCO MMG DMY 1.5 RK 0.000 0 8/2/2006 2 4570 3950 CAMCO MMG DMY 1.5 RK 0.000 0 8/2/2006 3 5787 4901 CAMCO MMG DMY 1.5 RK 0.000 0 8/2/2006 4 6623 5572 CAMCO MMG DMY 1.5 RK 0.000 0 8/2/2006 5 7180 6023 CAMCO MMG SOY 1.5 DCR 0.000 0 8/2/2006 Other (I luas. eauip. etc.\ - COMPLETION (POST WORKOVER 81212006) Deoth TVD Type Descriotion ID 477 477 NIP CAMCO 'DB' NIPPLE 2.812 7239 6072 PBR LOCATOR SEAL ASSEMBLY STABBED NTO PBR 3.000 7251 6081 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 7302 6123 NIP CAMCO 'D' NIPPLE 2.750 7351 6164 Overshot POOR BOY OVERSHOT 2.960 7352 6165 Chemical 2.441 Overshot Cut (7351-7352, Other (I luas eauiD. etc.) - ORIGINAL COMPLETION OD:6.000) Depth TVD Type Description ID 7385 6192 PBR Camco 'OEJ' 2.297 PBR 7413 6215 PKR Camco 'HRP-1-SP' 2.347 (7385-7386, 7431 6230 NIP Camco 'D' Nloole NO GO 2.250 OD:2.875) 7431 6230 PLUG CA-2 PLUG Set 5/11/2006 - DUMP BAILED 4' OF CALCIUM CARBONITE 0.000 ON TOP OF PLUG TO PROTECT 5/13/2006 7443 6240 SOS Camco 2.441 PKR 7444 6241 TTL 2.441 (7413-7414, OD:6.151) Fish - FISH Deoth I Description I Comment 7800 Packott DMY -rDANIEL'S PACKOFF DUMMY lost 5/10/2006 PLUG General Notes (7431-7432, Date Note OD:2.250) 5/14/1995 WAIVERED WELL: IA x OA COMMUNICATOIN TUBING 7/3/1998 SLIGHT CORKSCREW TBG BELOW 6500', BUT ABLE TO DO FCO TO 7650' CTM (7352-7443, 6/7/2000 Pumped 13 bbls of Litecrete Cement into the 9-5/8" x 16 Annulus. OD:2.875, 5/15/2006 Chemical Cut Tubina (â) 7352' ID:2.441) Perf - I-- (7508-7530) - I-- - I-- PROD. - ~ CASING ~ ~ (0-7880, ~ ~ OD:7.000, ~ ~ Wt:26.00) ~ ~ Perf -- ~ (7542-7570) ~ ~ ~ ~ ~ ~ - ~ - ~ - ~ . 3Q-09 Well Events Summary . Activity ng on Nordic 3 to move out of road C CIRC P U flow back tanks and hardline. Held pr b safety meeting. Circulated 9. 7/29/2006 CIRC P 2 1 CIRC P 0:00 1.5 PROD1 P L 0:00 2 PRO 2:00 2.5 PROD1 7/30/2006 11:00 6.5 PROD1 P test plug. NU BOPE. Received waiver CC (Chuck Shievy) on witnessing 0 16:30 5.5 P 17:00 0.5 P 7/30/2006 17:00 18:30 1.5 PULD P R/U TIW valve in landing jt. screw into hanger. BOLDS. P/U on tubing, pulled 55k max. cut tubing came loose wt dropped to 45K. Pulled hanger to rig floor. Broke out hanger and landing jt. RU and pumped 7/30/2006 18:3 22:00 PROD1 RPCOM TRIP mberger control line spooler. P ttoms up. POOH w/ 2.875" 0:00 2 D P P . 3Q-09 Well Events Summary . 1773172006 0:00 P Continue out of hole with 2.875" completion laying down. Layed down 2.875" stub from i chem. cut length = 15.70'. Tubing stub is somewhat rough (see pictures). 17/31/2006 6:00 P RU HES slickline. RIH with 5.912" 00 gauge ring. Tagged at 7338'.24' difference in wireline verses tubing tally and E-line depth. POH and RD slickline unit. (Note: RKB difference between rigs is 13', so actually only 7/31/2006 LD P Evaluate guage run and chem. cut stub P retrieved. Decided to continue with procedure unchanged unless unable to work po boy overshot over stub. RU tools to run completion. Held pre-job safty meeting before tinue in hole taJI 8/1/2006 ,Tag up at 7352' (28' in on joint 229), made ,Iseveral attempts to stab over 2.875" stub, 'were unsuccessful, rig up head pin and circulate @ 3 bpm 220 psi, work pipe, still no luck. Check strapped tally from old completion for depth correlation. 8/1/2006 3:00 3 PROD1 T Confirmed depth of stub, made several more P attempts to engage stub, were unsuccessful, both circulating and rotating pipe, decide to POOH w/ 3.5" completion standing back. rii7i/2006 ram meeting 8/1/2006 POOH standing back 3.5" tubing. Inspect overshot for damage. Guide on overshot shows a few notches where set down was JD, 8/1/2006 13:00 T Unload equipment for clean out run. Measure and caliper for IDs - ODs & lenths. MU Mill, Motor, jars and bumper sub on 3-1/2" 8rd E..9,. 15:30 witt} 8/1/2006 21:00 PROD1 Tag on top of 2-7/8" stub @ 7352.8' MD. Dress off outside of stub with mill while pumping at 3 bpm. Unable to pump at high rates because motor torques up and twisting ,beA;m.t1(.e.stri.=__..__.____..."..~,...__. ¡ 8/2/2006 0:00 T Tagged top of 2-7/8" stub @ 7352.8' '='~4 continued to mill over 5.0' of 2-7/8" stub to 7358.8' rkb. Would not mill off anymore, ¡motor stalling. Shut pump down, PU off of ¡stub, lowered back down with pump on, motor would stalll out at 7354.8'. Attempted to wash over but motor would stall due to small rate and could not get back down to original depth, shut off pump to stop motor and lowered back down to 7357.8'. ,.".@""."""«"""WN.=,"^"""",,,,,,,~_,_ '--"""'_'^~'='''.v.w,''''.'''''.'.w_w_w_'_' "'''_~_, irculate 30 bbls of high visc pill to sweep and 8/2/2006 Lowered back down to 7357.8' rkb without rotating mill/motor. Total depth made with mill was 5.0'. RD head pin and hose. MU /2/200 illing/motor tiA"T' 8/2/2006 12: ng up 3-1/2" m.Qen:jcls. 8/2/2006 18:30 Land Po-boy overshot 2' over 2-7/8" stub, see tattle tail inside overshot, then set down 2' more. Po-boy a total of 4' over 2-7/8" stub. . 3Q-09 Well Events Summary . 8/2/2006 19:30 20:00 0.5 PROD1 RPCOM PACK P Drop ball rod. Pressure up on tubing to P 2500 psi to set packer. Bleed tubing to 1500 psi and pressure up 3-1/2" x 7" casing to A to 0 psi, pressure tubing to 2500 P . Shea ..!;>IYL~~" 20:30 23:00 2.5 PROD1 RPCOM HOSO P PU completion string above seals and pump P 140 bbls of 1% Baker Petrolite CRW132 corrsoion inhibitor down 3-1/2" x 7" annulus. _"·w___y___"';....';.,;.,,,.,,..,,"'~,,"",,',,=,,,,'''__''w- 23:00 1 HOSO P pace out completion and land tubing anger. Seals in PBR are spaced out l' from 0:00 0.5 P 0:30 1:00 D1 RPCOM P P _·~·_"""",·_v,_____,_.,,"w"w"',..» PROD1 Set HP BPV. Nipple down BOPE. _A=='" '-'---'--'-_'~'=W"',"',',,'~="'''''''==____'_ 8/3/2006 6:00 10:00 4 PROD1 RPCOM Set test plug in BPV. NU tree, pressure test P packoff to 250/5000psi test tree to 250/5000 psi. Pulled HP BPV and plug. Set "H" type BPV. Clean tree and cellar. Released rig @ 13lI16.""........ -'==>''-'''''''Y'''''''''''' 8/3/200 10:00 10:00 0 se Rig P . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 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 attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1 BL / EOE Disk 3Q - 09 Caliper Report 27-Aug-06 1) 2) 3) 4) 5) 6) 7) Q 0 2GGB 5(;J.\NNED AUG cJ RECE\VED AUG 2 9 Z006 PJaska 011 & Gas Cons. commission Anchorage Print Name: c.iL- ~lÆ(~J1 Á.ç ÓÌ1,cJA,(J'.e<-1 Date: i" / t:A 10 (A I I Signed: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:IOO _ PDSANC-2006\Z _ WordlDistributionlTransmittal_ SheetslTran5mit_ Original.doc J~fo-/~~ I I I I I I I I I I I I I I I I I I I Mem:ory Multi-Finger Cali.per log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhmips Alaska, Inc. August 2006 7095 1 3.5" 9.3 lb. L-80 Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log I ntvl1. : 30-09 Kuparuk Alaska 50-029-21674-00 7,260 Ft. (MD) 7,346 Ft. (MD) Inspection Type : Overshot Stab Inspection COMMENTS: This log is tied into the end of the overshot @ 7,339' (Driller's Depth). This log was run to determine the status ofthe 2-7/8" tubing stab into the overshot. The interior of the T' casing and the exterior of the 2-7/8" liner appears visible from 7,340' to 7,346'. A 3-D log plot of the caliper recordings across the overshot and into the T' casing is included in this report. The 3.5" tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross- sectional wall loss or 1.0. restrictions recorded. I I u 3 Inc. I Well: Detail of 2006 Across Overshot and Exterior of I 1 ..._ ,,__ 'OF \ A"". Q500 MIN ID (1/100Q in ) 3500, 135 ~ JIffT 2.992" ID 3.S"OD 7270 I" I~- Pup Joint I 2.992" ID 7280 !- 3.S"OD I·· Nipple 2.7S"ID 3.S"OD Pup Joint 7290 - 2.992" ID 3.S"OD 7300 .~ 7310 2.992" ID 3.S"OD 7320 Pup Joint 1330 I Crossover Tubina Sub Overshot Casing wI 7340 Exterior of Tubing I I I I I I I I I I I I I I I I KRU 3Q-09 I I API: 500292167400 Well Tvpe: PROD Angle 34 deo@-P4 TUBING SSSV Type: NIPPLE Orig 1/4/1987 Angle @ TO: 33 deg @ 7990 (0-7357, Completion: OD:3.500, Annular Fluid: LastW/O: 81212006 Rev Reason: WORKOVER, Pull ID:2.992) RHC nlun Reference Lon: 34' RKB Ref Lon Date: Last Uooate: 18/8/2006 Last Tao: 7612 TD: 7990 ftKB T ~ ,Q,@oo Max Hole Angle: 43 de!] (âJ 4300 r Size Ton Bottom ND Wt Grade Thread UCTOR 16.000 0 115 115 62.50 H-40 CASING 9.625 0 4282 3739 36.00 J·55 PROD. CASING 7.000 0 7880 6604 26.00 J-55 ITubinôSlTinô/",THSING' Size 1 Ton 1 Bottom 1 NO I Wt I Grade I Thread 3.500 I 0 1 7357 I 6169 I 9.30 I L-80 I 2.875 I 7352 1 7443 ¡ 6240 I 6.50 I L-80 I EUE8RD Interval NO Zone Status Ft TVDe Comment 7508 - 7530 6294 - 6312 C-4,A-2 22 6 8125/1991 IPERF 21/8" EnerJet, Zero deg nhasinn 7542 - 7570 6322 - 6346 A-1 28 4 2127/1987 IPERF 4" HSC Csg Gun, 120 deg interval ì Date I Tvne Comment ~ Perf I Note on HandOver ¡-orm; MO Man Type VMfr V Type VOD Latch Port IRO Date Viv Mfr Run Cmnt 1 2926 2686 CAMCO MMG DMY 1.5 RK 0.000 0 81212006 2 4570 3950 CAMCO MMG DMY 1.5 RK 0.000 0 81212006 3 5787 4901 CAMCO MMG DMY 1.5 RK 0.000 0 81212006 4 6623 5572 CAMCO MMG &t 1.5 RK °ti 81212006 5 7180 6023 CAMCO MMG 1.5 OCR o 0 81212006 Deoth Tvne Descriotion ID 477 477 NIP CAMCO 'DB' NIPPLE 2.812 7239 6072 PBR LOCATOR SEAL ASSEMBLY STABBED INTO PBR 3.000 7251 6081 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 7302 6123 NIP CAMCO '0' NIPPLE 2.750 7351 6164 Overshot POOR BOY OVERSHOT 2.960 7352 6165 Chemical 2.441 Overshot Cut (7351-7352, OD:6.000) i.........U"'. ,TrAM ND T"oe Descriotion 10 7385 6192 PBR Cameo 'OEJ' 2.297 PBR 7413 6215 PKR Cameo 'HRP-1-SP' 2.347 (7385-7386, 7431 6230 NIP Cameo 'D' Nlpole NO GO 2.250 OD:2.875) 7431 6230 PLUG CA-2 PLUG Set 5/1112006 - DUMP BAILED 4' OF CALCIUM CARBONITE 0.000 ON TOP OF PLUG TO PROTECT 5/1312006 PKR 7443 6240 SOS Cameo 2.441 (7413-7414. 7444 6241 TTL 2.44.1 OD:6.151) Fisl1~F1SH Depth I Descrintion I Comment :MY I DANIEL'S PACKOFF DUMMY Iœt 511012000 PLUG (7431-7432, OD:2.250) 5/14/1995 ED WELL: lAx OA COMMUNICATOIN TUBING 71311998 I SLIGHT CORKSCREW TBG BELOW 6500' BUT ABLE TO DO FCO TO 7650' CTM (7352-7443, 6[112000 1 Pumoed 13 bbls of LilBcrete Cement into the 9·518" x 16 Annulus. OD:2.875, 5/15/20061 Chemica! Cut T ubion !àJ 7352' ID:2.441) Perf -.. I--- (7508-7530) - - _. PROD. - CASING (0-7880, - 00:7.000, - - 1-- Wt:26.00) - t= Perf - (7542-7570) - 1---- -- f--- - - -- - I I I I I I I I I I I I I I I I 12/30/05 Schlumbergep RFCEIVED NO. 3638 Schlumberger -DCS iJ{~N 0 9 2006 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman A TTN: Beth ~¡aska C¡¡ i?' Gas Gens. Commission 333 West 7th Ave, Suite 100 Ar.-d1crage Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD ~. 20-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1 A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE WIDEFT 12/27/05 1 2U-08 11166750 PROD PROFILE WIDEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 30-09 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE W/DEFT 12/26/05 1 30-09 leJo-llXn 11144055 LDL 12/23/05 1 2V-01 11144056 INJECTION PROFILE 12/24/05 1 ~ SIGNED&ðoQQ01'¡ ~ÇANNE ) JAN :I 1 2006 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumbergep RFCEIVED NO. 3638 Schlumberger -DCS ,JAN 0 9 2006 2525 Gambell Street, Suite 400 Com pany: Anchorage, AK 99503-2838 A TTN: Beth Ajaska CU ,i Gas Cœs. Commission .Ar~ Field: Well Job # Log Description Date BL 20-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE WIDEFT 12/27/05 1 2U-08 11166750 PROD PROFILE W/DEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 30-09 ¡A(o- 18ft; 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE W/DEFT 12/26/05 1 30-09 11144055 LDL 12/23/05 1 2V-01 11144056 INJECTION PROFILE 12/24105 1 SIGNED&ðoQOOit¡ SC;'?lNNEO ,AN 1J 1 2006 DATE: Please sign and return one copy of this transmittal to Beth at tne aBoVé address or fax to (907) 561-8317. Thank you. 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color <-" CD - WELi~ ARCOAlaska, Inc ~ Subsidiary of Atlantic Rlcl~field ComDany , CONTRACTOR ,._AARKS JPBDT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT 6o~0 I l-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ,8--/I= REMARKS CONTINUED: /?/~, /¢d,,y,,~ /o,,~,,",,¢ ,,CT~ ' DESCRIPTION DAILY ACCU M. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES , Roustabouts Diesel Methanol ! Supervision //, ,.,r¢-',~ Pre-Job Safety Meeting i AFE ; : TOTAL FIELD ESTIMATE /:- /y ARCO Alaska, Inc. Date: July 8, 1988 Transmittal #: 7218 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 1 Y-0 4 Kuparuk Well Pressure Report 7 - 0 1 - 8 8 'C' Sand 2 T- 1 7 Kuparuk Fluid Level Report 6 - 2 9 - 8 8 Casing 3 Q- 0 9 Kuparuk Fluid Level Report 6 - 2 9 - 8 8 Casing Receipt Acknowledged· Alaska 0ii & Gas Cons. Commission Anchorage ........................... Date' - ........... DISTRIBUTION: D&M State of Alaska Chevron Unocal SAPC Mobil STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~'~ 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 86-186 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21674 4. Location of well at surface 9. Unit or Lease Name 2259' FNL, 2134' FEL, Sec.17, T13N, R9E, UN ' Kuparuk River Unit At Top Producing Interval 10. Well Number 1541' FSL, 196' FEL, Sec.18, T13N, R9E, UM 3Q-9 At Total Depth 11. Field and Pool 1425' FSL, 439' FEL. Se¢.18, T13N, R9F, UM Kuparuk River Field 5. Elevation in feet (indicate I~B, DF, etc.) 6. Lease Designation and Serial No. RKB 60' ADL 25512 ALK 2553 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/29/86 01/02/87 05/19/87' N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD~TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7990'MD,- 6695'TVD 7789'MD, 6528'TVD YES ~ NO [] 1810' feet MD 1600' (approx.) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CBL, 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 115' 24" 1875# Poleset 9-5/8" 36.0# J-55 Surf 4282' 12-1/4" 1100 sx AS IV & 300 sx ~lass G 7" 26.0# J-55 Surf 7880' 8-1/2" 300 sx Class G & 175 s.~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7542'-7570'MD 6322'-6345'TVD 2-7/8" 7443' 7413' Perforated w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7454'-7456' 150 sx Class G See attached AddenJum~ dated 5/22/87, for fracture d~ta 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OILIBBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 01/04/87. Perforated well & ran tubing 02/27/R7. Form 10-407 WC3/8:DANi Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. , · - ..... GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · Top Kuparuk C 7503' 6289' N/A Base Kuparuk C :-7516' 6300' Top Kuparuk A 7516' 6300' Base Kuparuk A 7601' 6371' 31. LIST OF ATTACHMENTS Addendums (dated 5/22/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~, ~,;~/')~_./~'/LJ.~/.,,Lt'/}.../ Title Associate Engi neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3Q-9 1/06/87 Rn CBL and gyro. 1108187 Re-rn CBL to 7766' WLM TD. Rn GR/JB f/PBTD to surf. GR/JB pulled out of rope socket @ 700' while POOH. Trip back in hole w/6" GR/JB, tag 6-1/8" GR/JB @ 7752'; left in hole. 1/21/87 Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak. 5/19/87 Frac Kuparuk "A" sand perfs 7542'-7570' in 12 stages per procedure dated 5/12/87 as follows: Stage 1: 40 bbls 140° hot diesel 10% Musol @ 5 BPM, 1050 - 3520 psi Stage 2: Pad "A" - 90 bbls gel diesel @ 5-20 BPM, 3520 - 4600 psi Stage 3: Pad "A" - 10 bbls gel diesel @ 15 BPM, 4600 - 3760 psi Stage 4: Pad "B" - 300 bbls gel diesel @ 20 BPM, 2760 - 4340 psi Stage 5: 20 bbls gel diesel 2# 20/40 @ 20 BPM, 4340 - 4290 psi Stage 6: 40 bbls gel diesel 4# 20/40 @ 20 BPM, 4290 - 4190 psi Stage 7: 40 bbls gel diesel 6# 20/40 @ 20 BPM, 4190 - 4090 psi Stage 8: 40 bbls gel diesel 7# 20/40 @ 20 BPM, 4090 - 4160 psi Stage 9: 20 bbls gel diesel 8# 20/40 @ 20 BPM, 4160 - 4310 psi Stage 10:10 bbls gel diesel 9# 20/40 @ 20 BPM, 4310 - 4300 psi Stage 11:10 bbls gel diesel 10# 20/40 @ 20 BPM, 4300 - 4340 psi Stage 12: Flush - 46 bbls gel diesel @ 20 BPM, 4340 - 4390 psi Underflushed 1 bbl. Release well to Production. Fluid to Recover: Sand in Zone: Sand in Csg: Average Pressure: Drilling Supervisor 666 bbls 35,000# ±200# 4000 psi z DatZe January 23, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70007 Well: 3Q-9 Field: Kuparuk North Slope, Alaska Survey Date: January 7, 1987 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 WELL.. SLtRVEYING COMPANY ALA.= JK ANcH~ RAuE COMPUTATION DATE V E R T I C A L S E C:lIt IiI u': N ..... L.."'A .... L U':; l..l "' ~": :][:: ":'i~ii c':!iif ii: b~i!~ ~i~!if::~iff" :')]~ i':?( v'v!:,i' ::~,' ],~L:CI ~ .... N lj:<'']:':__. ....... L U4;F:''6'':'O Lt R E ................................. MEA'.SURFD VERT I CAI... VERT I CAL INCL. I NAT I ON D ~ mE .... r.[ ON DETF:'TH DE:P"I'H DEF'TH DEG P'i ! N DE(3REES ................ "' ~a7 DATE OF' SL~RVEY JANLtARY 7~ 1'~'''- ~'~ i ~ ,i'~' I~- ' ~ BOSS uYROo_.UF IC: SURVEY .... IANLIARY 9, 1'.-.:':,...-..:'7 ..... ~::' ! !~!. [~ NL. IPIBER It]K'""BfJ'""7('.}O0.'i.7 ........................... I<E{Li._Y P.'.',UEiU.-i[i'.I(3 EL.,.EV,,. = ....... /..-:~!~?..,..,.f-)C) F'-!~... .................... 0 F' ,IS.': R A'T' C F: -M C 1.5i i..11 F(' [ii: DOG-LEO I"OTAL. '..-3E-,'. VER I T'Y RE'C'T'ANGI..II...AR C:Cu':ff~:D I NA"I'IES VEi-'-i' T I C:AI,.. [:J E: Ii/ ]~ (:) ~:) ...... NORTH/~?:OJ,.II'TH Ji!i'A',i.:]T/l/Jl~ii:sT ".'".' ii'71i~i:L~CT ] OJ')'i fill, 0 :1. 0 () 2C) C) · '.i ~:"~ ~'"~ 70() F:OC~ t 00 0 i () 5 () ~ 100 J. '25(J t 300 1400 1600 1700 1800 190C~ 2000 2100 2300 2400 . -~ ~. % .". ,Z...3 (.7 .... '600 (2). J. C)(). 0 200.00 7:,:") C).. /I' ,::],! I.'.'~) . (7.) 50 C:,. (') () /.':, () C). 0 C) '7 ,."~ 0.00 800.00 90 () ,, O0 ,:a,,p,p. 9'.7 ]. 0/:I 9.5)0 109'P. 91 1149.72 1 ~ ':.)9 ':-'/- -., '::.; ;f. ,--~'-~.--rs- .............. Tz, F-] '":::-T~: .... i z. ~-,:,. /._, 11 ,:,,:,, /._., '! 297.85 12q7._ · ,:,._,""= 1 .-_:.,9¢. ':3'~' -' l'::_'i:-:,'5": :-::i ..... 1491.47 1431.47 1585 99 1'525.99 1678.79 1618.79 769.4-7 1709.4-7 'S S 2028.08 1968.08 2110.~= '~,-=' · _o ~Uo0.55 o191 99 2131 99 2'772.2:2: 2212.2:3 .'2:7 7 .--, .-~ rZ ,::..: ..... 1 5 ;[ ";"::":' 1 5";4 :7:'7 =' ''= I .,,.. ,..,,, .- I -- ._.1 ._1 2 4 3 (~). 21 2:37 0.21 :.}.': :_::: 18 . , () 00 0 ,, 01 (). 14 ,':'i ,, ZJ.'(i) :'). ';7,:!:, ,j ,",[:7 1. :2.::(::) !. 20 1. ::ii' 9 '!. ,, '7 4.94 :5:. '7,¢':, 14. :27 _ . .2 i . 45:' .r:] (') "7 -:, .... ~, ..' .4 7,'.':,. 04 106.69 141.7.':.:: ~ i .6,9 2:2,5,. ::': 5 :27:::::, 42 ..... :q22. 12 :5:: 72.27 42:":.:. 61 ...... 476 ':;] ~ ..- 5:7: i.., ., :!ii:'7. ;!5':;.-' W 0. W 0. 1 '7 b,J C) ,, Zl 0 (.,.,j 0.6"7 i,...! (': ,, 89 W 0.94 C) '-"--"' · ,. W 0.8:7.-; W ~-.~ ,.:,o W I. 44. W 2.':::'""'.._, W ...~. l)..j W 9.28 ' W 15 ":'"' W '.-T; 6 . W 3 ;.2. :2:6 ................................ {4 54, E. 5 .... N 82.01 W 114.57 W 151.67 _ . I,,,.I :I '--":~ .......... .......... b,~ 290.89 .................. W :344 · 92 W 401. :37 W 459.26 W 5 i 8. :_--.:6 b,I ~::--'.- ,:} 7,=' ....I / .. . · SF',ERF:;.'Y.-E;t...IN WEI...L :SLIF;,'VEY 11',113 CFd'"IF:'At'..IY F:'AGE ANCHORAGE ALASKA ARC:O ALASKA, INC:, DATE. OF 'SLIRVEY JANUARY' 7,, 1987 3Q-57 ................................................. :;;;::;:;:::.; ::.; :;:: ;.: q,:. ,... . ...,. . ___~ _. C:OtdPUTAT ION DATE .BOSS 6YROSC:OPI C ::SLtRVE¥ ......... .::.::.i:.;i;;;i;i:~!!~;" I.:::I...IF'AF?t...IK F I El_ D JANI...IARY '.:.';':, 15)87 JOB I',.ILIMBI.:.':Fi AK--BO-7()007 ......................................................................................................................................................................... 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";:;¥':-.:, x, S 42 ~2 $ 70.80 W 0'09 74,5, 7.5 ~;; . 42 49 -,S 72, a9 W l, 0'9 '767.21 -S 41 17 :=, 71 · 19.. W 3.4~ 777 · ,5,6 ':'._, 4046.49 3986.49 40:--:4,40 '-'4:024, 40 4123:.'. 4(:) 4062.4o 4199. "---'"'"" 4139. oo · i~..iO 4278.48 421R~ · 48 4.z.._ 7 06 4297.06 .':52'0,:5 ...... ';'-i' a.- 35.50 4 375.50 53,:) 0 451 4. :l 1 44-54. i 1 ::) d. ':.) (.) ; ~-' "-' '"" z]. ~ c'., o 834 11 o A~ ]'-, o .,,..~ :.q ,.? ,z.: ,:. ,..:7.. 4,_ · 0~,, i. 5:-'6. '.!3 4.. ,5, '7 5'"'. E: 1440.91 15()5.92 i~.-- ."% 1 .:,7.z. · ":'/- :i. 639, 65 t '7 () 7.44- .................................. :l 77F; .-:,o I d;,'--I I843. :L4 .~ .......... :L 910.8;! 1944.12 ' i 976.. 74 2009.2:.--.: 2,341. 7('..') .7::::7:: 9 C). :33 2:352. C)5) :;;:'"t- 1:3 ,, 51 ARC:O ALASKA, INC, 3Q-'? K LJF'AR U K !:.: I E L_ D · ~,~ ,¢'% .** .% A L. ~-., .:. t'... A VERT I CAi_ M E A :iii; U R 1F D DEF:']"H WELL SLIRVEYING (':C~MF:'ANY A.NL.HORA.,E ALASKA COMPLITATION DATE PAC!iE:. DATE OF SURVEY ,JANLIARY 7, 1'"'" BO'.=,.., C';YROSCOF'I C: ::3URV.EY ,JANIJAF:i:Y 9 1 ""-'-' ., y,::,/ ,JOB NUMBEF:;: AI<--BC~-70007 ........ I I KEL..I....Y BI...I~BH t I'~lt.'::i t:::L.[::.,/. .... 6(), ()0 F"T' oE'-' - .... F' 'lION ' ' '"- .,:; TRUE SUB-SEA L,U_ RoE COURSE DOG-LEG TOTAL. ....... . .......... .. "" 'l ..... .. . VE:R T ]: CA L..-% . VERT I (":Al_ VERT I CAL I NC:I_ I NA'I" 101',1 Ii I t.-,, E _. f I ONSEVE:R I TY RIEC:'I'AN(3LIL. AF:;: F:OOR.O I NAT'IES .. OEF'T H L.E.~: ~.H ................ PE 0 I'! ]: N .ii:',E;,3F!E'E:S OE 0 / in(', NORTH/'.~:::,"',. ITH [;!:F.~:i;';"F/Wi!i::::.:-: T 56()0 5'700 5800 59'00 600() 6 i O0 6200 6:30() 64 ()0 6500 660 () 6700 6900 7C~00 7100 7200 7400 7500 4672~ 05 ............ 4751.30 48:30.87 4 '.::~ ]:'(!:' .' ~;, :;~!- 4'?'.:;' ('~. 42 5 0 7 (). :3 4 5150, 4.-,"' ';'; ...... .e,( ) _.:'--,:fi'(),- ...... 2";';.I..-, ................ . .', e,:;;;'; ............ 4x.z'; ............. ....,;=: ........./., 2':'T. 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J. '.:.;' W 0 .14 130C) . ,_,o--,.... S · _,/='"""L'=lr.._. 0/:, .,7.:,5 .0/:, 36 3 .=,'-' 64 . 0 W O. 17 1326 .56 ':'._, 5:3'7 6.05 5957.25 ..... 6C):Z::::. 9c'-, o1=1.03 6203.53 6~o~.70 260 ('::,. 05 W 2659', '.-.? 5 W :2'7.1. 3.5'P W 2 :i:i: 2 0 ,, :}.': 4 W 2 :.::: 73.5'7 W 2i:"26.81. W 2980.05 W 30:B3.07 W 6061."-'0o 6226.70 7600 6370.04 6310.04 7700 645:3.42 ~:39:3."42 7800 Z-,ei:z:A '-".=,, /-,47/-, ~ :::5 7900 6620.27 6560.27 79.90 66:95.36 6635. o6 HAIR I z. CINTAL DISF'I._~CEMENT = 34 56 .~ 63,=C ~2 W 0,28 142e. 75 ~ 5Z $ 63.39 W ':'I~:'0~ 1455.01 ._~ 34 $ 63.89 W 0,42 1479,65 '-'- . . =' ')'-' 92 33 ::-:',-' S 64 0 W 0 07 1._,t.: ......S :2:8:36. :36 . · 28'.:.~6.51 .... '".? ~ ~=' 9 (") .~, :: .,_1 .,.i · ., , .. :BC) :1. 5... (')~;_ _. :30'74. 19 "::~ :t :B :3. :31 :3192.42 :B251.50 .:,.=, ! 0 · 41 :i:= 36. ':~... . 01 :34:2'7. :2:3 .......................... 3484. 'P 2: :3541. o,-.. ~ :3598.44 ' · .:,o...:,. 92 :3:3 27 S"6'4-"b'0 W ........... 0~45 ........ i'527.77 S :'.'.::440.:36 ':3'!:-:'" '~7 ........... ;._-i'""~;4":"i~i0 w ........................ 6]"6i~" i ~=',~.. ;?; s; 33 27 ~ 64..'-(C~) W ........... ;"'"~'?~0 1574.72 S 3540. 1:3 .....,.,x ~:::.:..,~:~ ..~ . n -- . .~1 ._. i_, ._ .. . .~.~ 1 ~95 A~ ._.':' .................. .. :3924. 1:3 FEE"F AT Si]I_ITFI 66 DEG. 0 MIN. WEST A"i' .......................................... :>'.: 7 () ?. 15 :3 '764-. :3:2 ::,,::, .1 '.9 45 i~874...,7 :'39'.--.._'4.18 'll-tE CAi...CL.li..AT1C;Uq f':'FU]CE1]UFi:E:S ARE BASED ON I"HE USE OF ]"HREE-"D"]~'iqENSIONAL R{:'.'I~.Zlil..I:/; ."IF: C'LiF:,::,;(:~'TL~i::::F:: I'lr?:-II'HO0, ARC:O ALASKA~ INC. K Ij I::' A R I_11< F ]; E L D M E A :f-~ U R IE 0 DEPTH ANC:HORAGE ALASKA DATE OF ..:,I_RVEY ,_ANt. JARY / ,:~ ~::.::::,;~:~!~:: j COMPL!TATION DATE: ............... '...:. ... '. . .... ~ ....... .... IANUARY !?~ 1'~)87 JOB NLIMBER AI.:J-BO-7(')O07 ........................................................................................................................................................................................................................... KEL..L.Y i:~LISHIN(:]~ EL..EV. = 60.C)0 ...................................................................................................................................................................................................................................................... CI F' ERA T I] R- ~"1 I] (3 I._1 ]: F(: [:~ NTE~:D:~ED VALUE,:, FOR EVEN I000 FEET OF MEASt, iREB DEPTH ..... ~.:~. "1' R !..I E S LIB-- S E A 'T' 0 T A L ~[~.~ ................................................................................................................... [~ [~ [~ ~F ~}1 ~ (2~ Lj[... ~j~ ~~ t } r'" rz~ T I":A~ ,..,=,',, .... I C:AL. ,:::C,::,R D I NA'r E'.~: MD-I'VD VER'T' '[ C::AI .... · -. ...............................................................................................................................................................................' EI E; F:' T H D E F::' T H N 0 R 'T' H / S 0 Lt'T' H E A S T / W E S "1" I:;I 1' F' F E R E N C E C 0 R ........................................................................................................................................................................................................................... . ............ 2 ()0 0 ]. 'P 4:3, '.:.') 6 :'_'-': (':, () 0 274 :_:i:. 6 '7 40,:'} () 35 ::J 0 ,, i 4 50C)(} ' ""-"-' 4 .,.'- / c:,. 4 6 0 0 0 5 0 7 0. :3 4 7 C' C) 0 "":'"'":, -76 0.'-1 ?;':' '~ z 05 7 9 ':;' Fj' 7 ',"',~ ,:¥- -;:77 ............ -;-,- .:-5:-2:--:.:,*¥ ........ · . ..... (:, (z, .': .. i ,, ..', t':, I-,/'-,...,. ~ ,, . .., 0.00 0. O0 0. O0 0.37 N 1.74 W 0.01 "I"HE: CAL. CULATICiN F'F;,'C,2EDUI::;,'E:.'.'-.'; ARE[ BASEI.] ON THE i...ISE OF 'T'HREE I]IMENSIIDNAI_ F;.:ADII. If:]; ()1:::' L'::L.IF;:VA'I'LJi::;,'[ii: ARC:O ALASKA, INC. ":' ITl -- K I._1 p A r-..~ [..i...~..:, k. A '.:-':;F'[':::RRY--.SLIN WELl .... SLIRVEY I NG C:OMF'ANY F:'AGE-: 5 .................. =.~ ......................... ~.t., .............. ~ ..t..., ..~.~..+w ,.?~. ANL. HORA :~E ALASKA DATE OF SURVEY ,-IANLIARY 7., ' I'"' ' "?, ':78 ............. JnNL~.'-~H,¥ ~ 7 JOB N~ ~MF~Ei~-]:~Y.'i:::"i~'~F.T~]]iO.'!~!Z I< E L I... Y B L.I:~.; H I N G iii:: L E V. = -60. ()C) F'"I'. OF:'E F,'A TOR- MC GLI I R E INT'~~~.D VALUE=, FOR EVEN ~00 FEE']' OF" SUB-SEA DEPTH T RUE .:, JB-..-:,EH TOTAL. ... MEA:F;URED VER"F I CAL vERY' i"i::A t- REC]-ANGLILAR COEIRD I NATES MD--]"VD D E! F' T H D E F' '1" H KI F..: F:' T H N 0 R T FI / S 0 I..I T H J!.:.: A :.-.-.-; '1" / N El: :'.-'.'; T D I F:' F E R E N C E VER"I' I .... ~.,.,I._ C 0 R R E C T I 0 t",t 0 O. 0("~ -60. O0 0. O0 0. 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(')F:. _ ._,.':' z~7,. ................................................................................................................................................................................................. 1~---, '~'~' .... /..: 1560.00 1500.00 .-,,-,. ~,, .~ , z. ,~,,, ~ ~ .~..:,._, ... ~ ~;79-' 1560. O0 1500. O0 51 84 ':' - . ~ 134.2~ W ! ?..58 7 2~ O. 00 0.0() 0., ()(]) 0.00 0. O0 .. '(). ,:)0 O. ()0 1789 1760. O0 1-700, 00- 66.5L~ ~ ! 77, .24 -:W -- 2:.'~], :4.4. 9 . 87 SF'ERRY-SLIN WE:I_L..:,..IF,,vE:.~ INb L..UMFANY F'¢:.U3E 6' ~ .... ANCHORA6E ALASKA ......................................................................................................................... u ' .... '" : . '[~' ~ ~ " ARCO ALASKA, INC I]ATE OF' .=,JRVEY JANUARY 7, 1'~8.7 :.::[_.-¢ ..... .? ....... ..-.._.:, ...... :_ ........................... ..,.:.:.:.!'i~?:~i;,;.:::::::,.:':i,h'::.:::!;:: __ .... .. ' : · COMPUTAT t ON ..DATE ';: ". . ......... 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ALA;~A .................................... ~ ... , , , , ,. , ,,, . .... , . ,JAI',IL~AF..'Y 9, 1'i.:~87 .... lOB NL~MBi~:;F;{ ............................................................................................................................................................................................................................................................ KIFI.._L.Y BIJti~; H :[ NI'} 1:::'1 E:V, = /-,(), ()('> F' T. ........ .:,-.: .................................... ,-,,,,,,~, ........ :~ :: ............................................... : ....................................................................................................... 0 F' E: R A T' .:::,::, ,:x :~:.'.',...: :~ '.:,::..':,: ~ j:~ :,.~,' I NTE~t~J~;g:~:D VALUES FOR EVEN 100 FEET UF ;~UB-.oEA DEPTH .... ..::..: .. , . .::. · 'TRLtE: MEASURED VERT I CAL... :CfE F"l"l-I DEt:::' ~I"H .:,i_IB--.:,EA TOT'AI .... (/E~'i~;:'=T=~"i~!'~'L. ' ..... i~iEi.'7.':]=AN(3UL. AF;; .... CO01:~:B I. NATI?i:; ' ' P'ID-TVD I)EF"I'H NOF;:TH/$OLITH EAST/WEST i]I FF'E RE:.IqC.::E 6'7:32 5660 ,, OC} ....... 5600, 00 1 '="::::::, ,:,4 S 2944 .,:.,::,.-,o W I0/~.- ,-"-' 74 24 ,, ():3 /.,:,:.: z. 57(':,C~. 00 ,.~:';7('}0..., O0 ..... 13'15, :37 '.9.'; :'::(') 1 (') 1":',= W 1(')'-=//-,.. _. 6,3 ~.....,":":' , :::'::'/... ....,,=, (_. (.). c~ 0 1:3,1- '7:36 S / ..:, .............. 7 .1. 0:3 .5'.:.."6C.~. 0C.~ 5':2(>.C~., 00 1:3'~')!:.~ i,' !~i'7' .'.-"_:; :31 ::-.':'.:.:', 7:1. W 1 .i. 4:3. ::-)'.:.~ 2'3. 1 '7 ';:' "::' F:;,'!:,060.0C) 6000 ,, ()("~ :i.'-;i.'.1. 0. "7:3 '.Fi :3::::_:C)2.58 W :L 165, 61 :ii:::.-:: ,..:'::2 7:2:47 Z!,"l/-:~) .......... :'"~:)i-") ............ ~::'i'i')'~5']'~i.:iO ............................... 1441. '-~c, 6 ...... .:,;=: ................ ..:,,~64,:4:=; ............ '=Vl ............................... W 1 lo7.'-:':'= ..... 4/ 7467 6260.00 6200.00 1471. ~:~1-,_. ::,' .... ,_-,":"-'.=,.:~.~ ..... ' l'~ 1 W i ~.'-' £')'7.96 20.4,'.'.':, .,..-z=:;'-"~,:,, 6:36('~... 00 ~,:::C~('.~ .... . O0 1501 01 '.:, .=,._~c,4.60 W 1227. ":' =i-;' ~' 6 ':' :35 () 4. ()'.:.~ W 12 6 7 "' =' 7:.:::;-2:'7 6,560. ()0 6.50C). 00 1 ._., .......... /.-, ............ ' ~=','-,r.:;. '"'~:'' :'" '-'") ":'>"'7 ;::'; 7'?47 ~:.,~:.,,':-,0 00 ,,L-,/=,OC~ .r')O .l...,c .... 9('~ '..'='.'; .:,..., (:,.=, , c, :: N 1.,.-,:.-.,,. (:,,::. 7'~'~ ::,' (] /'/- '-'-/ ' '--' '":' - . ~., .=,,.,~.,. 04 W ~,:~ :,o,:,,-, 0.,: 66.-:7 ~)2 1 ='" "' ._,0 '-' 20.0 0 1 '?. '? :!:: .1. '.:::' ,, :.:.i~'7 .L 'i? ,, ::.:.':,:!', 5. :37 THE: CAL. CUI_A"I'ION PRt]F:EDURES U~:,E A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADILIF; OF CLIRVA'I"LIRE) PO II',ITS .... ::: .... r~vc.~ING COMPANY ANuHoRAL. E ALA~,KA ARC:O ALA.:.F..A~ INC, :3~::.J-'.~ I<LiIF'i:-~I~'~IK F'I EL...I3 DATE OF SURVEY ,_IANLtARY 7~ 1""---' .......... ,:....:....=. ,..::':: .... .. ~ 'C OM P U =T.A T l O N D ~ T E '....., .... IANI...IARY ':).. ~ :1.'.-7~87 .... lOB NLIMBER AK--..BF'~-7('~()["F'~..., O F'E F~' A"I' [2 R-M C :}t. 1 i R TE~O~:T.E[! VALJEo FOR ,.-c,=,-. ,- .,~ :,-- ~,... [ ~L. SURVEY FU ] NT~:, 'T' R U E ._, L.I B-._, E ~ T (] 'TA L.. M lii£ A S Ij F;,' E'L] .... V ~:.'"' R'T' .'[ C:AL V ~/F~'~F ii:~!'i:~ i... F,'I..:.. C T A N G!..I L.. A R (]Cfi)RD I t',1A T'E'.!ii: .~')E F:' TI.-~ DEF:'T'H ][)EPI"H NC~RTH/SCtL.ITFI EAS'I" / WES"I" MAF;..'I<E R ,"-,:30(') 03 6240 ("~:~; 1483.54 c .... ":' '---' "" -' ' "1-" ........... · .: .... 4c,.o7 W BASE k. LtFAR..It-... C 6:::: (::, () ~' ci :::i ............ ;~t~ ?:L,-'-i-.T:"':F ......... ~~~-]~i ............ ]i:~:~'~:,,-'.-'i::i ?""i,~- ................. ':F?:l~l~:,,,..:i~,:i::ii:-' 6:3'7 ('~ 8'7 6:21 C) 87 1 .=; (.~ 4 17 :-'_-'; ":'""':) . . _ ............... .:,.; ! 08 W BASE I<IJF'AF~:UK ,'.!:,.-':!.!!:::3.42 ,'.':,::::~':~3,, 42 ,1. 5:2.7. "7'7 :iii; ::i',440. :3,'.?:, W C.;LIF-?VEy F~E.:.P'T'H ,'::,._';:~""'~..-:. z . 67'; .......... 64 c-, 7 ."' .......... ,'.:-,7;': ....................... i.,$,:,.~-Zw. .......... AZ.. ::,-' ' ..... ..:,4o4. ';;;" ~ ?'; :'~zc:," ................................................................ W F'LUG BAC:K TD ~":~" '-'= ':' '-'?,'-'= 03 W TOTAL DEPTH &,A':,"=~ 36 /-,1-,:'":~.':; ':'/- :! .... .: ._~. ,:,.., .... .: .... :,._, ......... :,:,i', "',::.:'.: ....... 7:,:, ARCO ALA~;KA, ,.INCl. ~ · ~?,i~!~ ............. ...... ~'-" "" .z,F-ERRY SiJN SURVEY DATA DER I ~1::'['1 US I NG Ii I I_ [ E.I- FI-.i.::, AND ""-' "" ' -' . ......... TVD ........... BKB c: .~ ' ' · _,LIB. ~,EA 'I"OP Kt...IF'AFCJK C tlH:I'CKN'ESS VERT I CAL 750:3 628'?,, 20 ,:!:,2..-.,c~ .'::,r) '7~ .......... .... 1 ,:':, 6:'.:.:C)() o:3 624('J) 0:3 BASE Kt..JPAF;,'I...IK C TOP KI..IPARI_IK A ""'::"': /..., 1 6 f'.".' A.z,E I'::.'UP A Rt_IK A 7 6 0 l PL_ UG BAC I< TD .... //Dy'"'- 6300.0:3 6240.03 6:370. ,=,7 6310. o7 e,.,.,.:. 7.67 6467~ 67 1) FROM't~-i'NE~R--EXTRAPOLATION BELOW DEEPEST ~ATION. 2) COMPUTER PROGRAM- SPERRY SUN THREE DIME'NSION~L l .... RADIUS DATA CALCULATION AND INTERPOLATION BY RADIUS' OF CURVATURE ............................................. DATE COMPI. ITAT I ON DATE - ;'"' '¥ . . JANUARY :;', 1987 JOB NU~-BO-70007 :: ;.::-~ ~-:~:~.?.~:~.,. ,-:~.~?~.E~; ~..~..- KEI_LY"B~I~i~6 ELEV. = 60,. oC!.. FT. . S P [-' !:-:~ Fi "t' ---S U N 5Cfll F . · [ !.hiCt~ ]0 50fJ. u,rJ / 5gO. O KdP~i'::1,,J?( !-'iF[ I.) AB{"O A~ 1::ISKA. 1hi'. TFIUE NOFITH '-'"q .................... I ......................... T -3blJO. gU -5000. []0. --2500. BO 1- I --2000. OO -1500. O0 .-rOOD. O0 -SO0. uu r.. -.-'.)GU. bO -- ~ 000. O0 --lmOO. O0 --2000. O0 O. O0 1500.00 3000.00 4500.00 7SOO. CC r-- \ 'x 6695.36 I ~7990 I 4500. STATE OF ALASKA .' ...... ALA,. .~. OIL AND GAS CONSERVATION CON, ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other I~. COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 60' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 2259' FNL, 2134' FEL, Sec.17, T13N, R9E, UM At top of productive interval 1541' FSL, 196' FEL, Sec.18, T13N, R9E, UM At effective depth 1472' FSL, 339' FEL, Sec.18, T13N, R9E, UM At total depth 1425' FSI', 439' FEL, 5eC.18, T13N, EgE, UN 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4245' Production 7845' 7990'MD 6695'TVD 7789'MD 6528'TVD feet feet feet feet 7. Well number 30-9 8. Approval number 7-48 9. APl number 50-- 029-21674 10. Pool Kuparuk River 0il Pool Plugs (measured) None Junk (measured) None Perforation depth: Size 16" 9-5/8" 7" Cemented Measured depth 1875# Pol eset 115'MD 1100 sx AS IV & 4282'MD 300 sx Class G 300 sx Class G & 7880'MD 175 sx AS I meaSured 7542 ' -7570 'MD true vertical 6322 '-6345'TVD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail (~ 7443' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7413' & TRDP-1A-SSA SSSV @ 1810' ~ue Vertical depth 115'TVD 3739'TVD 6603'TVD 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) 7454 ' -7456 ' Treatment description including volumes used and final pressure 150 sx Class G Representative Daily Average Production or Inj. ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Comp~eZ;ion ~ei i Hisz;ory Aaaenaum, oared uz/1//u/) Daily Report of Well Operations [~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer (DANI) SW02/3 Form 10-404 Rev. 12-1-85 Gyro Date~° Ib~7 Submit in Duplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, parish or borough . North Slope Borough Lease ADL 25512 or Unit Imitle Completion Kuparuk River IState Alaska IWell no. 3Q-9 Auth. or W.O. no. AFE AK1631 Nordic 1 API 50-029-21674 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour IPrior status if a W.O. Complete 2/24/87 1000 hrs. Date and depth as of 8:00 a.m. 2/25/87 2/26/87 2/27/87 Complete record for each day reported 56.24% 7" @ 7880' 7789' PBTD, POOH w/pkr 10.0 ppg NaC1/NaBr Accept rig @ 1000 hrs, 2/24/87. ND tree, NU & tst BOPE. RU WL, RIH, perf f/7454'-7456' @ 4 SPF, 120° phasing. Make GR/JB rn to 7550', RD WL. RIH, set pkr @ 7205'. Att to est IR w/o success, POH w/R-3 pkr. 7" @ 7880' 7789' PBTD, Drlg cmt 10.0 ppg NaC1/NaBr Fin POH w/R-3 pkr. RIH w/OEDP to 7758', M&P 150 sx C1 "G" w/.63% FL-28, .3% CD-31, .15% A-2 & displ w/39 bbls 10.0 ppg brine, POH 20 stds, rev circ. Att to sqz cmt w/o success. POH, PU bit & csg scrpr, TIH, tag cmt @ 7099', drl cmt to 7250'. 7" @ 7880' 7789' PBTD, RD WL 10.0 ppg NaC1/NaBr Drl cmt to 7500', CBU. Tst sqz perfs to 2000 psi; OK. Drl cmt to 7744', C&C, displ hole w/cln brine. POH. RU Gearhart, perf w/4" gun, 4 SPF, 120° phasing f/7550'-7570' & 7542'-7550', POH, The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor 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 it space is available. Accounting District County or Parish I State I Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25512 Auth. or W.O. no. T t e AFE AK1631 Completion Nordic 1 API 50-029-21674 cost center code Alaska JWell no. 3Q-9 Operator I A,R.Co. W,I, ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun J Date Complete [ 2/24/87 Date and depth Complete record for each day reported as of 8:00 a.m. 2/28/87 Iotal number of wells (active or inactive) on this i est center prior to plugging and bandonment of this well I our I Prior status if a W.O. I 1000 hrs. 7" @ 7880' 7789' PBTD, RR 6.9 ppg Diesel RU & rn 230 jts, 2-7/8", 6.3#, L-80 EUE 8RD AB-Mod tbg w/ SSSV @ 1810', HRP-1-SP Pkr @ 7413', TT @ 7443'. Tst pkr & SSSV; OK. ND BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. RR @ 1845 hfs, 2/27/87. Old TD New TD 7789 ' PBTD Released rig Date 1845 hrs. 2/27/87 Classifications (oil, gas, etc.) { Type completion (single, dual, etc.) Oil I Single Producing method [Official reservoir name(s) Flowing I Kdparuk Sands Potential test data IPB Depth Kind of rig Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Ch;ke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 1106187 1108187 1/21/87 3Q-9 Rn CBL and gyro. Re-rn CBL to 7766' WLM TD. Rn GR/JB f/PBTD to surf. GR/JB pulled out of rope socket @ 700' while POOH. Trip back in hole w/6" GR/JB, tag 6-1/8" GR/JB @ 7752'; left in hole. Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak. t D-a~e ARCO Alaska, Inc. Posl Office Bu.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 9, 1987 Transmittal # 5909 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. CBL Finals: 3Q-13 1-9-87 6162-8074 3Q-14 1-9-87 6416-8392 3Q-11 1-9-87 5158-7127 3Q-9 1-8-87 7113-7760 3Q-12 1-9-87 5127-7284 3Q-10 1-8-87 5418-8240 Receipt Acknowledged: DISTRIBUTION: BPAE Chevron (+ sepia) Unocal (+ sepia) NSK L. Johnston Mobil (+ sepia) SAPC (+ sepia) Drilling ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfleldCompany ARCO Alaska, Inc. .... Post Office E~... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal # 5896 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 retuzn one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3Q-9 2" & 5" DIL 1-3-87 4282-7970 2" & 5" FDC Raw 1-3-87 4282-7970 2" & 5" FDC Porosity 1-3-87 4282-7970 Cyberlook 1-3-87 4282-7970 3Q-7 2" & 5" FDC Raw 1-10-87 7300-9249 2" & 5" FDC Porosity 1-10-87 7300-9249 2" & 5" DIL 1-10-87 1000-9275 Cyberlook 1-10-87 8600-9100 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Rathmell L. J6hnston (vendor package) Date: D&M Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. '~ Post Office E,. o 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 20, 1987 Transmittal # 5890 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 T~ansmitted herewith are the following items. Piease acknowledge receipt and return one signed copy of this transmittal. 3Q-9 OH LIS Tape + Listing 1-3-87 3Q-7 OH LIS Tape + Listing 1-10-87 #72157 4244-7873.5 #72163 988-9306.5 Receipt Acknowledged: DISTRIBUTION: Date: Wetherell ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany STATE OF ALASKA .... ALASK,. OIL AND GAS CONSERVATION COMM. .;ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend r-] Operation Shutdown EX Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address F.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2259' FNL, 2134' FEL, 5ec.17, T13N, RgE, UM At top of productive interval 1334' FSL, 264' FEL, Sec.18, T13N, RgE, UM (approx) At effective depth 1372' FSL, 297' FEL, Sec.18, T13N, RgE, UM (approx) At total depth 1322' FSL, 395' FEL, Sec.18, T13N, RgE~ UM (approxl~ 11. Present well condition summary Total depth: measured 7990 'MD feet true vertical 6698 'TVD feet 5. Datum elevation (DF or KB) RKB 60 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 30-9 8. Permit number 86-186 9'. APl number 50-- 029-21674 10. Pool kuparuk River Oil Pool Plugs (measured) None fe ¢ Effective depth: measured 7789 'MD feet true vertical 6529'TVD feet Casing Length Size Conductor 80 ' 16" Surface 4245 ' 9-5/8" Production 7845' 7" Junk (measured) None Cemented Conductor Report Not received 1100 sx AS IV & 300 sx Class G 300 sx Class G Measured depth 115'MD 4282'MD 7880'MD ~e Vertical depth 115'TVD 3741'TVD 6606'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED JAN 2 987 Alaska 0il & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal W~ll Hi story 13. Estimated date for commencing operation January. 1987 Detailed operations program BOP sketch - 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~ ~ Title Associate Engineer Commission Use Only (DAN[ )SA/208 Date 1-/~)'~ 7 Conditions of approval Approved by Notify commission so representative may witness ,~ Plug integrity ? BOP Test Location clearanceI Approval .... .. Commissioner.- by order of the commission Date/-.,.~ ~/~-,~"~ Form 10-403 Rev 12-1-85 Submit in triplicate '~'~ ~r~.~?~ end' Submit 'the:.~'l~titla}~ ~rt~,f~the-'fft~t-',Wedneeday after a well is spudded or workover operations are started. ~i~:!':%.-.~all~-worl('prtor to spudding should be.~ on the form giving inclusive dates only. District ..... *~:'~[:?:~/~ County, parish or bo oug I State Alaska~ ~:!~i~'~ ' North Slope Borough I Alaska Kuparuk River ADL 25512 I 3Q-9 Auth. or W.O. no. Title AFE AK1631 Drill Doyen 9 API 50-029-21674 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun Io;te IHour [Prior status if a W.O. Spudded 12/29/86 1200 hrs. Date and depth as of 8:00 a.m. 12/29/86 12/30/86 12/31/86 1/01/87 thru 1/o2/87 Complete record for each day reported 56.24% 16" @ 115' ll0' (0') Rigging up Accept Ri~ @ 0450 hfs, 12/29/86. 16" @ 115' 2025' (1910') Drlg WT 9.0, PV 12, YP 19, PE 9.0, WL 10.0, Sol 6 Work on drawworks brakes, test diverter. Spud @ 1200 hfs, 12/29/86. Drl f/115'-1303', POOH, chg out Jars. DrI to 2025'. 1075'MD, 3.2°, S62.4W, 1074.94TVD, 4.24VS, 1.97S, 3.76W 1385'MD, 14.2°, S64.2W, 1380.91TVD, 51.73VS, 20.75S, 47.46W 1696'MD, 23.2~, S70.1W, 1675.11TVD, 151.44VS, 57.28S, 140.63W 16" @ 115' 4300' (2275') POE to run 9-5/8" csg WT 9.5, PV 15, YP 16, PE 9.0, WL 8.8, Sol 8 Drl f/2025'-2117'. POH, change BHA. RIE & drl f/2117'-4300'. Drop survey, POH to run 9-5/8" csg. 1850', 28.4°, S72.2eW, 1813.76TVD, 217.90VS, 78.94S, 204.06W 2042', 32.8°, S63.9°W, 1979.02TVD, 315.36VS, 115.13S, 294.65W 2570', 38.3°, S64.2eW, 2408.61TVD, 622.34VS, 250.44S, 570.45W 3137', 37.4°, S59.9°W, 2856.32TVD, 970.11VS, 413.51S, 877.78W 3703', 38.5~, S64.6°W, 3302.64TVD, 1318.08VS, 575.58S, 1185.83W 9-5/8" @ 4282' 7531' (3231') Drlg WT 9.9, PV 10, Y? 5, PH 9.5, WL 8.2, Sol 10 POE. LD BHA. RU & RIH w/9-5/8" csg. Cmt w/ll00 sx (406 bbls) AS IV lead @ 11.8 ppg, tailed w/300 sx Class G @ 15.8 ppg. CIP @ 1600 hrs. Good returns. ND diverter - NU BOPE & test to 3000 psi. RIH drlg FC & FS. Test csg to 2000 psi. Leakoff test to 12.5 ppg EMW. POH, 47 jts washout in slip area. Drld to 7531'. The above is correct For form'prep~ratlon and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ,A Oil'end Gas Company ,, Daily Well History-Final Report Inalructions: Prepare and submit the "Final Rel~ort" 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. District lCounty or Parish Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O, no, ~Title I AFE AK1631 Operator ARCO Alaska, Inc. Doyon 9 A.R.Co. W.i. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. North Slope Borough ADL 25512 1/03/87 1/05/87 IAccounting cost center code State Alaska IWell no. 3Q-9 Drill API 50-029-21674 [Total number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well i IHour J Prlor status if a W.O, 12/29/86 / 1200 hrs. I / 7" @ 7880' 7990' TD, (459'), RR 10.0 ppg NaC1/NaBr Drl & surv 8½" hole to 7990', short trip, C&C, POH. RU Schl, rn DIL/GR/SP/SFL f/7976'-7300' & 7650'-7450' hi resolution pass, FDC/CNL f/6900'-6250', CAL f/7874'-7400', RD Schl. RU & rn 180 its, 7", 26#, J-55 BTC csg w/FC @ 7789', FS @ 7880' csg, stuck pipe 20' off btm. M&P 100 sx 50/50 Pozz & 200 sx C1 "G". No cmt rtns, did not recip pipe. Displ w/10.0 ppg brine using rig pmps, bump plug. NU & tst tbg head. RR @ 1930 hrs, 114187. 7710', 33.3°, S62.7W, 6462.67 T1/D, 3774.14 VS, 1630.34, 3404.19 7990', 32.7°, S64.2W, 6697.50 TVI), 3926.64 VS, 1698.50, 3540.61 RECEIVED JAN 2 3 1987 Alaska Oil & Gas Cons. Commission Anchorage Old TD New TD PB Depth 7990' TD 7789' PBTD Released rig Date Kind of rig 1930 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 1/4/87 IType completion (single, dual, etc.) Single . Official rese~oir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production , Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected , The above is correct Signature For form preparation snd distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Date~/~;:~7._. ITM Drilling Supervisor December 5, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy.- (907) 276-7542 Re: Kuparuk River Unit 3Q-9 ARCO Alaska, Inc. Permit No. 86-186 Sur. Loc. 2259'FNL, 2134'FEL, Sec. 17, T13N, R9E, UM. Btmhole Loc. 1251'FSL, 431'FEL, Sec. 18, T13N, 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. [,/~~, trulv~v~urs, C. V. CHatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF %"HE COb~4ISSION dlf Enclosure cc: .Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA t..._ AND GAS CONSERVATION CU,,,MISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work Drill ~ Redrill [] I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [3 Developement Gas [] Single Zone J~ Multiple Zone CJ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. RKB 60' , PAD 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Ri vet Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 2259'FNL, 2134'FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nurpber Number 1334'FSL, 264'FEL, Sec.18, T13N, R9E, UM 3Q-9 #8088-26-27 At total depth 9. Approximate spud date Amount 1251 'FSL, 431'FEL, Sec.18, T13N, R9E, UM 01/06/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3Q-1 0 8029 'MD 2134' (~ surface feet 25' ~ surface feet 2560 (6687'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depthl000 feet Maximum hole angle 39 0 Maximum surface 2214 psig At total depth (TVD) 3220 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3/~" 1~" C-,') :;# H-40 Weld 80' ~5' ~5' 115' 115' ~200 cf I 2-1 /L~'cI-~/R" ~ _Cl# .I-r~r~ RTC. ~?~, '~, ~,c~ , 4?Re, ' '~7b, l') ' 1 ?f~r~ S" AS I I I & HF-E~W ~O0 -~x Class C, hl~.nd 8-1/2" 7" 26.0# J-55 BTC 7995' 34' 34' 8029' 6687' 200 ~sx Cla~ G(minimum HF-EFW T0C 5~)0' abov~ top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate '~'~ :;-'[" 0 '~ Production !": ...... Liner ',1~8.~ 0ii & 6~s Cons. 00remission Perforation depth: measured true vertical 20. Attachments Filing fee ~' Property plat [] BOP Sketch'1~ Diverter Sketch I)¢ Drilling program Drilling fluid program~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby cer.tJ4~hat the fore.going is true and correct to the best of my knowledge Signed 1~/.~¢'/ X' _~4,~' ' "¢¢'~~t Title Regional Drilling Engineer Date. ' z/k/ & u / ~'~ /' - Commission Use Only ( RH E ) PD/01 7 I APl number I Approval date I See cover letter Permit Number ¢~ '/~& 50-- ¢ ~'-)' -'*/¢ ~ ¢ :[2/05/86 for other requirements Conditions of approval Samples required [] Yes [~ No Mud Icg required [] Yes I~' No Hydrogen sulfide measures ~..,Yes ~3_,,No D. irectional survey required ~ Yes [] No Required working j;;~r, eb-'%"~re fCr"B/IDP/E~- E~ l;~,~M;~ [] 5M; [] 10M; [] 15M Other: ///' ~/f~ by order of Approved by ~ _~,, /',, ~,,..,,~~~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit irf triplicate KUPARUK RI VER UNIT 20' DIVERTER SCHEMATIC =l L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3, FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS S. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SIN6LE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER, VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTI~NANCE & OPERATION 2 .,II. 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL" --~e~,~ 0il UNDER ANY Cl RCUMSTANCEg JG 11-3-86 7 6 > > DIAGRAM #1 13-5/8" 5000 PS~ RSRRA BOP STACK I. 16" - 2000 PSI TAN<CO STARTING HEAD 2. il" - 3000 PSI CASING HEAD 3. II" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RA~ 5. 15-5/8" - 5000 PSI DRILLING SPOOL W/GHOKE AAD KILL LIhES 6. 15-5/8" - 5000 PSI DOUBLE RAM W/PIPE ~ ON TOP. BLIhD P~ ON BOTTOM. 7. 15.5/8" - 5000 PSI A~ ACCUMULATOR CAPACITY TEST i. CHECK AN) FILL A(X].IVM_ATDR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACO. MLIATOR PRESSURE IS 3~300 PSI WITH 1500 PSI ~TREAM OF THE REGULATDR. 3. 06.SERVE TINE, TFEN CLOSE ALL UNITS SINllTANEOUSLY ~ RECORD THE TIVE A~D PRESSIJRE REI~I~INING AFTER ALL UNITS ARE CLOSED WITH CHARGING PLM:~ OFF. 4. RECC~D ON NADC REPORT° THE ACCEPTABLE LC~ER LIMIT IS 4S SECON]~ CLO~ING TIVE ~ 1200 PSI RE]~IAINING PRESSURE. 5 4 2 13-5/8" BOP STACK TEST I, FILL EK:P STACK AI~ ~ MANIFOLD WITH AR~IC DIESEL. 2. CHECK THAT ALL LOCi< D(~N ~ IN ~E1.LHEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN ~LLHEAD WITH RUNNING JT mN) RUN IN L~ SCREWS. LIhE VALVES ADJACENT TO BOP STACK. ALL OTHER VALVES ~ CHOKES SHOULD BE (:PEN. 4. PRES,SURE UP TO 250 PSI ~ HOLD FOR I0 MIN. IN-- CREASE PRESSURE TO 3000 PSI AhD HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN AI~IJLAR PREVENTER AhD MANUAL KZLL mN] CHOKE LIhE VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON K~ILL mN) CHOKE LIhES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. 7. CONTIh~ TESTING ALL VALVES, LINSS, ~ CHOKES WITH A 250 PSI LO~ A~> 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSLIEE TFRT ANY CHOKE THAT IS h~T A FULL CLOSING POSITIVE SEAL CHOKE. ON_Y FUNCTION TEST CHOKES THAT DO hiJT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AhD CLOSE BOTTOM PIPE RA~. TEST BOTTOM PIPE RANIS TO 250 PSI AhD 3000 PSI. 9. OPEN BOTTOM PIPE RAMS, BACK OUT RUhNING JT AhD PULL OUT OF HOLE. I0. CLOSE BLIhD RAMS AhD TEST TO 250 PSI AhD 3000 PSI. II. OPEN BLIhD RA~ AhD RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LIHES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AhD INSIDE BOP TO 250 PSI AhD 3000 PSI. 13. RECORD TEST IhFC~TION ON BLONOUT PREVENTER TEST FO~Vl, SIGN, AhD SEND TO DRILLING SUPERVISOR. 14. PERF~ C(]VF~ETE BOPE TEST AFTER NIPPLING UP AhI) WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. . - . 510084001 REV. 2 MAY 15,1985 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Do%msqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary ~m~s tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plus back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. - 21. Secure well and release rig. 22. Fracture stimulate. r_~,, OEOAS~ER ! i SHALE _ SHAKERS .~. STIR .~..~,. STIR --4~ STIR TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 · 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow SensOr - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907' 276 1215 November 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3Q 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, d. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany I I 8 9 17 16 I I I I II ¥1CINITY ~ SCJ~E ~ I" ' 2 MILES ALL WELLS LOCATED IN SEC. 17, TISN, R9E, UMIAT MERIDIAN. /W,.l ',y, 6,025,873.23 6,025,867.50 6,025,861.28 6,025,855.29 6,025,649.:56 6,025,84:5.:57 6,025,837.44 6,025,831.4:5 6,025,613.50 6,025,807.25 6,025,801. :51 6,026, 795.53 6,025, 789.:51 6,025, 783.47 6,025, 777.44 6,025, 771.55 ;ps .. 'X' 515, 959.92 515, 9~4.20 516,008.42 516,032..55 516,056.99 516,081.28 516,105.64 516,129.72 516,202.58 516,226.82 516,251.42 516, 275. 5 Il, 21t. 52 516,223.60 516,~1~.20 516,3'~.$1 ",I L.4,TiT UD E: 70° 2 8' 54.756" 70° 28'54.701" 70° 28' 54.6:59" 70e 28' 54.5~:)' 70° 28' 54,52 I" 70" 26' 54.462" 70° 26' 54.4(~" 70' 26' 54. :54~" TO° 26'54, 165" 70° 28' 54. I05" 70° 26' 54.044' 70O 28' 5:5,907" 70O 28' 53.925" 700 29' 5:5.800" TOe 28' 53.749" NOTTS: I. ALL ~ATES AI~ A.S.R, ZONE 4. 2.M.L DI9T~ ~(NIN AN[ Tll~. $.ELE~KI'IONS All: I.P. ILS. L. 4.1KF. FIELD lOOK LI4-1I, Pel~l 21-22. 5. O. G. ELEVATIONS FROM F.R. BELL Ii A~)ClATES. ,.HORIZONTAL PO~ITIO#S BA.q~D ON 3Q C~,~ I '~'. L' ~ ~NTS PER LHD Ii ~ '* il Dlst. F..N.L. I Dllt',F'E-L: ~ ' L~NGITU~)I~" 149052` 10.512" 149° 52' 09.79~" 149° 52'0~ 14P 52'06.$76" 14~ 52'07,65e" ~2'o~.s44" ~ ~' os.2~o" ~4~ ~'o8.~o" 14~52'0~,]7l" 14~ ~2'01. I~'~. 529' I~1' 5~.~7" 14~ ~1' 2191' 2205' 2211' 2217' 2225' 2229' 22~' 2241' 2251' 2265' 2271' 2277' 2213' 22i¥ 2301' 2:562' 2521' 2:504' 22~0' 2255' 2251' 2207' 2134' 2110' 2085' 20~.' 2037' 2oiS' ~tes' 17.1 17.1 17.1 I?.~' 17.2 17.:5 17.3 17.4 17.5 17.3 17.5 175 17.5 17.~ 17.5 21.7 21.7 21.7 21.l 21.I 22,O 22.O 22,0 22.O 21.1 21.t 21.1 21,S I HEREBY CERTIFY THATI AM PIIOPERLY REGISTERED ANO LICENSED TO PRAC- TICE LAND SURVEYING IN TI,~ PLAT REPRESENTS A LOCATION SURVEY M~DE eY ME: OR UNDER4gT_, MY SUPERVISION' AND THAT ALL ~,eeeeeeeeeeeeeeeeeeeeeeeeee1 DIMENSIOI~ ANO OTHER DETAILS ARE CORRECT AS OF 11/2/86. CHECK LIST FOR NEW W~,L PERMITS ITEM APPROVE DATE (1) Fee ~ ~-~. L- ~ i 1. / (2) Loc ~ ~ ~ ~ ..... (2' thru 8) (3) Adndm thrU 13) ,. / 10. (10 and 13) 12. 13. (4) Casg ~~-~-~ ( '22) '("23 thru' 28) .... Company YES Is the permit fee attached .......................................... ~.. Lease & Well No. NO 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available, in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~'" Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 all casing give adequate safety in collapse, tension and burst,. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandomnent procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/AP1 RP-53 (Mmy 84) .................. Is the presence of H2S gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requir~ts ............................................. .Geologf: Engi~Dering: kl4B ,e,~.? LCS '~' BEW rev: 07/18/86 I INITIAL POOL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE 0 Additional Remarks: I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to "'simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ ., No special 'effort has been made to chronologically organize this category of information. .o I I I I I I I I I I I I I I I I I I I clds e e Memory Multi-Finger Caliper Log Results Summary /8¿,., ..~ 18G, Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. January 26, 2006 6555 1 2.875" 6.5 lb. J-55 8rd EUE Tubing Well: 3Q-09 Field: Kuparuk State: Alaska API No.: 50-029-21674-00 Top Log IntvI1.: Suñace Bot. Log Intvl1.: 7,443 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into bottom of the 2.875" Tubing @ 7,443' (Driller's Depth). This log was run to assess the condition of the 2.875" tubing with respect to corrosive and mechanical damages. The 2.875" tubing appears in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 70% in joint 191 (6,105'). The damage appears in the forms of general corrosion, isolated pitting, and lines of corrosion. Indications of apparent significant corrosive damage are recorded in GLM's 1, 2, and 3. The caliper recordings indicate a possible hole in the orientation guide slot at top of GLM 2 (4,685'). A detailed 3-D image of GLM 2 at the location of the possible hole is included in this report. The recordings indicate slight buckling of the tubing below 5,400'. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the 2.875" tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Corrosion Corrosion Corrosion Corrosion ( 70%) ( 66%) (61 %) ( 58%) ( 58%) Jt. Jt. Jt. Jt. Jt. 191 @ 136 @ 141 @ 127 @ 183 @ 6,105 Ft. (MD) 4,341 Ft. (MD) 4,498 Ft. (MD) 4,070 Ft. (MD) 5,862 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 12%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. ~:'Af"\I'" !.: t{ ¡ ;j! ¡"I , ',,) ....11 1.,.JV! I Field Engineer: N. Kesseru Analyst: M. Tahtouh Witness: T. Senden I Ine. P.O. Box Staffol-cl, TX 77497 Fax: ";65-J.369 E-mail: Phone: 659-2307 Fax: RECEIVED Pllone: or F'¡Ucltloe &\'J ~VC<' FEB 0 2 2006 "\.Iaska Oil & Gas Cons, Commission Anchorage I I I Well: Field: Company: Country: 3Q-09 Kuparuk ConocoPhillips Alaska, Ine. USA I Tubing: Nom.OD 2.875 ins 6.5 ppf Grade & Thread )-55 I Pl'l1l'tratiol1 ami Metal loss (% wali) I penetration body metal loss 200~ I 150 100 I 50 o 20 to 40 to 40(Y~ 85% o to 1 °/0 10 to 20% 1 to 10% I Number of joints pene. 0 21 loss 35 ¡ 97 (total = 23 7) 106 38 o 0 72 5 I I Damage Configuration ( body) 150 I 100 I 50 o I !sobted pitting genera! Imp ring hole I po<;<:, corroSion COITOSlon (OITO~~lon ¡hie hole I Number of joints damaged (total = 198) 88 101 9 0 0 I I I I over 85°;;) o o p SR dy R Survey Date: rool rype: 1'001 Size: No. of Fingers: Analvst: Nom.lD 2.441 Îns ort Overview gl n Analysis January 26. 2006 ¡v1FC 24 No. 40665 1.69 24 ¡\1. rahtouh Nom. Upset Upper len. 1.2 ins Lower len. 1.2 ins penetration CLM! CLM 2 CLvt 3 CUvt4 CLM 5 CLM 6 C LvI 7 Damage Profile ("/0 wall) metal loss 50 100 Bottom of Survey 230.9 Analysis Overview page 2 I I I I I I I I I I I I I I I I I I I Company: Log Date: Conoc:oPhillips Alaska, Inc. January 26, 2006 Well: 3Q-09 Field: Kuparuk Detail of Caliper Recordings in Orientation Guide Slot @ Top Of GLM 2 (damaged) & GLM 5 (Undamaged) Possible Hole in GLM 2 @ 4685' I I Pipe: BodyWall: Upset Wall: NominaIID.: I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 2.875 in 6.5 ppf )-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3Q-09 Kuparuk ConocoPhíllíps Alaska, Inc. USA January 26, 2006 Apprch. rool Deviation Appro". Borehole Profile ClM 2 ClM 1-· ClM 4 ClM 5 ClM 6 (~Ll\11 ì 230.9 o 50 Damage Profile ('j;) wall) / rool Deviation (degrees) I Bottom of Survey = 230.9 I I 2395 3986 4785 5577 6382 7187 7442 100 32 792 1584 3194 ...:; LL c: I PDS EPORT JOINT TABULATION SHEET I 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: Pipe: Body Wall: Upset Wall: NominaIID.: I I Joint No. Pen. Min. I.D. (Ins.) 2.40 2.39 _~___ (¡ 2.38 237 2.38 2.39 2.39 239 2.39 2.3ß ~~ _______---L~ ~ 2,39 23ß 2.37 239 Isol,ìtecl pitting. I I puP Shallow pitting. I -----"L-. 5 ~.. 7 8 9 ___IQ 11 -----.lL 13 14 95 127 159 190 222 254 285 317 349 381 412 444 {\ I ___m_ I I 570 _---.-.f~() 2 634 . ___º(22~i 697 _:23 ..-------'Z29 .... 24 _. 760 .... il __ 25 _. 792_ ~~.__ 26 824 II 2.40 2.39 ______~___ -=--4.39 2.3ß 239 2.38 IL_J .. 238 2.40 240 ..Jí.L..... L_.:L) 9 238 I pitting. lJ, Deposits. pitting. Lt. DeposLts. pitting. pitting. .l.......:2.39 Sh<1l1oW pit~lìg. 2.37 Lillf corrosion. It. Deposits. Line corrosion... Line shallow pit.!~ Line corrosion. pitting. ¡ f) ¡ -_._~- ------- I I I 40 12(2ª--... 0.04 41 1299 0.04 42 1331 0.04 43 1363 0.04 ___.1'L 1394 .. 0.04 _.1'L---.L426 0.04 ...AL _. 145ß.. _~ 008 ' ....Æ. ~() () 0.03 48 1521 0.03 _19 1553 0.02 2.40 23ß ... 2.37 . 23ß 2.39 239 238 2.37 2.38 2.38 3Q-09 Kuparuk ConocoPhillips Alaska, Inc. USA January 26,2006 Comments .---,-,._- I Line corrosion. Line corrosion. Lt. Deposits. Shallow pitting. Line ,Ç·9rrosion. Shallow pitting. Line corrosion. I I Page 1 I I Damage Profile ('Yo wall) o 50 100 Body Metal Loss Body I PDS REPORT JOINT TABULATION SHEET I 2.875 in 6.5 ppf JoSS 0.217 in 0.217 in 2.441 in Pipe: Body Wall: Upset Wall: NominaII.D.: Well: Field: Company: Country: Survey Date: 3Q-09 Kuparuk ConocoPhillips Alaska, Inc. USA January 26,2006 I I Joint It. Depth Pen. Min. No. (Ft.) Body 1.0. (Ins.) (Ins.) 50 1584 0.03 2.38 1616 0.03 2.39 1""') 1648 (1.05 I ¡ ') "J"""! )~ .....,)1 53 1679 0.02 2.39 54 17 (UB 2.40 r"!"" 1743 0.02 2.39 -'-' 56 1774 0.03 /) ')""'" ~..)/ 56.1 1807 (1.08 2.38 56.2 1817 0 2.31 57 1825 0.03 2.38 58 1857 0.03 2.37 59 --~ ~- 1888 0.07 2.39 60 1920 0.04 2.38 61 1952 0.03 2.38 ~-~.- (') 1983 0.02 2.36 )~ 63 2015 0.05 2.3ì 64 ;:'047 2.36 65 2078 0.03 2.36 66 2110 0.05 2.36 67 2141 0.07 2.34 68 21 0.03 2.36 69 2205 0.03 2.37 70 2237 0.04 2.36 71 2268 0.04 2.36 -F) 2300 () OJ)4 2.35 ._~..~~""'- 73 2332 0.07 2.36 74 2363 0.04 2.34 2395 0.05 2.35 76 2427 0.04 2.34 2459 0.05 2.34 78 2490 0.07 LiS 79 2522 005 237 80 2554 008 ') "j') ..:-._1....., 81 2585 (1.06 -." 2.36 82 2617 0.0.5 ') ') t" ."-._J_' 83 2649 iJ 0.03 234 84 2680 0.05 236 85 2712 Ii 0.12 2.31 85.1 2744 0 N/A 86 2750 CJ.05 2.32 87 2782 0.05 ") ')") .i-.,.)~ 88 2813 0.06 ') ') t"' ."-._J.) 89 2845 OJ)7 ') ',r:- ~.Y) 90 2877 0.06 ') 'J L ......-j.) 91 2909 0.04 2.35 92 2941 0.04 232 93 2972 0.05 2.35 94 3004 0.07 2.36 95 3036 0.08 2.34 96 3067 0.07 2.3.5 Damage Profile ('10 wall) o 50 100 COlmnents I Shallow pitting. Isolated pittil\g. I PUP line corrosiolL SSSV I Shallow pitting. 1~)lated pitting. It. Deposits. Shallow pitting. I Isolated pitting. Isolated pitting. SI1aIIO'v\/pitting. Isolated pitting. Corrosion. I Shallow pitting. pitting. Shallow pitting. _b;{) ;1ted pitting. Isolated pitting. Shallow pitting. Isolated pitting. 'iballow pitting. Isolated pitting. Corrosion. Corrosion. Corrosion. Isolated pitting. Isolated pitting. Shallow pitting. pitting, Corrosion. Deposits. GlM 1 @ 9:(0). Corrosion. Corrosion. Isolated pitting.. Isolated pitting. Corrosion. Corrosion. Shallow pitting. SIB!low pitting. IsolateçLpitting. l.?oIated pitting. Corrosion. Corrosion. I I I I I I I Body Metal loss Body I Page 2 I I I PDS EPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in I I joint Pen. No. 97 3099 98 3130 99 3162 100 3194 3226 10 3257 0.10 103 3289 Q)J4 104 Ii20 0.03 -----1 0 5.. '-) r) 1':"') 0.05 -'.)-),;.. 106 B84 0.06 107 3416 0.09 108 0.09 109 3479 0.08 110 3511 0.07 II! 3542 0.07 112 3574 0.07 113 3606 0.07 3638 .. 0.08 15 3669 0.07 116 3701 0.07 117 3733 0.08 118 3765 0.09 .. 119 37% 0.11 --1£(2. 3828 0.08 121 }859 0,129 122 3891 OJì9 ....lll... 3923 0.08 124 3955 0.09 pC' 19B6 0)28 ~.] 126 40lB 0.09 p~ 4050 0,13 ~I 12B .. 40BI 0.09 4113 0.08 4145 0.10 4177 (1.08 132 4208 ) <)r} 4240 Q.09 -)-) 134 4272 0.07 I ~) ~ 4304 I) 0.13 .) ~} ~ 4?'YL 4 -'-- -,._,.) 137 4367 ()..12 138 .4398 0.09 139 4430 0.09 140 4462 0.07 141 4494 0.13 142 4525. (LOB 143 4557 0.08 144 4588 (UJ8 145 4(..20 0.12 146 4652 0.10 I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: 3Q-09 Kuparuk ConocoPhillips Alaska, Inc. USA January 26,2006 () 2.34 2,35 2.33 ') -) L ,,-_.J_) 236 234 235 2.34 ') rlt'::' ....h)~) ') ")!:" ~.].J ') ') r:- ~.__)J ,) .) 'J .....__J._) ') ') k ......_,-) 2.33 ') ') 'J .....-_1.)' 231 2.34 ') 'J J:'" .......J.) 2.34 ') " L .....,:,.) ') ') r:- -<-._)..J 2.34 ') 'J r.- ......__,J 2.B 2~35 235 2.34 ,) ')"j .....,:)..) ~2.35 ¡ ¡ 237 Min. ID. (Ins.) Cornments 2.36 2.35 230 2.35 Isolated pitting~.... Corrosion. .Corrosion. ..CgIIQ;;iQI] . C(J[rosion. Lt Deposits. C 0 rrosioILJL[).~nosi ts. S h al I Q.\YJJitti 11g. Shallow pitting. Corrosion. Corrosion. Co rrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Lt. Dtt)()sits. Corrosion. CorrosioLl. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. CorrosiQl1. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosi(JIl· Corrosion. Corrosion. Corrgsion. Lt. Deposits. CorroslQP· Cor ros io 1.1. Lt Deposits. Corrosion. Corrosion. Corrosion. Corrosion. Lt Deposits. Corrosion. Corrosion. Lt. Deposits. Corrosion. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. 234 2.33 236 2.34 237 234 2.37 Page 3 Damage ('Yo wall) o 50 ! 00 Penetration Body Metal Loss Body I RT JOINT TABULATION SH I 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3Q-09 Kuparuk ConocoPhilfips Alaska, Inc USA January 26,2006 It Depth Pen. Min. (Ft.) I.D. COlnrnents (Ins.) 0 100 146.1 4684 Clivi 2 (Latch @ 12:(0). Corrosion. _HL 4690 2.36 Corrosion. 148 4'7')') 2.38 Corrosion. /........ 4754 (J 2.3ì Corrosion. ., j50 4785 h 235 Corrosion. ~jL_. 4817 0.07 2.37 Corrosion. 4848 008 2.36 Corrosion. 153 4880 0.10 2.39 Corrosion. _12.'L 4912 0.09 2.40 Corrosion. _1}.2._,. 4943 008 2.40 Corrosion. 156 4975 0.09 2.39 Corrosion. 157 5007 0.11 .Li8 Corrosion. 158 .5038 0.10 2.3~L Corrosion. 159 5070 (J09 2.3(~~ Corrosion. 60 5102 0.07 2.38 Corrosion. 161 5134 CL 10 Corrosion, 162 5165 0.09 ') ,)-. Corrosion. ~.-,I 163 5191. 0.08 I , 2.36 Corrosion. Lt. Deposits. I 164 5228 0.08 ') ')t" Corrosion. Lt. Deposits. ....._)-) 165 5260 0.11 2.33 Corrosion. ~-- 5292 0.09 2.36 Corrosion. 167 r- '"} 'j') 0.07 2.34 Corrosion. -),)>.---} 168 .5355 0.06 2.36 Corrosion. 169 5387 0.09 2.36 . <,:·orrosion. 170 5419 (W8 2.33 Corrosion. 171 5450 0.07 2,37 Corrosion. 172 5482 0.06 2.34 Corrosion. 173 5514 0.07 ') ')1'::'" Corrosion. ~._j-) 174 5545 0.09 2.31 Corrosion. 175 r.:'1'::'""""¡ 0.07 2.35 Corrosion. .UII 176 5609 Q.07 2.,38 Corrosion. 177 5640 0.07 236 Corrosion. -.lZZJ 5673 0 N/A CLM @9:(0). Corrosion. _...lZI3 . 5679 0.08 2,33 Cor rosiq 1. ...J12 5711 0.08 2.38 CorrosiqlL 180 5742 0.10 2.34 Corrosiql1. 5ì74 0.06 2.39 Corrosiqll. 5805 0.07 2.37 Corrosion. 5837 o.n 2.32 Corrosion. 184 5868 0.06 2.32 Isolated pitting. 185 5900 0.09 2.36 Isolated pitting. n186 5932 0.05 2.31 Corrosion. 187 5961. 0.06 2.32 Isolated pitting. 0.07 2.36 I sola ted pitting. O.Ocl 2.33 Isolated pitting. 0.06 í 2.34 Corrosion. 0,15 í I 2.35 Isolated pitting. N/A .CLM 4 (Latch @ 3:30) 0.04 2. 15 Shallow pitting. 0.04 2.37 Shallow pitting. Penetration Body Metal Loss Body Page 4 Pipe: Body Wall: Upset Wall: NominaIID.: I I I I I I I I I I I I I I I I I I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: I I PDS EPORT JOINT TABULATION S EET 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Joint t. Depth No. I 194 195 196 197 198 199 200 201 202 I I 203.1 204 205 206 207 208 209 I I II 212 213 214 15 ~2J6 217 217.1_ ---21 8.,.... 21'L 220 221 22.L. 223 """ 224_ 225 . 226 ,-.-12.Z ~228 229 229.1 I I I I I ..2.JJ),l 230.2 230.3 23 ().4 230.5 230.6 230.7 230.8 230.9 I I I I I 6192 6223 6255 6286 6319 6350 6382 6414 6445 6477 6508 6514 6547 6578 6610 6642 6674 6705 6736 6769 6799 61B2 6863 6895 ~)926 6959 6965 6997 7028 7060 7091 7123 7155 7187 7219 7249 7280 7312 7345 7354 7385 7395 739fL 7413 Z420 7423 7430 74;12 7442 Pen. Body (Ins.) ¡'vlin. I.D. (Ins.) " 0.04 0.04 0.04 0.04 0.04 0 0.04 (LQ3 0.04 2.33 0.04. 2.32 ,..0.06 2.34 0.04 ') '-}~ ......_)-) 0.03 2.33 ..DJ)5 2.33 0,04 2.33 0.07 2.34 0.07 2.32 0.04 0.04 2.37 0.04 2.31 0 N/A ... 0.03 2~31 OJ} 5 2.31 0.05 2.31 0.04 2.36 0.06 2.28 0.04 ~~.32 0.05 2.30 0.04 ') ',1':" ~ - '- - , "'-. ~)~) 0.09 2.31 0.04 0.06 0.06 2.34 0 N/A 0.05 2,.31 (J.09 239 {j 0 2.30 008 ') ') ,OJ .... ,....-) 0.06 2.33 0.03 2.37 0 ') rHo. ...._-):> () 2.25 0.04 2.36 0 2.44 Well: Field: Company: Country: Survey Date: 3Q-09 Kuparuk ConocoPhillips Alaska, Inc. USA January 26,2006 C:omrnents Shallow pitting. Isolated pitting. Shallow pitting. Isolated pitting. Isolated pitting. Shallow corrosion. Shallow pitting. Shallow pitting. Shallow pitting. Isolated pitting. 5 (Lìtch @ 8:(0) pi!ting. Shallow pitting. Shallow pitting. Shallo'v.v pitting. pitting. pitting. pitting. Lt. Deposits. ...5hallow pitting. Isolated pitting. Isolated pitting. Shallow pitting. Isolated pitting. Shallow pitting. CLM 6 (latch @ 2:30) SIHllow plttmg Lt Deposits Corrosion. Lt. Deposjts. Isolated pitting. Isolated pitting. Lt. Deposits. Isolated pittinILLt. Deposits, Shallow pittin8'-. Isolated pittilìg. Isolated pittillg. Corrosion, Lt.I)e'posits. Isolated pittinR.... Isolated pitting.. Isolated pitting. CLM 7 (Latch Cd) C):()()) Corrosion. Lt. De!2<)sits. PUP Isolated pitting.. PßR PBR Corrosion. PVP Isolated pitting. PUP Shallow pitting. ['ACKER D Nipple PUPJsolated pitting. rail Page 5 Damage Profile ("j,) wall) o ,50 100 Body Metal Loss Body .. .. .. .. .. .. Well: Field: Company: Country: Tubing: .. 3Q-09 Kuparuk ConocoPhillips Alaska, Inc. USA 2.875 ins 6.5 ppf )-55 Tool speed = 46 NominallD 2.441 NominalOD 2,875 Remaining wall area = 97 % Tool deviation = 45 0 191 .. .. .. .. .. .. depth 61 .. .. .. s s ons Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: January 26, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh ft Finger 8 Penetration 0.152 ins Isolated Pitting 0.15 ills = 70% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubing: 3Q-09 Kuparuk ConocoPhillips Alaska; Ine. USA 2.875 ins 6.5 ppf )-55 Section for 136 at Tool speed = 47 Nominal 10 = 2.441 Nominal 00 = 2,875 Remaining wall area 96 % Tool deviation = 51 0 .. .. .. .. .. .. .. .. .. s ons s rt Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: January 26; 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh 4340.713 Finger 20 Penetration = 0.144 ins Corrosion 0.14 ins = 66% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. .. .. I I SSSV I I Gas Lift :mdrellOummy Valve 1 I Gas Lift ;¡,ndrel/Dummy Valve 2 I Gas Lift mdre!/Dummy Valve 3 ( 5671-5672. 00:4750) I I Gas Lift 3ndrelfDummy Valve 4 I Gas Lift ;¡,ndre!/Dummy Valve 5 (6508-6509. 00:4.750) I Gas Lift 3ndre!!Dummy Valve 6 (6958-6959. 00:4.750) I Gas Lift ~~- I Valve (7344-7345. 00:5.460) I PBR (7385-7386. 00:2.875) I PKR (7418-7414. 00:6.151) I NIP I TUBING 10:2.441)) SOS (7448-7444. 00:2.875) Perf (7508-7530) I I Perf (7542-7570) I API: 500292167400 SSSV Type: TRDP Well Type: I PROD Orlg 1/4/1987 Completion: Last W 10 ;'- Annular Fluid: Reference Log: Last Tag: 7333 CTMD Date: 1 Ref Log Date: TO: 7990 ftKB Max 43 4300 Size 16.000 9.625 7.000 Top o o o Bottom 7443 Interval 7508 - 7530 6294 - 6312 Zone C-4,A-2 Status Ft SPF Data Type 22 6 8/25/1991 IPERF Comment 2 1/8" Ener Jet, Zero deg phasing 4" HSC Csg 120 deg 7542 - 7570 6322 - 6346 A-1 28 4 2/27/1987 IPERF Interval 7454 - 7456 Bottom 115 4282 7880 TVO Wt 6240 6.50 TVO VMfr Note on HandOver VOD St MD I V Type DMY DMY DMY DMY DMY DMY DMY Man Mfr Merla Merla Merla Merla Merla Merla Otis Man Type ,1 2746 2 4683 3 5671 4 6121 5 6508 6 6958 --r-'-'r344 1. 2544 4034 4808 5168 5479 5843 6158 2718 Xi 2 7/8 X 1 2718 Xi 27/8 Xi 27/8)( 1 2 7/8 X 1 ,27/8X1.5 Cameo 'TRDP- 1A-SSA' Cameo 'OEJ' Cameo 'HRP-1-SP' Cameo 'D' Nipple NO GO Cameo 1.0 1.0 1.0 1.0 1.0 1.0 1.5 Description KRU 3Q-09 Angle @ TS: 34 deg @ 7506 Angle @ TO: 33 deg @ 7990 RèvReason: TAG, GLVClO, FCO SCALE Last U¡:>date: 12/15/2005 TVD Wt 115 _.5;2.50 3739 36.00 6604 26.00 Grade L~80 Comment Tested to 2000 Latch Port Grade H-40 J-55 J-55 Thread BK BK BK BK BK BK RM 0.000 0.000 0.000 0.000 I 0.000 0.000 0.000 Thread 8RD AS MOD ËuE' mo Date Run 12/10/2005 12/10í2005 12/10/2005 1/20/1997 2/27/1987 1/20/1997 12/9/2005 Vlv Cmnt o o o o o o o (1 ) ID 2.310 2.297 2.347 2.250 2.441 2.441 Date Note 5/14/1995 WAIVERED WELL: IA x OA COMMUNICATOIN 7/3/1998 SLIGHT CORKSCREW TBG BELOW 6500', BUT ABLE TO DO FCO TO 7650' CTM .6/7/2000 Pumped 13 bbls of Lite crete Cement into the 9-5/8" x 1 ~Annulus. .",. 9/17/2002 A TTEMPTED TAG FILL: ONL Y TAGGED HARD SCALEWITH SUCKUNE @]362' fÒ/31 12002 FCO WìÜ-TAGGINGi=ILL; TBG CORKSCREWED TBG, COULD ONLY HARD TAG DOWN TO 6921' - I ,." "-'- - LIS TAPE VERIFICATION LISTING .VP OlO.H02 VERIFICATION ~LISTING PAGE 1 REEL HEADER ~ERVICE NAME :EDIT )ATE :87/01/ 8 ]RIGIN : ~EEL NAME :149351 ~ONTINUATION 9 >REVIOUS REEL : ~OMMENTS :LIBRARY TAPE ~ TAPE HEADER ~ ~ERVICE NAME :EDIT )ATE :87/01/ 8 ]RIGIN rAPE NAME : iONTINUATION # :Ot =REVIOUS T~PE : 'OMMENTS :LIBRARY TAPE ~ FILE HEADER =~ =ILE NAME :EDIT ~ERVlCE NAME : CERSION # : DATE : ~AXIMUM LENGTH : ~ILE TYPE : PREVIOUS FILE : .0.0! 1024 ,,-'~'.,. INFORMATION RECORDS ~-' MNEM CONTENTS UNIT TYPE CATE SIZE CODE CN : ARCO ALASKA, INC. 000 000 018 065 ~N : 3Q-9 000 000 004 065 FN : KUPARUK 000 000 008 065 RANG: 95 000 000 002 065 TOWN: 13N 000 000 004 065 SECT: 1T 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 065 CTRY: USA 000 000 003 065 ~NEM CONTENTS UNIT TYPE CATE SIZE CODE PRES .,..,,~ ::.- ;,,.. .VP OlO.HO2 VERIFICATION LISTING PAGE 2 F.' S CHLU MB E R GE R ~..o.. .... -'--'--'--,--,.-'-.'o.,.-'--'-.'--'--'--'--~-'-:?-'--'- AL A SKA COM PUT I NG CE NT .E R ]OMPANY = AR:C~ ALASKA [NC 4ELL = 3Q-9 =IELD = KUPARUK ]OUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 72157 ~UN #1, D~TE LOGGED: 03-JAN-87 ~DP: RICK KRUWEL'L ',4SING TYPE FLUID ]ENSITY ¢ISCOSITY ~H =:LUID LOSS 9.625" @-~282" - BIT SIZE : 8.5" TO 7990' LSND POLYMER 9,9 LB/G RM = 4.45 @ 68 DF 38 S RMF = 4.38 @ 68 DF 9,0 RMC := 3.59 @ 68 DF 9.2 C3 RM AT BHT ': 2.126 ~ 150 DF 4A'TRI X SANDSTONE NOTE: 'CHANNELS WITH THE EXTENSIDN DIL~ FDN ARE DATA SAMPLED AT .5' .VP 010.H02 VERIFICATION LISTING PAGE 3 CHANNELS WITH THE EXTENSION RP1 ARE DATA OF HIGH RESOLUTION DENSITY FROM B~LUELINE FILE ll SAMPLED CHANNELS WITH THE EXTENSION RP2 ARE DATA OF HIGH RESOLUTION DENSITY FROM BLUELINE FILE 13 SAMPLED .l' ,~.,.:;~- THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELO PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUAL INDUC'TION SPHERICALLY FOCUSED LOG (DIL) DATA AVAILABLE: 7970' TO 428.2' FORMATION DENSITY COMPENSATED LOG (FDN) COMPENSATED NEUTRON LOG (FDN) DATA ~VAI]LAB'LE: 7970' TO 6250' FORMATION DENSITY COMPENSATED 'LOG (RPi~) DATA AVAILABLE: 7630' TO 7472' FORMATION DENSITY COMPENSATED LOG (RP2) DATA AVAILABLE: 7644' TO 7468" .VP OlO.H02 VERIFICATION LISTING P~GE 4 -'~',~ DAT.A FORMAT. RECORD ...... -,--,- :NTRY 'BLOCKS TYPE SIZE REPR ~CODE ENTRY 2 I 66 0 4 1 66 I 8 4 73 6O 9 4 6 5 .1 t N 16 1 66 1 0 1 66 0 }ATUM SPECIFICATION BLOCKS 4NEM SERVICE SERVICE UNIT ~PI AP1 API AP1 FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO. )EPT FT O0 000 O0 0 0 4 ~FLU OIL OHMM O0 220 0I 0 0 4 [LO OIL OHMM O0 120 46 0 0 4 [LM OIL OHMM O0 120 44 0 0 4 ~P OIL MV O0 01,0 01 0 0 4 DR DIL G~PI O0 310 01 0 0 4 FENS OIL L3 O0 635 2I 0 0 4 iR FDN G~PI O0 310 01 0 0 4 ]ALI FDN iN O0 280 01 0 0 4 ~HOB FDN G/C3 O0 350 02 0 0 4 )RHO FDN G/C3 O0 356 01 0 0 4 ~R~T FON O0 420 O1 0 0 4 ~NR~ FON O0 000 O0 0 0 4 ~PHI FDN PU O0 890 O0 0 0 4 ]PHI FDN PU O0 890 O0 0 0 4 qCNL FDN CPS O0 330 31 0 0 4 :CNL FDN CPS O0 330 30 0 0 4 FENS FDN LB O0 635 21 0 0 4 PROCESS CODE (OCTAL) I 68 00000000000000 I 68 0000000000000:0 i 68 00000000000000 I 68 00000000000000 t 68 00000000000000 i 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 ]EPT 7873.5000 SFLU 2.7946 ILD SP -16.7500 GR 92.8125 TENS CALl 8.7891 RH08 2.5059 DRHO RNRA 3. 5723 NPHi 39. 1113 DPHi ~CNL 561.0000 TENS 4228.0000 DEPT 7800.0000 SFLU 2.9928 ILD SP -18.5000 GR 156.1250 TENS CALl 8.7734 RHOB 2.5352 DRHO RNRA 3.5508 NPHI 38.6230 DPHI FCNL 570.5000 TENS 5565.0000 2.1322 ILM 4228.0000 GR 0.1826 NRAT 8.7449 NCNL 2.4756 !LM 5568.0000 GR 0.2061 NRAT 6.9695 NCNL 2.3584 92.8125 3.3008 2005.0000 2.5416 156.1250 3.2715 2026.0000 .VP 010.H02 VERIFICATION LISTING PAGE )EPT 7700.0000 SFLU ;P -19.5000 GR :ALI 8.9219 RH08 ~NRA 3.3770 NPH! :CNL 637.0000 TENS )EPT 76,00.0000 SFLU ~P -23.5000 GR :ALI 9.2109 RH08 ~NRA 3.3965 NPHI =CNL 566.5000 TENS ]EPT 7500.0000 SFLU ~P -31.5156 GR :ALI 9.6016 RHOB ~NRA 3.0918 NPHI :CNL 696.5000 TENS )EPT 7400.0000 SFLU 5P -25.7500 GR :ALI 9.3672 RH05 ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 7300.0000 SFLU SP -31.0000 GR iALI -999.2500 RHD6 ~NRA -999.2500 NPHI :CNL -999.2500 TENS 3EPT 7200.0000 SFLU SP -29.2500 GR CALI -999.2500 RHOB RNRA -999.2500 NPHI ~CNL -999.2500 TENS 3EPT 7100.0000 SFLU SP -33.0313 GR 3ALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS DEPT 7000.0000 SFLU SP -37.5313 GR CALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS OEPT 6900.0000 SFLU SP -40.0313 GR CALl 9.9922 RH03 RNRA 3,2070 NPHI mCNL 565.0000 TENS 3.2694 98.3125 2.4844 36.6211 5512.0000 3.4150 92.3750 2.4727 39.2578 5244.0000 4.8347 115.1875 2.6016 30.8105 5368.0000 1.8911 107.0625 2.3164 -999.2500 5784.0000 2.7867 122.3125 -999.2500 -999.2500 -999.2500 4.4656 206.8750 -999.2500 -999.2500 -999.2500 4.0717 188.5000 -999.2500 -999.2500 -999.2500 3.7439 160,3750 -999.2500 -999.2500 -999.2500 3.8614 120.3125 2.4492 38. 5254 4652.0000 ILO T E N S ORHO DPHI ILO TENS DRHO DPHI ILD TENS DRHO DPHI ILD TENS DRHO DPHI ILD TENS DRHO OPHI ILD TENS DRHO DPHI ILD TENS DRHO DPHI ILO TENS DRHO DPHI ILD TENS DRHO DPHI 2.6974 ILM 5512.0000 GR 0.1152 NRAT 10.0469 NCNL 3.1391 ILM 5244.0000 GR 0.0703 NRAT 10.7570 N:CNL 3.9013 ILM 5368.0000 GR 0.1250 NRAT 2.9453 NCNL 1.6888 ILM 5784.0000 GR 0.0068 NRAT -999.2500 NCNL 2.4096 ILM 5284.0000 GR · -999.2500 NRAT -999.2500 NCNL 3.3154 ILM 5432.0000 GR -999.2500 NRAT -999.2500 NCNL 3.0805 ILM 4992.0000 GR -999.2500 NRAT -999.2500 NCNL 3.1785 ILM 4912.0000 GR -999.2500 NRAT -999.2500 NCNL 3.3015 ILM w652.0000 GR 0.0522 NRAT 12.1773 NCNL 2.7799 98.3125 3.1738 2152.0000 3.2300 92.3750 3.3438 1925.0000 4.1134 115.1875 2.8848 2154.0000 1.7437 107.0625 4.0508 -999.2500 2.4402 -999.2500 -999.2500 -999.2500 3.3937 -999.2500 -999.2500 -999.2500 3.1877 -999.2500 -999.2500 -999.2500 3.2506 -999.2500 -999.2500 -999.2500 3.3007 lZ0.3125 3.3672 1812.0000 .'VP OtO.M02 VERIFICATION LISTING PAGE 6 )EPT ;P ;ALI ~NRA :C NL )EPT ~ALI ~NRA :CNL )E PT ~P ~NRA :CNL )EPT ~P ;ALI ~NRA :CNL )EPT :ALI ~NRA :CNL )EDT ~P :ALI ~NRA :CNL ]EPT SP :ALI RNRA mCNL 2EPT SP CALI RNRA FCNL OEPT SP CALi RNRA FCNL 6800.0000 SF'LU -44.0313 GR 9.4375 RH08 3.2734 NPHI 676.0000 TENS 6700.0000 SFLU -29.0459 GR 8.6875 RHOB 3.2734 NPHI 626.0000 TENS 6600.0000 SFLU -31.0313 GR 8.4609 RHOB 3.5293 NPHI 543.5000 TENS 6500.0000 SFLU -48.7813 GR 9.3203 RHOB 4.0469 NPHI 493.2500 TENS 5400.0000 SFLU -54.2500 GR 9.0781 RHOB 3.9473 NPHI 487.0000 TENS 6300.0000 SFLU -36.5313 GR 8.6875 RHOB 3.3379 NPHI 630.0000 TENS 6200.0000 SFLU -38.5313 GR -999.2500 RHOB -999.2500 NPHI -999.2500 TENS 6100.0000 SFLU -45.2813 GR -999.2500 RH05 -999.2500 NPHI -999.2500 TENS 6000.0000 SFLU -41.2500 GR -999.2500 RHOB -999.2500 NPHI -999.2500 TENS 5.5843 87.0:000 .32.6172 4912.0000 1.9344 98.0625 2.3965 36.4258 4892.0000 1.9640 105. 5625 2.3555 43. 3105 6092. 0000 4.3893 137.5000 2.4512 41.9434 4700.0000 3.9624 143.2500 2.4238 43.1152 4452.0000 1.9069 91.3750 2.4102 38.6719 4664,0000 1.9699 114.0000 -999. 2500 -999.2500 -999.2500 3.0142 117.4375 -999.2500 -999.2500 -999.2500 4.0633 94.1250 -999.2500 -999.2500 -999.2500 I L D TENS DRHO DPHi ILO TENS O R HO DPHI ILD TENS ORHO DPH I ILO TENS DRHO DPHI ILO TENS DRHO OPHI ILD TENS DRHO DPHI ILD TENS DRHO DPHI ILO TENS DRHO DPHI ILO TENS DRHO DPHI 4.9737 ILM 4912.0000 GR 0.0366 NRAT 11.5855 NCNiL 2.0805 ILM 4892.0000 GR 0.:0322 NRAT 15.3730 NCNL 2.1595 ILM 6092.0000 GR 0.0615 NRAT 17.8586 NCNL 3.7647 ILM 4700,0000 GR 0,0469 NRAT 12.0590 NCNL 3.6457 ILM 4452.0000 GR 0.0449 NRAT 13.7160 NCNL 1,9848 ILM 4664,0000 GR 0,0391 NRAT 14,5445 NCNL 1.9468 ILM 4512.0000 GR -999.2500 NRAT -999.2500 NCNL 2.7577 ILM 4504,0000 GR -999,2500 NRAT -999.2500 NCNL 3.7175 ILM 4784.0000 GR -999.2500 NRAT -999.2500 NCNL 5.0795 87.0000 2-9902 2214.0000 2.1189 98.0625 3.1445 2050.0000 2.0732 105.5625 3.5039 1919.0000 3.7449 137.5000 3.4980 1997.0000 3.6348 143.2500 3.5430 1923.0000 1.9604 91.3750 3.2695 2104.0000 2.0365 -999.2500 -999.2500 -999.2500 2.7763 -999.2500 -999.2500 -999.2500 3.5839 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 7 )EPT 5900,00.00 SFLU ~P -42.2813 GR ]ALi -999.2500 RHOB ~NR~ -999.2500 NPHI :CNL -999.2500 TENS )EPT 5800.0000 SFLU ~P -42,0313 GR :ALI -999,2500 RHO~ ~NR~ -999.2500 NPHI :CNL -999,2500 TENS ]EPT 5700.0000 SFLU ~P -46.3125 GR :4LI -999.2500 RHOB ~NRA -999.2500 NPHi =CNL -999.2500 TENS ]EPT 5600.0000 SFLU ~P -45.0313 GR :ALI -999,2500 RHO5 ~NR4 -999,2500 NPHI :CNL -999.2500 TENS ]EPT 5500.0000 SFLU ~P -43.2513 GR SALI -999,2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS ]EPT 5400.0000 SFLU SP -46.0938 GR ~ALI -999.2500 RHO8 RNRA -999.2500 NPHi ~CNL ,-999..2500 TENS DEPT 5300,0000 SFLU SP -50.3125 GR CALI .-999,2500 RHOB RNR~ -999.2500 NPHI FCNL -999.2500 TENS DEPT 5200.0000 SFLU SP -49.0000 GR CALI -999.2500 RHOB RNR~ -999.2500 NPHi FCNL -999.2500 TENS DEPT 5100.0000 SFLU SP -55.6563 GR CALi -999.2500 RHOB RNRA -999.2500 NPHI ~CNL -999.2500 TENS 3.4529 93.8750 -999.2500 -999.2500 .-999.2500 2.8159 102,2500 -999.2500 -999,2500 -999.2500 3.1559 103.3750 -999,2500 -999,2500 -999.2500 2,8582 97,3125 -999.2500 -999,2500 -999,2500 3,0867 30,1250 -999,2500 -999,Z500 -999,2500 2.6964 87.3125 -999,2500 -999.2500 -999.2500 4.0466 101.2500 -999.2500 -999.2500 -999.2500 2.8308 101,1250 -999.2500 -999.2500 -999,2500 3,3491 103.3125 -999.2500 -999,2500 -999.2500 ILO TENS DRHO DPHI ILO TENS DRHO DPHI ILO TENS DRHO DPHI ILD TENS DRHO DPHI ILD TENS' DRHO DPHI ILO TENS DRHO DPHI ILD TENS DRHO DPHI ILO TENS DRHO DPHI ILO TENS DRHO DPHi 3,3730 ILM 4440,0000 GR -999.2500 NRAT -999,2500 NCNL 2.9302 ILM 4328,0000 GR -999,2500 NRAT -999,2500 NCNL 2.9096 ILM 4204,0000 GR -999,2500 NRAT -999,2500 NCNL 2.9555 ILM 4292,0000 GR -999.2500 NRAT -999,2500 NCNL~ 2,9198 ILM 4320,0000 GR -999.2500 NRAT -999,2500 NCNL 2.7331 ILM 4140.0000 GR -999,2500 NRAT -999.2500 NCNL 3.1357 ILM 4094.0000 GR -999.2500 NRAT -999.2500 NCNL 2.9216 ILM 3854.0000 GR -999.2500 NR~T -999.2500 NCNL 3,3049 ILM 3780,0000 GR -999.2500 NR~T -999.2500 NCNL 3.2987 -999.2500 -999.2500 -999.2500 2.8400 -999.2500 -999.2500 -999.2500 2.9027 -999,2500 .-999,2500 -999,2500 2,8893 -999,2500 -999,2500 -999,2500 2.8460 -999,2500 -999,2500 -999,2500 2,7028 -999.2500 -999.2500 -999,2500 3.1400 -999.2500 -999.2500 -999.2500 2.8644 -999,2500 -999,2500 -999,2500 3.2155 -999.2500 -999,2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING P4GE B )EPT 5000.0000 SFLU ~P -53.8125 GR :4LI -999.2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT ~900.0000 SFLU ~P -47.5313 GR ~ALI -999.2500 RHOB ~NRA -999.2500 NPHI =CNL -999.2500 TENS )EPT 4800.0000 SFLU ~P -54.5313 GR ~ALI -999.2500 RHOB ~NRA -999.2500 NPHI =CNL -999.2500 TENS )EPT ~700.0000 SFLU ~P -57.5625 GR ~4LI -999.2500 RHOB ~NR4 -999.2500 NPHI =CNL -999.2500 TENS )EPT .4600.0000 SFLU ~P -53.3438 GR ~ALI -999.2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS ]EPT 4500.0000 SFLU SP -58.6250 GR 'ALI -999.2500 RHDB RNRA -999.2500 NPHI ~CNL -999.2500 TENS DEPT ~00.0000 SFLU SP -60.5938 GR C~LI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS DEPT ~300.0000 SFLU SP -57.5625 GR C6LI -999.2500 RHO~ RNRA -999.2500 NPHI FCNL -999.2500 TENS DEPT 4244.0000 SFLU SP -43.6875 GR C~LI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS 0.9578 89.7500 -999.2500 -999.2500 -999.2500 3.0626 86,2500 -999.2500 -999.2500 -999.2500 3.0611 88.06.25 -999.2500 -999.2500 -999.2500 3.1029 90,3750 -999,2500 -999.2500 -999.2500 3.3097 92.5000 -99'9. 2500 -999.2500 -999.2500 2.0541 99.7500 -999.2500 -999.2500 -999.2500 2.5575 97.8750 -999.2500 -999.2500 -999.2500 2.6504 92.5625 -999.2500 -999.2500 -999.2500 85.7647 56.4688 -9'99.2500 -999.2500 -999.2500 ILO TENS DRHO DPHI ILD TENS DRHO DPHI ILO TENS DRHO DPHI ILD TENS DRHO DPHI ILO TENS DRHO OPHI ILD TENS DRHO DPHI ILD TENS DRHO OPHI ILO TENS DRHO DPHI ILD TENS DRHO DPHI 0,8914 ILM 3690.0000 GR -999.2500 NRAT -999,2500 NCNL 3.2175 ILM 360~.0000 GR -999.2500 NR4T -999.2500 NCNL 3,0990 ILM 3594.0000 GR -999.25.00 NRAT ,-999,2500 NCNL 3.2509 ILM 3464.10000 GR -999.2500 NRA'T -999.2500 NCNL 3.6041 ILM 3390.0000 GR -999.2500 NRAT -999.2500 NCNL 1.8561 ILM 3324.0000 GR -999.2500 NRAT -999.2500 NCNL 2.3546 iLM 3214.0000 GR -999.2500 NRAT -999.2500 NCNL 3.2132 ILM 3240.0000 GR -999.2500 NRAT -999.2500 NCNL 125.0025 iLM 3204.0000 GR -999.2500 NRAT -999.2500 NCNL 0.8926 -999.2500 -999.2500 -999.2500 3.1290 -ggg.2500 -g99.2500 -999.2500 2.9939 -999.2500 -999.2500 -999.2500 3,1180 -999.2500 -999.2500 -999,2500 3.4240 -999,2500 -999.2500 -999,2500 1.7399 -999.~500 -999.2500 -999.2500 2.4509 -999.2500 -999.2500 -999.2500 3.0408 -999.2500 -999.2500 -999.2500 2000.0000 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE :* FILE TRAILER ** :ILE NAME :EDIT .001 ;ERVICE NAME : IERSION ~ : )ATE : !AXIMUM LENGTH : 1024 :ILE TYPE : ~EXT-FILE NAME : -~ FILE HEADER ~ :iLE NAME :EDIT .002 ;ERVICE NAME : fERSION ~ : )ATE : ~AXIMUM LENGTH : 1024 :ILE TYPE : >REVIOUS FILE : ~ DATA FORMAT RECORD ~ ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~ 1 66 t g 4 65 .liN 16 I 66 1 0 1 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