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STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1Y-18 JBR 11/21/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 F/P on HCR kill vale and CV #5. Test Results TEST DATA Rig Rep:MoralesOperator:ConocoPhillips Alaska, Inc.Operator Rep:Kiser Rig Owner/Rig No.:Nabors 7ES PTD#:1931060 DATE:9/18/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopRCN230920170849 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 2827 Sundry No: 323-284 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8" x 5"P #2 Rams 1 blinds P #3 Rams 1 2 7/8" x 5"P #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"FP Check Valve 0 none NA BOP Misc 2 2 1/16"P System Pressure P3050 Pressure After Closure P1575 200 PSI Attained P19 Full Pressure Attained P109 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5 @ 2130 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P29 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 99 9 9 9999 9 9FP FP F/P on HCR kill vale and CV #5. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Pull/Replace Sel Comp Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9187'feet None feet true vertical 6523' feet None feet Effective Depth measured 8934'feet 8449', 8856'feet true vertical 6325' feet 5953', 6265'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 8895' 6294' Packers and SSSV (type, measured and true vertical depth)8449' 8856' N/A 5953' 6265' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 6140' 4420' Burst Collapse Production Casing 9171' 6510' 6098' 121'Conductor Surface 16" 9-5/8" 79' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-106 50-029-22390-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025641, ADL0025646 Kuparuk River Field/ Kuparuk Oil Pool KRU 1Y-18 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 83 Gas-Mcf MD 1404 Size 121' 191 110980 0 4930 159 323-284 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Baker FH Retrievable Baker FH Retrievable SSSV: N/A Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Staff RWO/CTD Engineer 8586-8678', 8718-8733', 8904-8924', 8931-8968' 6059-6129', 6160-6171', 6302-6317', 6323-6351' 9132' 7" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Page 1/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/24/2023 21:00 8/25/2023 00:00 3.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Rig sub on 3G pad at 21:00. Continue to hall rig mats from behind rig to infront. Moving rig pits to 2M-16. 8/25/2023 00:00 8/25/2023 03:00 3.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Moved service module to 2M-16, on 2M at 3:00. ND BOP and removing from rig sub cellar. 8/25/2023 03:00 8/26/2023 00:00 21. 00 0.0 0.0 MIRU, MOVE MIRU MOB P Shuffling rig mats from behind rig sub and laying them down in front of rig. 8/26/2023 00:00 8/26/2023 07:00 7.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Shuffling rig mats from behind rig to in front of the rig at 3G pad. 8/26/2023 07:00 8/26/2023 07:30 0.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P Cruz SOW's on location with drivers and truck pusher. Rig move meeting with crews 8/26/2023 07:30 8/26/2023 09:30 2.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Begin moving again towards 3F-pad, pulling with weighted SOW's x 2 8/26/2023 09:30 8/26/2023 12:30 3.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Rig became stuck on 4" mats, 1.3 miles from 3F-pad. Stop and unhook SOW's pull and stage on 3F-pad, while KDTH loaders move to double up mats in front of rig. Rig crew throwing plywood to make RIG level again. 8/26/2023 12:30 8/26/2023 13:00 0.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P Hook up SOW's and pull rig out of hole, and stage rig on platform, unhook SOW's and stage again on 3F-pad, 8/26/2023 13:00 8/27/2023 00:00 11. 00 0.0 0.0 MIRU, MOVE MIRU MOB P Continue double stacking mats in front of rig and triple stacking behind rig. 8/27/2023 00:00 8/27/2023 08:00 8.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Continue rig mat shuffle to3F pad. 8/27/2023 08:00 8/27/2023 08:30 0.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P Move meeting with crews and moving contractor CRUZ. 8/27/2023 08:30 8/27/2023 09:30 1.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Move rig to end of mats. Allow Wells Dispatch to get someone around rig for E-line Unit. *** Note: Notified Security to step up patrol on 2M-pad. Placed 5 mph signs on pad. Security officier stopped by, discused spending an hour a day on 2M-pad to deter people from speeding across the pad. 8/27/2023 09:30 8/27/2023 20:00 10. 50 0.0 0.0 MIRU, MOVE MIRU MOB P Continue to shuffle mats. Pull rig sub off road onto 3F pad at 20:00. 8/27/2023 20:00 8/28/2023 00:00 4.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Moving all the rig mats from behind the rig to in front of the rig toward 3B pad. 8/28/2023 00:00 8/28/2023 06:00 6.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Moving all the rig mats from behind the rig to in front of the rig toward 3B pad. 4/10 th of a mile matted towards 3B-pad 8/28/2023 06:00 8/29/2023 00:00 18. 00 0.0 0.0 MIRU, MOVE MIRU MOB P Continue shuffle mats from behind rig (between 3G and 3F) to in front (between 3F and 3B) with rig pareked on 3F pad. 8/29/2023 00:00 8/29/2023 09:45 9.7 5 0.0 0.0 MIRU, MOVE MIRU MOB P Rig sub parked on 3F pad. Four loaders laying down mats from 3F pad to 3B pad. Still have 180 mats on 3B pad and 1 mile left to mat to get to 3B pad. When all the mats are laid down we will have to start the rig mat shuffle again. Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 2/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/29/2023 09:45 8/30/2023 00:00 14. 25 0.0 0.0 MIRU, MOVE MIRU MOB P Rig stopped 0.6 miles from 3B pad to start the rig matt shuffle. Pulling all the way forward on single matts. Loaders behind us doubleing up the matts behind us. Then we back up on the double rig matts. Park then loaders in front of the rig remove the top layer of matts and place them on the road in front of the rig. We performed this rig mat shuffle all night and are almost to 3B pad. Tour pusher expects to be at 3B pad around noon. 8/30/2023 00:00 8/31/2023 00:00 24. 00 0.0 0.0 MIRU, MOVE MIRU MOB P We are performing the rig mat shuffle and are almost to 3B pad. Start moving rig to 3B, Front tires sink through road, tried to back up rear tires sink, crib up and get rear tires on good matting boards and work on front tires getting them back on solid ground. 8/31/2023 00:00 8/31/2023 08:30 8.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P Continue to mat road to 3B and move rig to stage for matting boards. Rig staged on 3B at 8:30. Change of plan to stop at 1Y- 18 and perform a workover on it then in a couple weeks continue with rig move to 2M-16. 8/31/2023 08:30 9/1/2023 00:00 15. 50 0.0 0.0 MIRU, MOVE MIRU MOB P Moving rig mats from between 3F and 3B to in front of the rig between 3B and the Y just before CPF3. Moved the rig from 3B to the Y just before CPF3. Rig sub at the Y at 00:00. 9/1/2023 00:00 9/1/2023 04:00 4.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P The rig sub is at the Y at 00:00. Moving rig mats from behind to infront of the rig. 9/1/2023 04:00 9/1/2023 16:00 12. 00 0.0 0.0 MIRU, MOVE MIRU MOB P Moved the rig from CPF3 to 1Q pad. Rig on 1Q pad at 16:00. 9/1/2023 16:00 9/2/2023 00:00 8.0 0 0.0 MIRU, MOVE MIRU MOB P Moved the rig from 1Q pad to 1A pad. Rig on 1A pad at 00:00. 9/2/2023 00:00 9/2/2023 12:00 12. 00 MIRU, MOVE MIRU MOB P Moving rig pits from 2M pad to 1Y pad. Retrieving BOP from 3G pad to place in the rig cellar. 9/2/2023 12:00 9/3/2023 00:00 12. 00 MIRU, MOVE MIRU MOB P Assemble stack in cellar and mob shop and office to pad, Shop and office on pad 13:00, set shop and office, complete ram swap to 2-7/8" X 5" VBRs, prep for spotting rig over 3S-18 9/3/2023 00:00 9/3/2023 04:00 4.0 0 0.0 0.0 MIRU, MOVE MIRU MOB P Move the rig sub from the pad entrance to over the 1Y-18 well. Linning up the pits and pushing them up next to the rig sub. 9/3/2023 04:00 9/3/2023 05:30 1.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P Going through check list to raise the derrick. PJSM to raise the derrick. 9/3/2023 05:30 9/3/2023 11:30 6.0 0 0.0 0.0 MIRU, MOVE MIRU RURD P Raise derrick, install cattle chute, hang bridal lines in derrick, misc rig up of rig floor, perform rig up checklist for acceptance of rig, hook up and air test tiger tank line to 3500 psi, Grease crew grease choke house and squeeze manifold, prep pits for fluids, set mud shack and smoke shack, run power from rig to shop and pusher shack, pressure test tiger tank lines. Take on fluids and accept the rig at 12:00. 9/3/2023 11:30 9/3/2023 12:00 0.5 0 0.0 0.0 MIRU, MOVE MIRU SVRG P Service Topdrive prior to picking it up 9/3/2023 12:00 9/3/2023 19:00 7.0 0 0.0 0.0 MIRU, WELCTL MIRU DISP P Displace well to 10.8# NaCl / NaBr. Pumped 415bbls. Rig on highline power at 14:30. Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 3/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/3/2023 19:00 9/4/2023 00:00 5.0 0 0.0 0.0 MIRU, WELCTL MIRU DISP P Adam Earl (AOGCC Inspector) waived witness to the BOPE test at 6:44 PM. Pump 135 bbls 10.8 ppg down tubing and up IA with no returns. Call town engineer and deside to cut MW back to 10.6 ppg. Pumped 100 bbls down IA then shut the well in for flow test. 9/4/2023 00:00 9/4/2023 03:00 3.0 0 0.0 0.0 MIRU, WELCTL MIRU DISP P Secure well pump 10.6# NaCl / NaBr down tubing 165 bbls 9/4/2023 03:00 9/4/2023 04:00 1.0 0 0.0 0.0 MIRU, WHDBOP MIRU OWFF P Flow check well no flow 9/4/2023 04:00 9/4/2023 06:30 2.5 0 0.0 0.0 MIRU, WHDBOP MIRU NUND P Install BPV, attempt test, pump 6 bbls per min unable to build pressure above 300 psi for 5 min well taking fluid , FMC bleed voids, nipple down tree 9/4/2023 06:30 9/4/2023 12:00 5.5 0 0.0 0.0 MIRU, WHDBOP MIRU NUND P Nipple up BOPs, get RKBs, prep test equipment for BOP test, make up 2-7/8" and 4" test joint, make up XO to TIW, install kill line 9/4/2023 12:00 9/4/2023 12:30 0.5 0 0.0 0.0 MIRU, WHDBOP MIRU CIRC P Circulate 10 bbls 10.6 into IA ensure well stays dead 9/4/2023 12:30 9/4/2023 13:30 1.0 0 0.0 0.0 MIRU, WHDBOP MIRU SVRG P Service test equipment 9/4/2023 13:30 9/4/2023 21:30 8.0 0 0.0 0.0 COMPZN, RPCOMP MIRU BOPE P BOPE test All test to 250/3000 PSI F/5 min each, Test annular with 2-7/8" and 4" test joint, Test UVBR/LVBR w/2-7/8" and 4" test joints, Test blinds rams, Choke valves #1 to #16, upper/lower IBOP valves. Test 3 1/2" HT-38 FOSV/Dart Valve, Test 3 ½ EUE FOSV, , Test 2" rig floor Demco kill valves, Test manual and HCR kill and choke valves.Test two ea 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1500 PSI, 200 PSI attained = 21 sec, full recovery attained = 105 sec. UVBR = 5 sec, LVBR = 5 sec, Annular = 25 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 2000 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Adam Earl witness waived Tested gas detectors 1 F/P, cellar high combustible alarm. 9/4/2023 21:30 9/4/2023 23:00 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU MPSP P Started to pull BPV and had a little bubbling so we pumped a tubing volume of 10.6 ppg NaCl/NaBr down tubing with no returns up IA. With the tubing on a vacuum, pulled the BPV. 9/4/2023 23:00 9/5/2023 00:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU DISP P Called town engineer and reduced the brine weight to 10.4 ppg. 9/5/2023 00:00 9/5/2023 03:30 3.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CIRC P Circulated the well to 10.4 ppg NaCl/NaBr. Pumped 320 bbls with only 10% returns. OWFF and still on a vacuum. 9/5/2023 03:30 9/5/2023 05:00 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU DISP P Mix up a 40 bbl vis pill. Reduce brine weight from 10.4 ppg down to 10.2 ppg. Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 4/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/5/2023 05:00 9/5/2023 06:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU DISP P Pump 40 bbl vis pill followed by 10.2 ppg brine. 9/5/2023 06:30 9/5/2023 07:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU OWFF P Check for flow at choke house, observed flow, shut well at well head observed 45 psi of well head pressure 9/5/2023 07:00 9/5/2023 08:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU CIRC P Complete set up of pits, circulate well to even out mud // Pump 30 bbls no returns // Open IA well on vac 9/5/2023 08:00 9/5/2023 09:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU OWFF P OWFF // Initially well on vac for 30 min tubing on vac // IA started giving air back continue to monitor IA and tubing for 30 min 9/5/2023 09:30 9/5/2023 10:30 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU WAIT P Wait for all fluid in pit to be brought to 10.2 ppg 9/5/2023 10:30 9/5/2023 11:15 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Pick up spear for pulling hanger // Well start flowing when about to stab into hanger// shut blinds and monitor pressures 9/5/2023 11:15 9/5/2023 12:30 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU SIPB T Shut in well to monitor pressures // (15 min = 50 psi) (30 min = 75 psi) (45 min = 90 psi) ( 1hr = 102 ) // Tubing continues to build pressure while IA stays at 18 psi 9/5/2023 12:30 9/5/2023 14:45 2.2 5 0.0 0.0 COMPZN, RPCOMP MIRU WAIT T Wait for mud truck // Build 520 bbls 10.3+ mud in pits // Bleed free gas off tubing // Bleed tubing from 260 psi down to 165 psi // 9/5/2023 14:45 9/5/2023 15:15 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU DISP T Displace tubing ( 100 bbls ) with 10.3+ brine // Bullhead down tubing 3 bbls/ min @ 325 psi // IA pressure while pumping 28 psi while pumping 9/5/2023 15:15 9/5/2023 15:45 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU OWFF T Shut down pump observe tubing for pressure build // Tubing pressure stable @ 18 psi // IA stable @ 23 psi 9/5/2023 15:45 9/5/2023 18:30 2.7 5 0.0 0.0 COMPZN, RPCOMP MIRU DISP T Displace IA bullhead 220 bbls 10.3+ brine @ 5 bbls/ min @ 370 psi // 100 bbls pumped pump pressure 450 psi // 200 bbls pumped pump pressure 490 psi 9/5/2023 18:30 9/5/2023 20:45 2.2 5 0.0 0.0 COMPZN, RPCOMP MIRU DISP T Make sure brine WT is 10.3 heavy Line up to pump down TBG, take returns out IA Start pumping at 2 BPM 125 PSI Take 50 BBLS to get returns Cont pumping at 2 BPM establise loss rate = 84 BPH - 70% while pumping at 2 BPM Pump a total of 326 BBLS total after catching fluid, no gas or oil to surface 9/5/2023 20:45 9/5/2023 21:30 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU OWFF T Shut down pumps, observe for pressure, no pressure Open blind rams Cont flow check fluid level dropping Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 5/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/5/2023 21:30 9/6/2023 00:00 2.5 0 0.0 0.0 COMPZN, RPCOMP MIRU OWFF T Continue to watch fluid level Fill hole every 30 min to establish a loss rate for filling while tripping out of hole on a fill schedule to see if vac trucks can round trip from Deadhorse Fill TBG at 22:00 HRS take 8 BBLS - 22:30 HRS take 8 BBLS - 22:45 HRS take 8 BBLS No fluid at the IA Rig up to pump down IA to see what it takes to fill IA 23:10 HRS pump down IA - take 4 BBLS to see fluid come up TBG - take 20 BBLS total to fill hole Total 24 HR lost to hole = 1,329 BBLS Total lost to hole = 2,083 BBLS 9/6/2023 00:00 9/6/2023 01:15 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU OWFF T Continue to watch fluid level Fill hole every 30 min to establish a loss rate for filling while tripping out of hole Pump down the IA 00:15 HRS pump DN IA - take 15 BBLS to fill hole 00:45 HRS pump DN IA - take 12 BBLS to fill hole - look like well was sucking fluid from pits thru mud pump - shut in pump stop loosing fluid from pits At 01:15 go to fill hole notice oil on top of fluid, gas breaking out, fluid level start coming up 9/6/2023 01:15 9/6/2023 03:15 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU SIPB T Shut in blind rams - monitor pressures while bring on fluid to pits and getting more coming to location Tubing start at 25 PSI build to 45 PSI in 30 min, 70 PSI in 45 min, 85 PSI in 1 HR, 95 PSI in 1.25 HRS, 99 PSI in 1.5 HRS, 107 PSI in 1.75 HRS, 120 PSI in 2 HRS IA on a vac close IA at 01:45 HRS - stay on a vac 9/6/2023 03:15 9/6/2023 06:00 2.7 5 0.0 0.0 COMPZN, RPCOMP MIRU CIRC T Circulate down tubing out IA at 1 BPM 160 PSI, 2 BPM 200 PSI Pump 15 BBLS get very little returns at MGS , at 50 BBLS pumped returns get better - loss rate at 65 - 70% while pumping 2 BPM Pump a total of 320 BBLS 9/6/2023 06:00 9/6/2023 08:00 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU OWFF T OWFF Fill hole every 10 min establish loss rate 00:10 HRS pump DN IA Take 10 BBLS to fill hole 00:25 Hrs Pump DN IA Take 15 bbls to fill hole 00:40 Hrs PUmp DN IA Take 15 bbls to fill hole 00:55 Hrs Pump DN IA Take 15 BBLS to fill hole Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 6/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/6/2023 08:00 9/6/2023 09:00 1.0 0 0.0 8,441.0 COMPZN, RPCOMP MIRU THGR P Make up spear attempt to spear hanger, unable to get spear into hanger change spear to 3.4", spear hanger and un-seat Grapple info 3.4" Grapple 3.412" Nominal Catch 3.365" min catch 3.46" Max catch Baker Q3 Qual LVL Right hand release Pull hanger off seat, 125K up wt, pipe free 9/6/2023 09:00 9/6/2023 09:30 0.5 0 8,441.0 8,435.0 COMPZN, RPCOMP MIRU OWFF P OWFF, Fill hole monitor for 15 min for static loss rate of 27 bbls 9/6/2023 09:30 9/6/2023 10:30 1.0 0 8,435.0 8,440.0 COMPZN, RPCOMP MIRU THGR P Remove hanger from top of joint, tubing gurgling out oil, stab into pipe with spear and lower into stack 9/6/2023 10:30 9/6/2023 12:00 1.5 0 8,440.0 8,440.0 COMPZN, RPCOMP MIRU CIRC T Circulate down tubing ( no pack off on spear ) take returns to pits with 50% losses, formulate plan forward, flow check to move forward found well to be flowing, 9/6/2023 12:00 9/6/2023 14:00 2.0 0 8,440.0 8,440.0 COMPZN, RPCOMP MIRU KLWL T Close annular pump, bullhead 300 bbls down tubing and IA 10.3+ @ 4.5 bbls/min @ 300 psi // Flow check well no flow 9/6/2023 14:00 9/6/2023 17:30 3.5 0 8,440.0 7,491.0 COMPZN, RPCOMP MIRU PULL P Pull first joint with spear and lay down, pull tubing // Found controll line ~ 20' wadded up on pipe on jt 11 // Continue to pull tubing controll line still secure 9/6/2023 17:30 9/6/2023 18:00 0.5 0 7,491.0 7,491.0 COMPZN, RPCOMP MIRU OWFF P Notice gas and crude inside tubing and coming up Stab floor valve, pick up out of slips, flow check back side fluid level down past wellhead, set slips look down tubing fluid level ~35' down Make up top drive 9/6/2023 18:00 9/6/2023 20:15 2.2 5 7,491.0 7,491.0 COMPZN, RPCOMP MIRU CIRC P Circulate 10.4 PPG fluid 2 BPM 85 PSI 4 BPM 250 PSI Get crude and gas cut back at 28 BBLS pumped, dump 169 BBLS to cuttings tank Loss rate = 40% while pumping 9/6/2023 20:15 9/6/2023 20:45 0.5 0 7,491.0 7,491.0 COMPZN, RPCOMP MIRU OWFF P Flow check, fluid level dropping 9/6/2023 20:45 9/6/2023 22:15 1.5 0 7,491.0 6,627.0 COMPZN, RPCOMP MIRU PULL P POOH laying down 4" tubing F/7,491' T/6,627' 75K UP 60K DN Got 24 SS bands out of 32 total 9/6/2023 22:15 9/6/2023 22:45 0.5 0 6,627.0 6,627.0 COMPZN, RPCOMP MIRU OWFF P Flow check, fluid level dropping 9/6/2023 22:45 9/7/2023 00:00 1.2 5 6,627.0 6,627.0 COMPZN, RPCOMP MIRU CIRC P Circulate condtion fluid for setting storm packer at 3 BPM 150 PSI Circulate S/S still have gas breaking out at surface Loss rate 47%, ~85 BPH pumping 3 BPM Clean clear rig floor of spooling unit equipment Load storm packer and G lock in shed 9/7/2023 00:00 9/7/2023 01:30 1.5 0 6,627.0 6,627.0 COMPZN, RPCOMP MIRU CIRC P Circulate condtion fluid for setting storm packer at 3 BPM 150 PSI Loss rate = 33%, circulate 1.5 times surface to surface still have gas breaking out at surface, cont pumping Load storm packer and G lock in shed Pump a total of 556 BBLS Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 7/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/7/2023 01:30 9/7/2023 02:00 0.5 0 6,627.0 6,627.0 COMPZN, RPCOMP MIRU CIRC P Flow check fluid falling Spot 37 BBLS hi vis pill at end of tubing 9/7/2023 02:00 9/7/2023 02:30 0.5 0 6,627.0 6,627.0 COMPZN, RPCOMP MIRU OWFF P Flow check 9/7/2023 02:30 9/7/2023 04:00 1.5 0 6,627.0 6,811.0 COMPZN, WHDBOP MIRU MPSP P Lay down X/overs and FOSV, pick up and make up storm packer RIH on 3 1/2" DP T/6,811' Set storm packer COE @ 177.19' 80K UP 65K DN POOH with 2 stands of DP 9/7/2023 04:00 9/7/2023 04:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P R/U test storm packer to 1000 PSI F/5 min 9/7/2023 04:30 9/7/2023 05:30 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Drain stack, set test plug R/U BOP test equipment Fill stack with water, work air out of system perform shell test 9/7/2023 05:30 9/7/2023 10:00 4.5 0 0.0 0.0 COMPZN, WHDBOP MIRU BOPE P Test blind rams and annular with 2 7/8" test joint to 250/3000 PSI F/5min each // Blow down test equipment // pull test plug when pulling test plug found well to be bubbling 9/7/2023 10:00 9/7/2023 14:00 4.0 0 0.0 0.0 COMPZN, WHDBOP MIRU PRTS P Pressure test storm packer 1000 psi 30 min twice, Second pressure test appeared to show good test with fluid, still getting gas bubbles at surface, when tested with gas detector showed 21% LEL 9/7/2023 14:00 9/7/2023 15:30 1.5 0 0.0 144.0 COMPZN, WHDBOP MIRU MPSP P Set G-plug COE 143.60' 9/7/2023 15:30 9/7/2023 16:30 1.0 0 144.0 144.0 COMPZN, WHDBOP MIRU PRTS P While rigging up to test G-lock found well to be bubbling 9/7/2023 16:30 9/7/2023 17:45 1.2 5 144.0 111.0 COMPZN, WHDBOP MIRU MPSP P Re-set G-lock higher up at 111' COE 9/7/2023 17:45 9/7/2023 19:00 1.2 5 111.0 111.0 COMPZN, WHDBOP MIRU OWFF P Flow check - observe bubbles in well, trouble shoot and double check all lines and valves Discuss options for plan forward 9/7/2023 19:00 9/7/2023 19:30 0.5 0 111.0 81.0 COMPZN, WHDBOP MIRU MPSP P Release G lock, OWFF, increase in bubbles when latched onto the G plug and open unloader seal Pull up ~30' reset Glock COE @ 81' 9/7/2023 19:30 9/7/2023 20:15 0.7 5 81.0 81.0 COMPZN, WHDBOP MIRU OWFF P Flow check - observe bubbles in well Put 1500 PSI on plug to watch OA, OA PSI = 4 PSI, no increase in OA pressure Bleed off, flow check 9/7/2023 20:15 9/7/2023 20:45 0.5 0 81.0 0.0 COMPZN, WHDBOP MIRU MPSP P Pull plug to surface to inspect elements, look good 9/7/2023 20:45 9/7/2023 21:45 1.0 0 0.0 46.0 COMPZN, WHDBOP MIRU MPSP P RIH set Glock at 46' COE Flow check still bubbles at surface Release plug see increase in gas break out at surface 9/7/2023 21:45 9/7/2023 23:00 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Clear rig floor of BHA tools, mobilize BHA components to rig floor for clean out run to above storm packer 9/7/2023 23:00 9/8/2023 00:00 1.0 0 0.0 165.0 COMPZN, RPCOMP MIRU MPSP P Make up clean out BHA RIH to 165', circ clean off top of twin thread equalizing valve 5 BPM 460 PSI dump 15 BBLS to cuttings box POOH L/D BHA Recover one SS band Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 8/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/8/2023 00:00 9/8/2023 00:45 0.7 5 165.0 0.0 COMPZN, RPCOMP MIRU MPSP P Circ 5 BPM 460 PSI, pump Hi Vis pill POOH L/D BHA Recover 1 SS band 9/8/2023 00:45 9/8/2023 02:30 1.7 5 0.0 165.0 COMPZN, RPCOMP MIRU MPSP P Pick up storm packer retrieving head RIH T/165' Make up to twin thread and open equalizing valve Check for pressure on drill pipe side 95 PSI Close annular, open up to choke, pick up to 100 - 110K unseat packer check for pressure on annulus side 680 PSI 9/8/2023 02:30 9/8/2023 03:30 1.0 0 6,811.0 6,811.0 COMPZN, RPCOMP MIRU SFTY P PJSM - line up IA to tiger tank to bleed off gas cap Crew change out, hold another PJSM and walk lines 9/8/2023 03:30 9/8/2023 05:00 1.5 0 6,811.0 6,811.0 COMPZN, RPCOMP MIRU CIRC P Bring on mud pumps, 700 PSI on casing and 105 PSI on drill pipe, stage pumps up to 3 BPM holding 120 PSI on drill pipe At 70 STKS pumped get straight gas back at choke Pump a total of 235 BBLS - never get brine back to surface - loss rate at 70% 9/8/2023 05:00 9/8/2023 05:45 0.7 5 6,811.0 6,811.0 COMPZN, RPCOMP MIRU CIRC P Monitor pressures 40 PSI on drill pipe and 40 PSI on casing Line up to bull head down with 10.4 PPG 9/8/2023 05:45 9/8/2023 07:15 1.5 0 6,811.0 6,811.0 COMPZN, RPCOMP MIRU DISP P Bullhead 220 bbls down IA @ 5 bbls/min @ 400psi 9/8/2023 07:15 9/8/2023 07:45 0.5 0 6,760.0 6,760.0 COMPZN, RPCOMP MIRU OTHR P Blow down rig lines 9/8/2023 07:45 9/8/2023 08:45 1.0 0 6,811.0 6,760.0 COMPZN, RPCOMP MIRU MPSP P Release storm packer while pumping snot pill, lay down packer and prep to send to baker for rebuild 9/8/2023 08:45 9/8/2023 13:15 4.5 0 6,760.0 2,800.0 COMPZN, RPCOMP MIRU PULL P Pull completion and lay down // 60 bbls/hr losses reported by mud engineer // When at end of 4" pump hi-vis pill in hopes of plugging losses while laying down GBR 9/8/2023 13:15 9/8/2023 14:45 1.5 0 2,800.0 2,800.0 COMPZN, RPCOMP MIRU CIRC P Circulate while rigging down GBR and releasing // Spot 45 bbl high vis pill for losses 9/8/2023 14:45 9/8/2023 17:45 3.0 0 2,800.0 0.0 COMPZN, RPCOMP MIRU PULL P Cont pulling 3 1/2" TBG F/2800' to surface Cut joint = 14.89' 9/8/2023 17:45 9/8/2023 19:00 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Rig down TBG tongs and equipment, change elevtors to 3 1/2" DP Clean and clear floor, load Glock set plug in pipe shed 9/8/2023 19:00 9/8/2023 19:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Make up BHA # 6 Glock set plug Get plug to well head and would not go in to 7" casing 9/8/2023 19:30 9/8/2023 22:45 3.2 5 0.0 0.0 COMPZN, RPCOMP MIRU WAIT T Wait on plug from Baker shop Plug on location at 22:30 HRS 9/8/2023 22:45 9/9/2023 00:00 1.2 5 0.0 1,215.0 COMPZN, RPCOMP MIRU PULD P Make up BHA # 6 Glock set plug RIH picking up singles from pipe shed T/1,215' 42K UP/DN 9/9/2023 00:00 9/9/2023 06:00 6.0 0 1,215.0 8,304.0 COMPZN, RPCOMP MIRU PULD P RIH with 3 1/2" DP F/pipe shed W/Glock plug F/1,215' T/8304' 145K UP 90K DN 9/9/2023 06:00 9/9/2023 06:30 0.5 0 8,304.0 8,304.0 COMPZN, RPCOMP MIRU MPSP P Set Glock plug COE = 8298' Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 9/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/9/2023 06:30 9/9/2023 08:00 1.5 0 8,304.0 8,304.0 COMPZN, RPCOMP MIRU CIRC P Circulate for testing packer, get oil/gas out of well 5 BPM 980 PSI Dump 60 BBLS to cuttings box 9/9/2023 08:00 9/9/2023 09:00 1.0 0 8,304.0 8,304.0 COMPZN, RPCOMP MIRU MPSP P R/U test Glock packer to 1000 PSI F/15 min 9/9/2023 09:00 9/9/2023 09:15 0.2 5 8,304.0 8,304.0 COMPZN, RPCOMP MIRU OWFF P Flow check , no flow 9/9/2023 09:15 9/9/2023 10:15 1.0 0 8,304.0 8,304.0 COMPZN, RPCOMP MIRU CIRC P Circulate while waiting for mud 9/9/2023 10:15 9/9/2023 12:00 1.7 5 8,304.0 8,304.0 COMPZN, RPCOMP MIRU DISP P Displace well with mud 10.4 PPG LSND 9/9/2023 12:00 9/9/2023 13:00 1.0 0 8,304.0 8,304.0 COMPZN, RPCOMP MIRU PRTS P Pressure test g-lock 1000 psi 45 min good test // consult town decision made to continue with de-complete 9/9/2023 13:00 9/9/2023 14:30 1.5 0 8,304.0 8,304.0 COMPZN, RPCOMP MIRU MPSP P Release g-lock with mud in hole, no flow when packer released, pump 10 bbls down drill pipe, pump 10 bbls down annulus // Flow check no flow no losses 9/9/2023 14:30 9/9/2023 16:00 1.5 0 8,304.0 7,730.0 COMPZN, RPCOMP MIRU TRIP P Trip out of hole with g-plug // observed swabbing decision made to pump out of hole 9/9/2023 16:00 9/9/2023 17:00 1.0 0 7,730.0 7,730.0 COMPZN, RPCOMP MIRU SVRG P Service rig, align TD to stump as to not damage quill or pipe when making up stands 9/9/2023 17:00 9/9/2023 18:30 1.5 0 7,730.0 7,730.0 COMPZN, RPCOMP MIRU CIRC P Flow check, slight ooze Circulate at 1 BPM 230 PSI, get slight returns with bubbles breaking out at surface but still losing mud down hole loss rate ~60 BPH at 1 BPM Crew change, PJSM pumping out of hole 9/9/2023 18:30 9/9/2023 21:30 3.0 0 7,730.0 5,845.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole at 1 BPM 230 PSI - pumping 4 BBLS per stand F/7730' T/5,845' 9/9/2023 21:30 9/9/2023 21:45 0.2 5 5,845.0 5,845.0 COMPZN, RPCOMP MIRU OWFF P Flow check due to hole fill changing 5 stands out 10.6 BBLS 10 stands out - 6.7 BBLS 15 stands out - 6.8 BBLS 20 stands out - 4.5 BBLS Notice gas breaking out at surface - montior pit gain Gain 3.2 BBLS in 5 min, gain 3.3 BBLS next 5 min 9/9/2023 21:45 9/9/2023 22:45 1.0 0 5,845.0 5,845.0 COMPZN, RPCOMP MIRU KLWL T Shut in well - monitor pressures CSG/DP - 40/10 CSG/DP - 70/10 in 5 min CSG/DP - 100/10 in 15 min CSG/DP - 110/10 in 45 min 9/9/2023 22:45 9/10/2023 00:00 1.2 5 5,845.0 5,845.0 COMPZN, RPCOMP MIRU KLWL T PJSM - line up to choke bleed gas off Casing from 110 PSI to 30 PSI Bullhead 250 BBLS down annulus 3 BPM 350 PSI 4 BPM 450 PSI 5 BPM 580 ICP - 5 BPM 990 FCP Shut down line up to pump down drill pipe Bull head 50 BBLS down drill pipe 4 BPM 770 ICP 4 BPM 990 FCP Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 10/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/10/2023 00:00 9/10/2023 00:30 0.5 0 5,845.0 5,845.0 COMPZN, RPCOMP MIRU OWFF T Shut down pumps 320 PSI, bleed to 100 PSI in 10 min Open bleeders on choke and drill pipe, shut in monitor pressure, no pressure increase in 15 min CSG/DP both zero Open rams fluid level down 10' 9/10/2023 00:30 9/10/2023 01:30 1.0 0 5,845.0 5,845.0 COMPZN, RPCOMP MIRU CIRC T Circulate fill hole dump 13 BBLS to cuttings tank CBU @ 2 BPM 300 PSI Loss rate 20% at 2 BPM 9/10/2023 01:30 9/10/2023 02:00 0.5 0 5,845.0 5,845.0 COMPZN, RPCOMP MIRU OWFF P Flow check - static 9/10/2023 02:00 9/10/2023 03:15 1.2 5 5,845.0 4,801.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole F/5,845' T/4,801' 2 BPM 300 PSI - pumping 5.5 - 6 BBLS per stand 9/10/2023 03:15 9/10/2023 05:00 1.7 5 4,801.0 4,801.0 COMPZN, RPCOMP MIRU SFTY P Rig H2S alarm go off in the pits, evac rig Flow check static, sniff pits with hand held Trouble shoot alarm find bad sensor, replace sensor and calibrate 9/10/2023 05:00 9/10/2023 09:00 4.0 0 4,801.0 2,500.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole F/4,801' T/2500' 2 BPM 300 PSI 9/10/2023 09:00 9/10/2023 10:30 1.5 0 2,500.0 2,500.0 COMPZN, RPCOMP MIRU DISP T Bullhead displace well with 10.4 mud // 285 bbls @ 3.5 bpm @ 800 psi 9/10/2023 10:30 9/10/2023 10:45 0.2 5 2,500.0 2,500.0 COMPZN, RPCOMP MIRU OWFF T OWFF and observed flow and oil/bubbles at surface 9/10/2023 10:45 9/10/2023 11:15 0.5 0 2,500.0 2,500.0 COMPZN, RPCOMP MIRU CIRC T Circulate S x S from 2500' 1500stks 9/10/2023 11:15 9/10/2023 11:30 0.2 5 2,500.0 2,500.0 COMPZN, RPCOMP MIRU SIPB T Shut in and see if pressure builds in annulus // observed 20 psi build up with 10.4 ppg mud in well 9/10/2023 11:30 9/10/2023 14:00 2.5 0 2,500.0 2,500.0 COMPZN, RPCOMP MIRU CIRC T Circulate while weighting up active pit to 10.5 ppg 9/10/2023 14:00 9/10/2023 15:30 1.5 0 2,500.0 2,500.0 COMPZN, RPCOMP MIRU DISP T Bullhead remainder of well with 10.5 ppg mud // 220 bbls 9/10/2023 15:30 9/10/2023 17:00 1.5 0 2,500.0 2,500.0 COMPZN, RPCOMP MIRU OWFF T OWFF 15 min for flow to stop, weight up to kill top 2500' of the hole with 10.8 ppg 9/10/2023 17:00 9/10/2023 18:45 1.7 5 2,500.0 2,500.0 COMPZN, RPCOMP MIRU DISP T Circulate at 2.5 BPM 180 PSI Weight up to 10.8 PPG 9/10/2023 18:45 9/10/2023 19:30 0.7 5 2,500.0 2,500.0 COMPZN, RPCOMP MIRU OWFF P Flow check - fluid dropping in stack Get pits prepped for pumping out of hole 9/10/2023 19:30 9/10/2023 20:45 1.2 5 2,500.0 1,555.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole F/2500' T/1,555' 2 BPM 150 PSI 9/10/2023 20:45 9/10/2023 21:15 0.5 0 1,555.0 1,462.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping Pull one stand to watch fluid level in stack for swabbing, fluid level fall 9/10/2023 21:15 9/10/2023 23:00 1.7 5 1,462.0 0.0 COMPZN, RPCOMP MIRU TRIP P POOH on elevators F/1,462' surface 9/10/2023 23:00 9/10/2023 23:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D Glock plug Clean clear rig floor Static loss rate ~20 BPH 9/10/2023 23:30 9/11/2023 00:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Rig up to fill under test plug with charge pump 9/11/2023 00:00 9/11/2023 00:45 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Set test plug, rig up test equipment, fill stack and flood lines with water, purge air out of system 9/11/2023 00:45 9/11/2023 02:15 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BOPE P Test UPR with 2 7/8" and 3 1/2" test joints 250/3000 PSI 5 min each Fill under test plug with mud take 3 - 4 BBLS every 10 to 20 min Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 11/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/11/2023 02:15 9/11/2023 03:00 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Rig down testing equipment, blow down lines, pull test plug Set wear ring 9/11/2023 03:00 9/11/2023 04:15 1.2 5 0.0 224.0 COMPZN, RPCOMP MIRU BHAH P PJSM Make up BHA #7 overshot with spear grapple T/224' 9/11/2023 04:15 9/11/2023 10:00 5.7 5 224.0 8,000.0 COMPZN, RPCOMP MIRU TRIP P RIH F/224' T/8000' // Break circulation every 1500' make sure hole will circulate // 9/11/2023 10:00 9/11/2023 12:00 2.0 0 8,000.0 8,000.0 COMPZN, RPCOMP MIRU CIRC P Circulate ensure mud column is clean 10.7 in and out // 2 bbls/min @ 350 psi 9/11/2023 12:00 9/11/2023 12:30 0.5 0 8,000.0 8,400.0 COMPZN, RPCOMP MIRU TRIP P TIH to 8400' // Get fishing parameters // Up Wt 170K Dn Wt 87K 9/11/2023 12:30 9/11/2023 12:54 0.4 0 8,400.0 8,414.0 COMPZN, RPCOMP MIRU FISH P Engage fish @ 8414' , Pick up 225K, 1 Jar hit, pick up 250K fish pulled free, moved up hole dragging 200K-225K 30' stop to circ B/U and to let packer relax if packer came free 9/11/2023 12:54 9/11/2023 14:00 1.1 0 8,414.0 8,414.0 COMPZN, RPCOMP MIRU CIRC P Circulate B/U ensure no gas from under packer in well bore 9/11/2023 14:00 9/11/2023 18:00 4.0 0 8,414.0 200.0 COMPZN, RPCOMP MIRU TRIP P TOOH with stands of drill pipe 9/11/2023 18:00 9/11/2023 19:15 1.2 5 200.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back drill collars, Lay down overshot and fish Cut JT = 14.68' Total fish length = 24.93' 9/11/2023 19:15 9/11/2023 20:00 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU OTHR P Clear and clean rig floor Get next BHA tools ready and bring to floor 9/11/2023 20:00 9/11/2023 20:45 0.7 5 0.0 228.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #8 Spear with 3.947 grapple to catch PBR T/228' 9/11/2023 20:45 9/11/2023 23:30 2.7 5 228.0 8,359.0 COMPZN, RPCOMP MIRU TRIP P RIH F/228' T/8,359' 170K UP 85K DN 9/11/2023 23:30 9/12/2023 00:00 0.5 0 8,359.0 8,492.0 COMPZN, RPCOMP MIRU FISH P Circulate at 2 BPM 450 PSI wash down T/8,439' Set DN 10K see pump pressure increase to 550 PSI, turn off pump Pick up no over pull 170K up, slack off set DN 10K, pick up see hole swabbing, slack off push mud away Pick up to 8,418' - bottom of fish ~8,492', fish = ~74' 9/12/2023 00:00 9/12/2023 02:45 2.7 5 8,492.0 8,492.0 COMPZN, RPCOMP MIRU CIRC P Circulate at 2 BPM 450 PSI Dump mud at 575 STKS due to gas cut mud coming back Dump 246 BBLS to cuttings tank Loss rate ~9 BPH at 2 BPM Pump a total of 387 BBLS mud weight 10.7 in/out 9/12/2023 02:45 9/12/2023 03:00 0.2 5 8,492.0 8,492.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping slowly 9/12/2023 03:00 9/12/2023 09:15 6.2 5 8,492.0 3,968.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole F/8,492' T/3,968' 2 BPM 450 PSI, pulling ~30 FPM to offset swab 9/12/2023 09:15 9/12/2023 09:45 0.5 0 3,968.0 3,873.0 COMPZN, RPCOMP MIRU OWFF P Flow check, dropping Pull one stand to watch fluid fall in stack to make sure not swabbing 9/12/2023 09:45 9/12/2023 12:45 3.0 0 3,873.0 228.6 COMPZN, RPCOMP MIRU TRIP P POOH F/3,873' T/228' 95K UP 9/12/2023 12:45 9/12/2023 13:30 0.7 5 228.6 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back DC, L/D BHA #8 *** Note: No Fish Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 12/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/12/2023 13:30 9/12/2023 14:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Rig Service 9/12/2023 14:00 9/12/2023 14:30 0.5 0 0.0 228.6 COMPZN, RPCOMP MIRU BHAH P M/U BHA #9 w/3.947" Grapple, side door circ sub, bumper sub, Oil Jars, 6 drill collars, accelerator, and XO. 9/12/2023 14:30 9/12/2023 17:45 3.2 5 228.6 8,359.0 COMPZN, RPCOMP MIRU TRIP P TBIH, w/BHA #9 Break circulation every ~1,500' at 2 BPM 9/12/2023 17:45 9/12/2023 20:00 2.2 5 8,359.0 8,359.0 COMPZN, RPCOMP MIRU CIRC P Circulate at 2 BPM 400 PSI 9/12/2023 20:00 9/12/2023 20:30 0.5 0 8,359.0 8,442.0 COMPZN, RPCOMP MIRU FISH P Wash down F/8,359' T/8,442' 2 BPM 400 PSI 170K UP 80K DN Slack off to 8,439' set down 5K see pump increase to 500 PSI, P/U clean, S/O set DN 10K, P/U clean at 170K, S/O set DN 20K P/U clean at 170K Rotate to left at 4 RPM 5K TQslack off set DN 5-8K stall rotatry at 5K P/U see a little grapple drag Turn off pump S/O to 8,442' P/U to 30K over to 200K Grapple act like it slipping S/O T/80K on the hook grapple act like slipping a little put 2 turns to left in string work down P/U to 250K hit jars, P/U to 350K = 180K over 9/12/2023 20:30 9/13/2023 00:00 3.5 0 8,442.0 8,442.0 COMPZN, RPCOMP MIRU FISH P Pull and jar on packer - keep hole full across the top P/U to 250 -275K = 80K to fire jars Pull to 350K on hook = 180K over Jar licks = 100 no movement Derrick inspection every 50 jar licks 9/13/2023 00:00 9/13/2023 01:30 1.5 0 8,442.0 8,419.0 COMPZN, RPCOMP MIRU FISH P Pull and jar on packer - keep hole full across the top P/U to 250 -275K = 80K to fire jars Pull to 350K on hook = 180K over Total Jar licks = 146 Derrick inspection every 50 jar licks 9/13/2023 01:30 9/13/2023 03:45 2.2 5 8,419.0 8,419.0 COMPZN, RPCOMP MIRU CIRC P Circulate at 2 BPM 400 PSI, 3 BPM 575 PSI Condtion mud for trip out Have 3.4 gas cut mud come back at 7.3 PPG dump ~170 BBLS to cuttings tank 9/13/2023 03:45 9/13/2023 04:00 0.2 5 8,419.0 8,419.0 COMPZN, RPCOMP MIRU OWFF P Flow check, dropping slowly 9/13/2023 04:00 9/13/2023 06:15 2.2 5 8,419.0 6,943.1 COMPZN, RPCOMP MIRU PMPO P Pump out of hole at 2 BPM pulling 30 FPM to offset swab 170K UP 9/13/2023 06:15 9/13/2023 11:45 5.5 0 6,943.1 228.6 COMPZN, RPCOMP MIRU TRIP P Line up across the top using the kill line, switch over to elevators, continue tripping out of hole, proper pipe displacement on every stand 9/13/2023 11:45 9/13/2023 12:15 0.5 0 228.6 44.0 COMPZN, RPCOMP MIRU BHAH P Stand back DC's Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 13/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/13/2023 12:15 9/13/2023 14:00 1.7 5 44.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA, discuss planforward with SLB, Rig and Town Team. Send FR for additional milling and fishing tools. *** Note: Recovered section of fish. , PBR - 13.37', Top of packer - 4.02' *** Left in hole - 4.35' of packer fish 9/13/2023 14:00 9/13/2023 14:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Service Rig 9/13/2023 14:30 9/13/2023 15:30 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU WAIT P Discuss planforward with SLB, Rig and Town Team. Send FR for additional milling and fishing tools. 9/13/2023 15:30 9/13/2023 16:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #10 with , XO PXP, Boot Basket x 2, Bit Sub, String Magnet x 2, Bumper Sub, Oil Jar, DC x 6, Accelorator, and XO Sub, 9/13/2023 16:00 9/13/2023 17:45 1.7 5 0.0 0.0 COMPZN, RPCOMP MIRU WAIT P Stand by for, Rotary shoe, extension, drive bushing, 9/13/2023 17:45 9/13/2023 18:30 0.7 5 0.0 265.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #10 6" rotary shoe for milling Camco packer 9/13/2023 18:30 9/13/2023 20:30 2.0 0 265.0 3,855.0 COMPZN, RPCOMP MIRU TRIP P RIH F/265' T/3,855'' Break circulation at 1976' 9/13/2023 20:30 9/13/2023 21:15 0.7 5 3,855.0 3,855.0 COMPZN, RPCOMP MIRU CIRC P CBU at 4 BPM 400 PSI Loss rate minimal 9/13/2023 21:15 9/13/2023 23:00 1.7 5 3,855.0 8,392.0 COMPZN, RPCOMP MIRU TRIP P RIH F/3,855' T/8,392' Break circulation at 5,740' 9/13/2023 23:00 9/14/2023 00:00 1.0 0 8,392.0 8,392.0 COMPZN, RPCOMP MIRU SLPC P Slip cut drilling line - cut 94' Service rig, adjust draw works break linkage 9/14/2023 00:00 9/14/2023 01:00 1.0 0 8,392.0 8,392.0 COMPZN, RPCOMP MIRU SLPC P Slip cut drilling line service rig Circulate 2 BPM 350 PSI 9/14/2023 01:00 9/14/2023 01:30 0.5 0 8,392.0 8,392.0 COMPZN, RPCOMP MIRU CIRC P Circulate 2 BPM 350 PSI - loss rate 10 BPH 4 BPM 730 PSI - loss rate 9 BPH 5 BPM 1000 PSI - loss rate 13 BPH 9/14/2023 01:30 9/14/2023 02:00 0.5 0 8,392.0 8,451.0 COMPZN, RPCOMP MIRU FISH P Wash down F/8,392' T/8,451' - set down 5K 2 BPM 360 PSI 170K UP 85K DN 9/14/2023 02:00 9/14/2023 10:00 8.0 0 8,451.0 8,440.0 COMPZN, RPCOMP MIRU MILL P Mill on packer F/8,451' 5 BPM 1020 PSI 4 BPM 750 PSI 80 RPM 8K - 8.5K TQ off bottom 80 RPM 9K - 9.5K TQ on bottom 3-5K WOM No forward progress, discuss with town, rig teams, and SLB completions. 9/14/2023 10:00 9/14/2023 10:30 0.5 0 8,440.0 8,440.0 COMPZN, RPCOMP MIRU OWFF P Rotate, PUH Shut down and monitor well for flowd No Flow 9/14/2023 10:30 9/14/2023 13:45 3.2 5 8,440.0 265.0 COMPZN, RPCOMP MIRU TRIP P Trip out of hole on stands 9/14/2023 13:45 9/14/2023 14:15 0.5 0 265.0 80.3 COMPZN, RPCOMP MIRU BHAH P At surface, Stand back DC's 9/14/2023 14:15 9/14/2023 14:30 0.2 5 80.3 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA Inspect burn shoe, signs of milling, no fish in side wash pipe. Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 14/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/14/2023 14:30 9/14/2023 14:45 0.2 5 0.0 39.1 COMPZN, RPCOMP MIRU BHAH P M/U BHA #11 with short catch 3.5" grapple 9/14/2023 14:45 9/14/2023 15:15 0.5 0 39.1 223.8 COMPZN, RPCOMP MIRU BHAH P M/U DC stands x 3 9/14/2023 15:15 9/14/2023 18:45 3.5 0 223.8 8,417.0 COMPZN, RPCOMP MIRU TRIP P TIH w/BHA #11, Short catch OS 3-1/2" GR, Bumper Sub, Oil Jars, DC's x 6, Accelorator, and XO. T/8,417' 9/14/2023 18:45 9/14/2023 21:15 2.5 0 8,417.0 8,417.0 COMPZN, RPCOMP MIRU CIRC P Circulate condtion well bore Stage up to 5 BPM 930 PSI Get 7.4 PPG gas/oil cut mud back at surface at 81 BBLS pumped slow pump to 2.5 - 3 BPM, dump to cuttings tank, Dump a total of 255 BBLS Pump a total of 329 BBLS 9/14/2023 21:15 9/14/2023 21:30 0.2 5 8,417.0 8,417.0 COMPZN, RPCOMP MIRU OWFF P Flow check, slight ooze and slowing down 9/14/2023 21:30 9/14/2023 21:45 0.2 5 8,417.0 8,449.0 COMPZN, RPCOMP MIRU FISH P Obtain parameters 30 RPM 6.5 - 7K TQ 117K Rot WT 150K UP, 90K DN 2 BPM 300 PSI Wash down tag fish at 8,449' Pick up pull 20K over, slack off, pull to 200K = 50K over 9/14/2023 21:45 9/15/2023 00:00 2.2 5 8,449.0 8,449.0 COMPZN, RPCOMP MIRU FISH P Work on jarring packer loose Pull 100K over to 250K for jar licks and straight pull to 200K over to 350K on hook Total jar licks = 120 Inspect derrick every 70 jar licks Loss rate ~6 BPH at 2 BPM 9/15/2023 00:00 9/15/2023 00:30 0.5 0 8,449.0 8,413.0 COMPZN, RPCOMP MIRU FISH P Jar packer loose Pull 100K over to 250K for jar licks and straight pull to 200K over to 350K on hook Total jar licks = 140 Inspect derrick every 70 jar licks Loss rate ~6 BPH at 2 BPM Slack off to re cock jars, pick up to 8,413' observe 10K over pull to 160K 9/15/2023 00:30 9/15/2023 01:00 0.5 0 8,413.0 8,413.0 COMPZN, RPCOMP MIRU CIRC P Circulate at 4 BPM 750 PSI Perform post jarring derrick inspection 9/15/2023 01:00 9/15/2023 01:30 0.5 0 8,413.0 8,386.0 COMPZN, RPCOMP MIRU OWFF P Stand one stand back with pumps T/8,386' Flow check 9/15/2023 01:30 9/15/2023 02:15 0.7 5 8,386.0 7,936.0 COMPZN, RPCOMP MIRU TRIP P POOH F/8,386' T/7,936', see some 10K over drag at a few spot, able to slack off thru them come up and was clean at 20 FPM 150K UP 95K DN At 7,936' take 20K over T/170K on hook, slack off take 20K DN T/75K on hook 9/15/2023 02:15 9/15/2023 03:15 1.0 0 7,936.0 7,881.0 COMPZN, RPCOMP MIRU FISH P Hang up in 7" casing collar Work packer free with 100K over jar licks to 250K S/O setting down to 65K hitting with bumper sub Pick up to 7,975' 9/15/2023 03:15 9/15/2023 03:45 0.5 0 7,881.0 7,881.0 COMPZN, RPCOMP MIRU CIRC P Finsh CBU at 5 BPM 9/15/2023 03:45 9/15/2023 04:30 0.7 5 7,881.0 7,787.0 COMPZN, RPCOMP MIRU OWFF P Flow check - gas bubbles and crude oil Circulate another 80 BBLS at 5 BPM 1050 PSI Flow check - dropping slowly Pull one stand watch fluid level fall T/7,787' Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 15/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/15/2023 04:30 9/15/2023 07:45 3.2 5 7,787.0 6,596.0 COMPZN, RPCOMP MIRU TRIP P POOH F/7,787' At 7,765' pull tight, Kelly up pump 5 BPM 950 PSI work past tight spot Pump out of hole at 5 BPM 930 PSI 9/15/2023 07:45 9/15/2023 08:00 0.2 5 6,596.0 6,500.0 COMPZN, RPCOMP MIRU PMPO P 6,596', Temporarily Detained, work pipe, through high dog leg area / collar pumping 5 bpm. Freely moving up hole again SOW=75k PUW=115k 9/15/2023 08:00 9/15/2023 09:30 1.5 0 6,500.0 5,674.0 COMPZN, RPCOMP MIRU PMPO P Continue TOOH with pumps working thru several tight spots PUW=115k 9/15/2023 09:30 9/15/2023 09:45 0.2 5 5,674.0 5,674.0 COMPZN, RPCOMP MIRU PMPO P 5,674', Temporarily Detained, SOW=65k PUW=105k 9/15/2023 09:45 9/15/2023 19:00 9.2 5 5,674.0 318.0 COMPZN, RPCOMP MIRU PMPO P Continue TOOH with pumps working thru several tight spots PUW=105k 9/15/2023 19:00 9/15/2023 19:15 0.2 5 318.0 318.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping slowly 9/15/2023 19:15 9/15/2023 20:15 1.0 0 318.0 82.0 COMPZN, RPCOMP MIRU BHAH P Pump out BHA and lay down to 82' 9/15/2023 20:15 9/15/2023 22:00 1.7 5 82.0 0.0 COMPZN, RPCOMP MIRU PULL P L/D fish, and 3 1/2" tubing Cut JT = 15.35' Total length of fish = 72.17' 9/15/2023 22:00 9/15/2023 22:45 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU OTHR P Clean clear rig floor, C/O elevators to 3 1/2" DP P/U jars and bumper sub, release grapple and L/D over shot and fish 9/15/2023 22:45 9/16/2023 00:00 1.2 5 0.0 224.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #12 over shot with pack off T/224' 9/16/2023 00:00 9/16/2023 01:00 1.0 0 224.0 2,297.0 COMPZN, RPCOMP MIRU TRIP P RIH F/224' T/2,297' Observe incorrect hole fill, flow check, have gas/oil breaking out at surface 9/16/2023 01:00 9/16/2023 02:15 1.2 5 2,297.0 2,297.0 COMPZN, RPCOMP MIRU CIRC P Circulate at 3.5 BPM 200 PSI Dump 98 BBLS to cutting tank, circulate clean Flow check, slight flow slowing down, still oil/gas coming to surface 9/16/2023 02:15 9/16/2023 04:45 2.5 0 2,297.0 8,450.0 COMPZN, RPCOMP MIRU TRIP P RIH F/2,297' T/8,450' 9/16/2023 04:45 9/16/2023 06:00 1.2 5 8,450.0 8,450.0 COMPZN, RPCOMP MIRU CIRC P Circulate condtion mud Stage up to 5 BPM 9/16/2023 06:00 9/16/2023 07:30 1.5 0 8,450.0 8,450.0 COMPZN, RPCOMP MIRU CIRC P Continue to circulate/condition well Gas returns Pumping 4 bpm SOW=95 k PUW=150 k Note: Increase Mud Weight 10.8 ppg 9/16/2023 07:30 9/16/2023 08:30 1.0 0 8,450.0 8,522.7 COMPZN, RPCOMP MIRU FISH P 10.8 ppg all the way around Wash down over fish, Slip off, rotate left slowly work down over fish drill string assended down, stop rotating set down addtional weight 10 k, work pipe, PUH, 125 k x 2 jar licks, straight pull 175k, 225k, and 225k, free fish @ 275K, 125K over 9/16/2023 08:30 9/16/2023 09:30 1.0 0 8,522.7 8,500.0 COMPZN, RPCOMP MIRU CIRC P CBU Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 16/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/16/2023 09:30 9/16/2023 11:15 1.7 5 8,500.0 7,403.0 COMPZN, RPCOMP MIRU TRIP P Attempt to pull one stand on elevators Seems we are swabbing Trip/Pump out of hole w/TD 9/16/2023 11:15 9/16/2023 11:45 0.5 0 7,403.0 7,403.0 COMPZN, RPCOMP MIRU TRIP P Damage Saber Sub, Swap out joint for like Swap out Saber Sub 9/16/2023 11:45 9/16/2023 12:15 0.5 0 7,403.0 7,403.0 COMPZN, RPCOMP MIRU SVRG P Sim-ops Service Rig 9/16/2023 12:15 9/16/2023 17:45 5.5 0 7,403.0 1,540.0 COMPZN, RPCOMP MIRU TRIP P POOH on elevators @ 30 fpm, increaseing pulling speed as hole allows T/1,540' 9/16/2023 17:45 9/16/2023 18:15 0.5 0 1,540.0 1,540.0 COMPZN, RPCOMP MIRU OWFF P Notice mud coming over top drill pipe Flow check Determine mud in/out uneven Circ at 5 BPM 10.8 PPG in/out 9/16/2023 18:15 9/16/2023 19:00 0.7 5 1,540.0 482.0 COMPZN, RPCOMP MIRU TRIP P POOH T/482' 9/16/2023 19:00 9/16/2023 19:15 0.2 5 482.0 482.0 COMPZN, RPCOMP MIRU OWFF P Flow check 9/16/2023 19:15 9/16/2023 20:00 0.7 5 482.0 258.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #12 and cut JT of 3 1/2" tubing fish 9/16/2023 20:00 9/16/2023 23:15 3.2 5 258.0 0.0 COMPZN, RPCOMP MIRU PULL P Rig up to L/D 3 1/2" TBG L/D 3 1/2" TBG with blast rings Top cut joint = 16.80' Bottom cut joint = 14.90' 9/16/2023 23:15 9/17/2023 00:00 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Clean clear rig floor of tubing equipment and blast rings and blast ring equipment 9/17/2023 00:00 9/17/2023 01:00 1.0 0 0.0 390.0 COMPZN, RPCOMP MIRU BHAH P P/U jars and bumper sub, remove 3 1/2" tubing from over shot M/U BHA #13 T/224' RIH one stand DP to 390' 9/17/2023 01:00 9/17/2023 01:45 0.7 5 390.0 390.0 COMPZN, RPCOMP MIRU CIRC P Mud coming over top of pipe, Circulate to get clean mud around 9/17/2023 01:45 9/17/2023 02:30 0.7 5 390.0 690.0 COMPZN, RPCOMP MIRU TRIP P RIH F/390' T/690' Circulate to get clean mud around Dump 25 BBLS oil/gas cut mud 9/17/2023 02:30 9/17/2023 03:15 0.7 5 690.0 2,489.0 COMPZN, RPCOMP MIRU TRIP P RIH F/690' T/2,389' 9/17/2023 03:15 9/17/2023 04:00 0.7 5 2,489.0 2,489.0 COMPZN, RPCOMP MIRU CIRC P Stop and Circulate due to oil/gas cut mud coming back Dump mud dump 95 BBLS Pump at 3 BPM 155 PSI Flow check, still oil on top and bubbles breaking out, slight ooze 9/17/2023 04:00 9/17/2023 06:00 2.0 0 2,489.0 8,302.0 COMPZN, RPCOMP MIRU TRIP P RIH F/2,489' T/8,302' 9/17/2023 06:00 9/17/2023 08:00 2.0 0 8,302.0 8,777.0 COMPZN, RPCOMP MIRU CIRC P CBU, taking returns overboard, gas/crude returns. Washing down last 2 stands. Weight bobble 5 k Clean fluid 10.8 ppg in/out. Bring returns back to the pits *** Note: Dump 242 bbls to cuttings tank 9/17/2023 08:00 9/17/2023 09:00 1.0 0 8,777.0 8,780.0 COMPZN, RPCOMP MIRU FISH P Pumping 1.0 bpm/18 spm/350 psi, Set down, no pressure increase, recep pipe, increase pump rate to 5.0 bpm/84 spm/1,029 psi w/no pump increase, PUH, dragging 5-7 k, Assume fish in on, 9/17/2023 09:00 9/17/2023 10:00 1.0 0 8,780.0 8,760.0 COMPZN, RPCOMP MIRU OWFF P PUH, check well for flow No flow observed 10.8 ppg in/out Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 17/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/17/2023 10:00 9/17/2023 12:00 2.0 0 8,760.0 7,688.0 COMPZN, RPCOMP MIRU PMPO P Pump OOH on top drive PUW-=155 k 9/17/2023 12:00 9/17/2023 14:00 2.0 0 7,688.0 4,670.0 COMPZN, RPCOMP MIRU PMPO P Continue pumping out of hole PUW=131 k 9/17/2023 14:00 9/17/2023 17:00 3.0 0 4,670.0 4,005.0 COMPZN, RPCOMP MIRU PMPO P Continue pumping out of hole T/4,005' PUW=100 k 9/17/2023 17:00 9/17/2023 17:45 0.7 5 4,005.0 4,005.0 COMPZN, RPCOMP MIRU CIRC P Circulate BU from 4,005' Circulate 105 bbls 10.8 ppg in\out Flow check 9/17/2023 17:45 9/17/2023 18:30 0.7 5 4,005.0 3,528.0 COMPZN, RPCOMP MIRU TRIP P Pull 5 stands on elevators T/3,528' Flow check - dropping slowly 9/17/2023 18:30 9/17/2023 19:45 1.2 5 3,528.0 3,528.0 COMPZN, RPCOMP MIRU CIRC P Circulate weight up to 11 PPG for a mud cap Circ at 4 BPM Flow check 9/17/2023 19:45 9/17/2023 20:00 0.2 5 3,528.0 3,152.0 COMPZN, RPCOMP MIRU TRIP P POOH F/3,528' T/3,152' 9/17/2023 20:00 9/17/2023 20:45 0.7 5 3,152.0 3,152.0 COMPZN, RPCOMP MIRU CIRC P Circulate weight up to 11.5 PPG for a mud cap Circ at 4 BPM Flow check 9/17/2023 20:45 9/17/2023 21:00 0.2 5 3,152.0 3,152.0 COMPZN, RPCOMP MIRU OWFF P Flow check 9/17/2023 21:00 9/17/2023 23:30 2.5 0 3,152.0 318.0 COMPZN, RPCOMP MIRU TRIP P POOH F/3,152' T/318' 9/17/2023 23:30 9/18/2023 00:00 0.5 0 318.0 318.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping 15 min loss rate = 2 BBLS, static loss rate ~8 BPH 9/18/2023 00:00 9/18/2023 00:45 0.7 5 318.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back 1 stand of DP and drill collars, L/D BHA #13, no fish Clean clear rig floor 9/18/2023 00:45 9/18/2023 01:15 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Pull wear ring 9/18/2023 01:15 9/18/2023 02:00 0.7 5 0.0 0.0 COMPZN, WHDBOP MIRU WWWH P P/U joint DP and johnny wacker, flush BOP stack, lay down joint and Johnny wacker 9/18/2023 02:00 9/18/2023 04:00 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Set test plug, rig up testing equipment, fill stack and lines with water, purge air out of system, obtain good shell test R/U to keep hole full under test plug with charge pump Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 18/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/18/2023 04:00 9/18/2023 11:00 7.0 0 0.0 0.0 COMPZN, WHDBOP MIRU BOPE P Test BOP, All test to 250/3000 PSI F/5 min each Test 1 - annular, TD HYD IBOP, Dart Valve, Kill, Choke manifold valves #1, #2, #3, #15, #16, and Outer Test Spool, Test 2 - Test Upper Pipe Rams, TD Lower Manual, Kill HCR (Fail Pass), Choke Manifold valves #4, #6, #7, #9, and Inner Test Spool, Test 3 -Test Upper pipe Rams, TIW, Kill Inside Manual, Choke Manifold valves #5 (Fail Pass), #11, #10. Test 4 - Upper Pipe Rams, TIW,Kill Inside Manual, Choke Valves #14, Test 5 - Test Lower Pipe Rams, TIW, Test 6 - Blind Rams, Choke Manifold Valves, #8, #12, and #13. Test 7 - Super Choke and Manual Choke Function Test - Switch over to 2-7/8" test joint, #8 Annular, 3-1/2" FOSV, Choke HCR, Test 9 Upper Pipe Rams, Choke Inside Manual, 3-1/2" FOSV, #10, Lower Pipe Rams, FOSV. Perform accumulator test. Initial pressure = 3,000 PSI, after closure = 1,575 PSI, 200 PSI attained = 19 sec, full recovery attained = 109 sec. UVBR = 6 sec, LVBR = 6 sec, Annular = 29 sec, Simulated blinds = 6 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 2,130 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Bob Noble witness test *** Note: Fill hole under test plug with 11.5 PPG mud total of 38 bbls 9/18/2023 11:00 9/18/2023 11:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Rig down testing equipment, blow down lines, drain stack, Pull test plug Set wear ring 9/18/2023 11:30 9/18/2023 12:30 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU OWFF P Fill hole take 15 BBLS Flow check 9/18/2023 12:30 9/18/2023 13:30 1.0 0 0.0 228.0 COMPZN, RPCOMP MIRU BHAH P PJSM, M/U BHA #14 w/3-1/2" GR OverShot, Upper Extention, Bumper Sub, Oil Jar, DC's x 6, Accelorator, and XO 3- 1/2" IF x 3-1/2" HT38. 9/18/2023 13:30 9/18/2023 16:45 3.2 5 228.0 8,765.0 COMPZN, RPCOMP MIRU TRIP P TIH, w/BHA #14 9/18/2023 16:45 9/18/2023 18:00 1.2 5 8,765.0 8,765.0 COMPZN, RPCOMP MIRU CIRC P Condition wellbore prior to washing down over fish At 4 BPM 900 PSI Dump 72 BBLS of mud Pump a total of 320 BBLS 9/18/2023 18:00 9/18/2023 18:15 0.2 5 8,765.0 8,765.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping slowly Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 19/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/18/2023 18:15 9/18/2023 18:45 0.5 0 8,765.0 8,783.0 COMPZN, RPCOMP MIRU FISH P Obtain parameters 2 BPM 420 PSI 30 RPM 8K TQ 117K Rot WT 170 - 165K UP, 90K DN Wash down F/8,765' T/8,780' , set DN 5K , no increase in pump pressure, P/U rotate DN T/8,781' at 20 RPM 7K TQ, pump pressure increase to 600 PSI, set DN 7K TQ up to 8K Turn off rotary, bleed pump pressure off, slack off to 8,783' set DN 10K Rotate to left to insure grapple in catch position, Slack off to 8,783' 9/18/2023 18:45 9/18/2023 19:00 0.2 5 8,783.0 8,783.0 COMPZN, RPCOMP MIRU FISH P Pick up to 175K - 5 - 10K over confirm grapple bit, slack off to 75K - 15K DN P/U to 225K let jars hit, pull to 250K S/O cock jars, P/U to 250K 80K over for jar lick, pick up pull seals out see 5-7K drag Pump pressure fall off, pump at 12 SPM 320 PSI, slack off see pump[ pressure increase to 490 PSI, pick up see pump pressure drop off at 8,775' confirm seals out of packer 9/18/2023 19:00 9/18/2023 19:45 0.7 5 8,783.0 8,783.0 COMPZN, RPCOMP MIRU CIRC P Pick up to 8,774' CBU at 5 BPM 1200 PSI 9/18/2023 19:45 9/18/2023 20:30 0.7 5 8,783.0 8,638.0 COMPZN, RPCOMP MIRU OWFF P Flow check dropping slowly Pull one stand to 8,638' watch fluid level fall 170K UP Blow down top drive Line up on trip tank 9/18/2023 20:30 9/19/2023 00:00 3.5 0 8,638.0 4,952.0 COMPZN, RPCOMP MIRU TRIP P POOH F/8,638' T/4,952' 173K UP 9/19/2023 00:00 9/19/2023 03:30 3.5 0 4,952.0 323.0 COMPZN, RPCOMP MIRU TRIP P POOH F/4,952' T/323' 9/19/2023 03:30 9/19/2023 03:45 0.2 5 323.0 323.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping slowly 9/19/2023 03:45 9/19/2023 04:45 1.0 0 323.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back one stand of DP , 2 stands collars, L/D BHA #14 Fish length = 29.20' 9/19/2023 04:45 9/19/2023 05:15 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Clean clear rig floor 9/19/2023 05:15 9/19/2023 06:30 1.2 5 0.0 257.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #15 packer mill T/257' 9/19/2023 06:30 9/19/2023 09:45 3.2 5 257.0 8,557.0 COMPZN, RPCOMP MIRU TRIP P RIH F/257' T/8,557' Place TopDrive in slips 9/19/2023 09:45 9/19/2023 10:45 1.0 0 8,557.0 8,557.0 COMPZN, RPCOMP MIRU CIRC P Slip and cut drill line. Sim-ops - Circulate BU 9/19/2023 10:45 9/19/2023 11:30 0.7 5 8,557.0 8,557.0 COMPZN, RPCOMP MIRU CIRC P Continue circulating, condition well bore for trip *** Note: Nothing to report for returns, 11.1 ppg all the way around 9/19/2023 11:30 9/19/2023 11:45 0.2 5 8,557.0 8,807.2 COMPZN, RPCOMP MIRU TRIP P TIH slowly, tag fish @ 8,807' PUW No-Rot=115 k SOW No-Rot=95 9/19/2023 11:45 9/19/2023 12:00 0.2 5 8,807.2 8,808.4 COMPZN, RPCOMP MIRU MILL P Obtain free spin numbers Tag top of sub 8,807' 4 bpm = 1010 psi Dn Wt.-Rot = 93K Up Wt. -Rot = 110k RPM 80 TQ 8100 WOB=2-3k Mill F/ 8,807' T/ 8,808.4' Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 20/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/19/2023 12:00 9/19/2023 17:45 5.7 5 8,808.4 8,810.0 COMPZN, RPCOMP MIRU MILL P PUH, PUW=119k, back ream Obtain free spin numbers Tag top of sub 8,808' 4 bpm = 940 psi Dn Wt. -Rot = 93K Up Wt. -Rot = 110k RPM 80 TQ 8,300' WOB=12k Mill F/ 8,808.4' T/ 8,810' Seeing minor amount of metal on magnets Hammer on fish x 2 continue milling ahead 9/19/2023 17:45 9/19/2023 19:00 1.2 5 8,810.0 8,793.0 COMPZN, RPCOMP MIRU CIRC P Packer free up and moving down hole P/U to 8,793' space out tool joint for BOP's if needed Circulate at 4 BPM 975 PSI to get packer gas out Dump 110 BBLS to tank 9/19/2023 19:00 9/19/2023 20:00 1.0 0 8,793.0 8,900.0 COMPZN, RPCOMP MIRU MILL P Push packer down F/8,810' T/8,900' Dress up inside for spear 4 BPM 990 PSI 80 RPM 8.3K TQ 0-15K WOM 9/19/2023 20:00 9/19/2023 21:30 1.5 0 8,900.0 8,885.0 COMPZN, RPCOMP MIRU CIRC P Circulate hole clean 7 BPM 2000 PSI 75 RPM 8.4K TQ 117K Rot WT Pump 32 BBL hi vis sweep around Slack off to 8,900' tag packer again to insure clean for spear retrieval 9/19/2023 21:30 9/19/2023 22:00 0.5 0 8,885.0 8,860.0 COMPZN, RPCOMP MIRU OWFF P Pump one stand out and stand back T/8,860' Flow check - dropping 9/19/2023 22:00 9/19/2023 23:30 1.5 0 8,860.0 7,442.0 COMPZN, RPCOMP MIRU TRIP P POOH on TT F/8,860' T/7,442' 9/19/2023 23:30 9/20/2023 00:00 0.5 0 7,442.0 7,442.0 COMPZN, RPCOMP MIRU OWFF P Flow check Pump 17 BBL 11.7 PPG dry job Blow down top drive Line up on TT 9/20/2023 00:00 9/20/2023 04:30 4.5 0 7,442.0 351.0 COMPZN, RPCOMP MIRU TRIP P POOH F/7,442' T/351' 9/20/2023 04:30 9/20/2023 04:45 0.2 5 351.0 351.0 COMPZN, RPCOMP MIRU OWFF P Flow check 9/20/2023 04:45 9/20/2023 06:00 1.2 5 351.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back one stand of DP , 2 stands collars, L/D BHA #15 packer mill Clean magnets and boot baskets out 9/20/2023 06:00 9/20/2023 06:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Clear and clean rig floor 9/20/2023 06:30 9/20/2023 07:00 0.5 0 0.0 COMPZN, RPCOMP MIRU SVRG P Serviced Rig Top Drive, Roughnecks, elevators, tuggers, etc. 9/20/2023 07:00 9/20/2023 07:45 0.7 5 0.0 231.0 COMPZN, RPCOMP MIRU BHAH P Pick up JT DP from shed, break off spear and X/over M/U Spear w/3.198" Grapple, XO Sub, Side Door Circ Sub (2,400 psi), Bumper Sub, Oil Jars, DC's x 6, Accelorator, and XO Sub. 9/20/2023 07:45 9/20/2023 10:30 2.7 5 231.0 8,860.0 COMPZN, RPCOMP MIRU TRIP P TIH w/3.198 grapple BHA #16 F/231' T/8,860' 9/20/2023 10:30 9/20/2023 11:30 1.0 0 8,860.0 8,860.0 COMPZN, RPCOMP MIRU CIRC P Circulate BU (4,098 stks) F/8,860' w/11.1 ppg LSND *** Note: No gas/crude to surface Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 21/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/20/2023 11:30 9/20/2023 12:00 0.5 0 8,860.0 8,860.0 COMPZN, RPCOMP MIRU OWFF P Check wellbore contion (good), fluid is dropping every so slowly. 9/20/2023 12:00 9/20/2023 12:30 0.5 0 8,860.0 8,829.0 COMPZN, RPCOMP MIRU FISH P PUW=165, SOW=95k Pump online 1 bpm/34 spm/730 psi Spear Packer @ 8,898.5', set down 8,899.4' w/5k down Pump pressure 1,000 psi,, PUH, shut down pump, set back down 10 k, 8,899.68', PUH, set back down 12 k 8,900.65', PUH 179 k 8,898.8', set back down 8,901.5', Bring pump online @ 2 bpm/831 psi, set back down 15 k, 8,905', PUH 8,895.5, PUW 215 k 50 k over blocks Continue up hole dragging, bring pump up to shear disc, pressure slowly dropped 400 psi. Don't think shear disc sheared. 9/20/2023 12:30 9/20/2023 13:30 1.0 0 8,829.0 8,829.0 COMPZN, RPCOMP MIRU CIRC P Circulate BU @ 5 bpm/83 spm/3,000 psi *** Note: No gas/crude to surface 9/20/2023 13:30 9/20/2023 14:15 0.7 5 8,829.0 8,450.0 COMPZN, RPCOMP MIRU PMPO P PUMP OOH, with fish, BHA #16 @ 2 BPM 740 PSI pulling at 20 fpm F/8,829' T/8,126' 9/20/2023 14:15 9/20/2023 20:15 6.0 0 8,450.0 324.0 COMPZN, RPCOMP MIRU TRIP P POOH F/8,450' T/324' 9/20/2023 20:15 9/20/2023 20:30 0.2 5 324.0 324.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping 9/20/2023 20:30 9/20/2023 21:30 1.0 0 324.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back one stand of DP , 2 stands collars, L/D BHA #16 and fish Model D packer with tubing tail Length of fish = 24.10' 9/20/2023 21:30 9/20/2023 22:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Service rig 9/20/2023 22:00 9/20/2023 23:00 1.0 0 0.0 275.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #17 , clean out assyembly W/6.125" junk mill, casing scraper and 2 x 6.125" smooth OD string mills 9/20/2023 23:00 9/21/2023 00:00 1.0 0 275.0 2,653.0 COMPZN, RPCOMP MIRU TRIP P RIH F/275' T/2,653' 9/21/2023 00:00 9/21/2023 03:00 3.0 0 2,653.0 8,875.0 COMPZN, RPCOMP MIRU TRIP P RIH F/2,632' T/8,875' 9/21/2023 03:00 9/21/2023 03:30 0.5 0 8,875.0 8,878.0 COMPZN, RPCOMP MIRU CIRC P Obtain parameters 2 BPM 500 PSI, 30 RPM 9.4K TQ 173K UP 90K DN 123K Rot WT Wash DN F/8,875' T/8,878' 2 BPM 500 PSI Tag up at set DN 5 - 15K Rotate at 15 RPM stall rotarty out at 11K Rotate at 50 RPM 8.5K TQ - Slack off to 8,876' stall rotary at 12K - pick up see 8- 10K over pull Note : 8,878' is same depth we stack up at and stalled rotary while pushing packer down after it was free Places scrapper right at the top of the bottom set of perfs from 7ES RKB 9/21/2023 03:30 9/21/2023 05:00 1.5 0 8,878.0 8,876.0 COMPZN, RPCOMP MIRU CIRC P Circulate hole clean at 7 BPM 2500 PSI pump 30 BBL Hi vis weighted sweep No gas/oil cut mud back on bottoms up 9/21/2023 05:00 9/21/2023 05:30 0.5 0 8,876.0 8,876.0 COMPZN, RPCOMP MIRU OWFF P Flow check Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 22/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/21/2023 05:30 9/21/2023 06:00 0.5 0 8,876.0 8,876.0 COMPZN, RPCOMP MIRU TRIP P Crew change Prep RF for Triipping OOH 9/21/2023 06:00 9/21/2023 06:30 0.5 0 8,876.0 8,876.0 COMPZN, RPCOMP MIRU SVRG P Service Rig 9/21/2023 06:30 9/21/2023 08:30 2.0 0 8,876.0 8,237.0 COMPZN, RPCOMP MIRU PULD P TOOH sideways F/8,876' T/8,237' @ 20 fpm Pump dry job PUW=176 k SOW=92 k 9/21/2023 08:30 9/21/2023 12:30 4.0 0 8,237.0 1,391.0 COMPZN, RPCOMP MIRU TRIP P Plans changed - decide to do clean out run to bottom of perfs POOH F/8,237' T/1,391' Start Standing back DP 9/21/2023 12:30 9/21/2023 13:00 0.5 0 1,391.0 1,391.0 COMPZN, RPCOMP MIRU OWFF P Check well for flow 9/21/2023 13:00 9/21/2023 13:45 0.7 5 1,391.0 1,710.0 COMPZN, WHDBOP MIRU BHAH P PUW=51 k, SOW=60 k M/U Storm packer - XO Sub, TST 3 RTVBL Packer, Pup Joint, ROT EQUALIZING Valve, Twin Thread Safety JT, Pup Joint, and XO TT=30.42' TIH DP stands x 3 and a single T/1,710' *** Note: 6.8' COE to bottom of BHA 9/21/2023 13:45 9/21/2023 14:00 0.2 5 1,710.0 0.0 COMPZN, WHDBOP MIRU MPSP P PUW=56 k SOW=30 k Rotate to the right 15 times, Plug set @ 315.8' total depth C.O.E. @ 309' CBU to get air out of mud POOH 9/21/2023 14:00 9/21/2023 14:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU PRTS P Line up surface lines, Test & Chart Storm packer 1,000 psi, 9/21/2023 14:30 9/21/2023 15:15 0.7 5 0.0 256.4 COMPZN, WHDBOP MIRU BHAH P M/U G-plug, TIH with 3 stands COE from bottom of BHA 6.5' Run 2 stands 94.66' & 94.68, plus one single 31.58', BHA 21.92, minus 6.4' = COE 250' Total Depth=256.4' CBU to get air out of mud 9/21/2023 15:15 9/21/2023 15:45 0.5 0 256.4 0.0 COMPZN, WHDBOP MIRU TRIP P TOOH standing back DP 9/21/2023 15:45 9/21/2023 16:15 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P Chart and Test G-plug to 1,000 psi, good test 9/21/2023 16:15 9/21/2023 17:00 0.7 5 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Blow down Top Drive and surface lines. Suckout stack Pull wear ring Confirm OA is dead - zero PSI 9/21/2023 17:00 9/21/2023 19:00 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Pull riser, break kill line N/D BOPE and rack back 9/21/2023 19:00 9/21/2023 21:00 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU CUTP P PJSM - break bolts on tubing head to see if 7" casing will grow R/U Hydro tight to tubing head to grow 7" casing Grow 7" casing .64' - first jack with Hydro Tight = 108K up force 9/21/2023 21:00 9/21/2023 21:45 0.7 5 0.0 0.0 COMPZN, WHDBOP MIRU CUTP P Pull pack off off 7" casing M/U 7" spear, spear casing, P/U to 130K on hook = 100K over Set slips on 7" casing in well head, slack off release spear, L/D spear and joint drill pipe Stretch 7" casing 1.05' Total growth/stretch 7" casing = 1.69' 9/21/2023 21:45 9/21/2023 22:45 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU CUTP P Install pack off and cut off excess casing with wachs cutter Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 23/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/21/2023 22:45 9/22/2023 00:00 1.2 5 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Install new tubing head and IA valves 9/22/2023 00:00 9/22/2023 01:45 1.7 5 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Install new tubing head and IA valves, test void to 3000 PSI F/5 min 9/22/2023 01:45 9/22/2023 03:45 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/U BOP, riser and lines, hook up turn buckles and center up stack 9/22/2023 03:45 9/22/2023 04:15 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU BOPE P Set test plug, fill stack and lines with water, purge air out of system, test breaks on BOP to 250/3000 PSI 5 min each 9/22/2023 04:15 9/22/2023 04:45 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Pull test plug, rig down testing equipment Drain stack Set wear ring 9/22/2023 04:45 9/22/2023 06:00 1.2 5 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P Make up Glock retreiving head RIH to 256' Set DN on plug open unloader valve, flow check Pick up , rotate to the right unset plug Flow check while elements relax POOH from 256', L/D Glock *** Note: At surface, observe ample amount of metal shavings stuck in retrieval tool, This is why we had difficulty latching up. Take pictures and discuss with wellhead hands. 9/22/2023 06:00 9/22/2023 07:15 1.2 5 0.0 1,391.0 COMPZN, WHDBOP MIRU MPSP P Make up, TIH with storm packer retieving tool Bring pump onling 5 bpm/70 psi, wash down to top of packer, tag packer, PUH, RBIH with pumps off, vertical mark on pipe, torque limiter 1k, set 2 k down, rotate 6 rpm, 13 rotations, shear pins @ 1,200 lbs, open valve, 11.5 turns to the right, let torque, close annular, PUH to release from packer 1,391' of DP below storm packer PUW=56 k SOW=33 k 9/22/2023 07:15 9/22/2023 08:15 1.0 0 1,391.0 1,391.0 COMPZN, WHDBOP MIRU CIRC P Bring pump online 2 bpm, lost 7 bbls Pressure gauge on pump 40 psi, choke pressure 20 psi Take returns out side, mud weight 11.0 ppg/Crude/Gas Circulate BU 1,024 stks. Still dirty returns. Dump 96 BBLS oil/gas cut mud 9/22/2023 08:15 9/22/2023 08:45 0.5 0 1,391.0 1,391.0 COMPZN, WHDBOP MIRU OWFF P Shut down pump and close choke. Monitor well, no pressure Function open annular Observe well for flow Fluid dropping in riser. 9/22/2023 08:45 9/22/2023 09:15 0.5 0 1,391.0 1,121.0 COMPZN, WHDBOP MIRU TRIP P TOOH, L/D storm packer 9/22/2023 09:15 9/22/2023 10:00 0.7 5 1,121.0 272.0 COMPZN, RPCOMP MIRU TRIP P Continue Standing back DP 9/22/2023 10:00 9/22/2023 10:30 0.5 0 272.0 0.0 COMPZN, RPCOMP MIRU BHAH P LD BHA #17 *** Note: 2 pieces of metal recovered from boot backets, magnets were clean, no wear on either sting mills, little wear on outer edge of 6.125" Junk Mill 9/22/2023 10:30 9/22/2023 11:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Service Rig 9/22/2023 11:00 9/22/2023 11:15 0.2 5 0.0 0.0 COMPZN, RPCOMP MIRU OWFF P Crew change Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 24/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/22/2023 11:15 9/22/2023 12:00 0.7 5 0.0 247.0 COMPZN, RPCOMP MIRU BHAH P M/U Cleanout Assembly BHA #21 w/5- 3/4" Junk mill 9/22/2023 12:00 9/22/2023 14:00 2.0 0 247.0 3,070.0 COMPZN, RPCOMP MIRU TRIP P TIH w/BHA #21 5.75" Junk Mill, Boot Basket x 2, Bit Sub, 5.75" Sting Mill x 2, Bumper Sub, Oil Jars, DC's x 6, Accelorator, and XO Sub to DP. 9/22/2023 14:00 9/22/2023 14:45 0.7 5 3,070.0 3,070.0 COMPZN, RPCOMP MIRU CIRC P CIrculate BU to condition well bore to continue TIH 2,120 stks away fluid is cleaning up. 2,881 stks away, shut down pump, Monitor well for flow, fluid is dropping in riser Dump 130 BBLS gas/oil cut mud 9/22/2023 14:45 9/22/2023 17:00 2.2 5 3,070.0 8,850.0 COMPZN, RPCOMP MIRU TRIP P RIH F/3,070' T/8,850' 175K UP 85K DN 9/22/2023 17:00 9/22/2023 19:00 2.0 0 8,850.0 8,850.0 COMPZN, RPCOMP MIRU CIRC P Circulate condtion mud 3 BPM 680 PSI Dump 263 BBLS oil/gas cut mud Pump a total of 392 BBLS 9/22/2023 19:00 9/22/2023 19:30 0.5 0 8,850.0 8,913.0 COMPZN, RPCOMP MIRU WASH P Wash DN F/8,850' T/8,912' 5 BPM1380 PSI 163K UP, 85K DN, 115K Rot WT at 30 RPM 9K TQ Tag up with 10K at 8,912', P/U to 8,895', rotate at 60 RPM 9K TQ Wash/Ream down to 8,901' set down 3- 5K stall rotary at 12K, let TQ out of string, pick up to 8,895', over pull 27K to 190K when picking up Slack off to 8,908' see 5K bobble, contuine to slack off to 8,908', attempt to rotate down at 30 RPM stall rotarty at 12K at 8,909', pick up see 50K over pull to 215K Pick up to 8,851', wash down to 8,913' set down 15K, pick up to 8,851', see 15-20K over pull and drag until 8,873' then pick up clean Call and discuss with town 9/22/2023 19:30 9/22/2023 19:45 0.2 5 8,913.0 8,850.0 COMPZN, RPCOMP MIRU WASH P Work mills thru perfs with 5 BPM F/8,850' to 8,913' See 5 -15K drag with mills thru perfs Work mills 4 times thru perfs 9/22/2023 19:45 9/22/2023 23:15 3.5 0 8,850.0 8,850.0 COMPZN, RPCOMP MIRU WAIT T Pick up to 8,850', turn pumps down to 2 BPM 380 PSI Waiting on mud truck from Deadhorse to get to rig and off load 22:00 HRS truck on location off load to pits and build 11.5 PPG Hi vis sweep Weight up system to 11.2 PPG 9/22/2023 23:15 9/23/2023 00:00 0.7 5 8,850.0 8,845.0 COMPZN, RPCOMP MIRU CIRC P Pump 25 BBL 11.5 PPG Hi vis sweep Pump 5 BPM 1400 PSI Slack off to 8,900' set down 5K, wait there until sweep cleared drill pipe, pick up to 8,845' See 5-10K coming back up thru perfs to 8,873', then pull clean to 8,845' Pump 7 BPM 2110 PSI Increase mud weight to 11.4 PPG Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 25/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/23/2023 00:00 9/23/2023 04:00 4.0 0 8,845.0 8,845.0 COMPZN, RPCOMP MIRU CIRC P Continue to circulate hole clean at 7 BPM 2110 PSI Get a lot of sand back from 1st sweep Circulate another 25 BBL Hi vis sweep around - second sweep bring increase in sand back Circulate a total of 1555 BBLS, 5x surface to surface to get cleaned up 9/23/2023 04:00 9/23/2023 04:15 0.2 5 8,845.0 8,845.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping 9/23/2023 04:15 9/23/2023 06:00 1.7 5 8,845.0 8,255.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole at 2 BPM pulling 25 FPM to offset swab F/8,845' T/8,255' 2 BPM 460 PSI, pump at 4 BPM 980 PSI 165K UP 85K DN At 8,835' pull to 185K, 20K over, slack off clean, continue to work up seeing 15 - 35K over pulls and working free, acts like we dragging something up hole 9/23/2023 06:00 9/23/2023 07:45 1.7 5 8,255.0 7,060.0 COMPZN, RPCOMP MIRU PMPO P Continue to pump out of hole @ 2 bpm, pulling =/- 25 FPM to off set swab, standing back DP 4 bpm/971 psi, PUW=159 k, SOW=30 k 9/23/2023 07:45 9/23/2023 08:00 0.2 5 7,060.0 7,060.0 COMPZN, RPCOMP MIRU OWFF P Check well for flow, fluid falling in riser Install stripping rubbers Pump dry job (47 bbl) Fill trip tank 9/23/2023 08:00 9/23/2023 11:30 3.5 0 7,060.0 3,092.0 COMPZN, RPCOMP MIRU TRIP P TOOH, filling across the top, standing back DP PUW=100 k SOW=31 k 9/23/2023 11:30 9/23/2023 13:30 2.0 0 3,092.0 247.0 COMPZN, RPCOMP MIRU TRIP P Check well for flow (no flow), continue TOOH, filling across the top, standing back DP PUW=70 k SOW=31 k 9/23/2023 13:30 9/23/2023 14:00 0.5 0 247.0 247.0 COMPZN, RPCOMP MIRU OWFF P Check well for flow Fluid falling in riser 9/23/2023 14:00 9/23/2023 15:00 1.0 0 247.0 0.0 COMPZN, RPCOMP MIRU BHAH P At surface, PJSM, Stand back DC stands x 3, L/D Cleanout assembly BHA #21 w/5- 3/4" *** Note: Recovered element piece and metal from milling packer. 9/23/2023 15:00 9/23/2023 15:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Service Rig Top Drive, Iron Roughneck, elevators, dog collar, etc. 9/23/2023 15:30 9/23/2023 16:30 1.0 0 0.0 263.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #22 with RCJB (6.0"OD), XO Sub PXP, Boot Basket x 2 (4.75"OD), Bit Sub, String magnets x 2, Bumper Sub, Oil Jar, DC's x 6, Accelorator, and XO Sub to DP 9/23/2023 16:30 9/23/2023 20:15 3.7 5 263.0 8,771.0 COMPZN, RPCOMP MIRU TRIP P RIH w/BHA #22 Cleanout/RCJB F/263' T/8,771' 175K UP 85K DN 9/23/2023 20:15 9/23/2023 21:15 1.0 0 8,771.0 8,771.0 COMPZN, RPCOMP MIRU CIRC P CBU @ 5 BPM 1720 PSI Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 26/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/23/2023 21:15 9/23/2023 22:45 1.5 0 8,771.0 8,862.0 COMPZN, RPCOMP MIRU FISH P Wash DN W/RCJB F/8,771' T/8,911' 5 BPM 1660 PSI 50 RPM 8.5K TQ 160K UP, 90K DN, 120K Rot See a little TQ increase at 8,876' to 9.5K, cont wash/ream down to 8,911' to clean up any junk in hole Pick up stall rotary at 12K, let TQ out pull 40K over pop free, rotate at 50 RPM back ream up, see little increase in TQ at 8,900' to 8,873' to 9.7K, at 8,873' TQ fall back to 8.4K Pick up to 8,862', stand back a stand 9/23/2023 22:45 9/24/2023 00:00 1.2 5 8,862.0 8,862.0 COMPZN, RPCOMP MIRU CIRC P Circulate to clean casing Work pipe F/8,862' T/8,875' 7 BPM 3000 PSI, 50 RPM 8.4K TQ Pump 27 BBLS Hi vis sweep 9/24/2023 00:00 9/24/2023 00:30 0.5 0 8,862.0 8,862.0 COMPZN, RPCOMP MIRU OWFF P Flow check - dropping slowly Blow down top drive Line up on trip tank 9/24/2023 00:30 9/24/2023 02:00 1.5 0 8,862.0 8,862.0 COMPZN, RPCOMP MIRU SLPC P Slip and cut drilling line, cut 75' of line Service top drive, draworks and crown Monitor well on trip tank while cutting line 9/24/2023 02:00 9/24/2023 05:45 3.7 5 8,862.0 6,975.0 COMPZN, RPCOMP MIRU PMPO P Pump out of hole at 2 BPM , pulling 25 - 30 FPM F/8,862' T/6,975' 9/24/2023 05:45 9/24/2023 06:15 0.5 0 6,975.0 6,975.0 COMPZN, RPCOMP MIRU OWFF P Check well for flow Blew down Top Drive Pump dry job 9/24/2023 06:15 9/24/2023 13:00 6.7 5 6,975.0 2,020.0 COMPZN, RPCOMP MIRU TRIP P Tripped out of hole on elevators @ 40 fpm 9/24/2023 13:00 9/24/2023 15:00 2.0 0 2,020.0 263.0 COMPZN, RPCOMP MIRU TRIP P 2,020', check well for flow Pipe pulling wet Pump second dry job 5 bbls Continue TOOH 9/24/2023 15:00 9/24/2023 16:45 1.7 5 263.0 0.0 COMPZN, RPCOMP MIRU BHAH P At surface, L/D DC's, BHA #22 Inspect boot baskets, and RCJB 9/24/2023 16:45 9/24/2023 20:45 4.0 0 0.0 0.0 COMPZN, RPCOMP MIRU TRIP P TIH with 22 stands of DP out of derrick L/D to pipe shed Had to use rig tongs on some due to being over torqued 9/24/2023 20:45 9/24/2023 22:45 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Drain stack, pull wear ring R/U to run 2 7/8" tubing Load completion equipment in pipe shed and organize as per running order 9/24/2023 22:45 9/25/2023 00:00 1.2 5 0.0 46.0 COMPZN, RPCOMP MIRU PUTB P PJSM - run 2 7/8" completion as per detail T/46' 9/25/2023 00:00 9/25/2023 13:00 13. 00 46.0 8,852.0 COMPZN, RPCOMP MIRU PUTB P Run 2 7/8" completion as per detail F/46' T/8,833' 9/25/2023 13:00 9/25/2023 13:45 0.7 5 8,852.0 8,852.0 COMPZN, RPCOMP MIRU THGR P M/U 2-7/8" EUE-M space out pup on top of JT #273 P/U Joint #274 M/U XO 4.5" EUE-M x 2-7/8" EUE-M bx/pin w/1.31 2-7/8" pup joint 4-1/2" 12.6#, L-80, EUE-M pup joint. FMC Gen 4 hanger with 4-1/2" EUE lift threads, 4-1/2" EUE box down 9/25/2023 13:45 9/25/2023 14:15 0.5 0 8,852.0 8,852.0 COMPZN, RPCOMP MIRU OWFF P Check well for flow Fluid falling in riser 9/25/2023 14:15 9/25/2023 14:30 0.2 5 8,852.0 8,895.0 COMPZN, RPCOMP MIRU THGR P Land hanger, RLDS, P/T 250/5,000 psi Backout 4-1/2" EUE Landing Joint 76K UP 51K DN Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 27/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/25/2023 14:30 9/25/2023 15:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU MPSP P Set BPV in hanger 9/25/2023 15:00 9/25/2023 15:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P P/T BPV from below by rolling test around packers and up tubing 1,000 psi Line up down the secondary kill line M/U and open sensor on stack Pump a total of 20 BBLS to test BPV, bullhead Pump at 1.3 BPM 9/25/2023 15:30 9/25/2023 20:30 5.0 0 0.0 0.0 COMPZN, WHDBOP MIRU CLEN P Flush stack, gas buster, and surface lines w/Deep Clean pill Pull riser Super Sucker on location Clean rig floor, under rig floor drip pans, rorarty table and pipe racks of mud Start cleaning pits 9/25/2023 20:30 9/26/2023 00:00 3.5 0 0.0 0.0 COMPZN, WHDBOP MIRU OTHR P Perform CPAI BWM on BOP's Change out lower rams to 3 1/2" x 5 1/2" VBR's 9/26/2023 00:00 9/26/2023 01:00 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU OTHR P Perform CPAI BWM on BOP's Change out upper rams to 3 1/2" x 5 1/2" VBR's Continue cleaning pits 9/26/2023 01:00 9/26/2023 02:00 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/D BOP Stack and secure back on pedestal 9/26/2023 02:00 9/26/2023 04:30 2.5 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Clean off hanger and BPV profile, Install test dart in BPV N/U tubing adaptor and tree 9/26/2023 04:30 9/26/2023 06:00 1.5 0 0.0 0.0 COMPZN, WHDBOP MIRU PRTS P Test tubing adaptor to 5,000 PSI R/U testing equipment Test tree to 5,000 PSI R/D test equipment 9/26/2023 06:00 9/26/2023 06:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P Check IA for pressure Check pop it on test dart for pressure Pull BPV 9/26/2023 06:30 9/26/2023 07:45 1.2 5 0.0 0.0 COMPZN, WHDBOP MIRU RURD P R/U circulating lines and equipment to IA and wing valve on tree to bull head CI brine Test lines to 2000 PSI 9/26/2023 07:45 9/26/2023 12:00 4.2 5 0.0 0.0 COMPZN, WHDBOP MIRU DISP P Bull head 9.8 PPG CI brine down 2 7/8" x 7" annulus Pump 280 BBLS at 2 BPM 1000 PSI, 2.3 BPM 1300 PSI, 1.6 BPM 1500 PSI FCP Bull head 9.8 PPG CI brine down 2 7/8" tubing Pump 382 BBLS at 2 BPM 1900 PSI Shut down pumps, have 450 PSI on TBG and 450 PSI on IA 9/26/2023 12:00 9/26/2023 13:00 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Close master valve, bleed off pressure Rig up lubricator to drop ball and rod Open master valve drop ball and rob with a 1 5/16", with 1 3/8" OD x .41' fish neck Close master valve, bleed off pressure, R/D lubricator, put Otis cap back on tree 9/26/2023 13:00 9/26/2023 15:00 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU PRTS P Pressure up to 3,000 PSI, set packers Test tubing to 3,000 PSI F/30 min Bleed tubing to 1,500 PSI Pressure test IA to 2,500 PSI F/30 min Dump tubing pressure shear out SOV Packers shear @ 1700 psi and 2300 psi 9/26/2023 15:00 9/26/2023 15:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Blow down lines and perform end of well ops 9/26/2023 15:30 9/26/2023 16:00 0.5 0 0.0 0.0 DEMOB, MOVE MIRU SVRG P Rig Service. Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Page 28/28 1Y-18 Report Printed: 10/4/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/26/2023 16:00 9/27/2023 00:00 8.0 0 0.0 0.0 DEMOB, MOVE MIRU RURD P Prep rig for move. Clean pits. Shuffle rig mats for move. Rig release at Midnight. Rig Name: NABORS 7ES Rig Accept : 9/3/2023 Rig Release : 9/27/2023 Well Name: 1Y-18 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,934.0 1Y-18 9/30/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig GLD, pull RHC, tag 1Y-18 9/30/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 10/25/2004 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 47#/36# 9 5/8 8.92 41.5 6,139.9 4,420.1 36.00 J-55 BTC PRODUCTION 7 6.28 38.3 9,170.6 6,509.8 26.00 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.9 Set Depth 8,894.6 String Max No 2 7/8 Set Depth 6,294.4 Tubing Description Tubing Completion Upper Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.9 35.9 0.04 Hanger 7.060 FMC Gen 4 hanger with 4 1/2" EUE lift threads - 4 1/2" EUE box down FMC Gen 4 4.020 2,946.4 2,362.1 52.72 Mandrel GAS LIFT 5.560 2.875" x 1.5" MMG SLB MMG 2.366 5,900.2 4,266.3 49.47 Mandrel GAS LIFT 5.560 2.875" x 1.5" MMG SLB MMG 2.366 7,845.4 5,519.4 48.10 Mandrel GAS LIFT 5.560 2.875" x 1.5" MMG SLB MMG 2.366 8,372.8 5,894.9 40.21 Mandrel GAS LIFT 5.560 2.875" x 1.5" MMG SLB MMG 2.366 8,427.6 5,936.8 40.02 Seal Assembly 3.230 Baker locator 1.05' W/80-32 seal assy 19.70' long W/6 pins @ 21,390# shear out Baker 80-32 Seal's 2.400 8,428.6 5,937.6 40.01 PBR 5.440 Baker PBR 20.38' long W/19.73' PBR - 2.34" ID 80-32 PBR H68319 0062 3.230 8,449.0 5,953.2 39.94 Packer 5.960 Baker FH Retrievable packer 47B2 - W/40K shear release FH Retrieva ble H78108 3511 2.380 8,499.7 5,992.1 39.79 Nipple - X 3.682 2.875" x 2.313" X-nipple Halliburt on 2.313 X Nipple 2.313 8,548.8 6,029.9 39.54 Mandrel PROD 5.560 2.875" x 1.5" MMG SLB MMG 2.366 8,856.4 6,265.0 39.92 Packer 5.960 Baker FH Retrievable packer 47B2 - W/40K shear release FH Retrieva ble H78108 3511 2.380 8,879.7 6,283.0 39.67 Nipple - X 3.682 2.875" x 2.313" X-nipple Halliburt on 2.313 X Nipple 2.313 8,893.3 6,293.4 39.52 Wireline Guide 3.510 WLEG Baker WLEG 2.390 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,946.4 2,362.1 52.72 1 GAS LIFT GLV RK 5.54 1,209.0 9/30/2023 SLB MMG 0.188 5,900.2 4,266.3 49.47 2 GAS LIFT GLV RK 5.54 1,207.0 9/30/2023 SLB MMG 0.188 7,845.4 5,519.4 48.10 3 GAS LIFT DMY RK 5.54 9/25/2023 SLB MMG 8,372.8 5,894.9 40.21 4 GAS LIFT OV RK 5.54 0.0 9/29/2023 SLB MMG 0.125 8,548.8 6,029.9 39.54 5 PROD DMY RK 5.54 9/25/2023 SLB MMG Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,586.0 8,678.0 6,058.6 6,129.2 UNIT D, C-4, C- 3, 1Y-18 10/9/1993 12.0 IPERF 4.5" SWS Guns, Spiral Phasing 8,718.0 8,733.0 6,159.7 6,171.1 C-1, 1Y-18 10/9/1993 12.0 IPERF 4.5" SWS Guns, Spiral Phasing 8,904.0 8,924.0 6,301.7 6,317.2 A-5, A-4, 1Y-18 8/24/1995 4.0 IPERF 2 1/8" SWS EnerJet, 180° Phasing 8,931.0 8,968.0 6,322.6 6,351.2 A-4, A-3, 1Y-18 10/9/1993 4.0 IPERF 4.5" SWS Guns, 180° Phasing 1Y-18, 10/5/2023 10:21:59 AM Vertical schematic (actual) PRODUCTION; 38.3-9,170.6 IPERF; 8,931.0-8,968.0 IPERF; 8,904.0-8,924.0 Nipple - X; 8,879.7 Packer; 8,856.4 IPERF; 8,718.0-8,733.0 IPERF; 8,586.0-8,678.0 Mandrel PROD; 8,548.8 Nipple - X; 8,499.6 Packer; 8,449.0 Seal Assembly; 8,427.6 Mandrel GAS LIFT; 8,372.8 Mandrel GAS LIFT; 7,845.4 SURFACE 47#/36#; 41.5- 6,139.9 Mandrel GAS LIFT; 5,900.2 Mandrel GAS LIFT; 2,946.3 CONDUCTOR; 42.0-121.0 Hanger; 35.9 KUP PROD KB-Grd (ft) RR Date 8/7/1993 Other Elev 1Y-18 ... TD Act Btm (ftKB) 9,187.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292239000 Wellbore Status PROD Max Angle & MD Incl (°) 52.89 MD (ftKB) 2,470.96 WELLNAME WELLBORE1Y-18 Annotation Last WO: End Date 9/26/2023 H2S (ppm) 367 Date 7/15/2019 Comment SSSV: TRDP 323-284 By Grace Christianson at 9:31 am, May 12, 2023 DSR-5/12/23 X 10-404 , ADL0025646 BOP test to 3000 psig Annular preventer to 3000 psig X MDG 6/9/2023 VTL 6/22/2023GCW 06/22/2023 06/223/23Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 08:57:05 -08'00' RBDMS JSB 062723 . STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r— Alter Casing 9 Change Approved Program Plug for Redrill r R;rforate New Pool r Repair Well Re-enter Susp Well r Other: tbq patch fir 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pi Exploratory r 193-1060 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22390-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 KRU 1Y-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9187 feet Plugs(measured) N/A true vertical 6523 feet Junk(measured) N/A Effective Depth measured 8981 feet Packer(measured) 8408, 8432, 8450, 8475, 8479 true vertical 6361 feet (true vertical) 5922, 5940, 5954, 5973, 5976 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 121' 121' SURFACE 6098' 9 5/8 6140' 4420' PRODUCTION 9132' 7 9171' 6510' 'SCANNED MAY I ,5 20 L. RECEIVED Perforation depth: Measured depth: 8586-8678, 8718-8733, 8904-8924,8931-8968 MAR 2 8 ?917 True Vertical Depth: 6059-6129,6160-6171, 6302-6317,6323-6351 AOGCC Tubing(size,grade, MD,and TVD) 2 7/8 ,L-80, 8865 MD,6272 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV=OTIS 4"SERIES 10 SELF EQUALIZING SAFETY VALVE @ 1805 MD and 1656 TVD PATCH-UPPER=2.74"WFT ER PKR(#CP350083),20.5'SPACER PIPE, ANCHOR(1.75" ID/25.08'OAL)@ 8408 MD and 5922 TVD PATCH-LOWER=2.74" ER PACKER(MIN ID 1.81" , OAL-2.86')@ 8432 MD and 5940 TVD PATCH-UPPER=2.72" ER PACKER, SPACER PIPE&SEAL ASS'Y(OAL=26.08'/1.75" MIN ID) @ 8450 MD and 5954 TVD PATCH-LOWER=2.74" ER PACKER(35"OAL/1.812" ID)@ 8475 MD and 5973 TVD PACKER=CAMCO 3.5 X 7 HRP-4-SP RETRIEVABLE PACKER @ 8479 MD and 5976 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17, Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kelly Lyons/Brent Rogers Email: n1617@conocophillips.com Printed NameKelly Lyons - Title: NSK Well Integrity Supervisor n,/- Signature /✓�� ( Phone:659-7535 Date WV-4 (7 Form 10-404 Revised 5/2015 Suhmit Original Only , ,f7'/7 Kn.- 57ib!i7- RBDMS t)' APR - 3 2017 • • y' RECEIVED ConocoPh i l l i ps 01 7 Alaska P.O. BOX 100360 fi�ri'i� G ANCHORAGE,ALASKA 99510-0360 CC March 21, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU development well 1Y-18 (PTD 193-106) for multiple retrievable patches set in the tubing above the packer. Please call Brent Rogers or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons ConocoPhillips Well Integrity Supervisor Enclosures • 1Y-18 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/16 (AC EVAL) TIFL- FAILED DUE TO A TOTAL IA FLUID LEVEL INFLOW OF 2962'AND PRESSURE INCREASE OF 50 PSI. Initial T/I/O=225/1300/1050. IA FL @ 8212' (8414' OV) Shut in WH/AL and stacked out T with lift gas. T/I/O= 1150/1195/880. IA FL @ 6886' (inflowed 1326') Bled AL line to 200 psi. Bled IA gas 60 min. T/I/0=1075/560/610. IA FL @ 5559' (inflowed 1327') T FL @ 7108' 15 min. reading T/I/O= 1075/580/610. IA FL @ 5417' (inflowed 142' &20 psi. increase) T FL @ same location. 30 min. reading T/I/O= 1075/610/610. IA FL @ 5250' (inflowed 167' &30 psi. increase) T FL @ same location. Final T/I/O= 1075/610/610 11/14/16 RIH WITH ACX. PERFORM BASELINE FROM SURFACE TO 8500' KB AT 100 FPM. LRS OPEN IA TO FLOWLINE. LOG PASS FROM 8500'TO 7700' KB AT 20 FPM. PERFORM STOP COUNTS. SAW NOISE SIGNATURE @ APPROX 8,420' KB (GLM#5, OV). LRS PRESSURE UP TUBING TO 2500 PSI. LLR OF 0.1 BPM. PERFORM STOP COUNTS. PERFORM PASS FROM 8500'-8300' ELMD. PRESSURE UP TUBING TO 3000 PSI. PERFORM PASS FROM 8500' -8300' ELMD. BLEED TUBING DOWN TO 1450. PERFORM PASS FROM 8500' - 8300' ELMD. MANIPULATED TUBING PRESSURES, BUT COULD NOT REPLICATE NOISE SIGNATURE AT GLM#5 AFTER FLUID PACKED. PRESSURE UP TO 2500 PSI. PERFORM PASS FROM 8500' -SURFACE ELMD AT 20 FPM. LRS FP IA WITH DIESEL. RDMO. JOB COMPLETE. DATA SENT TO TOWN FOR POST PROCESSING. 02/08/17 24 ARM CALIPER LOG PERFORM REPEAT PASS FROM 8519.5FT RKB TO 8475FT RKB PERFORM MAIN PASS FROM 8519.5FT RKD TO 5200FT RKB. SUSPEND LOGGING, POOH AND RDMO DUE TO HIGH WINDS AND PHASE 2 02/09/17 LOG 24 ARM CALIPER PERFORM MAIN PASS IN 4IN TUBING FROM 5750FT RKB TO SURFACE 03/11/17 SET CATCHER @ 8522' RKB PULLED OV @ 8414' RKB & PULLED CATCHER. SET 2.74" ER PACKER MID ELEMENT 8475' RKB. SET TEST TOOL IN LOWER PACKER @ SAME. READY FOR LRS TO CIRC OUT. IN PROGRESS. 03/12/17 PULLED ER TEST TOOL @ 8475' RKB. SET UPPER 2.74" ER PATCH ASS'Y MID ELEMENT 8050' RKB. SET TEST TOOL IN UPPER PACKER; CMIT 2500 PSI (PASS) PULLED TEST TOOL. IN PROGRESS. BEGIN CMIT INITIAL T/I/O = 550/575/100 LRS PT TBG TO 2500 PSI W/2.7 BBLS DSL. START=2625/2650/300 15 MINS =2600/2625/300 30 MINS =2590/2615/300 ( PASS ) • 1Y-118 • DESCRIPTION ggOuuF��WORK COMPLETED 03/13/17 SET 2.74" LOWER ER PACKER @8432�RKBYSET TEST TOOL IN LOWER PACKER @ SAME. CMIT TO 2500 PSI( PASS ) PULLED TEST TOOL. ATTEMPT SET UPPER PATCH ASS'Y; SETTING TOOL MALFUNTIONED. IN PROGRESS. BEGIN CMIT. INITIAL T/I/O =600/575/75 LRS PT TBG/ IA TO 2600 PSI W/ 1.7 BBLS DSL. START=2610/2600/250 15 MINS =2600/2575/250 30 MINS = 2600/2575/250 03/14/17 SET UPPER 2.74"WFT ER PKR (#CP350083), 20.5' SPACER PIPE, ANCHOR (#CPS35047) @ 8408' RKB. SET TEST TOOL @ SAME. MIT TBG TO 2500 PSI (PASS), CMIT T x IA TO 2500 PSI (PASS). PULLED GLV @ 7766' RKB &SET OV. JOB IN PROGRESS. MITT TO 2500. PRE T/I/O= 600/575/75. PSI UP w/0.7 BBLS. START=2510/675/75 15 MIN= 2450/675/75 30 MIN=2440/675/75 ***PASS*** CMIT T x IA TO 2500. PRE T/I/O= 1025/550/75 PSI UP w/2.1 BBLS. START= 2550/2500/225 15 MIN= 2525/2475/225 30 MIN= 2525/2475/225 ***PASS*** 03/21/17 (AC EVAL) Re-TIFL PASSED. Initial T/I/O = 160/1260/400 IA FL @ 7766' (OV). SI WH @ WV. SI lift gas @ manifold bldg. Stack T x IA 60 minutes. T/I/O = 1050/1115/200. IA FL @ same. Bled lift gas line to 200 psi. Bled IA to T/I/O = 1050/520/40 in 60 minutes. IA FL @ same. 15 min T/I/O = 1050/520/40. 30 min T/I/O = 1060/520/40 IA FL same. 45 min T/I/O = 1060/520/40. 60 min T/I/O = 1060/520/40 IA FL same. Final T/I/O = 1060/520/40. Executive 2 Weatherford retrievable patches above the packer were set to isolate leaks across the PBR Summary and area just under the gas lift mandrel at 8414'. A 25' patch was used across the PBR from 8475'to 8450' and a 24' patch was used across the GLM area from 8408' to 8432'. Patch integrity was confirmed with a followup TIFL. .,, KUP PROD • 1Y-18 ConocoPhillips a Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Ad Btm(ft88) cr..,,, valps 500292239000 KUPARUK RIVER UNIT PROD 52.89 2,470.96 9,187.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 11-18,3119/2017 3:4404 PM SSSV:TRDP 5 9/10/2016 Last WO: 8/7/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ----------------------------- - - ---- Last Tag:SLM 8,981.0 10/16/2014 Rev Reason:H2S,SET PATCHES&GLV CIO pproven 3/19/2017 HANGER;36.3 lei4° - Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread �I � CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 47#/36# 9 5/8 8.921 41.5 6,139.9 4,420.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.3 9,170.6 6,509.8 26.00 L-80 BTC-MOD CONDUCTOR;42.0-1210 I � I isTubing Strings Tubing Description String Ma...10(in) Top(ftKB) Set Depth(ft.Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection SAFETY VLV;1,6052 1,..27 '( TUBING 4x3.5x2.875 4 3.476 36.3 8,865.6 6,272.1 11.00 J-55 BTC-MOD iT. Completion Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(") Item Des Com (in) 36.3 36.3 0.05 HANGER FMC GEN IV TUBING HANGER 4.000 1,805.2 1,656.0 46.18 SAFETY VLV OTIS 4"SERIES 10 SELF EQUALIZING SAFETY 3.313 GAS LIFT;3,166.7 VALVE;CLOSURE TEST OK 4/24/98 5,669.4 4,116.9 49.34 XO Reducing CROSSOVER 4 x 3.5 2.992 8,455.6 5,958.3 39.93 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 GAS LIFT;5,677.4 8,465.8 5,966.1 39.92 PBR CAMCO PBR w/10'STROKE 2.937 li!I 8,479.2 5,976.4 39.88 PACKER CAMCO 3.5 x 7 HRP-4-SP RETRIEVABLE PACKER 2.937 8,572.0 6,047.8 39.53 BLAST RINGS CARBIDE BLAST RINGS(4) 2.992 8,719.1 6,160.5 40.44 BLAST RING CARBIDE BLAST RING(1) 2.992 SURFACE47#(36#;41.599 1 6,13 _ 8,787.8 6,212.7 40.62 SLEEVE CAMCO CB-1 SLIDING SLEEVE CLOSED 10/17/2007 2.750 8,835.6 6,249.1 40.13 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS LIFT;6,970.2 - 8,836.4 6,249.7 40.12 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.441 _. 8,838.4 6,251.3 40.10 PACKER BAKER D PERMANENT PACKER w/5'SBE 3.250 8,842.0 6,254.1 40.07 SBE BAKER SEAL BORE EXTENSION 3.250 GAS LIFT;7,766.0 4 8,855.2 6,264.2 39.93 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,864.9 6,271.6 39.83 SOS CAMCO PE-500 SHEAR OUT SUB,ELMD TTL 8866' 2.441 during PPROF on 8/30/2007 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,414.31 :16. Top(ND) Top Incl PATCH-UPPER;6,408.0 Top(ftKB) (ftKB) 7) Des Corn Run Date ID(in) 8,408.0 5,921.8 40.12 PATCH- 2.74"WFT ER PKR(#CP350083),20.5'SPACER 3/14/2017 1.750 I UPPER PIPE,ANCHOR(#CPS35047,1.75"ID/25.08'OAL) PATCH-LOWER;8,432.0 8,432.0 5,940.2 39.99 PATCH- 2.74"ER PACKER(SN:CP350118/MIN ID 1.81", 3/13/2017 1.810 LOWER OAL-2.86') 8,450.0 5,954.0 39.94 PATCH- 2.72"ER PACKER(SN:CP350036)SPACER PIPE& 3/12/2017 1.750 NIPPLE;8,455.6 II a a UPPER SEAL ASS'Y(SN:CP535045)(OAL=26.08'/1.75" PATCH-UPPER;8,450.0 :I MIN ID) PBR;8,465.8 l 8,475.0 5,973.1 39.90 PATCH- 2.74"ER PACKER(SN:CP350106/35"oal/1.812" 3/11/2017 1.812 Illi LOWER ID) PATCH-LOWER,8,475.0 I 8,522.0 6,009.3 39.65 PATCH- 3-1/2"PARAGON 2 UPPER PACKER(1.62" 11/27/2013 1.620 UPPER 10/23.01 OAL) PACKER;8479.2 8,545.0 6,027.0 39.55 PATCH- 3-1/2"PARAGON 2 LOWER PACKER(1.62" 11/23/2013 1.620 LOWER ID/4.01'OAL) al Perforations&Slots PRODUCTION;8,525.7 Shot PATCH-UPPER;8,522.0 ' ; Dens Top(TVD) BtmKB( (shotstf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Cam PATCH-LOWER;8,545.0 I 6,586.0 8,678.0 6,058.6 6,129.2 UNIT D,C-4, 10/9/1993 12.0 IPERF 4.5"SWS Guns,Spiral C-3,1Y-18 Phasing 8,718.0 8,733.0 6,159.7 6,171.1 C-1,1Y-18 10/9/1993 12.0 IPERF 4.5"SWS Guns,Spiral IPERF;8,586.0-4678.0- I Phasing 8,904.0 8,924.0 6,301.7 6,317.2 A-5,A-4,1Y- 8/24/1995 4.0 IPERF 2 1/8"SWS EnerJet,180 I 18 deg.Phasing 8,931.0 8,968.0 6,322.6 6,351.2 A-4,A-3,1Y- 10/9/1993 4.0 IPERF 4.5"SWS Guns,180 IPERF;8,778.0-8,733.0- mi.f. 18 deg.Phasing 111 Mandrel Inserts . St i eti on Top(TVD) Valve Latch Port Size TRO Run SLEEVE;8,767.8 - e N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 3,186.7 2,509.5 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,417.0 3/15/2017 2 5,677.4 4,122.1 CAMCO MMG-2 11/2 GAS LIFT GLV RK 0.188 1,291.0 3/15/2017 3 6,970.2 4,942.4 CAMCO MMG-2 11/2 GAS LIFT GLV RK 0.188 1,274.0 3/15/2017 4 7,766.0 5,466.5 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 3/14/2017 15 8,414.3 5,926.6 CAMCO MMG-2 1 1/2 GAS LIFT OPEN 3/11/2017 SEAL ASSY;8,836.4 - 6 8,525.7 6,012.1 CAMCO 3.5x 11/2 PROD DMY RK 0.000 0.0 7/15/2012 5 PACKER;8,838.4 Notes:General&Safety SBE;8,842.0 .�.. End Date Annotation ill 10/25/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION ® 10/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;8,855.2 _ . ■ SOS;8,864.9 'F' IPERF;8,904.0-8,924.0 IPERF;4931.0-8,968.0 PRODUCTION;38.35,770.6 - • v z (1 ~ N > C Vf D C • � p � °rW v , _00 3 • W v- "6 (6 OJ CO C r T- N.- 0 • ,,,(:) v E u 0) > a Q C o W +J• C a - -6 1- 0 u OU v T r Q o• Q (� r N N- N f` r v) a) N O� 1- m au o _ 6 N _C .0 LL LL LL LL LL LL LL C ro C U N L N Q N M CO a) N 0 -0 CO p +C+ (/i Z U Z g 0 F.2 j E 6 '1313 VI U ro O G G G 0 G 13 CI C a.) p a J J J J J J J C `�- U W W W W W W W 42 N a) 'C a) 'o u a J J J J J J J U) iF < < < < < < < v 'n C w O Z Z Z Z Z Z Z CU 0 v O v eW:, LL LL LL LL LL LL LL cc — -0 _ > E L U E (1 U '0 C O N r6 0. O � 2 a) Y U r C a o u ~ u < aai a a o a e `° 14 r c..) a M a 0 7r C d o Q. LL fl- £ N N Ci E Zr.' 0 0 u I C r4-,o cq ii OS O 0 z 9 ° apros — . z —, tx41 y W ° ` = V a J J J 0 J J J I a 5 ro - 2 3 3 3 ELaJ 3 3 3 L FI C`� in W 2 bA 0 IC Ci VT r CLIXLY1rX1r1r E W W W W W W W .:... W > > > > > > t Zin Y Y Y Y Y Y Y Ci CLCLCCWCLrYCLN Q Q Q Q Q Q Q T a a a a a a a 0fl W `` `y t V YYYYYYMMDDDDD Y u 019 Mir V tip m ce W (O N- co p O co (O X N .'� W Co cs o 0 0 Q o o o E 0 - - . . . . v �� O O O O O o o o ''''' G: r r O r t: 1-.- co C W QWro Cr co vl Q O O O O O O C ,nu o 0 o co 0 0 0 0.0a N- 6 1. ,- o (O m '71 E { — co N Al C) co CO i 0 111\'7 ▪ O N N () O O U O M M N M CO N N N N N N N Nt. 4 SM O) CA C) 6) O) Q) co N ER O N N N N N N � U P ' O O 0 0 0 0 3 4 C It) LC) ([) 1!) U) in U) Q O L E�� v aa W Y W — i C 1- 0 Q N t6 3 d 0 aj (-1 Z Q co co " N W 0 0 4, N a+ N a Z b bo A, z YC v I- '� a s p N 4 J N tj N LLJ Cj tj E Z a) rao A Y" d0 .. 1 rl L ^ :,, ,- C C 1a vi .0 V rl C p co ._ a) ro O CID 0. to d c.:. a a Q RECEIVED tcv3- t°G • • 27 .673 FEB 032017 WELL LOG TRANSMITTAL#903663707 AOGCC To: Alaska Oil and Gas Conservation Comm. February 1, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED 2../Anchorage, Alaska 99501 M. K BEND/201R RE: Leak Detect Log with ACX: 1Y-18 me JUN 3 0 2(J17 Run Date: 11/14/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-18 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22390-00 *Re-Deliver due to incomplete digital data,E-Set#27873 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'F1'BNTION OF: Halliburton Wireline& Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signedy 411 / ' ,/, Z7SI3 WELL LOG TRANSMITTAL#903663707 To: Alaska Oil and Gas Conservation Comm. January 5, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 092017 DMAT.KA7LOoGJEDDs RE: Leak Detect Log with ACX: 1Y-18 AOGCC Run Date: 11/14/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-18 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22390-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-22390-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Si ned:liviti2-."7-4.)907-273- g STATE OF ALASKA ALA t OIL AND GAS CONSERVATION COW. .ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other Set Patch 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 r Exploratory r 193-106 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22390-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 1Y-18 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 9187 feet Plugs(measured) 8855 true vertical 6523 feet Junk(measured) none Effective Depth measured 9084 feet Packer(measured) 8479, 8838 true vertical 6442 feet (true vertical) 5976,6251 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 47#/36; 6098 9.625 6140 4420 PRODUCTION 9132 7 9171 6510 RECEIti i ' SCANNED JAN 2 ',ry `':014 {FE- L 6 2013 Perforation depth: Measured depth: 8586-8678, 8718-8733,8904-8924,8931-8968 True Vertical Depth: 6059-6129,6160-6171,6302-6317,6323-6351 AWAwilkS Tubing(size,grade,MD,and TVD) 4x3.5x2.875, L-80,8865 MD,6272 ND Packers&SSSV(type,MD,and ND) PACKER-CAMCO 3.5 X 7 HRP-4-SP RETRIEVABLE PACKER @ 8479 MD and 5976 ND PACKER-BAKER D PERMANENT PACKER W/5'SBE @ 8838 MD and 6251 ND SSSV-OTIS 4"SERIES @ 1805 MD and 1656 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in _ Subsequent to operation 172 934 149 - 180 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ . Service r Stratigraphic r 16.Well Status after work: Oil P- . Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact John Peirce Cad 265-6471 Email John.W.Peirce a(�.conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 Date . ,t, — 12/-13/1.3 / f/.� r 1/'": '4y RBr ML DEC 16 CQ Form 10-404 Revised 10/2012 1 / 1/ / / # Submit Original Only 1Y-18 Well Work Summary • DATE SUMMARY 9/19/2013 BAILED THROUGH SCALE BRIDGE FROM 8730-8742'SLM &TAG X-OVER @ 8336' RKB. IN PROGRESS. 9/20/2013 PULL 2.25" SV @ 8855' RKB; MEASURE BHP (A/C)@ 8936' RKB (2700 psi)&8530' RKB (2566 psi); BRUSH AND FLUSH TBG PATCH INTERVAL @ 8500-8550' RKB & ATTEMPT TO DRIFT W/25'X 2.75" DMY PATCH (UNABLE TO PASS 6116' RKB); DRIFT TBG W/4'X 2.75" DMY PACKER TO 8591' RKB. IN PROGRESS. 9/21/2013 DRIFTED TBG W/5'x 2.78"& 15'x 2.5" BAILER (DUMMY PATCH DRIFT)TO 8591' RKB. READY FOR E-LINE CALIPER. 9/24/2013 RUN CALIPER F/8836' RKB TO SURFACE. JOB COMPLETE 11/7/2013 PERFORMED FILL CLEANOUT FROM 8920'CTMD TO HARD TAG AT 9064'CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 2 BPM (EST 110'OF RATHOLE), MAINTAINED 1:1 RETURNS THOUGHOUT CLEAN-OUT. MODERATE SOLID CONCENTRATIONS OBSERVED. EST TOTAL SOLIDS VOLUME AT 5.5 BBLS, WELL LEFT SI & F/P, READY FOR DSL TBG PATCH, JOB IN PROGRESS. 11/23/2013 SET PARAGON 2 LOWER PACKER CENTER ELEMENT @ 8545' RKB. CCL TO MID ELEMENT=25'. CCL STOP DEPTH=8520' RKB...JOB IN PROGRESS. 11/27/2013 SET 2.73" UPPER PARAGON II PACKER @ 8522' RKB. UPPER SECTION 23' OAL...JOB IN PROGRESS 11/28/2013 SET PARAGON II TEST TOOL IN TOP OF PATCH 8522' RKB. LRS PERFORMS PASSING MIT-T TO 2500#...JOB COMPLETE. . i KUP PROD 1Y-18 .- _ ConocoPhi lips $ Well Attributes Max Angle&MD TD Alaska,Inc. Welmore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Lr.O4v+n11,1.K" 500292239000 IKUPARUK RIVER UNIT PROD 52.89 2,470.96 9,187.0 ••• Comment I H2S(ppm) I Date Annotation 'End Date KB-Grd(R) 1 Rig Release Date W-18.12/10/2013 6.igo#PM SSSV:TRDP Last WO: I 817/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date , Last Tag:SLM 8,895.0 1 7/142012 Rev Reason:SET PATCH I lehallf I 12/8/2013 HANGER;363- I _ Casing Strings Casing Description OD(in) ID(in) Top IRKS) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED �I� � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L-.Grade Top Thread SURFACE 47#/36# 9 5/8 8921 41.5 6,139.9 4,420.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(1...Grade Top Thread PRODUCTION 7 6.276 38.3 9,170.6 6,509.8 26.00 L-80 BTC-MOD ,--Tubing Strings CONDUCTOR;42.6121.0 t Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(IbMt) Grade Top Connection TUBING 4x3.5x2.875 4 3.476 36.3 8,865.6 6,272.1 11.00 J-55 BTC-MOD SAFETY VLV;1,e05.2 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Coin (in) 36.3 363 0.05 HANGER FMC GEN IV TUBING HANGER 4.000 1,805.2 1,656.0 46.18 SAFETY VLV OTIS 4"SERIES 10 SELF EQUALIZING SAFETY 3.313 VALVE;CLOSURE TEST OK 4/24/98 5,669.4 4,116.9 49.34 XO Reducing CROSSOVER 4 x 3.5 2.992 GAS LIFT;3,186.7 Ir.- 8,455.6 5,958.3 39.93 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 8,465.8 5,966.1 39.92 PBR CAMCO PBR w/10'STROKE 2.937 8,479.2 5,976.4 39.88 PACKER CAMCO 3.5 x 7 HRP-4-SP RETRIEVABLE PACKER 2.937 GAS LIFT;5,677.4 8,572.0 6,047.8 39.53 BLAST RINGS CARBIDE BLAST RINGS(4) 2.992 I 8,719.1 6,160.5 40.44 BLAST RING CARBIDE BLAST RING(1) 2.992 8,787.8 6,212.7 40.62 SLEEVE CAMCO CB-1 SLIDING SLEEVE CLOSED 10/17/2007 2.750 8,835.6 6,249.1 40.13 XO Reducing CROSSOVER 3.5 x 2.875 2.875 SURFACE 4781366;41.5- . 8,836.4 6,249.7 40.12 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.441 6,1399 8,838.4 6,251.3 40.10 PACKER BAKER D PERMANENT PACKER w/5'SBE 3.250 GAS LIFT;6970.2 8,842.0 6,254.1 40.07 SBE BAKER SEAL BORE EXTENSION 3.250 II 8,855.2 6,264.2 39.93 NIPPLE CAMCO D NIPPLE NO GO 2.250 ,• 8,864.9 6,271.6 39.83 SOS CAMCO PE-500 SHEAR OUT SUB,ELMD TTL @ 8866' 2.441 during PPROF on 8/30/2007 GAS LIFT;7.766.0 B Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ■ Tap(ND) Top Inc! Top(ftKB) (ftKB) (°) Des _ Com Run Date ID(in) I. 8,522.0 6,009.3 39.65 PATCH PARAGON II PATCH 11/27/2013 1.600 8,855.2 6,264.1 39.93 PLUG 2.25""D"CAT STANDING VALVE 7/15/2012 0.000 GAS LIFT,8,414.3 all al Perforations&Slots U Shot Dens NIPPLE;8,4556 Top(TVD) Bbn(TVD) (shotsM Top(ftKB) Bier(ftKB) MB) (flK8) Zone Date q Type Corn 6,465.6 8,586.0 8,678.0 6,058.6 6,129.2 UNIT D,C-4, 10/9/1993 12.0 IPERF 4.5"SWS Guns,Spiral C-3,1Y-18 Phasing PACKER;8,4792 j__1 8,718.0 8,733.0 6,159.7 6,171.1 C-1,1Y-18 10/9/1993 12.0 IPERF 4.5"SWS Guns,Spiral Phasing 8,904.0 8,924.0 6,301.7 6,317.2 A-5,A-4,1Y- 8/24/1995 4.0 IPERF 2 1/8"SWS EnerJet,180 E;Flki 18 deg.Phasing PRODUCTION;8,525.7- PATCH;8,522.0 8,931.0 8,968.0 6,322.6 6,351.2 A-4,A-3,1Y- 10/9/1993 4.0 IPERF 4.5"SWS Guns,180 18 deg.Phasing Mandrel Inserts St at! C IPERF;8,586.0-8,678,S�f on Top(TVD) Valve Latch Port Size TIRO Run m _ Top(ftKB) (RKB) Make Model OD(!n) Sery Type Type (in) (psi) Run Date - 1 3,186.7 2,509.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,265.0 10/2/2006 2 5,677.4 4,122.1 CAMCO MMG-2 1 1/2 GAS LIFT GLV RK 0.250 1,275.0 10/2/2006 3 6,970.2 4,942.4 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 10/2/2006 !PERF;8,718.0-8,733.0 4 7,766.0 5,466.5 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 3/12/2005 5 8,414.3 5,926.6 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 09 9/25/2006 Witi 6 8,525.7 6,012.1 CAMCO 3.5 x 1.5 1 1/2 PROD DMY RK 0.000 0.0 7/15/2012 Notes:General&Safety I i. End Date Annotation SLEEVE;8,787.8 10/25/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION U 10/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 ■ All I SEAL ASSY;8,836.4 ■ PACKER;8,838.4 SBE;8,842.0 ■ PLUG;8,855.2 U NIPPLE;8.855.21 II • SOS;8,864.9 IPERF;8,9049.8,924.0 IPERF;8,931.0.8,968.0 PRODUCTION;38.3-9,170.6 1`13- k06 ! • 2 53CM DATA LOGGED WELL LOG TRANSMITTAL ata2o13 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 27, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 4.ECEPVEn OCT 10 Lul: RE: Multi Finger Caliper(MFC): 1Y-18 Run Date: 9/24/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook,Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook@halliburton.com 1Y-18 Digital Data(LAS),Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22390-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. $(A{�NE� l 4 J Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: \°1\O I‘3 Signed: �,QeG� _,-~;; ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: i Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, `~ M.J. Loveland • ~'~~~N~~M AUi~ ~ ~. 2008 ConocoPhillips Well Integrity Projects Supervisor s • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • ~tik~-~- - Well Job # Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. '~~_._ _ a ~~,1, ~ l; `~ ~3 ~ G ~ ~ ~,~1~~ NC~i~ ~ ~ 2002 Log Description N0.4445 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 995r01~ ~, i~ Field: Kuparuk ~~3 Date BL Color CD 10/15/07 2N-343 iREDO) 11745232 MEM INJECTION PROFILE ` 'Z C - 08108107 1 1B-14 11837493 PRODUCTION PROFILE •C - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE d - 08/30107 1 1Y-18 11837499 PRODUCTION PROFILE ~ 08/30/07 1 1G-14 11839652 INJECTION PROFILE ~ ~j- ~ 08131/07 1 1A-01 NIA USIT - 08/31/07 1 1Y-04 11839653 INJECTION PROFILE fi5 09101107 1 1Y-32 11839655 PRODUCTION PROFILE ~ - 09/02/07 1 2T-TAB-01 11839656 INJECTION PROFILE C - 09103107 1 2K-25 11846439 INJECTION PROFILE U = ( - 09/06/07 1 2K-18 11846440 INJECTION PROFILE / -~(~ 09/07107 1 1B-18 11846441 PRODUCTION PROFILE ~ - (D 09/08/07 1 2T-20 11846442 PRODUCTION PROFILE ~ -- 09/09107 1 2N-310 11850433 SONIC SCANNER 7b'~ -U Z5 09/16/07 1 2N-310 11850433 SONIC SCANNER-FMI ~' C~`~ (~ 09176107 1 1J-176 11846443 USIT ~ -p 09/17107 1 1E-29 N/A UCI ~ - ~ 09/19/07 1 3F-21 11837503 RST! WFL 09120/07 1 2B-10 11839661 INJECTION PROFILE ~ - 09122107 1 1G-05 11837506 INJECTION PROFILE JZC - 09/23/07 1 2H-13 11839662 INJECTION PROFIL ~ - 09/23/07 1 1B-05 11837508 INJECTION PROFILE ~ j„C 09/24/07 1 3H-08 11839663 PRODUCTION PROFILE tj 09/24/07 1 1Y-31 11839664 PRODUCTION PROFILE (~'i - 09/25107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - ~( 09127!07 1 2V-08A 11837511 ISOLATION SCANNER •4fz(_ 09!28107 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE - (~ 09/30/07 1 • .:' (' Mike Mooney ( Wells Group Team Leader Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 ConocoPh ill i pS Phone: 907-263-4574 December 17,2003 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 1 Y -18 (APD # 193-106) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 Y -18. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 11(, 11~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 5 2004 Alaska Oil & Gas Cons. Commission Anchorage ,\;iÇA~N\i!Ë[) JAt.J 2 «J 2004 l) ~ \ G \ N A L ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D Alter Casing D Repair Well D Plug Perforations D Stimulate 0 Time Extension D Other D Change Approved Program D Pull Tubing D Perforate New Pool 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 193-106/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22390-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 107' 1Y-18 8. Property Designation: 10. Field/Pool(s): ADL 25641, ALK 2572 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9187' feet true vertical 6523' feet Plugs (measured) Effective Depth measured 9045' feet Junk (measured) true vertical 6411' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 6033' 9-5/8" 6140' 4420' PROD. CASING 9062' 7" 9169' 6509' Perforation depth: Measured depth: 8586'-8678', 8718'-8733', 8904'-8924', 8931'-8968' true vertical depth: 6059'-6129',6160'-6171',6302'-6317',6323'-6351' Tubing (size, grade, and measured depth) 4" / 3.5" / 2-7/8", J-55/L-80, 8866' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 3 1/2 X 7 HRP-4-SP RETR; BAKER 2 7/8" X 7" '0' PERM PKR WIRE eE'tIV~, D sssv= sssv SSSV= 1805' 12. Stimulation or cement squeeze summary: JAN 0 5 2004 Intervals treated (measured) 8855' . . . lU....ltft nit & Gas Cons CommisSion Treatment descriptions including volumes used and final pressure: 94M# In fØII~""'" . . A 13. Representative Daily Average Production or Injection Data' ., Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 150 608 125 - 153 Subsequent to operation 219 465 244 - 253 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 foregoing is true and correct to the best of my knowledge. Sundry Number or NIA it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature "A' ~ 1.Jl_- . A Phone Date J z) z.. Z/6..3 ff/ .. , ""'.. r '" Preoared bv Sharon AlIsun.Drak~ 26.'?4612 - . "~\NAL fB)MSBFL JAN 10 -¡10M Form 10-404 Revised 2/2003' 0 R \ (:, , . .1 , . SUBMIT IN DUPLICATE ( ( ConocoPhillipsAlaska, Inc. KRU 1 Y -18 1Y.18 API: 500292239000 PROD sssv SSSV T .e: TRDP 8/7/1993 (1805-1806, Annular Fluid: 00:4.000) L t U d t as a e: Bottom TVD Thread 9169 6509 3001 2395 6140 4420 121 121 Bottom Wt Thread 5669 11.00 BTC-MOD 8488 9.30 EUE 8RD MOD 8836 9.30 EUE 8RD MOD 8866 6.50 EUE 8RD MOD Interval TVD Zone Status Ft SPF Date T e Comment 8586 - 8678 6059 - 6129 UNIT 92 12 10/9/1993 IPERF 4.5" SWS Guns, Spiral D,C-4,C-3 Phasin 8718 - 8733 6160 - 6171 C-1 15 12 10/9/1993 IPERF 4.5" SWS Guns, Spiral Phasin 8904 - 8924 6302 - 6317 A-5,A-4 20 4 8/24/1995 IPERF 21/8" SWS EnerJet, 180 de . Phasin 8931 - 8968 6323 - 6351 A-4,A-3 37 4 10/9/1993 IPERF 4.5" SWS Guns, 180 deg. Phasin Gas Lift Mandrels/Valves. NIP St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv (8456-8457, Mfr Run Cmnt 00:3.500) ~ 1 3187 2510 Merla TMPD GLV 1.0 BK 0.156 1347 11/27/2003 2 5677 4122 Cameo MMG-2 GLV 1.5 RK 0.250 1328 11/27/2003 PKR 3 6970 4942 Cameo MMG-2 GLV 1.5 RK 0.250 1310 11/27/2003 (8479-8480, 4 7766 5466 Camco MMG-2 GLV 1.5 RK 0.250 1291 11/27/2003 00:6.156) 5 8414 5926 Cameo MMG-2 OV 1.5 RK 0.250 0 11/27/2003 St MD TVD Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt DMY 1.5 9/7/1995 Closed Descri tion I D Perf Otis 4" Series 10 Self Equalizing 3.313 (8586-8678) CLOSURE TEST OK 4/24/98 8456 5959 NIP Camco 'W-1' Selective Landin 2.813 Perf 8466 5966 PBR Cameo wI 10' stroke 2.938 (8718-8733) I 8479 5976 PKR Cameo 3 1/2 X 7 HRP-4-SP RETR 2.938 8787 6212 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE' CLOSED 12/25/98. 2.750 8838 6251 PKR Baker 27/8" X 7" 'D' Perm PKR wI 5' SBE 3.250 8855 6264 NIP CAMCO D-Ni Ie, NOGO Profile 2.250 8865 6272 SOS Cameo PE-500 2.438 8866 6272 m 2.438 PKR (8838-8839, 00:6.156) NIP (8855-8856, 00:2.875) , I TUBING I (8836-8866, - 00:2.875, 10:2.441) Perf (8904-8924) Perf (8931-8968) ( 1Y-18 Event History ( Date Comment 10/26/03 ATTEMPT TO DRIFT W/ 2.60" FLUTED CENT TO 2600# HUNG UP ---- HAD TO PUMP AND FLOW WELL TO WORK FREE---- RECOVERED ALL TOOLS----LRS FREEZE PROTECT FL. AND TUBING, LDFN ---- LEAVE SHUT IN, INFORM PAD OP. [, TAG, PRESSURE DATA] 10/27/03 DRIFTW/2.30 GAUGE RIG TO CAMCO D-NIPPLE @ 8821' WLM------ LRS DISPLACED W/55 BBLS DIESEL- ---- SET CAMCO W/ 2.25 II CCS LOCK W/2.2511 X-EQUILIZING, DIVICE AND HES SHUT IN TOOL W/ SPARTEK GAUGES @ 8821' WLM (8855 RKB) ----- 40 HR TIMER STARTING TIME 11:24 11/19/03 FREEZE PROTECT FLOWLINE W/ DIESEL. PUMP 10 BBLS METH, 20 BBLS DIESEL DOWN TBG. TAG FILL AT 89681 RKB WITH 2.19 CENT, S.BLR. SAMPLE OF CARBO LITE. SET 2.25 CA2 PLUG AT 8855' RKB. 11/20/03 PUMPED 57 BBLS DIESEL FIRST, FOLLOWED BY 205 SEAWATER, THEN 30 BBLS DIESEL DOWN TBG, UP IA AND RETURNS TO FLOWLINE. PUMPED 20 BBLS DIESEL INTO FLOWLINE FOR FREEZE PROTECT. 11/21/03 PUMP PRE FRAC SAND PLUG TO A WINDOW OF 8930' TO 8920' 1000# 20/40 SAND. 11/22/03 TAG SAND TOP AT 8882' SLM + 41' = 8923' RKB. SET FRAC SLEEVE AT 1778' SLM /1805' RKB 11/23/03 PUMPED A SAND FRACTURE TREATMENT. PUMPED BREAKDOWN, SCOUR STAGE, AND DATAFRAC. PUMPED FRAC JOB, SAW TSO AT 35 MINUTES INTO JOB, HAD TSO WITH 94M# IN FORMATION, 8 PPA ON PERFS. LEFT 2M# IN WELLBORE. LOST HALF OF THE TREESAVER CUPS IN THE WELL. [FRAC] 11/24/03 CLEAN OUT TO 9054' RKB USING SLICK WATER WITH GEL DIESEL SWEEPS. WASH GLM'S ON THE WAY OUT OF THE HOLE. [FCO] 11/26/03 TAGGED FILL @ 9045' RKB, 77' OF RAT HOLE, PULLED FRAC SLEEVE @ 1805' RKB, PULLED DV'S @ 5677',6970' &7766' RKB, IN PROGRESS [TAG, SSSV WORK, GLV] 11/27/03 PULLED DV'S @ 8414' & 3187' RKB. INSTALL NEW GLD IN STA #1,2,3,4,5. GIVE TO DSO TO BOL. Page 1 of 1 12/12/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate ~ Plugging_ Perforate X Pull tubing __ Alter casing __ Repair well ~ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 210' FNL, 1734' FWL, Sec 1, T11N, R9E, UM At top of productive interval 87' FNL, 44' FEL, Sec 35, T12N, R9E, UM At effective depth 230' FSL, 122' FEL, Sec 26, T12N, R9E, UM At total depth 292' FSL, 136' FEL, Sec 26, T12N, R9E, UM Present well condition summary Total Depth' measured true vertical 9187 6523 12. X 6. Datum elevation (DF or KB) RKB 1 O7 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-18 9. Permit number/approval number 93-106 10. APl number 50-029-22390 11. Field/Pool feet feet feet . Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 9 0 8 4 true vertical 6442 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 121' 16" 6104' 9.625" 9127' 7" measured 8586'-8678', true vertical 6059'-6129', feet Junk(measured) None '"'-' feet Cemented Measured depth Tru~..~:ve~i6~l~ depth 250 SX PFC CMT 1 21 ' 900 SX PF E & 6140' 900 SX Class G CMT 150 SX ASI CMT Top Job 91 6 9' 250 SX Class G CMT 121' 4420' 6492' 8718'-8733', 8904'-8924', 8931'-8968' 6160'-6171', 6300'-631 4', 6323'-6351' 5661' & 2.875", 6.5#, J-55/L-80 @ 8858' SSSV: Otis Series 10 SE@ 1797' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55/L-80 @ 8828' & 4", 11#, J-55 @ Packers and SSSV (type and measured depth) PKR: Camco HRP-4-SP @ 8471' & Baker 'D' @ 8830'; 13. Stimulation or cement squeeze summary Perforated "A" Sand 'interval on 08/24/95. Intervals treated (measured) 8904'-8924' Treatment description including volumes used and final pressure Shot using 2-1/8" EJ II @ 4 spf, 0©, Ph, oriented 90© cw f/ Iowside. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 159 165 402 1128 1 75 167 467 1144 Tubing Pressure 187 202 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date SUBMIT IN'DUPLICATE ARCO Alaska Inc. (_..,. KUPARUK RIVER UNIT ' "'-' '~WELL SERVICE REPORT ,~ K1(1Y-18(W4-6)) WELL JOB SCOPE JOB NUMBER 1 Y- 1 8 PERFORATE, PERF SUPPORT 0822950516.2 DATE DAILY WORK UNIT NUMBER 08/24/95 PERF'A' SAND DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 ~ Yes (~ No (~) Yes O No WEST PAISE FIELD AFC# CC# DAILY COST ACCUM CObil Signe/~ % ESTIMATE 998452 230DS10YL $7,937 $7,937 ~IL ~ b---¢. ~_V-.-~ Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann l lnitial Outer Ann I Final Outer Ann~ 250 PSI 1000 PSI 1100 PSI 1100 PSII 0 PSII 0 PSI DAILY SUMMARY I IPERF 'A' SAND INTERVAL 8904' - 8924' USING 2-1/8" EJ W/BH CHARGES, 4 SPF, 0 DES PH, ORIENTED +/- 90 DES F/ I LOWSIDE TIME 14:30 15:30 15:45 17:00' LOG ENTRY ARR. ON LOC W/SWS. RU SWS PT'LUB TO 3000#. TEST OK. RIH W/PERF GUN #1 - WGT BAR, MPD, CCL, 20' 2-1/8" EJ II W/BH CHARGES, 2 SPF, 0 PH, ORIENTED 90 DES CW F/LOWSIDE. ON BOT TO TIE-IN TO E-LINE SET PKR AND TBS TAIL; SHORT JOINTS ARE BEHIND TUBING. POSITION CCL @ 8899.5' TO SHOOT 8904' - 8924'. WELL 400# UNDERBALANCED 1 7:1 5 GUN FIRED; POH 1 7:45 AT SURF W/GUN #1; ALL SHOTS FIRED. 1 8:1 5 RIH W/GUN #2 - 2 WGT BARS, MPD, CCL, 20' 2-1/8" EJ II W/BH CHARGES, 2 SPF, 0 PH, ORIENTED 90 DES CCW F/LOWSIDE 19:15 19:20 1 9:45 AT SURF W/GUN #2; ALL SHOTS FIRED. 20'1 5 RDFN. ON BOT TO TIE-IN. POSITION CCL @ 8899.5' TO SHOOT ,8904' - 8924'; WELL 400# UNDERBALANCED. GUN FIRED; POH. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging_ Perforate__ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic __ Service X 4. Location of well at surface 210' FNL, 1734' FWL, Sec 1, T11N, R9E, UM At top of productive interval 87' FNL, 44' FEL, Sec 35, T12N, R9E, UM At effective depth 230' FSL, 122' FEL, Sec 26, T12N, R9E, UM At total depth 292' FSL, 136' FEL, Sec 26, T12N, R9E, UM NAL 12. Present well condition summary Total Depth: measured true vertical 9187 6523 feet feet 6. Datum elevation (DF or KB) Effective depth: measured 9 0 8 4 true vertical 6442 feet feet RKB 107 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-18 9. Permit number/approval number 93-106 10. APl number 5o-029-22390 Casing Length Structural Conductor 1 2 1' Surface 61 0 4' Intermediate Production 91 2 7' Liner Perforation depth: measured 8586'-8678', true vertical 6059'-6129', Tubing (size, grade, and measured depth) Size 16" 9.625" 7" Plugs (measured) None 11. Field/Pool Kuparuk River Oil Fie!d/Pool "~ i--,? !1.4 ~ ;; i~ ~'?, Junk (measured) None Cemented Measured depth 250 SX PFC CMT 1 21 ' 900 SX PF E & 61 40' 900 SX Class G CMT 150 SX ASI CMT Top Job 91 6 9' 250 SX Class G CMT 8718'-8733', 8904'-8924', 8931'-8968' 6160'-6171', 6300'-6314', 6323'-6351' , /',:;,';h:'.:v':} ~. True vertical depth 121' 4420' 6492' 3.5", 9.3#, J-55/L-80 @ 8828' & 4", 11#, J-55 @ 5661' & 2.875", 6.5#, J-55/L-80 @ 8858' Packers and SSSV (type and measured depth) PKR: Camco HRP-4-SP @ 8471' & Baker 'D' @ 8830'; SSSV: Otis Series 10 SE@ 1797' 13. Stimulation or cement squeeze summary Re-Fracture "A" Sand on 09/04/95. Intervals treated (measured) 8931 '-8968' 8904'-8924' ! Treatment description including volumes used and final pressure Pumped 40 Mlbs 20/40 & 12/18 ceramic proppant into formation, fp was 4800 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 227 2 2 7 402 1246 187 Subsequent to operation 190 93 876 1420 195 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed.~J~"~------~ Form 10-404 Rev 06/15/88 Title Wells Superintendant Date ~.//'//,~/~'" SUBMIT i'N DUPLICATE PERMIT DATA 93-106 5849 93-106 5953 93-106 407 93-106 DAILY WELL OP 93-106 SURVEY ~- 106 SURVEY 93-106 CBT 93-106 CDN-LWD/DC 93-106 CDR-E/LWD/DC 93-106 CDR-LWD/DC 93-106 CET 93-106 CNT/G 93-106 CNTG-DC 9° 106 93-106 ~NTG/CORRECT D CN/CH/CNTG 93-106 TDTP ~ AOGCC Individual Well '-~ Geological Materials Inventory T DATA_PLUS 93-106 TDTP-DC OH-CDR/CDN, 6890-9187 ., T~~540-9080, CH-TDTP LR~OMp DATE' 10/12/93 31/93'~ TO '-I-0~/12/93 DiR ,CTIONAL O.F~ 0.00-9187 .,j~"6890-9050 ~t~'~ 2 &5'', 8280-9180 5" , 8500-9150 2&5" ,8290-9160 . ;oo- ooo ~5~0-9080 600-9000 /~550-9072 550-9071 ~8550-9062 Page · 1 Date: 09/29/95 RUN DATE_RECVD 10/25/1993 I 01/18/1994 11/16/1993 11/16/1993 09/14/1993 1i/16/1993 08/30/t993 10/25/1993 10/25/1993 10/25/1993 08/30/1993 1 05/03/1995 11/09/1993 ! 05/05/1995 09/27/1993 09/27/1993 11/09/1993 Are dry ditch samples Was the well cored.? required? yes yes ,~n..~o~ Analysis Are well tests required? ]l~es .... Received? Well is in compliance Initial COMMENTS _~.And received? ~~-~o & description received? ARCO Alaska, Inc. Date' May 4, 1995 Transmittal Cf: 9235 RETURN ~¢.,,~~~ ............. ~ ARCO Alaska, Inc. ---' _'7,-,% // Attn: Brian Hebert _ (' Kuparuk Operations File Clerk ~__ _ A_TO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please ackr~nwledge receipt and return one signed copy of this transmittal. ,~, ~" - ,~3,,c~ 2T-20 - Lo 1Y-18 CDR Final Print CNTG Depth Corrected 3/18-23/95 Ref# 50-123-20215 9/9/93 Ref#93423 2T-19 CDR Final Print 3/6-1 2/95 Acknowledg ed: ~~'~/~~~~:~~ Date'__ DISTRIBUTION' Ref# - - 14~ Alaska Oil & Gas 6ons. Commission Anchorage Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO-12O5 Clifton Pose,/ Geology ATO 1251 Erickson/Zuspan NSK Central Files NSK 69 Larry Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lcmke ATO 1336 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'FI'N: Sherrie NO. 9438 Company: 5/2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2T-19 95105 CDR 031295 I I 1 2T-20 95113 CDR 032395 1~ I 1 1Y-18 93423 REDO CNT-G 090993 I I 1 D h i\L ~.,L ! V I- I~ ?!¢~[EA~E: NOTE:" ';~::J:"~?R~EpROcEsSED TO INCLUDE AVERAGE; SIGNED: DATE: Alaaka 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' January 14, 1994 Transmittal Cf' 8980 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATe- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. .~, ·" "~;'"' 1 Y-27 · Please acknowledge receipt ,.., ~.--' :: :.: ,..:., ,~ 1" "" "'" u-z ~- ~ ~ 93426 L[SJ~ap.e~nd Listing· Ga_se~d. Nole-TD~l~¢3 passes and average LIS Tape and Listing: 10-28-93 93423 C N-T-GJvtaicPar~d-re peat-passe s. 1Y-23 5c~1%lq. LIS Tape and Listing: 10-28-93 93425 c¢-CNTG Main and repeat passes. L¢tcc~- -~-~-% P,\ cl~0 1Y-31 ~oi5~ LIS Tape and Listing' ~CNTG ¢i. 5_i-5.~ 2A-21 ~ct 5~ LIS Tape and Listing' ¢-k-'CDR/CDN, 2 Bit Runs 2A-17 ~5"~ LIS Tape and Listing' o~ -CDR/CDN, 2 Bit Runs c2,~_/~ ?,. 2A-23 5q¢;'~ LIS Tape and Listing' O~--CDR/CDN, 2 Bit Runs ~.-ILI~ 2A-24 '5~ 5~ LIS Tape and Listing' o~-CDR/CDN, 1 Bit Runs 10-04-93 12-07-93 with QRO Processing 12-07-93 with QRO Processing 12-07-93 with QRO Processing 12-19-93 with QRO Processing 2A-20 59~¢ LIS Tape and Listing' 12-20-93 o~--CDR/CDN, 2 Bit ,~_ns with QBe Proces,iing Receipt Acknowledged' _/¢/~/X~,,,,~; .~/~.¢~/~. DI~;TRIBUTION' Bob Ocanas 93429 93452 H tccce_i ~-~c)p,. \ 93474 9347O 93480 93497 Date: State of Alaska STATE OF ALASKA ALASI~J~, OIL AND GAS CONSERVATION COMMIS~,, aN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging Pull tubing __ Alter casing Repair well 5. Type of Well: Other_ ~.>/" J., 6. Datum elevation (DF or KB) RKB 107 feet '2. Name of Operator ARGO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 9951O 210' FNL, 1734' FWL, Sec 1, T11N, R9E, UM At top of productive interval 87' FNL, 44' FEL, Sec 35, T12N, R9E, UM At effective depth 230' FSL, 122' FEL, Sec 26, T12N, R9E, UM At total depth 292' FSL, 136' FEL, Sec 26, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Development X Exploratory _ Title Senior Engineer Signed 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Prior to well operation Subsequent to operation 9187 6523 feet feet Plugs (measured) None Effective depth' measured 9 0 8 4 true vertical 6442 feet feet Junk (measured) None Casing Length Structural Conductor 1 21 ' Surface 61 0 4' Intermediate Production 91 2 7' Liner Perforation depth: measured 8586'-8678' true vertical 6059'-6129' Size Cemented Measured depth 1 6" 250 SX PFC CMT 1 21 ' 9.625" 900 SX PF E & 61 40' 900 SX Class G CMT 7" 150SXASICMTTopJob 9169' 250 SX Class G CMT , 8718'-8733', 8931'-8968' , 6160'-6171', 6323'-6351' True vertical depth / 121' 4420' R6C_e( I V E D DEC 3 0 1995 0il & Gas Cons. Commission Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55/L-80 @ 8828' & 4", 11#, J-55 @ 5661' & 2.875", 6.5#, J-55/L-,.,,., ,~...~858' Packers and SSSV (type and measured depth) PKR: Camco HRP-4-SP @ 8471' & Baker 'D'@ 8830'; SSSV: Otis Series 10 SE@ 1797' 13. Stimulation or cement squeeze summary Fractured "A" Sand on 11/26/93. Intervals treated (measured) 8931 '-8968' Treatment description including volumes used and final pressure Pumped 243 Mlbs 16/20 & 12/18 ceramic proppant into formation, fp was 4620 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl GasoMcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 0 0 650 750 425 550 200 16. Status of well classification as: Oil X Gas Suspended __ Service Date RI IRMIT IN/F~I II51 I~,,~TF 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-18 9. Permit number/approval number 93-106 10. APl number 5o-029-22390 11. Field/Pool Kuparuk River Oil Field/Pool Stratigraphic Service '-KIj, ,4RUK STIMULATION ~UMM~.,Y ~ ~~/~/~ , HOLEAN~LEOPERF8:.~'._ :.-'~ AFES: ~O~8-- PERFORATED INTERVAL: ' ~ ORIENTATION OOMMENTS/OTH[R FRICTION CORRELATIONS: RATE (PSI/FT vs. BPM) . ' ' zo ! · TVD TOP PERF: ~, 3 2 Z MD TOP PERF: ,~3 / MD TBG T/~I' Z ~.E ~ · . · . MD]'BG~; ~ [ , :~ "~ :~::'~i :.':,;PRE-TREATMENT XLGW GW SLK WTR SLK DSL o 1~-0 oire) FORMATION FRAC GRADIENT:' , '7 5 FRAC FLUID GRADIENT: o 4 ~- · -. :· CALCULATIONS EXPECTED TREATING PRESSURE = (FORM FRAC GRAD X TVD TOP PEoR~F).+ (TBG FRIC X MD TBG TAIL) - (~UID G~D X ~D TOP PER~..= 2 ?~/ ' -7. .~~ ..... ~--.~ ~ F PERF- MD ~G TAIL) FLUSH VOLUME = ( L-MD TaG HGR) X (~G BBLS/~ (~u~O~ X (~ B~- (~ UNDER~USH) = I PRESSURE ANALYSIS AOTUAL FRAC GRADIENT = ISlP / TVD TOP PERF + FRAO FLUID GRADIENT St. lC ~ 124o EXCESS FRICTION = ~HTP- ISIP - ~BG FRIC X MD ~G TAIL) A~ . .FW. HTP ISIP FG XS FRIC .z s 5 41~ 51 ,4,7 -7,1'57 "20 "-" · TREATMENT SUMMARy RECEIVED ( DEC 30 199;$ z?~.,~.¢ska u:: & 6as Cons. CLOSURE PRESS Ar~.lE~go 4'i'1~,/.17$('' ' ~'~ % 7,84- EFFECTIVE PAD:_.-43~ ~FFECTIVE SLURRY: __11 q- 5 PROP PUMPED: ~6/20/~;;¢°° 12/18~,z7..2~c(~ 10/14 PPA @ PERFS:_:Jz]--, ~ PROP IN WELLBORE: I Z ~ 7 SEA WATER US!.:. / (~ I~, _,C' DIESEL USED: ~.¢~ NOTES. PAD/SLURRY RATIO: TOT~ ~44; of'Fo PROP IN FORMATION: .~'4 ADDITIVES USED: INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT 11/18/1993 PAGE: 1 PERMIT DATA DETAIL 93-106 CBT 93-106 CDN-LWD/DC 93-106 CDR-E/LWD/DC 93-106 CDR-LWD/DC 93-106 CET 6890-9050 2&5",8280-9180 5",8500-9150 2&5",8290-9160 7500-9802 93-106 CNTG-DC 8540-9080 93-106 DCN/CH/CNTG 93-106 TDTP 8550-9072 8550-9071 93-106 TDTP-DC 8550-9062 93-106 407 93-106 DAILY WELL OP 93-106 SURVEY COMP DATE: 10/12/93 7/31/93 TO 10/12/93 0.00-9187 93-106 SURVEY SS DIRECTIONAL 93-106 5849 OH-CDR/CDN,6890-9187 SUMMARY Are well tests required? Was well cored? Yes No Yes No If yes, was the core analysis & description received? Are dry d. itch samples required? Yes No Yes No WELL IS IN COMPLIANCE. INITIAL COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,.,,.,~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OiL F~I GAS ~] SUSPENDED E~ ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska. Inc 93-106 3Address OR I G I /~jA i 8 APINumber P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22390 4 Location of well at surface L~~ 9 Unit or Lease Name / 210' FNL, 1734"FWL, SEC 1, T 11N, R 9E, UM }'!~ ~ -J ~~~ r[ Vt"~~~ KUPARUK RIVER AtTop Producing Interval ~' _/'O~¢:?~~~ .: ,~.~.~ff~ t~!~ 10 Well Number 87' FNL, 44' FEL, SEC 35, T 12N, R 9E, UM '- ' t~ ~ 1Y-18 At Total Depth ~":- ii' ~~.~ 11 Field and Pool 292' FSL, 136' FEL, SEC 26, T 12N, R 9E, UM : - KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 107', PAD 66' GL ADL 25641 ALK 2572 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband._ /..-, -,' I 15 Water Depth, if offshore 116 No. of Completions 30-Jul-93 0S-Aug-93 ~/4'tfg'3(Comp) /d)//~ ~,/~?,.5I NA feet MSLi 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 9187' MD, 6523' TVD 9084' MD, 6442' TVD YES--X~ NO [~I 1805' feet MD 1400' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CNTG, TDTP, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SE'FTING DEPTH MD CASING SIZE Wl' GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 250 SX PFC CMT 9.625" 36#/47# J-55/L-80 SURF 6140' 12.25" 900 SX PF E, 900 SX CLASS G CMT 150 SX ASI CMT TOP JOB 7" 26# L-80 SURF 9169' 8.5" 250 SX CLASS G CMT 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) 8586'-8678' @ 12 SPF MD 6058'-6129' TVD 4"/3.5" 11#/9.3# 8866' 8479', 8838' 8718'-8733' @ 12 SPF MD 6160'-6171' TVD 8931'-8968' @ 4 SPF MD 6323'-6351' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24oHOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N,^ R£C£1VEO IqOV 1 B ,. ,--~,, 0il & Gas Cons. Commission Anchorage Form 10-407 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 OF KUPARUK C 8572' 6048' 1 31. LIST OF A'FFACHMENTS I I REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEYS(GCT) 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~/-/~J/~~~ Title ~,/-'~,-7'~/*/~ ~--J~ DA'rE - / 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 (rnultiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-18 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25641 ALK 2572 50-029-22390 93-106 ACCEPT: 07/30/93 05:30 SPUD: 07/30/93 09:30 RELEASE: 10/11/93 06:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 07/31/93 ( 1) PARKER 245 TD: 1375'( o) 08/01/93 (2) PARKER 245 TD: 4657' (3282) 08/02/93 (3) PARKER 245 TD: 6155' (1498) o) 08/03/93 (4) PARKER 245 TD: 6155'( 08/04/93 (5) PARKER 245 TD: 8394'(2239) DRILLING 16"@ 121' MW: 9.3 VIS: 62 MOVE F/1Y-21 TO 1Y-18. ACCEPT RIG @ 1730 HRS ON 07/30/93. NU 20" DIVERTER & FUNCTION TEST. AOGCC WAIVED WITNESSING TEST. PU BHA & ORIENT. DRILL & SURVEY W/MWD & NAVIDRILL F/121'-1375', SLIDING AS NEEDED. TIH W/NEW BIT 16"@ 121' MW:10.0 VIS: 57 DRILL F/1375'-3157'. CBU. SHORT TRIP TO HWDP. TIH. DR ILL F/3157'-4657'. CIRC & COND MUD. PMP SLUG. POOH F/NEW BIT. SWABBED SLIGHTLY F/1850'-1476'. MU NEW BIT, ORIENT TOOLS, TIH. RUNNING 9-5/8" CSG 16"@ 121' MW:10.0 VIS: 44 FIN TIH-WASH 90' TO BTM. NO FILL. DRILL F/4657'-6155'. CIRC & COND MUD. PMP PILL & POOH. NO PROBLEMS. RU CSG EQUIP & HOLD SAFETY MEETING. RUNNING 9-5/8" CSG @ REPORT TIME. CUTTING DRILL LINE 9-5/8"@ 6139' MW: 9.1 VIS: 32 FIN RUNNING 9-5/8" CSG. SHOE @ 6140' RECIP CSG WHILE CIRC & COND MUD. PMP TOTAL OF 600 BB~S. CMT W/900 SX PERM E CMT @ 12 PPG. FOLLOWED W/900 SX TYPE G CMT @ 15.8 PPG. BMP PLUG TO 2000 PSI. FLOATS HELD. NO CMT TO SURF. LOST RETURNS AFTER 240 BBLS OF LEAD CMT HAD BEEN PUMPED UP THE ANN. CIP @ 1350 HRS 08/02/93. FLOWED WELL BACK. LD LANDING JT & RD CSG EQUIP. ND 20" DIVERTER & REMOVE SEAL F/DIVERTER QUICK CONNECTOR. RU DS & PMP 25 BBLS WATER & PMP TOP JOB-125 SX ASI CMT @ 15.7 PPG. INSTALL PACKOFF & TORQUE 11-3/4" BTC X 11" 3M BRADENHEAD TO 12000 FT/LB. INSTALL NEW SEAL RING IN DIVERTER QUICK CONNECTOR. NU 13-5/8" 5M BOPE. RU & TEST BOPE EQUIP TO 300/3000 PSI. WITNESSING TEST WAIVED BY JOHN SPAULDING OF AOGCC. INSTALL WEAR RING. MU BHA, ORIENT, TEST, & TIH. SLIP & CUT DRILL LINE. TRIP IN HOLE 9-5/8"@ 6139' MW:10.1 VIS: 43 TAGGED UP @ 6058'_ TEST 9-5/8" CSG TO 2000 PSI FOR 30 MIN. DRILL PLUGS, FC, CMT, SHOE, & 10' NEW FORMATION TO 6165' CIRC & COND MUD. RAN EMW TEST @ 4413' TVD W/9 PPG MUD. FORMATION BROKE @ 550 PSI. EMW=ll.4 PPG. DRILL 8.5" HOLE F/6165'-6785' SERVICE RIG. DRILL 8.5" HOLE F/6785'-8394'. RAISE MUD WT TO 10.0 PPG. CBU. SLUG DP. POOH. LD BHA. PU NEW BHA-INSTALL RA SOURCE-RIH SLOW. RECEIV£C) ,~,..!~,~:,a~' Oil & Gas Cons. Commission Anchorage WELL: 1Y-18 API: 50-029-22390 PERMIT: 93-106 PAGE: 2 08/05/93 (6) PARKER 245 TD: 8817' ( 423) 08/06/93 (7) PARKER 245 TD: 9187' ( 370) 08/07/93 (8) PARKER 245 TD: 9187'( o) 08/16/93 (12) DOWELL TD: 9187 DRILLING 9-5/8"@ 6139' MW:ll.0 VIS: 45 TIH SLOW. CIRC & COND MUD @ 8394'. LOAD MUD SYSTEM W/30 LBS/BBL LCM & RAISE MUD WT TO 10.5 PPG. POH W/25 STD DP. BIT IN 9-5/8" CSG. HOLE TIGHT & SWABBING F/8394'-7600'. SHUT WELL IN TO RUN EMW TEST. PRESS UP TO 350 PSI-LEAKED OFF TO 240 PSI IN 15 MIN-REPRESS TO 350 PSI-LEAKED OFF TO 270 PSI IN 15 MIN. EMW=ll.6 PPG @ 4413' TVD W/10.5 PPG MUD. TIH SLOW TO 8382' CIRC & RAISE MUD WT TO 11 PPG. NO MUD LOSS. PMP 100 SPM~1700 PSI. DRILL 8.5" HOLE F/8394'-8817'. NO MUD LOSS-NO GAS. LD BHA 9-5/8"@ 6139' MW:ll.0 VIS: 45 DRILL 8.5" HOLE F/8817'-9033' SERVICE RIG. DRILL 8.5" HOLE F/9033'-9187'. CBU. SL6G DP. POH W/16 STDS DP TO 7726'. HOLE TIGHT & SWABBING F/9120'-8570'. RIH SLOW. CBU @ 9187'-NO GAS OR MUD LOSS. DROP SURVEY & SLUG DP. POH. LD 24 JTS "G" DP. RETRIEVE SURV. LD BHA FOR INSPECTION. DOWN LOAD LWD TOOLS. FIN LD BHA. RIG RELEASED 7"@ 9169' MW:ll.0 VIS: 46 RU CASERS. HOLD SAFETY MEETING. RAN 217 JTS 7" 26# BT &C MOD CSG. CIRC @ 9-5/8" SHOE. CIRC & COND W/CSG ON BTM @ 9169'. SHAKE OUT LCM. PMP 950 BBLS MUD. NO MUD LOSS. SET & CMT'D 7" W/SHOE @ 9169' & FC @ 9084' DOWELL CMT'D PUMPING 20 BBLS PRE-FLUSH, 50 BBLS 12.0 PP~ SPACER, & 250 SX PREM G W/ADDITVES. DISPLACED W/347 BBLS 11 PPG BRINE. RECIP PIPE W/FULL RETURNS THROUGH OUT JOB. PLUG DOWN & JC @ 2230 HRS. TEST 7" TO 3500 PSI FOR 30 MIN. HELD. FLOATS HELD. PU STACK. LANDED 7" W/150,000# ON SLIPS. CUT OFF 7" CSG. ND & SET OUT BOP'S. TEST TBG HEAD TO 3000 PSI. HELD. RT TO TBG HEAD 37'. FREEZE PROTECT 9-5/8" X 7" ANN W/100 BBLS WATER & 70 BBLS DIESEL. RELEASED RIG @ 0500 HRS 08/07/93. MOVE RIG F/1Y-18 TO 1Y-19. 7"@ 9169' DO ARCTIC PACK 10/10/93 ( 9) NORDIC 1 TD: 9187 PB: 9084 PERFORATING 7"@ 9169' MW:ll.3 NaC1/Br CHECK WELL F/PRESS. 7" SICP=0 PSI. 7" X 9-5/8" ANN=0 PSI. MOVE RIG F/1Y-19 TO 1Y-18. ND TREE. NU BOP. CHANGED PIPE RAMS TO 3-1/2" TEST SAME & ALL FLANGE BREAKS TO 3000 PSI. RU SCHLUMBERGER TO PERF. PERF F/8948'-8968' W/4 SPF, 180 DEG PHASING, ORIENTED 171 DEG CCW. PERF F/8931'-8948' W/4 SPF 180 DEG PHASING, ORIENTED 154 DEG CCW. PERF F/8638'-8733' W/12 SPF. RECEIVED b~l & Gas Cons. Commission .Anchorage WELL: 1Y-18 API: 50-029-22390 PERMIT: 93-106 PAGE: 3 10/11/93 (10) NORDIC 1 TD: 9187 PB: 9084 SPACE OUT TO LAND TBG 7"@ 9169' MW:ll.3 NaCl/Br RIH W/PERF GUN & PERF F/8618'-8638' @ 12 SPF. POOH. RIH W/PERF GUN & PERF F/8598'-8618' @ 12 SPF. PERF F/8586'-8598'. POOH. RIH W/SWS & 6" GAUGE RING & JB TO 8910'. LARGE AMT OF PERF DEBRIS RECOVERD RERUN GAUGE RING & JB TO 8910'. PU BAKER D PERM PKR & TAILPIPE W/BALL IN PLACE ON E-LINE. SET PKR @ 8229.5' WLM. RU FLOWLINE. RU FLOOR TO RUN COMP STRING. RIH W/3-1/2" TBG & JEWELRY. MU BLAST RING JTS & CONT RIH TO 3-1/2" X 4" XO. MU TBG HGR & LAND TBG. CHANGE OUT 3-1/2" PR'S TO 4", TEST SAME TO 3000 PSI. PU ON COMP ASSY, BACK OUT TBG HGR, & LD SAME. CONT RIH W/4" TBG & JEWELRY TO 4" SSSV. MU OTIS 4" SSSV & ATTACH CONTROL LINE. PRESS CONTROL LINE TO 5000 PSI. HOLD FOR 10 TEST. CONT RIH W/4" TBG & C-LINE, ATTACH SS BANDS EVERY OTHER JT TO SURF. TOTAL 32 BANDS. STING LSA INTO D PKR @ 8930' PRESS UP ON TBG TO 500 PSI. PRESS BLEEDS OFF 50 PSI/MIN W/RETURNS TO 4" X 7" ANN. 10/12/93 (11) NORDIC 1 TD: 9187 PB: 9084 RIG RELEASED 7"@ 9169' MW:ll.3 NaCl/Br SPACED OUT & LANDED TBG HGR. RU OTIS. RIH W/RETR TOOL. RETRV CIRC VALVE F/GLM @ 8414'. DEBRIS IN VALVE HOLDING CHECK OFF SEAT. RIH W/DUMMY VALVE @ SET IN GLM @ 8414' POOH. TEST TBG TO 500 PSI-OK. PRESS TBG TO 2500 PSI T6 SET HRP-4SP PKR @ 8479'. HELD 2500 PSI FOR 30 MIN-OK. BLED PRESS. BOLDS. PU & SHEARED PBR W/83,000#. 14,000# OVER PU WT. LANDED TBG. RILDS. TESTED ANN TO 2500 PSI-OK. TESTED TBG TO 3000 PSI-OK. BLED OFF. BACKED OUT LANDING JT. SET BPV. ND BOP. NU FMC TREE, PULL BPV, SET TEST PLUG, TEST TREE & PO TO 5000 PSI. PULL TEST PLUG, OPEN SSSV. RU OTIS, RIH & ATTEMPT TO PULL DV F/4" MANDREL @ 3187'. KICK OVER TOOL FAILED. POOH & PU 3" PULLING TOOL. RIH & PULL DV F/3-1/2" MANDREL @ 5668' POOH. PRESS ANN & TBG TO 1000 PSI & CLOSE SSSV. BLEED TBG TO 250 PSI F/SSSV TEST. HOLD 15 MIN. PMP 17 BBLS DIESEL DN ANN. OPEN ANN TO TBG & ALLOW DIESEL TO U-TUBE & EQUALIZE, LEAVING 11 BBLS IN ANN & 6 BBLS IN TBG. RIH W/OTIS & REPLACE DV IN MANDREL @ 5668'. POOH. PRESS TEST TBG TO 3000 PSI-OK. BLEED PRESS & RD OTIS WL. SET BPV, SECURE WELL. SITP=0, SICP=O, 9-5/8"=0. RELEASE RIG @ 1830 HRS 10/11/93. SIGNATURE: (dr~p~rinter~t) DATE: Gas gons. g~mmissior, Anchorage SUB - SURFACE DIRECTIONAL SURVEY l'~ UIDANCE ~'J ONTINUOUS ~ OOL RECEIVED · ", ~'-. '~'" Oil & (J-'as Corm. Commission Anchorage Company Well Name Field/Location ARCO ALASKA, INC. 1Y-18 (210' FNL, 1734' FWI_, SEC 1, TllN, RgE, UR) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93388 Logged By: Date 17-AUG-93 Computed By: ~ARNER SINES · SCHLUMBERGER · OCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1Y - 18 RECEIVED V. ! 6 'i'3 fi,:';~ Gas 6ons. Commission Anchorage KUPARUK NORTH SLOPE, ALASKA SURVEY DATE' AUG-16-1993 ENGINEER' D. WARNER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 17 DEG 20 MIN WEST COMPUTATION DATE' 30-AUG-93 PAGE 1 ARCO ALASKA, INC. 1Y - 18 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY' AUG-16-1993 KELLY BUSHING ELEVATION' 107.00 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0.00 -107 O0 100 O0 200 299 399 499 598 697 794 889 -7 O0 93 99 192 95 292 65 392 97 491 42 590 30 687 78 0 0 O0 0 26 O0 0 28 99 0 35 95 2 50 65 5 27 97 8 2 42 12 11 30 16 7 782.78 18 30 N 0 0 E S 78 11 W S 61 16 W N 50 49 W N 4 34W N 1 7 E N 0 55 W N 9 2 W N 11 52 W N 10 5 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERI-FY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH FEET DEG/IOO FEET FEET FEET DEG MIN 0 O0 0 O8 -0 04 0 14 2 84 10 06 21 08 38 11 62 66 92 17 0 oo 0 8O 0 41 0 41 2 O2 2 64 2 35 3 87 2 31 2 86 0 O0 N 0 O1 S 0 37 S 0 39 S 224 N 9 78 N 21 38 N 38 72 N 62 95 N 92 08 N 0 O0 E 0 29 W 1 05 W 1 70 W 2 36 W 2 45 W 2 28 W 3 86 W 8 63 W 14.34 W 0.00 N 0 0 E 0.29 S 87 47 W 1.11 S 70 33 W 1.74 S 77 12 W 3.26 N 46 30 W 10.08 N 14 3 W 21.50 N 6 5 W 38.92 N 5 42 W 63.54 N 7 48 W 93.19 N 8 51W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 lgO0 983 97 O0 1076 O0 1167 O0 1256 O0 1342 O0 1426 O0 1505 O0 1580 O0 1652 O0 1719 876.97 20 55 63 969.63 23 24 43 1060.43 25 54 58 1149.58 28 14 89 1235.89 31 54 19 1319.19 35 42 41 1398.41 39 39 81 1473.81 42 44 35 1545.35 46 0 82 1612.82 49 16 N g 56 W N g 16 W N 9 11W N 10 19 W N 13 19 W N 14 8 W N 14 47 W N 15 28 W N 15 26 W N 16 4 W 125 44 162 67 204 11 248 99 299 24 354 43 415 33 480 95 550 77 624 51 2 91 2 42 2 49 2 43 3 O5 3 46 3 83 3 67 3 46 3 3O 125 14 N 162 20 N 203 54 N 248 18 N 297 56 N 351 21N 410 28 N 473 66 N 54O 612 20 09 W 126 74 N 9 7 W 26 32 40 5O 64 79 96 98 N 115 02 N 135 30 W 164 96 W 206 57 W 251 98 W 301 34 W 357 52 W 417 69 W 483 33 W 553 24 W 626 32 N 9 13 W 19 N 9 12 W 47 N 9 17 W 90 N 9 43 W 06 N 10 23 W 91 N 10 58 W 43 N 11 32 W 14 N 12 2 W 79 N 12 28 W 2000 O0 1783.66 1676 66 51 11 2100 O0 1846.03 1739 03 51 37 2200 O0 1907.87 1800 2300 O0 1969,41 1862 2400 O0 2030 30 1923 2500 O0 2090 76 1983 2600 O0 2151 35 2044 2700 O0 2212 32 2105 2800 O0 2273 15 2166 2900 O0 2333 92 2226 92 52 34 87 51 56 41 52 12 30 52 40 76 52 51 35 52 27 32 52 30 15 52 38 3000 O0 2394 54 2287 54 52 37 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2455 O0 2517 O0 2579 O0 2643 O0 2708 O0 2774 O0 2839 O0 2905 O0 2970 97 2348 60 2410 24 2472 64 2536 81 2601 32 2667 91 2732 39 2798 92 2863 97 51 53 60 52 6 24 51 0 64 49 30 81 49 12 32 49 4 91 48 59 39 49 11 92 48 56 N 16 20 W 701 46 N 16 4 W 779 61 N 15 49 W 858 18 N 15 32 W 936 97 N 15 22 W 1016 25 N 14 48 W 1095 84 N 14 30 W 1175 30 N 16 32 W 1254 52 N 16 29 W 1333 88 N 16 26 W 1413 29 N 16 41W 1492 81 N 18 14 W 1571 N 17 54 W 1650 N 18 22 W 1729 N 19 25 W 1805 N 19 13 W 1881 N 19 5 W 1956 N 18 57 W 2032 N 19 4 W 2107 N 18 55 W 2183 71 45 19 64 45 96 41 96 47 3 O2 2 20 1 O0 0 43 0 56 0 54 0 50 0 79 0 73 0 61 0 28 0 9O 0 95 1 05 1 44 1 45 1 O7 0 25 0 21 0 24 685 94 N 156 68 W 703 61 N 12 52 W 761 836 912 988 1065 1142 1219 1295 O0 N 178 56 N 200 46 N 221 91N 242 81N 263 79 N 283 17 N 304 26 N 327 50 W 781 10 W 86O 37 W 938 52 W 1018 29 W 1097 34 W 1177 51W 1256 O7 W 1335 65 N 13 12 W 16 N 13 27 W 93 N 13 38 W 21 N 13 47 W 85 N 13 53 W 39 N 13 55 W 62 N 14 I W 92 N 14 10 W 1371.43 N 349 57 W 1415 28 N 14 18 W 1447.71 N 372 06 W 1494 76 N 14 25 W 1522.88 N 396 1597.74 N 420 1672.63 N 444 1744.84 N 47O 1816.41N 495 1887.78 N 519 1959.14 N 544 2030.63 N 569 2102.06 N 593 06 W 1573 48 W 1652 83 W 1730 07 W 1807 19 W 1882 98 W 1958 57 W 2033 12 W 2108 68 W 2184 54 N 14 35 W 15 N 14 45 W 77 N 14 54 W RECEIVED O5 N 15 5 W 70 N 15 15 W~ UOaS. Comm[ssio 08 N 15 24 W 4nchorar, e_ ~ 42 N 15 32 W 87 N 15 39 W 29 N 15 46 W ARCO ALASKA, INC. 1Y - 18 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 30-AUG-g3 PAGe 2 DATE OF SURVEY: AUG-16-1993 KELLY BUSHING ELEVATION: 107.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA CDURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMLFFH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARI'URE SECTION SEVERI1-Y NDRTH/SDU1-H EAST/WEST DIST. AZIMUTH FEET DEG/1OO FEET FEET FEET DEG MIN 4000.00 3036 81 2929.81 48 45 4100 O0 3102 4200 4300 4400 4500 4600 4700 4800 4900 O0 3169 O0 3234 O0 3298 O0 3363 O0 3429 O0 3494 O0 3558 O0 3623 80 2995.80 48 42 01 3062.01 48 29 24 3127.24 49 46 86 3191.86 49 43 79 3256.79 49 20 19 3322.19 48 58 86 3387.86 49 21 95 3451,95 50 17 33 3516.33 49 38 N 18 56 W 2258 67 N 19 0 W 2333 N 19 0 W 2408 N 21 1W 2484 N 21 2 W 2560 N 21 15 W 2636 N 21 25 W 27~1 N 21 47 W 2787 N 22 25 W 2863 N 22 40 W 2939 77 69 38 53 42 89 10 57 78 O. 27 0 22 0 56 0 96 0 82 0 81 0 34 0 44 0 80 0 87 2173 22 N 618 07 W 2259.40 N 15 53 W 2244 2315 2386 2457 2528 2598 2669 2740 2810 29 N 642 18 N 666 34 N 692 55 N 720 47 N 747 93 N 775 09 N 8O2 13 N 832 81N 861 44 W 2334.43 N 15 58 W 77 W 2409 28 N 16 4 W 85 W 2484 89 N 16 11W 27 W 2560 93 N 16 20 W 74 W 2636 72 N 16 28 W 28 W 2712 11 N 16 37 W 96 W 2787 25 N 16 45 W 01 W 2863 66 N 16 53 W 34 W 2939 82 N 17 2 W 5000.00 3688 39 3581 39 49 7 5100.00 3753 5200.00 3817 5300.00 3881 5400.00 3945 5500.00 4008 5600.00 4071 5700.00 4136 5800.00 4201 5900.00 4266 52 3646 06 3710 02 3774 08 3838 18 3901 98 3964 90 4029 66 4094 15 4159 52 50 15 O6 5O 28 02 SO 08 50 47 18 50 42 98 49 56 90 49 10 66 50 11 15 49 28 N 22 29 W 3015.40 N 21 1W 3091 03 N 20 21W 3168 N 20 25 W 3244 N 18 27 W 3321 N 17 29 W 3399 N 17 40 W 3476 N 17 43 W 3552 N 17 23 W 3628 N 17 12 W 37O4 13 89 59 17 18 23 43 85 0 85 0 99 1 18 1 16 1 12 1 23 1 31 0 97 0 84 0 74 2880 91N 890 54 W 3015 41 N 17 11W 2951 3023 3095 3167 3241 3315 3387 3460 3533 26 n 918 60 N 946 66 N 972 88 N 998 81N 1022 23 N 1045 69 N 1068 35 N 1091 32 N 1114 96 W 3091 O0 W 3168 74 W 3244 80 W 3321 32 W 3399 54 W 3476 65 W 3552 60 W 3628 31W 3704 03 N 17 18 W 13 N 17 22 W 89 N 17 27 W 61 N 17 3O W 19 N 17 30 W 19 N 17 30 W 25 N 17 30 W 44 N 17 30 W 87 N 17 30 W 6000 O0 4331 33 4224 33 49 27 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4395 O0 4458 O0 4521 O0 4584 O0 4647 O0 4710 O0 4773 O0 4836 O0 4898 02 4288 17 4351 33 4414 40 4477 48 4540 51 46O3 35 4666 O0 4729 51 4791 02 51 2 17 50 48 33 50 52 40 50 54 48 50 52 51 50 58 35 51 10 O0 51 14 51 51 17 N 17 22 W 3780 69 N 17 32 W 3857 N 18 0 W 3935 N 18 17 W 4012 N 18 27 W 4090 N 18 41W 4168 N 18 54 W 4245 N 19 17 W 4323 N 19 40 W 4401 N 19 56 W 4479 78 32 84 43 O1 61 36 25 24 0 6O 0 93 0 87 0 75 0 3O 0 21 0 2O 0 25 0 30 0 32 3605 76 N 1136.78 W 3780 71 N 17 30 W 3679 3753 3826 3900 3974 4047 4121 4194 4267 29 N 1159 92 W 3857 12 N 1183 80 N 1207 45 N 1232 O1N 1256 51N 1281 02 N 1307 51N 1333 96 N 1359 60 W 3935 72 W 4012 20 W 4090 87 W 4168 88 W 4245 31W 4323 27 W 4401 69 W 4479 79 N 17 30 W 33 N 17 30 W 85 N 17 31W 45 N 17 32 W O3 N 17 33 W 65 N 17 34 W 41 N 17 36 W 31 N 17 38 W 31 N 17 40 W 7000 O0 4961 02 4854 02 51 18 7100 O0 5024 10 4917 10 49 47 7200 O0 5089 56 4982 56 48 51 7300 O0 5155 52 5048 52 48 44 7400 O0 5222 02 5115 02 48 1 7500 7600 7700 7800 7900 N 20 15 W 4557 20 N 21 27 W 4634 66 N 22 22 W 4709 99 N 22 47 W 4784 85 N 20 11W 4859 30 0 29 0 75 1 21 1 25 1 25 4341 27 N 1386 50 W 4557 30 N 17 43 W 4413 87 N 1413 85 W 4634 79 N 17 46 W 4483 91N 1442 29 W 4710 16 N 17 50 W 4553 34 N 1471 09 W 4785 08 N 17 54 W 4622 66 N 1498 84 W 4859 58 N 17 58 W O0 5288 oo 5355 O0 5422 O0 5489 oo 5555 94 5181 70 5248 55 5315 12 5382 89 5448 94 48 5 70 48 1 55 48 14 12 48 12 89 48 4 N 20 33 W 4933 N 20 52 W 5007 N 19 2 W 5082 N 19 33 W 5156 N 2O 15 W 5231 51 83 11 69 06 115 086 087 081 080 RECEIVED 4692 4762 4831 4902 4972 39 N 1524 02 N 1550 87 N 1576 32 N 1601 30 N 1626 54 W 4933 88 W 5008 41W 5082 02 W 5157 38 W 5231 2084 NN 1818 20 wW ....... ,2_ _:~;(~" L, OnS. u I ir'o~rrl'SS'Ol 52 N 18 4 W ¢,achorage 13 N 18 5 W 53 N 18 7 W ARCO ALASKA, INC. 1Y- 18 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 30-AUG-g3 PAGE 3 DATE OF SURVEY: AUG-16-1993 KELLY BUSHING ELEVATION: 107.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEC MIN DEC MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMU1-H FEET DEG/IO0 FEET FEET FEET DEC 8000 O0 5622 go 5515 90 47 30 8100 8200 8300 8400 85OO 86OO 8700 8800 8900 O0 5691 O0 5763 O0 5839 O0 5915 O0 5992 O0 6069 O0 6145 O0 6222 O0 6298 94 5584 94 45 47 68 5656 68 42 22 28 5732 28 40 12 70 5808 70 40 9 35 5885 35 39 48 40 5962 40 39 38 99 6038.99 40 22 O0 6115.00 40 29 62 6191.62 39 28 N 20 41W 5305 17 N 20 51W 5377 N 19 35 W 5446 N 19 8 W 5512 N 20 7 W 5576 N 16 38 W 5640 N 13 47 W 5704 N 14 3 W 5768 N 14 21W 5833 N 13 40 W 5897 38 93 35 79 99 68 85 73 89 0 55 1 02 2 21 2 73 2 40 1 72 1 70 1 73 1 O2 0 78 5041 82 N 1652 42 W 5305 70 N 18 9 W 5109 5174 5236 5297 5358 5419 5482 5545 5607 50 N 1677 85 N 1702 68 N 1723 40 N 1745 29 N 1765 84 N 1782 28 N 1797 24 N 1813 56 N 1829 93 W 5377 O1W 5447 46 W 5512 21W 5577 60 W 5641 14 W 5705 47 W 5769 52 W 5834 18 W 5898 96 N 18 11W 56 N 18 12 W 99 N 18 13 W 47 N 18 14 W 68 N 18 14 W 32 N 18 12 W 43 N 18 9 W 26 N 18 7 W 36 N 18 4 W 9000.00 6376.10 6269.10 38 50 9100.00 6454.44 6347.44 '38 21 9187.00 6522.66 6415.66 38 21 N 13 20 W 5960.96 N 13 3 W 6022.93 N 13 3 W 6076.77 0.85 0.00 0. O0 5669.04 N 1843.89 W 5961.37 N 18 1W 5729.57 N 1857.97 W 6023.30 N 17 58 W 5782.17 N 1870.15 W 6077.08 N 17 55 W RECEIVED 1 6 9S,3 ;,.:,:~:~La (~!i & Gas Cons. Commission Anchorage COMPUTATION DATE: 30-AUG-93 PAGE 4 ARCO ALASKA, INC. 1Y - 18 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: AUG-i6-1993 KELLY BUSHING ELEVATION: i07.00 FT ENGINEER: D. WARNER INTERPOLATED VALU~ FOR EVEN 1000 FEET 0f MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 -107 O0 O0 983 O0 1783 O0 2394 O0 3036 O0 3688 O0 4331 O0 4961 OO 5622 O0 6376 0 0 97 876 66 1676 54 2287 81 2929 39 3581 33 4224 02 4854 90 5515 10 6269 97 20 55 66 51 11 54 52 37 81 48 45 39 49 7 33 49 27 02 51 18 90 47 30 10 38 50 N 0 0 E 0.00 N 9 56 W 125.44 N 16 20 W 701.46 N 16 41W 1492,81 N 18 56 W 2258.67 N 22 29 W 3015.40 N 17 22 W 3780.69 N 20 15 W 4557.20 N 20 41W 5305.17 N 13 20 W 5960.96 0 O0 2 91 3 02 0 28 0 27 0 85 0 6O 0 29 0 55 0 85 0 O0 N 125 685 1447 2173 2880 3605 4341 5041 5669 000 E 14 N 20 94 N 156 71N 372 22 N 618 91N 890 76 N 1136 27 N 1386 82 N 1652 04 N 1843 09 W 126 68 W 7O3 06 W 1494 07 W 2259 54 W 3015 78 W 378O 50 W 4557 42 W 5305 89 W 5961 0 O0 N 0 0 E 74 N 9 7 W 61 N 12 52 W 76 N 14 25 W 40 N 15 53 W 41 N 17 11W 71 N 17 30 W 30 N 17 43 W 70 N 18 9 W 37 N 18 I W 9187.00 6522.66 6415,66 38 21 N 13 3 W 6076,77 0.00 5782.17 N 1870.15 W 6077.08 N 17 55 W RECEIVED OV 16 Gas Cons. Commission Anchorage COMPUTATION DATE' 30-AUG-93 PaGE 5 ARCO ALASKA, INC. 1Y - 18 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY' AUG-16-1993 KELLY BUSHING ELEVATION' 107.00 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET Of SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR'rURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 107 207 307 407 5O7 6O8 709 813 918 0 O0 -107 O0 0 0 N 0 0 E O0 107 O0 207 O1 307 06 4O7 38 507 11 607 81 707 23 807 19 907 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 28 S 73 38 W O0 0 27 S 61 49 W O0 0 40 N 44 14 W O0 3 3 N 3 57 W O0 5 34 N I 10 E O0 8 21 N 1 31W O0 12 36 N 9 43 W O0 16 24 N 11 43 W O0 18 52 N g 52 W 0 O0 0 O8 -0 05 0 2O 3 21 10 73 22 20 40 20 66 34 97 97 O. O0 0.78 O. 35 0.45 2.13 2.61 2.41 3.98 2.40 2.94 000N 0 02 S 040 S 0 34 S 2 61 N 10 48 N 22.54 N 40.81 N 66.57 N 97.84 N 15 0.00 E 0 34 W 0 I 10 W 1 76 W 1 2 39 W 3 2 43 W 10 2 31W 22 4 21W 41 g 39 W 67 35 W 99 0 O0 N 0 0 E 34 S 86 20 W 17 S 70 9 W 79 S 79 0 W 54 N 42 24 W 76 N 13 4 W 66 N 5 51W 02 N 5 53 W 23 N 8 2 W 04 N 8 55 W 1024 69 1007 O0 go0.o0 21 24 N g 39 W 134 25 1133 1244 1357 1476 1602 1736 1880 2037 2198 22 1107 14 1207 96 1307 51 1407 07 1507 O1 1607 44 1707 32 1807 59 1907 O0 1000.00 24 22 N 9 g W 175 O0 1100.00 26 46 N 9 36 W 223 O0 1200.00 30 47 N 12 14 W 277 O0 1300.00 34 31 N 14 10 W 340 O0 1400.00 39 42 N 14 49 W 416 O0 1500.00 43 51 N 15 32 W 505 O0 1600.00 48 43 N 15 58 W 609 O0 1700.00 51 23 N 16 17 W 730 O0 1800.00 51 56 N 15 49 W 857 gg 49 41 90 66 66 75 58 07 2.76 2 48 2 46 2 96 3 25 3 82 3 70 3 32 2 74 I 01 133.90 N 21 60 W 135 63 N 9 10 W 175.48 N 28 45 W 177 222.84 N 36 14 W 225 276 22 N 46 12 W 280 338 07 N 61 03 W 343 411 56 N 79 86 W 419 497 48 N 103.30 W 508 597 82 N 131.18 W 612 713 90 N 164.85 W 732 835 49 N 199.79 W 859 77 N 9 13 W 75 N 9 13 W 04 N 9 29 W 53 N 10 14 W 24 N 10 59 W og N 11 44 W 04 N 12 23 W 68 N 13 0 W 05 N 13 27 W 2361.61 2007 O0 lgO0.O0 52 35 N 15 28 W 985 76 2526.88 2107 2691.26 2207 2855 72 2307 3020 47 2407 3182 75 2507 3343 44 2607 3497 24 2707 3649 86 2807 3802 46 2907 O0 2000 O0 52 48 N 14 41 W 1117 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 52 29 N 16 25 W 1247 O0 52 33 N 16 29 W 1378 O0 52 20 N 17 7 W 1509 O0 52 2 N 17 59 W 1636 O0 49 45 N 19 26 W 1762 O0 49 13 N 19 14 W 1879 O0 49 0 N 19 2 W 1994 O0 49 11 N 19 4 W 2109 23 59 14 O4 85 58 36 60 82 0 43 0 53 1086 0 75 1212 0 67 1337 0 36 1463 0 93 1584 1.37 1704 1.45 1814 0.32 1923 0.21 2O32 959 50 N 234.42 W 987.72 N 13 44 W 52 N 268 73 W 1119.26 N 13 54 W 52 N 302 71N 339 25 N 376 80 N 416 22 N 455 44 N 494 37 N 532 38 N 569 56 W 1249 70 N 14 1 W 61W 1380 15 N 14 15 W 77 W 1510 98 N 14 26 W 29 W 1638 56 N 14 43 W 69 W 1764 09 N 14 58 W 50 W 1880 61 N 15 15 W 27 W 1995 66 N 15 28 W 72 W 2110 73 N 15 40 W 3954 79 3007 O0 2900 O0 48 44 N 18 56 W 2224 69 4106 4257 4412 4566 4718 4874 5028 5184 5340 36 3107 gl 3207 56 3307 16 3407 76 3507 75 36O7 39 3707 19 3807 37 3907 O0 3000 O0 48 42 N lg 1W 2338 O0 3100 O0 49 33 N 20 27 W 2452 O0 3200 O0 49 38 N 21 5 W 2570 O0 3300 O0 49 6 N 21 25 W 2686 O0 3400 O0 49 53 N 22 5 W 2801 O0 3500.00 49 45 N 22 36 W 2920 O0 3600.00 48 56 N 22 25 W 3036 O0 3700.00 50 33 N 20 22 W 3155 O0 3800.00 49 56 N 20 19 W 3275 54 35 O8 39 35 6O 76 95 75 0.27 2141.07 N 607 05 W 2225 46 N 15 50 W 0 24 2248.81 N 644 77 2356.33 N 681 83 2466.48 N 723 47 2575.14 N 765 55 2682.35 N 808 86 2793.03 N 853 73 2900.73 N 898 19 3012.16 N 941 14 3124.63 N 983 O0 W 2339 49 W 2452 71W 2570 95 W 2686 31W 2801 93 W 292o 72 W 3036 76 W 3155 50 W 3275 20 N 15 59 W 89 N 16 8 W 46 N 16 21W 64 N 16 34 W 49 N 16 46 W 66 N 17 0 W 77 N 17 13 W 95 N 17 22 W 76 N 17 28 W ECEIVED Ar~cl~orage COMPUTATION DATE: 30-AUG-g3 PAGE 6 ARCO ALASKA, INC, 1Y - 18 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: AUG-16-1993 KELLY BUSHING ELEVATION: 107.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 5498 14 4007 O0 3900 O0 50 42 5654 5808 5962 6119 6277 6435 6594 6753 6913 Z6 4107 34 4207 71 4307 03 4407 30 4507 85 4607 42 4707 68 4807 58 4907 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 45O0 O0 4600 O0 4700 O0 4800 O0 49 27 O0 50 11 O0 49 11 O0 50 58 O0 50 50 O0 50 55 O0 50 58 O0 51 12 O0 51 18 N 17 29 W 3397 74 N 17 42 W 3517 N 17 23 W 3634 N 17 16 W 3752 N 17 37 W 3872 N 18 12 W 3995 N 18 30 W 4118 N 18 53 W 4241 N 19 28 W 4365 N 19 58 W 4489 48 83 43 56 24 25 28 17 82 1 23 1 38 0 85 0 62 0 92 0 79 0 27 0 2O 0 27 0 31 3240.44 N 1021 89 W 3397 75 N 17 30 W 3354 59 N 1058 3466 46 N 1093 3578 77 N 1128 3693 38 N 1164 3810 08 N 1202 3926 84 N 1241 4043.40 N 1280 4160.48 N 1321 4277.92 N 1363 08 W 3517 51W 3634 37 W 3752 38 W 3872 22 W 3995 02 W 4118 47 W 4241 18 W 4365 31W 4489 50 N 17 30 W 85 N 17 30 W 44 N 17 30 W 58 N 17 30 W 26 N 17 31W 28 N 17 32 W 31 N 17 34 W 22 N 17 37 W 90 N 17 41W 7073 28 5007 O0 4900.00 50 41 7226 46 5107 7377 53 5207 7527 06 5307 7676 66 5407 7826 80 5507 7976 40 5607 8121.44 5707 8257.69 5807 8388.62 5907 O0 5000.00 48 44 O0 5100.00 48 5 O0 5200.00 48 10 O0 5300.00 48 10 O0 5400.00 48 5 O0 5500.00 47 58 O0 5600.00 45 14 O0 5700.00 40 25 O0 5800.00 40 11 N 20 51W 4614 17 N 22 26 W 4729 N 20 56 W 4842 N 20 42 W 4953 N 19 2O W 5064 N 19 47 W 5176 N 2O 45 W 5287 N 2O 44 W 5392 N 18 53 W 5485 N 2O 6 W 5569 82 61 62 72 64 75 62 O0 46 0 47 1 23 1 31 1 15 0 78 0 82 0 51 1 09 2 81 2 45 4394.72 N 1406 45 W 4614 29 N 17 45 W 4502 31N 1449 4607 4711 4815 4921 5025 5123 5210 5290 03 N 1492 25 N 1531 43 N 1570 12 N 1607 50 N 1646 77 N 1683 81N 1714 51N 1742 88 W 4730 94 W 4842 63 W 4953 70 W 5065 73 W 5177 26 W 5288 34 W 5393 55 W 5485 69 W 5570 O1 N 17 51W 89 N 17 57 W 96 N 18 1W 13 N 18 4 W 09 N 18 6 W 27 N 18 8 W 21 N 18 11W 64 N 18 13 W 13 N 18 14 W 8519 04 6007 O0 5900.00 39 40 8648 97 6107 O0 6000 O0 40 0 8780 27 6207 O0 6100 O0 40 38 8910 85 6307 O0 6200 O0 39 24 9039 51 6407 O0 6300 O0 38 21 9167 03 6507 O0 6400 O0 38 21 9187 O0 6522 66 6415 66 38 21 N 15 59 W 5653 15 N 13 44 W 5735 99 N 14 20 W 5820 93 N 13 32 W 5904 76 N 13 3 W 5985 50 N 13 3 W 6064 41 N 13 3 W 6076 77 1 . 64 1.71 1.15 0.80 0.00 0.00 0.00 5369.97 N 1768 98 W 5653 84 N 18 14 W 5450.32 N 1789 58 W 5736 60 N 18 11 W 5532.82 N 1810 34 W 5821 46 N 18 7 W 5614.26 N 1830 79 W 5905 23 N 18 4 W 5693.00 N 1849 50 W 5985 90 N 18 0 W 5770.09 N 1867 35 W 6064 73 N 17 56 W 5782.17 N 1870 15 W 6077 08 N 17 55 W RECEIVED ;,'.~:-;i.,:E. 'ii & ~aS ..... ~ ...... ' ~ Ancherage COMPUTATION DATE' 30-AUG-93 PaGE 7 ARCO ALASKA, INC. 1Y - 18 KUPARUK NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C GCT LAST READING PBTD 7" CASING DATE OF SURVEY' AUG-16-1993 KELLY BUSHING ELEVATION' 107.00 Fl' ENGINEER' D. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS · SURFACE LOCATION 210' FNL & I734' FWL, SECOi TI1N RgE MEASURED DEPTH 'l-VD BELOW KB FROM KB SUB-SEA 6140.00 4420.22 4313.22 8572.00 6047.81 5940.8I' 9020.00 6391.71 6284.71 9084.00 6441.89 6334.89 9169.00 6508.55 6401.55 9187.00 6522.66 6415.66 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3708 90 N 5402 53 n 5681 21N 5719 90 N 5771 29 N 5782 17 N 1169.32 W 1777.80 W 1846.77 W 1855.73 W 1867.63 W 1870.15 W RECEIVED ~;,.~i & 8a$ Cons. Come,ss/on ~nchorage ARCO ALASKA, INC. 1Y - 18 KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUPARUK C PBTD 'T'D COMPUTATION DATE: 30-aug-g3 PAGE 8 DATE OF SURVEY: AUG-16-1993 KELLY BUSHING ELEVATION: 107.00 Fl' ENGINEER: D. WARNER SURFACE LOCATION = 210' FNL & 1734' FWL, SEC01TllN R9E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 8572.00 6047.81 5940.81 5402.53 N 1777.80 W 9084.00 6441.89 6334.89 5719.90 N 1855.73 W 9187.00 6522.66 6415.66 5782.17 N 1870.15 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9187.00 6522.66 6415.66 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6077.08 N 17 55 W RECEIVED CJI a Gas Cons. Commission Anchorage DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK WELL 1Y - 18 COUNTRY USA RUN I DATE LOGGED -16 - AUG - 19 DEPTH UNIT FEET REFERENCE 93388 RECE VEC) ~ ..... ~,,' O~i & Gas Cons. Commission Anchorage All Interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accur&cy or correctness of any Ir~erpretatlorts. and we shall not. except In the case of C ,ss or wllfull negligence on our part. be liable or responsible for any lose. costs, damages or expenses Incurred or ,u~talned by anyone resulting from any Interpretation made by any of our offlcer~, agents or employees. These Interpretations are also subject to our General Terms and Conditions as set out in our current price Schedule, WELL' 1¥-18 (210' FNL, 1734' Fi/L, SEC 1, TllN, R9E, UR) HORIZONTAL PROJECTION SC,~.E - I 1000 tN/FT 6000 5OOO 4000 3OOO 200O 1000 sou'iH -1000 -4000 WEST !";i'i",;ii"?' ~ ........... - ...................... .- i: ;i ~;;i.i i-~.i; iii.i, ~;91~l~iii i. iiii ilii ¢iii .;..ii.i i..;i..i..;;.i..i .i..i..ii i¢~. ;: ~ '; i ''~', .". i :'' i"'i! 'ii;' i; ~" ;' ' :,"; ':' i ,; i";: i":' '~ ..... ' := ;- !:il !ii! ~ ! i :'.~. i: ii ili i ! i il : ;i! ii;! i: ii !i!i i!i ~ '; .' '''. :: : :: : : ::':: !''i :': :: i : ; ! J · J i i . : :'' :~ 50C0 i: ..~ . . : ;'' ; :';;, : ; .... ;: ~: ~ i .'!i i! I i! '; !!!! ! ~ii : ;i:' ; "i ! ' !'i! : ; ' : .... ~ ...... '"'~ ........ : ...... :'":' .... ...... :'"i ....... i!"'~~' ..... ....... i---~ ......... ~ ............................. ,---! ....................................... :': ....... · : -:--:ii!- I;:~: i-i-:! :'~::"ii?'i .~:-:~I;: ::;; .... : ,.::: : :: :, : :: : :: :: :~ : , · . · . ~ : ~ i ~ ~ ~ , ! : ~ : ~ ~ ~' : : ~ ; .;.i...i.-¢ ..... ~ ...... ;..i ;' ; i ; ; .., i.~ ...... ; :., ; ........ i .... ~..~.~.~...~...~..,~...~...~...i...~...~...~ ...... t.~..~..i..~.~ ...... : : · : ~ ~ ~ ~ ' : ~ : : i ~ ! i ; i.i I i.l.i.i i..i i ; i ~ i.i : ~ , I i ! ; i i ; ~ ~ . ; : : :::: .:.: ..... :...:...:..:.: :::..: .... :s!: i-?;--! ..... i---ii.i -i ;i-: !-!-;i --!-i-i--i ;-i-;i ;~s.;i ~i.;.~ ..... :-i-.-; .... i ;--~.,I :-.:.;-;. , , ........ ....... ii!; I!I i!i! :!: !':~ .... :!i: :~i j ..!: ::: .:.: ; ;'; !''?';'"~'~:''; ..... ;~:'~F~'; ;~";'~;;:':;;~ :;~'~ ' -i.~-!.~j..?;-!~.::-., -3000 -2000 - 1000 0 1000 2000 3000 RECEIVED & Gas Coi~s. Commission Anchorage 4O0O WELL' {210' 1Y-18 FNL, 1734' FWL, SEC 1, T11N, RgE, Uti) VERTICAL PROJECTION 163.00 4000 6000 8000 10000 12000 P~OJECTION ON VEFITIOAL PLANE 16300 34.3100 ~OALED IN VERTICAL DEPTH~ i,iOV 1 6 ';1:)();) Gas Co,is. Commission Anchorage ARCO Alaska, Inc. Date: N~3vember 5, 1993 Transmittal #: 8919 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. Y-23 Y-18 c~..~ Y-27 Receipt Acknowledged: DISTRIBUTION: D&M NSK TDTP Depth Corrected CNTG Depth Corrected TDTP Depth Corrected CNTG Depth Corrected TDTP Depth Corrected CNTG Depth Corrected 10-22-93 6700-7304 10-22-93 6610-7364 10-22-93 8550-9062 10-22-93 8540-9080 10-22-93 9250-9790 10-22-93 9250-9810 Drilling State of Alaska (+Sepia) Date' Cmhe~ne Wodey(Oeology) Bob O~nas ARCO Alaska, Inc. Date: October 22, 1993 Transmittal Cf: 8903 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. '1Y-27 0J'5"3'~' /1Y-27 ~Y-27 ~Y-18 ~ ~ .-{.0~, 11Y'18 U.Y-18 'i Y-31 ~'clO 1Y-31. Y-31 I Y-28 ~)~ ,, ~o~ '11Y'28 L1Y-28 1Y-21 0[.-5 ,.. t0'L I 1Y-21 UY-21 Y-19 ~l'b -'t°7 Y-19 Y-19 cl ~-'7~ ~1Y-24 Il Y-34 ,/CDR Enhancement 5 '~ 8-23-93 LWD/Depth Corrected ¢CDN LWD/Depth Corrected~-~"8-23-93 ,/CDR LWD/Depth Corrected a'~5"8-23-93 v~CDN LWD/Depth Corrected z ~"9-08-93 ¢CDR Enhancement ~ 9-08-93 LWD/Depth Corrected ,-/CDR LWD/Depth Corrected z~-~"9-08-93 '/CDR LWD/Depth Corrected ~-~" 8-26-28-93 ,./CDR Enhancement 5" 8-26-28-93 LWD/Depth Corrected v'HLDT Corrected Casedhole 5" 10-08-93 Density ¢'CDR Enhancement 5 9-08-93 LWD/Depth Corrected ¢'CDR LWD/Depth Corrected ;z.t~ 9-08-93 ¢CDN LWD/Depth Corrected ;~ 9-08-93 ,-'CDR Enhancement _- 5 9-08-93 LWD/Depth Corrected *'CDR LWD/Depth Corrected 4~-~ 9-08-93 ,/CDN LWD/Depth Corrected .~s' 9-08-93 ,/CDN LWD/Depth Corrected .~t-3 9-09-93 ~CDR LWD/Depth Corrected =-~-5 9-09-93 ,/'CDR Enhancement 5' 9-09-93 LWD/Depth Corrected ¢TDTP Depth Corrected ~ 8-24-93 ¢/CDN LWD/Depth Corrected 2'¢~ 7-2-5-93 ..~CDR LWD/Depth Corrected z~ 7-2-5-93 Please acknowledge 8858-10012 8850-1OO18 8870-9990 8280-9180 8500-915O 8290-9160 6910-7830 7100-7700 7000-7700 7650-8250 7280-8250 7260-8250 6900-7450 6670-7640 6650-7590 6900-7610 6900-7660 7050-7500 745O-8220 6250-8640 625O-8640 ARCO Alaska, Inc. q5-72_ Date: October 22, 1993 'Transmittal #: 8904 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y- 19~5~-~z 1Y-34~~5 1Y-24~5~s,( 1Y-31 1Y-31-/~5~:5~ 1Y.27-~ 5~3 LIS Tape and Listing: 9-13-93 93327 o~-z-¢~/CDR/CDN/RAB Data 1Y-18.~5~q~t LIS Tape and Listing: 9-13-93. 93362 c~-'CDR/CDN, 1 Bit Run with QRO Processing ~ ~o-~,'7 1Y-28~5o LIS Tape and Listing: 9-14-93 93391 o~- CDR/CDN, 1 Bit Run with QRO Processing 1Y-2~5~5[ LIS Tape and Listing: 9-08-93 93347 ~'-CDPJCDN/RAB in 1 Bit Run and QRO Processing 5-~ .c~5--7u~/ LIS Tape and Listing: 9-13-93 93380 CDR/CDN, 1 Bit Run with QRO Processing LIS Tape and Listing: 9-24-93 93296 CDR/CDN, 2 Bit Runs, QR0 Processed b, ~r~--~,~ u~o LIS Tape and Listing: 8-24-93 93319 3 Passes TDTP, LDWG Format 75~5 -- ~_-'z_, LIS Tape and Listing: 9-13-93 93362 CDR in 1 Bit Run, QRO Processed u mso- LIS Tape and Listing: 10-08-93-93 93430 3 Passes, Averaged and Reprocessed HLDT Receipt Acknowledged: Bob Ocanas DISTRIBUTION: ARCO Alaska, Inc. Date: September 24, 1993 Transmittal #: 8870 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following ~items. receipt and return one signed copy of this transmittal. Please acknowledge ~ ~-~o(~ 1 Y- 18 q%i~o 1Y-31 q%~[c(~ 1Y-18 ~-~% 1Y-27 11Y'23 Y-23 1Y-27 ,,JDual Compensated Neutron 9-09-93 Cased Hole CNTG v' Dual Compensated Neutron 9-08-93 CNTG v/Thermal Decay Time Dual Burst 9-09-93 TDTP ,/ Thermal Decay Time Dual Burst 9-10-93 TDTP ,/Dual Compensated Neutron 9-08-93 Cased Hole CNTG v/Thermal Decay Time Dual Burst 9-08-93 TDTP ./Dual Compensated Neutron 9-10-93 Cased Hole CNTG Receipt Acknowledged' DISTRIBUTION: D&M 8550-9072 6450-7689 8550-9071 9250-9798 6600-7378 6700-7300 9250-9799 Drilling Catherine Worley(Geology) · State of Alaska (;Sepia) NSK Bob Ocanas ARCO Alaska, Inc. Date: September 10, 1993 Transmittal #: 8860 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~'~i~ 1Y-18 1Y-28 Receipt Acknowledged' Directional Survey Directional Survey DISTRIBUTION: 8-17-93 93388 8-24-93 93395 Date' D&M _ . . S'i~a-t'~--~f-Al'aska (2 copies) ARCO Alaska, Inc. Date: August 27, 1993 Transmittal Cf' 8846 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following~O~ased Hol~ items. receipt and return one signed copy of this transm~t~i. 1Y-19 ¢['~.. t~? 1Y-19 q%.- ~Of.~ Y-18 Cement Evaluation Log CET Cement Bond Log CBT Cement Evaluation Log CET Cement Bond Log CBT 8-15-93 8-15-93 8-16-93 8-16-93 Please acknowledge 6200-7541 ~\ 6200-7520 7500-9802 6890-9050 Receipt Acknowledge' Drilling Date' State of Alaska(+sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION July 28, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Kuparuk River Unit 1Y-18 ARCO Alaska, Inc. Permit No: 93-106 Sur. Loc. 210'FNL, 1734'FWL, Sec. 1, T!IN, R9E, UM Btmhole Loc. 412'FSL, 109'FEL, Sec. 26, T12N, R9E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout. prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redriil [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry F~ Deepen [~ Service r-~ Development Gas [] Single Zone X Multiple Zone ~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 107', Pad 66' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25641, ALK 2572 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 210' FNL,1,734' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 3' FSL, 19' FWL, Sec. 25, T12N, R9E, UM 1Y-18 #U-630610 At total depth 9. Approximate spud date Amount 412' FSL, 109' FEL, Sec. 26, T12N, R9E, UM 8-/.1/93 ~'/-"' '3~/'¢'/3 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 Y-19 9,277' MD 109' @ TD feet 29' @ 475' MD feet 2459 6,558' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 50° MaxJmumsurface 2,605 psig At total depth (TVD) 3,738 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'I-VD (include sta~ie data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 6,058' 41' 41' 6,099' 4,400' 560 Sx Permafrost E & HF-ERW 890 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 9,236' 41' 41' 9,277' 6,558' 200 SxClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Reddll, 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 Vedical depth ~t°rnU(~tu~rta°lr /-'~ E ~ ElY E D Surface Intermediate Production IU l., 2 6 1,99 Liner 'J Perforation depth: measured Alaska 0JJ & Gas Cons. 60rnrCssil true verticalAnchorage 20. Attachments Filing fee X Property plat ~ BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis ~ Seabed report BI 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -//~'/~'-~ ~- CommissionTitleuse Only Area Drillin, En~lineer Date Permit Number IAPInumber I Approval date7 ~,~~ I See cover ,etter for ~,,~--,,/~/' 50- 0~__~-- ~__~_,.,~ ~ "" other requirements Conditions Of approval Samples required [] Yes [~ No Mud Icg required [] Yes ~] No Hydrogen sulfide measures D Yes ,[~ No Directional survey required [~ Yes ~ No Required working pressure for BOPE [] 2M [] 3M [] 5M [] 10M [] 15M Other: Origina! S~gr~ed BY Approved by David W. Johnston by order of Commissioner the commission Date --'"' Form 10-401 Rev. 7-24-89 Submit in trieiicate Created by : jones For: D STOL'rZ Dote plat'ted : 20-May-93 Plot Reference is 18 Version ~4. Coordinates ore in feet reference slot ~18. True Vertical - o. o " - ' _ - _ . V - 52~0_ _ _ 5950_ . 6200. ,ARCO ALASKA, II-lC. Structure : Pod 1Y ; · Field : Kuporuk River Unit Well : 18 Location : North Slope, Alaska <-- West 2100 1750 1400 ~050 ~00 350 Depths ore reference wellhead.! I TD LOCATION' ~ ~ " J ~ ~ , I I I I N 17.34 DEG W I'~~"°"' I ~ 5755' (To ~A~T) I ~'~'~'~ I ~ T~ ~RTH ~93 ~ - . ~B E~X~: 107' W~ 1715 ~ / KOP WD=3~ TMD=~ DEP.0 ~ ~.~ ~ .~ Z ~ ~o.oo ~ _ 0 E~ ~=1771 ~D=1978 ~P-691 0 " K-10 ~5047 TM0~5~9 D~3318 ~ M~MUM ANG~ 50.35 DEG ~ ' ~ I~'°' ~' BEGIN ~GLE DROP ~=5561 ~D~9 ~5266 ~ 49 T~GET T/ ~ SNDS (EOD) ~-6~7 TMD-8~9 DEP 57~ T/ ZONE A ~=6288 TMD=8924 ~P 5957 N TARGET40 DEG~GLE = / ~ ~ ~ ~=~ ~=,~= ,s~=,,, ~ Alaska Oil & ~as" Cons. Commission Anchorage' I I I ~ I I I I I I I I I I I I I I I I I I ] I I I I I I I I ~ I I I I I I I 0 ~ 7~ 1~ 1~ 17~ 21~ 24~ 2~ 31~ ~ ~ 42~ 4~ 4~ 52 ~ 5~ Scale 1 : 175.00 Vertical Section on 342.66 azimuth wlth reference 0.00 N, 0.00 £ from slot ~118 ARCO ALASKA, Structure · Pad 1Y Field · Kuparuk River Unif Well · 18 / 19 / 21 Location · North Slope, Alaska s=~,: ~o.oo E a st - - > 1:2~0124.012~:)1~ 1,3~ 1400 14..4~ 1.4.~1~2'01~ 1600 1~4~ 16~0 I~ 17~:)1~00 1~40 1~ lg;~ 196,0 720 52'0 ~20 A 28O 2O0 7O0 ~ 1900 100 1700 2700 25O0 2500 47OO 1500 1'700 1.T, O0 720 520 .200 Z , . . . . , . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-18 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,099')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9,277') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AA(3 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro survey. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. 4iask~ Oi! & Gas Co~s, Oor~raissior~ DRILLING FLUID PROGRAM Well 1Y-18 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids . Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 +10% Drill out to wei[Iht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% 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 and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,605 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-18 is 1Y-19. As designed, the minimum distance between the two wells would be 29' @ 475' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. Oil & Gas Cons. Commission /-~,.,ri,. I ag ~ Casing Design / Cement Calculations 23-Jul-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 1Y-18 6,099 ft 4,400 ft 9,277 ft 6,558 ft 3,854 ft 8,636 ft 6,067 ft 11.3 ppg 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 4,400 ft {(13.5*0.052)-0.11 }*'l'VDshoe =[ 2,605 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight Top of Target Zone, TVD 100 psi Overbalance 11.3 ppg 6,067 ft 3,566 psi 3,466 psiI Surface lead: 5 4ft Top West Sak, TM D = Design lead bottom 500 ft above the Top of West Sak = 3,354 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,050 cf Excess factor = 15% Cement volume required = 1,208 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 560 sxI Surface tail: TMD shoe = 6,099 ft (surface TD - 500' above West Sak) * (Annulus area) = 860 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 894 cf Excess factor = 15% Cement volume required = 1,029 cf Yield for Class G cmt = 1.15 Cement volume required =[ 890 sxJ aiaska Oi~ & Gas Oep, s. 6omrp. Jssio~'~ Anchorage Casing Design/Cement Calculations 23-Jul-93 Production tail: TMD = Top of Target, TMD = Want TOC 500' above top of target = Annulus area (9" Hole) = (TD-TOC)*Annulus area = Length of cmt wanted in csg = Intemal csg volume = Cmt required in casing = Total cmt = Excess factor = Cement volume required = Yield for Class G cmt = Cement volume required =[ 9,277 fi 8,636 ft 8,136 fi 0.1745 199 cf 80 fi 0.2148 17 cf 216 cf 15% 249 cf 1.23 200 sx] TENSION - Minimum Design Factors are: T(pb)=l.5 and T(_is)=l.8 Surface (Pipe Body): Casing Rated For.' Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 564000 lb 6,099 fi 36.00 lb/fi 219564.0 lb 36721.0 lb 182843.0 lb Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 6,099 fi 36.00 lb/fi 219564.0 lb 36721.0 lb 182843.0 lb 3.5] Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 604000 lb 9,277 fi 26.00 lb/fi 241202.0 lb 41119.4 lb 200082.6 lb Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Fa(:;~jp~L~. J~ 667000 lb 9,277 ft 26.0O lb/fi 241202.0 lb 41119.4 lb 200082.6 lb 3.31 Alaska Oil 8, Gas Cons. Co~.~rnission Anchora§~ Casing Design/Cement Calculations BURST- Minimum Desitin Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =! Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*'I'VD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 23-Jul-93 3520 psi 2604.8 psi 1.41 7240 psi 7355 psi 3035 psi 4320 psi 1.71 2020 psi 0.588 Ib/ft 1650 psi 1.21 5410 psi 0.588 Ib/ft 3855 psi 1.4J Casing Design/Cement Calculations 23-Jul-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 916000 lb 3090 psi 5750 psi 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section I 7.000 6.276 26 L-80 7.5491 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength Body Strength Collapse Burst 667000 lb 604000 lb 5410 psi 7240 psi 490000 lb 415000 lb 4320 psi 4980 psi KUPARUK RIVER UNIT 21-1/4" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" -2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3/1Q/92 7 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITy TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOVVNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BO'I-rOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPQOL 4. 13-5/8' - 5000 PSi PIPE RAMS 5. 13-5,/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR SRE 8/22/89 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** ['2 -~hru i ] (3) Admin ~ ~ [10 & 13] (4) Casg ~ ~/~ [14 thru 22] (5) BOPE [23 thru ] e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YS 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. ~ Is adequate well bore separation proposed ................ ~ Is a diverter system required ............ Is drilling fluid program schematic & list of equipment adequate ..... ~,""" Are necessary diagrams & descriptions of diverter & BOPE attached .... ~ Does BOPE have sufficient pressure rating -- test to ~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... /~/.~ Is presence of H2S gas probable ...................................... Lease & Well ~'~/_ NO /-- (6) Other ~[29 thru 31] (7) Contact (8) Addl [32] geology' encjineer inq: DWJ MTM RAD TAB ~ rev 6/93 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE 77 /o C¢o ///do MERIDIAN' / / remarks' UM SM WELL TYPE' Exp/Dev Redrill · , Inj Rev 0 .-4 ""r' Z ~-.-, 0 (.n .-! 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. ALASKA COMPUTZNG CENTER SCHLUMBERGER COMPANY NAME : ARCO ALASKA, ZNC. WELL NAME : 1Y-18 FZELD NAME : KUPARUK RZVER BOROUGH : NORTH SLOPE STATE : ALASKA APZ NUMBER : 50-029-22390-00 REFERENCE NO : 93422 RECEIVED JAN ,~Jaska Oil & 6as Cons. Commission Anchorage LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen~er 28-0CT-1993 10:22 **~* REEL HEADER **** SERVICE NAME : EDIT DATE :93/10/27 ORIGIN : FLIC REEL NAME : 93422 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., 1Y-18, KUPARUK, 50-029-22390-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE :93/10/27 ORIGIN : FLIC TAPE NAME : 93422 CONTINUATTON # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., 1Y-18, KUPARUK, 50-029-22390-00 TAPE HEADER KUPARUK RIVER CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD SURFACE LOCATION 1Y-18 500292239000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 26-0CT-93 93422 JEFF FORMICA JIMMY PYRON 1 llN 9E 210 1734 107.00 107.00 66.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FF) WEIGHT (LB/F1-) IST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.625 6139.0 36.00 7.000 9169.0 26.00 PAGE: LIS Tape Veri¢ica%ion Listing 28-0CT-1993 10:22 Schlumberger Alaska Computing Center CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CET LDWG CURVE CODE: GR RUN NUMBER: 1 PASS NUMBER: 1 DATE LOGGED: 16-AUG-93 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES B^SELZNE DEPTH 88888 0 8970 0 8879 0 8837 0 8822 0 8792 0 8780 S 8699 0 100 0 REMARKS: GRCH 88888 S 8970 5 8879 S 8837 5 8822 0 8793 0 8781 $ 8700 0 101 0 EQUIVALENT UNSHZFTED DEPTH, THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT GRCH OF PASS 1 TO THE CASED HOLE CET/GR. ALL OTHER TDTP CURVES OF PASS 1 WERE CARRIED WITH THAT SHIFT. LIS FORMAT DATA LIS FORMAT DATA PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9055.0 8540.0 TDTP 9080.0 8540.0 $ LIS Tape Verifica¢ion Lis¢ing Schlumberger Alaska Compu¢ing CenCer 28-0CT-1993 10:22 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: EQUIVALENT UNSHZFTED DEPTH BASELINE DEPTH GRCH TDTP REMARKS: THIS FILE CONTAINS THE FIRST PASS OF THE TDTP, AND NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. THE GRCH.CET ZS CONTAINED ZN THIS PASS. LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 88 .4 66 $ 66 6 73 7 65 8 68 0.$ 9 65 FT 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440836 O0 000 O0 SIGM TDTP CU 440835 O0 000 O0 SZGC TDTP CU 440836 O0 000 O0 SZBH TDTP CU 440836 O0 000 O0 SDSI TDTP CU 440835 O0 000 O0 0 I I I 4 68 0000000000 0 I i I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: NAME SERV UNIT SERVICE API APZ API APZ FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHN TDTP CU 440836 O0 000 O0 SBHF TDTP CU 440836 O0 000 O0 TPHZ TDTP PU-S 440836 O0 000 O0 TRAT TDTP 440836 O0 000 O0 TCAN TDTP CPS 440836 O0 000 O0 TCAF TDTP CPS 440836 O0 000 O0 TCND TDTP CPS 440836 O0 000 O0 TCFD TDTP CPS 440836 O0 000 O0 TSCN TDTP CPS 440836 O0 000 O0 TSCF TDTP CPS 440836 O0 000 O0 ZNND TDTP CPS 440836 O0 000 O0 INFD TDTP CPS 440836 O0 000 O0 BACK TDTP CPS 440836 O0 000 O0 TBAC TDTP CPS 440836 O0 000 O0 GRCH TDTP GAPZ 440836 O0 000 O0 TENS TDTP LB 440836 O0 000 O0 GRCH CET GAPI 440836 O0 000 O0 0 1 ~ 1 4 68 0000000000 0 I ~ I 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 DATA DEPT. SDSI.TDTP TRAT.TDTP TCFD.TDTP INFD.TDTP TENS.TDTP DEPT. SDSI.TDTP TRAT.TDTP TCFD.TDTP INFD.TDTP TENS.TDTP 9183 000 -999 250 -999 250 -999 250 -999 250 -999 250 6888 000 -999 250 -999 250 -999 25O -999 250 -999 250 SIGM TDTP SBHN TDTP TCAN TDTP TSCN TDTP BACK TD1-P GRCH CET SIGM TDTP SBHN TDTP TCAN TDTP TSCN TDTP BACK TD'rP GRCH CET -999 250 SZGC.TDTP -999 260 SBHF.TDTP -999 250 TCAF.TDTP -999 250 TSCF.TDTP -999 250 TBAC.TDTP -999 250 -999 2S0 SIGC.TDTP -999 250 SBHF.TDTP -999 250 TCAF.TDTP -999 250 TSCF.TDTP -999 250 TBAC.TDTP 58 784 -999.250 SIBH.TDTP -999.2S0 TPHZ.TDTP -999.250 TCND.TDTP -999.2S0 ZNND.TDTP -999.250 QRCH.TDTP -999.2S0 SZBH.TDTP -999.250 TPHI.TDTP -999.2S0 TCND.TDTP -999.2S0 ZNND.TDTP -999.2S0 GRCH.TDTP -999.2S0 -999.2S0 -999.250 -999.250 -999.2S0 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifica%ion Listing Schlumberger Alaska Computing Cen%er **** FILE HEADER **** FILE NAME : EDIT .002 SERVTCE : FLIC VERSION : 001C01 DATE :93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-0CT-1993 10:22 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shif%ed and clipped curves for each pass in separate ¢i les. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9056.0 8540.0 TDTP 9080.0 8540.0 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWO CURVE CODE: GRCH PASS NUMBER: 1 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TD-FP 88888 0 9001 5 8971 5 8971 0 8889 5 8885 0 888O 5 8865 5 8782 0 8733 5 8733 0 8703 0 8597 0 8503 5 8541 0 100 0 REMARKS: 88888.0 88888.0 9001.5 8971.5 8971.0 8889.5 8885.5 8880.5 8782.5 8734.0 100.5 8865.5 8733.5 8703.0 8697.5 8603.5 8541.0 100.0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 2 GRCH TO PASS 1 GRCH, AND PASS 3 SIGM TO PASS 1 SZGM, WITH ALL OTHER TDTP CURVES CARRIED WITH THE SZGM SHIFTS. L~S Tape Verifica%ion Lis%lng Schlumberger Alaska Compu%ing CenCer LZS FORMAT DATA 28-0CT-1993 10:22 PAGE: ** DATA FORMAT SPECZFZCATZON RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 84 4 66 1 S 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 l 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNZT SERVZCE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR PROCESS ID ORDER ¢ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440836 O0 000 O0 SZGM TDTP CU 440836 O0 000 O0 SIGC TDTP CU 440836 O0 000 O0 SZBH TDTP CU 440836 O0 000 O0 SDSI TDTP CU 440836 O0 000 O0 SBHN TDTP CU 440836 O0 000 O0 SBHF TDTP CU 440836 O0 000 O0 TPHZ TDTP PU-S 440836 O0 000 O0 TRAT TDTP 440836 O0 000 O0 TCAN TDTP CPS 440836 O0 000 O0 TCAF TDTP CPS 440836 O0 000 O0 TCND TDTP CPS 440836 O0 000 O0 TCFD TDTP CPS 440836 O0 000 O0 TSCN TDTP CPS 440836 O0 000 O0 TSCF TDTP CPS 440836 O0 000 O0 INND TDTP CPS 440836 O0 000 O0 INFD TDTP CPS 440836 O0 000 O0 BACK TDTP CPS 440836 O0 000 O0 FBAC TDTP CPS 440836 O0 000 O0 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen~er 28-0CT-1993 10:22 PAGE: NAME SERV UNIT SERVICE APZ APZ APZ APZ FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GRCH TDTP GAPI 440836 O0 000 O0 TENS TDTP LB 440836 O0 000 O0 0 2 I I 4 68 0000000000 0 2 I I 4 68 0000000000 ** ~ATA ** DEPT. SDSZ.TDTP TRAT.TDTP TCFD,TDTP INFD,TDTP TENS,TDTP DEPT SDSZ TDTP TRAT TDTP TCFD TDTP INFD TDTP TENS TDTP 9080 000 0 801 2 297 3417 374 401 721 1870 000 8546 SO0 1 221 1 641 2540 571 330 182 1700 000 SIGM,TDTP 45.592 SIGC.TDTP 0.000 SIBH.TDTP 99.730 SBHN.TDTP 67.683 SBHF,TDTP 46.486 TPHZ.TDTP 96.012 TCAN.TDTP 78169.156 TCAF.TDTP 17834.512 TCND.TDTP 15959.994 TSCN.TDTP 1445.244 TSCF.TDTP 277.835 INND.TDTP 2574.710 BACK.TDTP 218.785 FBAC.TDTP 157.923 GRCH.TDTP -999.250 SIQM.TDTP 54.635 SIQC.TDTP 0.000 SIBH.TDTP 108.708 SBHN.TDTP 71.641 SBHF.TDTP 67.607 TPHI.TDTP 69.093 TCAN.TDTP 44910.195 TCAF.TDTP 10471.475 TCND.TDTP 11760.293 TSCN.TDTP 563.442 TSCF.TDTP 137.875 ZNND.TDTP 2186.545 BACK.TDTP 185.805 FBAC.TDTP 37.367 GRCH.TDTP 85.438 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES LIS Tape Veri¢ication Listing Schlumberger Alaska Computing Center 28-0CT-1993 10'22 Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LbWG TOOL CODE START DEPTH STOP DEPTH GRCH 9056.0 8540.0 TDTP 9080.0 8540.0 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) B^SELZNE CURVE FOR SHIFTS LDWQ CURVE CODE: GRCH PASS NUMBER: I E~UZVALENT UNSHZFTED DEPTH BASELINE DEPTH GRCH TDTP 88888 0 9001 5 8971 5 8971 0 8889 5 8885 0 8880 5 8865 5 8782 0 8733 5 8733 0 8703 0 8697 0 8603 5 8541 0 100 0 REMARKS: 88888.0 88888.0 9001.5 8971.5 8971.0 8889.5 8885.5 8880.5 8782.5 8734.0 100.5 8865.5 8733.5 8703.0 8697.5 8603.5 8541.0 100.0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 3 GRCH TO PASS 1 GRCH, AND PASS 3 SIGM TO PASS 1 SIGM, WITH ALL OTHER TDTP CURVES CARRIED WITH THE SZGM SHIFTS. $ LIS FORMAT DATA PAGE' ** DATA FORMAT SPECIFICATION RECORD ** ** S~ TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LZS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: TYPE REPR CODE VALUE 3 73 84 4 66 1 S 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 1S 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNZT SERVZCE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440836 O0 000 O0 SZGM TDTP CU 440836 O0 000 O0 SIGC TDTP CU 440836 O0 000 O0 SZBH TDTP CU 440836 O0 000 O0 SDSZ TDTP CU 440836 O0 000 O0 SBHN TDTP CU 440836 O0 000 O0 SBHF TDTP CU. 440836 O0 000 O0 TPHZ TDTP PU-S 440836 O0 000 O0 TRAT TDTP 440836 O0 000 O0 TCAN TDTP CPS 440836 O0 000 O0 TCAF TDTP CPS 440836 O0 000 O0 TCND TDTP CPS 440836 O0 000 O0 TCFD TDTP CPS 440836 O0 000 O0 TSCN TDTP CPS 440836 O0 000 O0 TSCF TDTP CPS 440836 O0 000 O0 ZNND TDTP CPS 440836 O0 000 O0 ZNFD TDTP CPS 440836 O0 000 O0 BACK TDTP CPS 440836 O0 000 O0 FBAC TDTP CPS 440836 O0 000 O0 GRCH TDTP GAPZ 440836 O0 000 O0 TENS -I'D-I-P LB 440836 O0 000 O0 0 3 1 I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 .0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 -0000000000 0 3 I 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 I 1 4 68 0000000000 0 3 I 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 I 1 4 68 0000000000 ** DATA ** DEPT. 9080.000 SDSI.TDTP 0.977 TRAT.TDTP 1.106 TCFD.TDTP 4048.083 INFD.TDTP 373.081 SIGM.TDTP 29.693 SIGC.TDTP 6.935 SIBH.TD-I-P 8S.S30 SBHN.TD-FP 65.056 SBHF.TDTP 63.199 TPHI.TDTP 20.913 TCAN.TDTP 37311.367 TCAF.TDTP 12408.174 TCND.TDTP 15336.232 TSCN.TDTP 1156.S72 TSCF.TDTP 673.502 ZNND.TDTP 22S2.638 BACK.TDTP 270.923 FBAC.TDTP 147.539 GRCH.TDTP -999.2S0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0¢T-1993 10:22 PAGE: 10 TENS.TDTP 1830.000 DEPT. 8540.000 SDSI.TDTP 0.975 TRAT.TDTP 1.512 TCFD.TDTP 3096.791 INFD.TDTP 329.857 TENS.TDTP 1640.000 SIGM.TDTP 48.991 SIGC.TDTP 1.316 SIBH.TDTP 105.580 SBHN.TDTP 70.261 SBHF.TDTP 64.455 TPHI.TDTP 61.555 TCAN.TDTP 53862.461 TCAF.TDTP 13759.912 TCND.TDTP 13358.262 TSCN.TDTP 725.330 TSCF.TDTP 207.291 INND.TDTP 2209.479 BACK.TDTP 198.961 FBAC.TDTP 36.545 GRCH.TDTP 72.438 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX RE¢ SIZE : 1024 FILE TYPE .: LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes ¢or all curves. Pulsed Neutron: Unaveraged edited Pass I gamma ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED ZN AVERAGE LDWG TOOL CODE PASS NUMBERS GRCH 1, 2, 3 $ REMARKS: THE ARITHMETIC AVERAGE DF PASSES 1, 2 A 3 WAS CDMPLFFED AFTER ALL DEPTH ADJUSTMENTS WERE APPLIED. $ LIS FORMAT DATA LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er 28-OCT-1993 10:22 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 $ 66 6 73 7 65 8 68 0.$ 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API aPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440836 O0 000 O0 0 4 1 1 4 68 -0000000000 SIGM PNAV CU 440836 O0 000 O0 0 4 I I 4 68 0000000000 SIGC PNAV CU 440836 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 440836 O0 000 O0 0 4 1 1 4 68 -0000000000 SDSI PNAV CU 440836 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN PNAV CU 440836 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 440836 O0 000 O0 0 4 I 1 4 68 0000000000 TCAN PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 440836 O0 000 O0 0 4 1 I 4 68 0000000000 INFD PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 BACK PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PNAV CPS 440836 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH PNAV GAPZ 440836 O0 000 O0 0 4 1 I 4 68 0000000000 TENS PNAV LB 440836 O0 000 O0 0 4 1 I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0¢T-1993 10:22 PAGE: 12 DATA DEPT. SDSZ.PNAV TRAT.PNAV TCFD.PNAV INFD.PNAV TENS.PNAV 9080 000 0 892 I 661 3869 293 410 079 1889 811 SIGM.PNAV 40.058 SIGC.PNAV 2.311 SIBH.PNAV 92.547 SBHN.PNAV 65.725 SBHF.PNAV 57.481 TPHI.PNAV 59,627 TCAN.PNAV S4944.930 TCAF.PNAV 14948.086 TCND.PNAV 16028.682 TSCN.PNAV 1312.$85 TSCF.PNAV 474.025 INND.PNAV 2468.247 BACK.PNAV 118.135 FBAC.PNAV 126.785 GRCH.PNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 BATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and og header data for each pass in separate files; raw background pass in last fi PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 9083.0 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: -FO DRILLER (FT): TD LOGGER (F-F): 85S0.0 09-SEP-93 CP 32.6 1500 09-SEP-93 9084.0 9078.0 LIS Tape Verificabion Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LDGGZNG SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP CASING COLLAR LOG TDTP TELEMETRY CARTRIDGE TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY 8550.0 9071.0 600.0 NO TOOL NUMBER CAL-UB 1269 ATC-CB 1199 TNC-P 39O TND-P C-395 TNG-P B-400 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 6139.0 BRINE 11. O0 164.0 NEUTRON TOOL TOOL TYPE (EPZTHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): NEITHER SANDSTONE 2.65 BLUELZNE COUNT RATE NORMALIZATION ZN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELZNE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 40 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 40 REMARKS: TOOL STANDOFF (IN): TIED INTO SWS CET DATED 16-AUG-1993. RAN THREE TDTP PASSES ~ 600 FPH. $ PAGE: 13 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er LIS FORMAT DATA 28-0CT-1993 10:22 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 256 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APZ APZ APZ APZ FILE NUMB NUMB SIZE REPR. PROCESS ZD ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440836 O0 000 O0 0 5 1 1 4 68 .0000000000 SIGM PS1 CU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 STDT PS1 440836 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 ISHU PS1 V 440836 O0 000 O0 0 5 1 1 4 68 0000000000 SFFD PS1 CU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 SFND PS1 CU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PSZ CU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN PS1 CU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 FTDT PS1 CPS 440836 00 000 00 0 6 1 1 4 68 0000000000 N-FDT PS1 CPS 440836 O0 000 O0 0 6 1 1 4 68 0000000000 AFFD PS1 CPS 440836 O0 000 O0 0 6 1 1 4 68 0000000000 ABFD PS1 CPS 440836 O0 000 O0 0 5 1 1 4 68 0000000000 AFND PS1 CPS 440836 O0 000 O0 0 5 1 1 4 68 0000000000 ABND PS1 CPS 440836 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PSI CU 440836 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS1 CU 440836 O0 000 O0 0 5 1 1 4 68 0000000000 MMOF PS1 440836 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 440836 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 440836 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS1 CPS 440836 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verifica¢ion Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: 1S NAME SERV UNZT SERVZCE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR PROCESS ZD ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FBAC PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 TCAN PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 TCAF PS1 CPS 440836 O0 000 O0 0 5 I 1 4 68 0000000000 TCND PS1 CPS 440836 O0 000 O0 0 5 I 1 4 68 0000000000 TCFD PS1 CPS 440836 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 TSCF PS1 CPS 440836 O0 000 O0 0 5 1 1 4 68 0000000000 ZNND PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 INFD PS1 CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RN1 PSI CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN2 PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN3 PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN4 PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN5 PSI CPS 440836 O0 000 O0 0 5 1 1 4 68 0000000000 RN6 PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN7 PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 '0000000000 RN8 PS1 CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN9 PSi CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RNIO PS1 CPS 440836 O0 000 O0 0 S 1 1 4 68 0000000000 RNll PS1 CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RNI2 PSI CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RN13 PSI CPS 440836 O0 000 O0 0 S I I 4 68 0000000000 RN14 PS1 CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RNIS PS1 CPS 440836 O0 000 O0 0 S 1 1 4 68 0000000000 RN16 PS1 CPS 440836 O0 000 O0 0 S I 1 4 68 0000000000 RN1 PSI CPS 440836 O0 000 O0 0 S I ~ 4 68 0000000000 RN2 PSI CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RN3 PSI CPS 440836 O0 000 O0 0 $ I 1 4 68 .0000000000 RN4 PSi CPS 440836 O0 000 O0 0 $ 1 1 4 68 0000000000 RN$ PSI CPS 440836 O0 000 O0 0 S I ~ 4 68 0000000000 RN6 PSi CPS 440836 O0 000 O0 0 S 1 ~ 4 68 -0000000000 RN7 PSI CPS 440836 O0 000 O0 0 S I 1 4 68 0000000000 RN8 PSI CPS 440836 O0 000 O0 0 S 1 1 4 68 0000000000 RN9 PSI CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RNIO PS1 CPS 440836 O0 000 O0 0 S I 1 4 68 0000000000 RN11 PSI CPS 440836 O0 000 O0 0 $ I I 4 68 0000000000 RN12 PS1 CPS 440836 O0 000 O0 0 S I ~ 4 68 0000000000 RN13 PSI CPS 440836 O0 000 O0 0 S 1 ~ 4 68 0000000000 RN14 PSi CPS 440836 O0 000 O0 0 S 1 Z 4 68 0000000000 RNI$ PS1 CPS 440836 O0 000 O0 0 $ I 1 4 68 0000000000 RN16 PS1 CPS 440836 O0 000 O0 0 S 1 I 4 68 0000000000 GR PS1 GAPZ 440836 O0 000 O0 0 S I 1 4 68 0000000000 TENS PSI LB 440836 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er DEPT, ISHU,PS1 SBHN.PS1 ABFD PS1 $IBH PS1 BACK PS1 TCND PS1 INND PSI RN3 PS1 RN7 RNll PS1 RN15 PSI RN3 PS1 RN7 PS1 RNlt PS1 RNI$ PS1 9089 000 0 000 69 296 84 958 79 644 7 361 -999 250 -0 250 0 000 0 000 0 000 0 000 0 000 0 000 0 000 0 000 SIGM PS1 SFFD FTDT AFND PS1 MMOF PS1 FBAC PS1 TCFD PSI INFD PS1 RN4 PSt RN8 PS1 RN12 PS1 RN16 PS1 RN4 PS1 RN8 PS1 RN12 PSt RN16 PS1 DEPT ISHU SBHN.PS1 ABFD.PS1 SIBH.PS1 BACK.PS1 TCND.PSl INND.PSl RN3.PSI RN7 PS1 RNlt PS1 RN15 PS1 RN3 PSI RN7 PS1 RNlt PS1 RNI$ PS1 8537 000 42 969 58 622 94 174 101 166 352 12268 164 2142 945 1183 594 526 042 1402 344 515 625 294 715 1.09 248 358 232 100 356 SIOM PSI SFFD PSI FTDT PSI AFND MMOF FBAC PS1 TCFD PSI INFD PS1 RN4 PS1 RN8 PS1 RN12 PS1 RN16 PS1 RN4 PS1 RN8 PS1 RN12 PS1 RN16 PS1 28-0CT-1993 10-22 53 581 STDT PS1 53 0 575 -999 2 -999 -0 0 0 0 0 0 0 0 0 999 SFND 000 NTDT 668 ABND 250 TRAT 629 TCAN 250 TSCN 089 RN1 000 RN5 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 000 RN9.PS1 000 RN13.PS1 000 RN1.PS1 000 RNS.PS1 000 RNg.PSl 000 RN13.PSl 000 GR.PSl 53 983 STDT.PS1 54 1 487 0 32 2728 347 1484 855 1016 631 339 270 240 116 330 SFND.PS1 764 NTDT.PS1 825 ABND.PS1 929 TRAT.PS1 684 TCAN.PS1 935 TSCN.PS1 646 RN1.PS1 375 RNS.PSl 469 RNg.PSl 927 RN13.PS1 510 RN1.PS1 177 RNS.PS1 579 RNg.PS1 091 RN13.PS1 87O GR.PS1 0 000 TPHI PS1 53 0 401 0 0 0 0 581 SBHF 000 AFFD 289 SZOC 000 SDSI 000 TCAF 000 TSCF 000 RN2 0 000 RN6 0 000 RNIO 0 000 RN14 0 000 RN2 0 000 RN6 0 000 RNIO 0.000 RN14 0.000 TENS PSI PS1 PS1 PSi PS1 PS1 PS1 PSI PS1 PS1 PS1 PSi PS1 PS1 PSI 66.000 TPHI PS1 54 165 SBHF 7 432 1 48921 616 906 1345 1444 613 306 330 381 35O AFFD 538 SIGC 618 SDSI 945 TCAF 749 TSCF 250 RN2 O52 RN6 010 RNIO 281 RN14 148 RN2 285 RN6 O98 RNIO 138.465 RN14 56.906 TENS PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PAGE: 16 0 000 62 382 132 584 0 000 0 981 0 000 0 000 0 000 0 000 0 000 0 000 0 000 0 000 0 000 0 000 295 000 67 611 67 180 91 570 0 091 1 133 11599 779 147 530 152 220 1089 844 1299 479 440 104 33 342 254 065 337 906 88 923 1725 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen%er **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-0CT-1993 10:22 PAGE: 17 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and Icg header da~a for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH files; raw background pass in las~ fi TDTP $ LOG HEADER DATA 9083.0 8550.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT.): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BO-I-I-OM) VENDOR TOOL CODE TOOL TYPE 09-SEP-93 CP 32.6 1500 09-SEP-93 9084.0 9078.0 8550.0 9071.0 600.0 NO TOOL NUMBER TDTP TDTP TDTP TDTP TDTP CASING COLLAR LOG TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSTTY (LB/G): SURFACE TEMPERATURE (DEGF): CAL-UB 1269 ATC-CB 1199 TNC-P 39O TND-P C-395 TNG-P B-400 6139.0 BRINE 11.00 LIS Tape Veri¢icat, ion Listing Schlumberger Alaska Compu%ing Cen%er 28-0CT-1993 10'22 PAGE' 18 BOIl-OM HOLE TEMPERATURE (DEGF): FLUID SALINTTY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DE(~): NEUTRON TOOL TOOL TYPE (EPZTHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): :[64.0 NEITHER SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION ZN OIL ZONE TOP NORMALIZING WINDOW (FT)' BASE NORMALIZING WINDOW (FT)' BLUELZNE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 40 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 40 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS CET DATED :[6-AUG-1993. ~AN THREE TDTP PASSES ~ 600 FPH. LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 $ 73 256 4 66 1 $ 66 6 73 7 8 68 0.$ 9 65 FT 11 66 4 12 68 lS 66 o 14 65 LZS Tape Verifica%ion Lis%lng Schlumberger Alaska Compu%ing Cen%er 28-OCT-1993 10'22 PAGE- 19 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNZT SERVZCE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR ZD ORDER # LOQ TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 440836 O0 000 O0 0 6 1 1 4 68 SIGM PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 STDT PS2 440836 O0 000 O0 0 6 1 1 4 68 TPHI PS2 PU 440836 O0 000 O0 0 6 1 1 4 68 ISHU PS2 V 440836 O0 000 O0 0 6 1 i 4 68 SFFD PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 SFND PS2 CU 440836 O0 000 O0 0 6 1 I 4 68 SBHF PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 SBHN PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 FTDT PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 NTDT PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 AFFD PS2 CPS 440836 O0 000 O0 0 6 I 1 4 68 ABFD PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 AFND PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 ABND PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 SIGC PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 SIBH PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 MMOF PS2 440836 O0 000 O0 0 6 1 1 4 68 TRAT PS2 440836 O0 000 O0 0 6 1 1 4 68 SDSI PS2 CU 440836 O0 000 O0 0 6 1 1 4 68 BACK PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 FBAC PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 TCAN PS2 CPS 440835 O0 000 O0 0 6 1 I 4 68 TCAF PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 TCND PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 TCFD PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 TSCN PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 TSCF PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 INND PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 INFD PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN1 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN2 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN3 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN4 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN5 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN6 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN7 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RN8 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN9 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RNIO PS2 CPS 440835 O0 000 O0 0 6 1 1 4 68 RNll PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 RN12 PS2 CPS 440836 O0 000 O0 0 6 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 '0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 .0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LZS Tape Veri¢ication Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: 2O NAME SERV UNTT SERVZCE APZ APZ APZ APZ FTLE NUMB NUMB SZZE REPR ZD ORDER # LOG TYPE CLASS MOD NUMB SAMP ELF___M CODE PROCESS (HEX) RN13 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RN14 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RNI$ PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RN16 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF1 PS2 CPS 440836 O0 000 O0 0 6 I 1 4 68 RF2 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF3 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF4 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF$ PS2 CPS 440836 O0 000 O0 0 6 I 1 4 68 RF6 PS2 CPS 440836 O0 000 O0 0 6 I 1 4 68 RF7 PS2 CPS 440836 O0 000 O0 0 6 i I 4 68 RF8 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF9 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RFIO PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF11 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF12 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF13 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF14 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF15 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 RF16 PS2 CPS 440836 O0 000 O0 0 6 I I 4 68 GR PS2 GAPI 440836 O0 000 O0 0 6 I I 4 68 TENS PS2 LB 440836 O0 000 O0 0 6 I I 4 68 0000o00000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 '0000000000 0000000000 0000000000 0000000000 o0000000o0 0000000000 0000000000 ** DATA ** DEPT. ZSHU.PS2 SBHN.PS2 ABFD.PS2 SZBH.PS2 BACK.PS2 TCND.PS2 ZNND.PS2 RN3.PS2 RNT.PS2 RN11 PS2 RNIS PS2 RF3 PS2 RF7 PS2 RF11 PS2 RFI$ PS2 9088 000 43 813 68 622 94 174 101 861 166 352 12263 164 2142 945 1330 492 771 780 1846 591 795 454 288 826 312 500 525 568 440 341 DEPT ZSHU SBHN ABFD SIBH BACK TCND PS2 PS2 PS2 PS2 PS2 PS2 8546.000 38.188 71.641 88.975 108.708 185.805 11760.293 SZGM PS2 SFFD PS2 FTDT PS2 AFND PS2 MMOF PS2 FBAC PS2 TCFD PS2 ZNFD PS2 RN4 PS2 RN8 PS2 RN12 PS2 RN16 PS2 RF4 PS2 RF8 PS2 RF12 PS2 RF16 PS2 SZGM PS2 SFFD PS2 FTDT PS2 AFND PS2 MMOF PS2 FBAC PS2 TCFD PS2 53 983 54 330 1 764 487 825 0 929 32 684 2728 935 347 646 1737 689 913 826 1429 924 923 295 445 076 326 705 435 606 549 242 54 635 55 302 1 678 474 884 0 917 37 367 2540 571 STDT.PS2 SFND.PS2 NTDT.PS2 ABND.PS2 TRAT.PS2 TCAN.PS2 TSCN PS2 RN1 PS2 RN$ PS2 RN9 PS2 RN13 PS2 RF1 PS2 RF5 PS2 RF9 PS2 RF13 PS2 GR PS2 STDT PS2 SFND PS2 NTDT PS2 ABND PS2 TRAT PS2 TCAN PS2 TSCN PS2 66 000 TRHI PS2 54 7 432 1 48921 616 975 1595 1638 1022 355 454 478 369 263 165 SBHF 350 AFFD 538 SI-GC 618 SDSI 945 TCAF 749 TSCF 379 RN2 644 RN6 257 RNIO 727 RN14 114 RF2 545 RF6 22O RFIO 318 RF14 000 TENS PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 66 000 TPHI PS2 54 635 SBHF PS2 6 773 AFFD PS2 428 653 SIGC PS2 I 641 SDSZ PS2 44910 195 TCAF PS2 563 442 TSCF PS2 67.611 67 180 91 570 0 091 1 133 11599 779 147 530 206 400 1439 394 1529 356 738 636 154 800 464 015 411 932 355 114 1505 000 69 093 67 607 87 827 0 000 1 221 10471 475 137 875 LIS Tape Verification Listing Schlumberger Alaska Computing Center INND PS2 RN3 PS2 RN7 PS2 RNll PS2 RNI$ PS2 RF3 PS2 RF7 PS2 RFll PS2 RFI$ PS2 2186 545 1177 591 517 022 1261 433 551 321 257 812 114 583 328 125 113 281 INFD PS2 RN4 PS2 RN8 PS2 RN12 PS2 RN16 PS2 RF4 PS2 RF8 PS2 RF12 PS2 RF16 PS2 28-0CT-1993 10:22 330 182 1453 252 854 929 867 632 693 598 347 656 265 625 217 448 130 208 RN1 PS2 RN5 PS2 RN9 PS2 RN13 PS2 RF1 PS2 RF5 PS2 RF9 PS2 RF13 PS2 GR PS2 924.797 1285.569 RN6 1366 870 RNIO 546 240 RN14 289 062 RF2 291 667 RF6 360 677 RFIO 145 833 RF14 85438 TENS RN2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PAGE: 21 174.150 997 205 1167 429 434 451 32 250 225 26O 296 875 91 146 1700 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE .: 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header da%a for each pass in separate PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH files; raw background pass in last fi TDTP 9083. o $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): 8550.0 09-SEP-93 CP 32.6 1500 09-SEP-93 9084.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: 22 Tb LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LSGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9078.0 85S0.0 9071.0 600.0 NO TOOL NUMBER TDTP TDTP TDTP TDTP TDTP $ CASING COLLAR LOG TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY CAL-UB 1269 ATC-CB 1199 TNC-P 39O TND-P C-395 TNG-P B-400 BOREHDLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 6139.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE 11.00 164.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): NEITHER SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION ZN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELZNE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 40 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 40 REMARKS: TOOL STANDOFF (IN): TIED INTO SWS CET DATED 16-AUG-1993. ~AN THREE -FDTP PASSES ~ 600 FPH. $ LZS Tape Verification Li$%ing Schlumberger Alaska Computing Cen~er LTS FORMAT DATA 28-06T-1993 10:22 PAGE: 23 ** DATA FORMAT SPECZFZCATZON RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 256 4 66 $ 66 6 73 7 65 8 68 0.$ 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNZT SERVZCE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR ID ORDER ¢ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 440835 O0 000 O0 0 7 1 1 4 68 SIGM PS3 CU 440836 O0 000 O0 0 7 I I 4 68 STDT PS3 440836 O0 000 O0 0 7 1 1 4 68 TPHZ PS3 PU 440836 O0 000 O0 0 7 1 1 4 68 ISHU PS3 V 440836 O0 000 O0 0 7 1 1 4 68 SFFD PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 SFND PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 SBHF PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 SBHN PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 FTDT PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 NTDT PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 AFFD PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 ABFD PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 AFND PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 ABND PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 SIGC PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 SIBH PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 MMOF PS3 440836 O0 000 O0 0 7 1 1 4 68 TRAT PS3 440836 O0 000 O0 0 7 1 1 4 68 SDSI PS3 CU 440836 O0 000 O0 0 7 1 1 4 68 0o00000000 0000000000 o000o000o0 0000000000 000o0o0000 000o000000 00000o0o00 0000000000 o000o00000 000o0o000o 0000000o0o 0000000000 000000o000 0000000o00 000o000o0o 000000o0o0 0000000o00 0000000000 00o0000000 o000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: 24 NAME SERV UNIT SERVICE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR PROCESS ZD ORDER # LO~ TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BACK PS3 CPS 440836 O0 000 O0 0 7 i 1 4 68 0000000000 FBAC PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 440836 O0 000 O0 0 7 1 ~ 4 68 0000000000 TSCN PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 ZNND PS3 CPS 440836 O0 000 O0 0 ¥ 1 1 4 68 0000000000 ZNFD PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 RN1 PS3 CPS 440836 O0 000 O0 0 7 1 I 4 68 0000000000 RN2 PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RN3 PS3 CPS 440836 O0 000 O0 0 7 1 ~ 4 68 0000000000 RN4 PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RN5 PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 RN5 PS3 CPS 440836 O0 000 O0 0 7 [ 1 4 68 '0000000000 RN7 PS3 CPS 440836 O0 000 O0 0 7 Z Z 4 68 0000000000 RN8 PS3 CPS 440836 O0 000 O0 0 7 1 Z 4 68 0000000000 RN9 PS3 CPS 440836 O0 000 O0 0 7 1 ~ 4 68 0000000000 RNIO PS3 CPS 440836 O0 000 O0 0 7 ~ 1 4 68 0000000000 RNZl PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RNi2 PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RN13 PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 RN14 PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 RNZ5 PS3 CPS 440826 O0 000 O0 0 7 I I 4 68 0000000000 RN16 PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 RF1 PS3 CPS. 440836 O0 000 O0 0 7 I I 4 68 0000000000 RF2 PS3 CPS 440836 O0 000 O0 0 7 1 I 4 68 0000000000 RF3 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF4 PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RF5 PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RFC PS3 CPS 440836 O0 000 O0 0 7 I Z 4 68 0000000000 RF7 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF8 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF9 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RFiO PS3 CPS 440836 O0 000 O0 0 7 1 1 4 68 0000000000 RF11 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF12 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF13 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF14 PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 RF15 PS3 CPS 440836 O0 000 O0 0 7 I 1 4 68 0000000000 RF16 PS3 CPS 440836 O0 000 O0 0 7 I I 4 68 0000000000 GR PS3 GAPZ 440836 O0 000 O0 0 7 I I 4 68 0000000000 TENS PS3 LB 440836 O0 000 O0 0 7 I I 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. ISHU. PS3 SBHN. PS3 ABFD, PS3 STBH. PS3 BACK, PS3 TCND. PS3 INND PS3 RN3 PS3 RN7' PS3 RNll PS3 RNI$ PS3 RF3 PS3 RF7 .PS3 RFll ,PS3 RFI$ .PS3 9089 000 42 969 71 641 88 975 108 708 185 8O5 11760 293 2186 545 1306 818 833 333 1827 651 842 803 364 583 355 114 487 689 558 712 SIGM PS3 SFFD PS3 FTDT PS3 AFND PS3 MMOF PS3 FBAC PS3 TCFD PS3 INFD PS3 RN4 PS3 RN8 PS3 RN12 PS3 RN16 PS3 RF4 PS3 RF8 PS3 RF12 PS3 RF16.PS3 DEPT, ISHU.PS3 SBHN.PS3 ABFD PS3 SIBH PS3 BACK PS3 TCND PS3 ZNND PS3 RN3 PS3 RN7 PS3 RNll PS3 RN15.PS3 RF3.PS3 RF7.PS3 RFll.PS3 RF15.PS3 8539 000 45 125 68 407 94 659 101 373 197 208 12263 504 2055 011 1167 969 565 104 1420 573 583 333 287 760 144 531 394 531 119 792 SIGM PS3 SFFD PS3 FTDT PS3 AFND PS3 MMOF PS3 FBAC PS3 TCFD PS3 ZNFD PS3 RN4 PS3 RN8 PS3 RN12 PS3 RN16 PS3 RF4 PS3 RF8 PS3 RF12 PS3 RF16 PS3 28-0CT-1993 10'22 54 635 STDT PS3 55 1 474 0 37 2540 33O 1742 875 1448 956 430 307 449 705 3O2 SFND 678 NTDT 884 ABND 917 TRAT 367 TCAN 571 TSCN 182 RN1 424 RN5 947 RN9 864 RN13 439 RF1 871 RF5 765 RF9 811 RF13 492 GR PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 52.065 STDT PS3 53,005 SFND 1,945 NTDT 487,480 ABND 1 059 TRAT 37 2813 321 1464 85O 985 729 346 272 247 149 785 TCAN 210 TSCN 241 RN1 844 RN5 260 RN9 677 RN13 167 RF1 354 RF5 135 RF9 396 RF13 740 GR PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 66.000 TPHZ PS3 54.635 SBHF 6,773 AFFD 428.653 SIGC 1.641 SDSI 44910,195 TCAF 563.442 TSCF 946.970 RN2 1628.788 RN6 1652.462 RNIO 1055 871 RN14 321 970 RF2 445 076 RF6 468 750 RFIO 430 871 RF14 282 750 TENS PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 66.000 TPHI.PS3 52.556 SBHF.PS3 7.263 AFFD.PS3 436.637 SlGC PS3 1.528 SDSI 48638.688 TCAF 628.142 TSCF 808,594 RN2 1355.469 RN6 1415 365 RNIO 647 135 RN14 263 021 RF2 329 427 RF6 385 417 RFIO 158 854 RF14 94 813 TENS PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PAGE- 25 69.093 67 607 87 827 0 000 1 221 10471 475 137 875 258 000 1382 576 1482 0O7 771 780 144 480 440 341 454 545 411 932 1395 000 62 686 62 987 93 983 0 243 1 053 12180 711 166 788 193 500 1104 167 1250 000 479 167 37 410 273 437 329 427 109 375 1685 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LZS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 10:22 PAGE: 26 **** TAPE TRAZLER **** SERVZCE NAME : EDZT DATE : 93/10/27 ORZGZN : FL:lC TAPE NAME : 93422 CONTZNUATZEIN # : 1 PREYZOUS TAPE : COMMENT : ARCO ALASKA ZNC., 1Y-18, KUPARUK, .50-029-22390-00 **~* REEL TRAILER **** SERVZCE NAME : EDTT DATE :93/10/27 OR]:GZN : FL]:C REEL NAME : 93422 CONTZNUATTON # : PREVZOUS REEL : COMMENT : ARCO ALASKA TNC., 1Y-18, KUPARUK, $0-029-22390-00 ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 1Y-18 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE BOROUGH API NUMBER : REFERENCE NO : 93362 RECEIVED OCT 2 $199~ A/~sl~a Oil & Gas Oons. Commissior~ Anchorage ¢',,J '~' o0o z ~~ ~ 00~ z ~N Z ON Z 0 0 co · ~ 14'~ I--- oo mo~m mo~m mo~m mo~m momm 111 ii 00000000000000000 00000000000000000 00000000000000000 00000000000000000 00000000000000000 mz C'"3 o- "~ w 0 c:~ ¢-,'"~ c) · ,c~ c:l"' OC~ 0 CD 0 0 ~ CZ) ~ CO z N 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 Ilil Iiil iiii iii 0 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-SEP-1993 19:49 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 93/09/13 ORIGIN : FLIC REEL NAME : 93380 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, 1Y-18,50-029-22390-00 PAGE: * ALASKA COMPUTING CENTER * ****************************** *------- SCHLUMBERGER ~mmmmmmmm~mmmmmmmmmmmmmmmmmm~* ****************************** RECEIVED MAY. 0 ;5 1995 Naska Oil & Gas Cons. Comm[s.s[o.n Anchorage COMPANY NAME : ARCO ALASKA, INC, WELL NAME : 1Y'18 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STAT~ : ALASKA AP1 NUMBER : 50-029'223g0'00 REFERENCE NO : 9342] Tape Verification Llstlnq ;chlumberger Alaska Computing Center 26-APR-1995 13:t0 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/04/26 O~IGIN : FLIC REEL NAME : 93423 CONTINUATION ~ : PREVIOUS REE5 : CON ENI : ARCO AI~ASKA INC, KUPARUK RIVER 1Y-18, API #50 029 22390 O0 ***$ TAPE HEADER *~ SERVICE NAME : EDIT DATE : 95/04/26 ORIGIN : FbIC TAPE NAME : 93423 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, KUPARUK RIVER 1Y-18, APl #50-0~9-2~90-00 TApF HEADER K~PAR[]K RIVER CASED HOL~ WIRELINE bOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: jOB NUMBER: LOGGING ENGINEEr: OPEPATOR WITNESS: SURWACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEb: FWL: ELEVATION(FT FRO~ MSL O) KELLY BUSHING: DERRICK FLOOR: ~ROUND LEVEL: WEb[. CASING RECORD 1ST STRING ~ND STRING 3RD STRING PRODUCTION STRING 1¥-18 500292239000 ARCO ALASKA. INC. SCHLUMBERGE~ WELL SERVICES 26-APR-95 93423 J,FORMICa J.PYRON 9E 1734 107,00 107.00 66.00 OPEN }~OLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9'625 6~39.0 36.00 7.000 9169.0 26'00 # CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) e3ep uo~3n~ose~ q~q eq£ *H3a9 &33 ~H~ ~gN~V~Y ~gaI~ 3H& NI $3ABO3 V&VO B3H&O q~V 'HDa9/~3~ 3H~ O~ O3~&~HS 9~0' 3qI~ Oq3ZJ WOa~ gg~d NI¥~ 9~N3 ~0 3H& ~D3~3a~3AO~V ~OH~ ~£N3N&S~Q~ ~£d~Q HDa9*o~3 eq3 ~0 uu~e~eAe 3~3eaq~e eq3 ~9&ND aloq raseo SSed Pu: ~ 3s; se pa3ea~ a~a~ sas seal o~3 asa~ 'o06S8 o~ o:L06 ao~ puooas un~ se~ ssed u~ea 9&~3 e puc ~,0~88 03 ~L06 ao~ 3sz'[~ uaz ssed 3eadaz D~N3 e 3eq3 a3eo~pu~ sau~anzq p[a~ *~6'£DO'L~ 03~ 0£ ~'00t 0'~0] 0'~88 0'9~88 §'6£88 ~'8888 0'0~68 0'8E68 0'9~68 0'9~68 ~'£968 0'£&68 0'~868 0"~006 0'8106 0'~06 0'L8888 0'88888 IHdN 'OOt 'ES88 0'~S88 0~6L88 0 0888 0'6888 0i~068 00Zb8 S 6Eh8 ~'9S68 S ~68 0 ~968 0 E868 ~ gO06 S ~06 0 ~06 0 8888~ H&d~G ~Nlri3~¥~ E6-DQV-9~ :O3DDOq HD~D :~OOD ~.a~fiD D~Qq m3O :~OOO qO0£ Ot:iI S661'ad~-9~ 89 f~ £ 0 99 0 99 ~NqVA ~QOD ~8~ # · seuI~entq ~tet~ ~q~ uo ssed ,&¥MdMHo e~ se ~d OZ ~Vd ON 'DZNO ~HZ 30 t# ~SVd SNiV~NOO ~qI~ SIHZ -=--------H£d~O O~£~IH~N~ ZN~q~AXflO~-----='--- :3QOO MA~RO DMQq ~MIH~ MOM 3^MflO 3Niq3~¥8 (H~dMG O~flSV3W)~¥d O~ 9S~d - ~VQ ~IHS ~AH~D $ 0'0~88 0'g£06 IHdN O'O~B8 o'gg06 HOMO H&d30 dO~ H£d3~ &HV~S M~OO qO0~ DMOq O()Og'O :$NM~MaONI :H~flNflN 'saTt~ e~eaedes ut ssea qoea ~o; saaano paddIIo pue p~g~qS q~d~Q ~gOt : 3Zig OMB X~ tOO[O0 : NOI~B~A **** 8MGVMH 3qlM **** O):EI ~661-HdV-9g Tape Verlflcatlom Listing ~chlumberger AlasKa Computing Center 26-APR-lg95 13:10 PAGE~ 4 66 ! 5 66 6 73 7 65 8 68 0,5 9 65 FT la 66 15 12 68 13 66 0 14 65 FI i5 66 68 16 66 ! 0 66 0 ** SET NAMF SERV UNIT ID DEPT NPHI CNTG ENpH CNTG CPHI CNTG CFTC CNTG CNTC CNTG NCNT CNTG FCNT CNTG CRAT CNTG NRAT CNTG ENRa CNTG CFEC CNTG CNEC CNTG GPCH CNTG TENS CNTG CCL CNTG GRC~ CET FT PU -$ PU-S PU-$ CPS CPS CPS CPS CPS CPS GAP! LB YPE - CHAN ** ERVICE APl API APl API FILE NUMB NUMB SIZE REPR PROCESS ORDER # LOG TYPE CSASS MOD NUMB SAMP E~EM CODE (HEX) 440836 O0 000 O0 0 I i 1 4 68 0000000000 440836 00 000 00 0 1 I 1 4 68 0000000000 440836 00 000 00 0 1 I 1 4 68 0000000000 440836 00 000 00 0 I I I 4 68 0000000000 440836 00 000 00 0 I I I 4 68 0000000000 440836 O0 000 O0 0 I 1 1 4 68 0000000000 440836 00 000 00 0 1 1 1 4 68 0000000000 440836 O0 000 00 0 1 1 1 4 68 0000000000 440836 00 000 00 0 I 1 1 4 68 0000000000 440836 O0 000 O0 0 I ! 1 4 68 0000000000 440836 00 000 O0 0 1 1 1 4 68 0000000000 440836 00 000 00 0 1 I 1 4 68 0000000000 440836 00 000 00 0 1 I I 4 68 0000000000 440836 00 000 00 0 1 1 I 4 68 0000000000 440836 00 000 00 0 I 1 1 4 68 0000000000 V 440836 00 000 00 0 1 1 1 4 68 0000000000 GAPI 440836 O0 000 00 0 1 I 1 4 68 0000000000 ~mmm~m~mmmmmmmm~m~mmmm#~~#m~mmmm~mmmm~mmm~m~mmmmm~m~m~m~~m~~m~m#~ DATA DEPT. CFTC.CNTG CRAT,CNTG CNEC.CNTG GPCH,CET DEPT. CFTC.CNTG C~AT.CNTG CNEC.CNTG 9183.000 -999,250 -999,250 -999.250 -999.250 6888.000 -999,250 -999.250 =999.250 MPHI,CNTG CNTC,CNTG NRAT,CNTG GRCH,CNTG MPHI.CNTG CNTC.CMTG NRAT.CNTG GRCH.CNTG -999.250 ENPH,CNTG =999,250 -999,250 NCNT,CNTG -999,250 -999.250 ENRA,CNTG -999.250 -999.~50 TEN$.CNTG -999,250 CPHI.CNTG FCNT,CNTG CFEC.CNTG CCL,CNTG CPHI,CNTG FCNT,CNTG CFEC.CNTG CCL.CNTG ,-999'250 '999,250 "'999,250 '999.250 -999.250 -999,250 ..999,250 -999,250 Tape Vertficatlon Listing ~chlumberger Alaska Computing Center GRC,.CET 58.784 END OF DATA 26-APR-1995 13:10 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FbIC VERSION : 00~CO! DATE : 95/04/26 MaX REC SIZE : 1024 FILE TYPE LAST FILE **** FILE HEADER FILE NAME : E~IT .002 SERVICE : FLIC VERSION : O0~COi DATE : 95/04/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FIL~ NUMOER~ 2 EDITED CURVES Depth shifted and clipped curves for each Pass ~n separate files, PASS NU~BER~ 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 906~.0 8550,0 CNTG 907~.0 8550,0 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTN) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: CRCH PASS NUMBER~ 1 BASELINE D~PTH 9045.5 9044.5 9040.0 ....... ---EQUIVALENT bNSHIFTED DEPTH- .... ----- GRCH NPHI -- . 9044.5 9045.0 9039.5 ils Tape Verification ~,istlng ~Chlumberger AlasKa Co%putlr~g Center 26-APR-1995 13:10 9033 0 9030 0 9027 0 9024 5 9018 5 9OO0 5 8987 0 8972 5 8960 5 8949 0 8943 0 8939 5 8937 5 8922 5 8920 0 8908 0 89O0 5 8898 0 8885 0 8879 0 8868 5 8854.0 8827.0 8783 5 8727 5 8719 0 8708 5 8706 5 8693 0 8667 0 8659 0 8648 5 8634 5 8587 5 8586 0 100 0 $ 9030.5 9018,0 8987.0 8973.o 8943,0 8938,0 8920,0 8900,0 8879.5 8870.0 8856.0 8825.5 8781,5 871 5 8705,0 8664.0 8657.5 8633,0 8586°5 9032.0 9025,0 9023,5 8999.5 8959,0 8947.5 8936.0 8921.5 8908,0 8897,0 8884.5 8708,5 8692.5 8648,5 8586,5 99.0 100.5 REMARKS: THIS FILE CONTAINS PASS #2 OF THE CNTG. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH & PASS #2 NPHI TO PASS ~1NPH! FROM 9072' TO 8840', AND PASS ~2 GRCH T9 GRCH,CET & PASS #2 NPHI TO GRCH.CET FROM 8840 TO 8550 . ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFTS This pass is identified as the '~AIN' pass on the f~eld bluelines, LTS FORMAT DATA PAGE~ ,IS Tape Verification Listing ~chlumberger AlasKa Computing Center 26-APR-1995 13:10 PAGE~ ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REP~ CODE VALUE I 66 2 66 0 3 73 64 4 66 5 66 6 73 7 65 9 65 I1 66 16 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE APl API .AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUMB SAMP E~EM CODE (HEX) DEPT FT 440836 O0 000 O0 0 2 ! i 4 68 NPHI CNTG PU-S 440836 O0 000 O0 0 2 1 1 4 68 E~PH CNTG PU-S 440836 O0 000 O0 0 2 ! I 4 68 CPH! CNTG PU-S 440836 O0 000 O0 0 ~ I 1 4 68 NCNT CNTG CPS 440836 O0 000 O0 0 ~ i I 4 68 FCNT CNTG CPS 440836 O0 000 O0 0 2 1 1 4 68 CRAT CNTG 440836 O0 000 O0 0 2 1 i 4 68 NRAT CNTG 440836 O0 000 O0 0 2 1 1 4 68 ENR~ CNTG 440836 O0 000 O0 0 2 I 1 4 68 CNTC CNTG CPS 440836 O0 000 O0 0 ~ 1 1 4 68 CFTC CNTG CPS 440836 O0 000 O0 0 2 1 I 4 68 CFEC CNTG CPS 440836 O0 000 O0 0 2 ! 1 4 68 CNEC CNTG CPS 440836 O0 000 O0 0 2 ~ I 4 68 G~CH CNTG GAPI 440836 O0 000 O0 0 2 1 1 4 68 TENS CNTG LB 440836 O0 000 O0 0 2 1 1 4 68 CCL CNTG V 440836 O0 000 O0 0 2 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmm#mmmm~m~mm~mmm~m~m~~# ** DATA ** DEPT 9070.50O NPHI.CNTG 46.125 ENPH,CNTG 40,204 CPHI.CNTG NCNT:CNTG 1161,452 FCNT.CNTG 286.763 CRAT.CNTG 3.933 NRAT.CNTG R~,CNTG 5,636 CNTC,CNTG 1176.791 CFTC,CNTG 305,126 CFEC.CNTG EC ,CNTG 2462.104 GRCH.CNTG -99q.~50 TENS,CNTG 1955.000 CCL.CNTG 436,827 0.010 # ue e~e ~88 oh ~L06 =o~ seA=n= pebe~e~e eq~ ssed ueq3 ~uot ~00£ s~ ~# ssed asne~a~ 'a3&OdNOD ~m~m~mmm ~m~~m~m~ 2DVB3A~ NI Q~QRqDNI S~SS~d 000~'0 ~N~28DN! H£d~O a~e~e~e ~amq~e ~s~uno~ puno~eq pue Ae~ emmeD I SSed pe~pa pa6e~aAeu~ :uo~l~aN PaSI~d *saA~n~ ~e ~o; sassed pa~pe 7o abe~aAe J~amq~V :uoJ~neN pa~esuedmo3 Oq : 3di~ 9~/~0/S6 : 319~ : MOIAB39 £00' ~I0~ : 3NVN IOO~O0 : NOISH~A ~Iq~ : 3DIAH3~ ~00' JiG3 : 3~¥N g~o'o 9iNO"Q33 O00'~L81 D~ND'IHdD ~06'6£ DSND'SN3£ 0Sg'666- 9IND'HDH9 SLS'609g 9£ND'O3N3 DiND'I~SD ~LB'SOE DtND'iND~ 0"[~'99Tt DIND°HdN3 BgE°t9 DIN~'IHdN 000'0~8 :3DVd Ot:Et ~66 l'Mdv-gg ~a]uao Du[3ndmoD eNseI¥ aebaeqmntqD~ 0000000000 89 9 I £ 0 0 000 O0 9[8099 0000000000 89 9 I ] [ 0 O0 000 O0 9[8099 gdD AYND 0000000000 89 ~ Y ] [ 0 O0 000 O0 9£809~ ~dD A~ND 3343 0000000000 89 9 * ~ [ 0 O0 000 O0 9[8099 AVND 0000000000 89 9 ~ ~ [ 0 O0 000 O0 9[809~ A~ND 0000000000 89 9 ! ] E 0 O0 000 O0 9E809~ 0000000000 89 ~ t t [ 0 O0 000 O0 9[8099 ~dD A~ND 0000000000 89 9 ] ~ ~ 0 O0 000 O0 9[8099 0000000000 8g ~ ~ ] E 0 O0 000 O0 9[8099 9dD AVND 0000000000 89 9 ~ ~ ~ 0 O0 000 O0 91809~ 0000000000 89 9 ~ ] [ 0 O0 000 O0 9~B099 ~-~d A~ND IHdD 0000000000 89 9 ~ $ E 0 O0 000 O0 9E809~ 0000000000 89 9 { ] [ 0 O0 000 O0 9E809~ S-ad A{ND iHdN 0000000000 89 t ] ] [ 0 O0 000 O0 9[809~ e~N~Qm~m~m.emm$m~mmmmmm~em~mmmmm~mmmmmmm~mmmmmm#mmmmQmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmm ~~~~m~m~mm~~mm~mm~mmm~m~m~mmmmm~mm~m~m~mm~m~m~m~~mmmmmm~m~ I 99 0 t g9 89 99 0 g9 ET 89 8¥'. 99 &~ ~9 6 ~'0 89 8 ~ 99 g~ EL 0 gg 0 gg ** ~aOD:~ NOI£VDIJIDAd9 £V~O~ O~tE~ 566I-ad~-9E bU~3ndmoD e~set¥ adem ~I- Tape verification Listing ~chlumberger AlasKa Comp~]ting Center 26-APR-1995 13:10 E~D OF DATA **** FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 0OlCO! DATE : 95/04/26 MAX REC SIZE : i024 FILE TYPE : LO LAST FILE : **** FILE NEADER FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01C0! DATF : 95/04/26 MAX REC SIZE : 1024 FILl TYPE : LO fILE HEADER FIL~ NUMBER 4 RAW CURVES Curves and log header data for each pass in separate PASS NUMBER: 1 DEPTH INCREMENT~ 0.5000 # FILF SUMMARY VENDOR TOO[. CODE START DEPTH $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTO~ LOG INTERVAL (FT): LOGGING SPEED (FPHR)~ DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE f/les; raw back,round pass in last STOP DEPTH 09-SEP-93 CP 32.6 2100 9084 0 9078~0 8550.0 9072.0 600.0 NO 09-8EP-93 TOOb NUMBER # :(NI) ~300N~9 0000~ :(~3) 3~J~ HDIH 3~ tNflOD OOSL :(gdD) 3~D~ HDIH 3~ &N[IOD :(&~) MOONIM DNIZI~¥~BON :(£~) MOONIM DNI~Ig~W~ON dO~ 3NOZ qlO NI NOI&~ZI~ON 3£V~ &NIIOD 3NIq3fl~ 0'99[ O0'TT 2NI~ 0"6£T9 S9 D&ND 66Tt TT :39¥d :(NI) NOI&D2~OD 3qOH :XIa~W :(D3d) 3~OHD :(~3) Q3A~ :(D/Sq) I£ISN3O OIAq~ :3di~ OINq~ SNOI£IQNOD SqOH380~ :(~M) N&dSd DNiSVD S~SDDO~ :(&$) H~d~O DNISVD :(NI) 3Zi9 iI~ 3~OH N3~O NO~3N dS&~gNSd~OD D£ND 90q ~qqOJ DNIS~D D&ND UT%ST~ UOT~T~T~aA ad~& SI~ 0000000000 89 t ~ I ~ 0 O0 000 O0 9E80~ ~d3 lsd ~H 0000000000 89 ~ I I ~ 0 O0 000 O0 9£~0~ ~d3 t~d 0000000000 89 V ~ ~ ~ 0 O0 000 O0 9tSOVV lid I~d OdNH 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 9E80~ fid I~d 0000000000 89 ~ ~ I ~ 0 O0 000 O0 9[~0~ ~d3 I~d 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 9£809~ ~dD I~d 0000000000 89 ~ I I 9 0 O0 000 O0 9~80~9 A l~d qDD 0000000000 89 ~ { I 9 0 O0 000 O0 9E809~ ~q I~d 0000000000 89. 9 I ] t 0 O0 000 O0 9t8099 Id~D I~d 0000000000 89 9 t ~ 9 0 O0 000 O0 9£809~ ~dD led 0000000000 89 9 * ~ 9 0 O0 000 O0 9£809~ ~dD I~d D£ND 0000000000 89 9 ] ~ 9 0 O0 000 O0 9[8099 ~d3 t~d 0000000000 89 9 I ~ 9 0 O0 000 O0 9£80~ ~dD g~d 0000000000 89 9 * g ~ 0 O0 000 O0 9E8099 fid [~d aOdN 0000000000 89 9 t t ~ 0 O0 000 O0 91809~ i~d 0000000000 89 9 ~ ~ ~ 0 O0 000 O0 9£8099 ~d 0000000000 89 9 ~ I ~ 0 O0 000 O0 9E809~ Ad t~d 0000000000 89 ~ ] ~ ~ 0 O0 000 O0 9£809~ ~dD I~d 0000000000 89 ~ I ~ ~ 0 O0 000 O0 9E80~ ~dD t~d 0000000000 89 ~ i ~ ~ 0 O0 000 O0 9~flO~ ~dO tSd 0000000000 89 9 ~ i ~ 0 O0 000 O0 9E809~ ~dD I~d 0000000000 89 9 t ~ ~ 0 O0 000 00 9E8099 I~d ~8N3 0000000000 89 9 ~ I ~ 0 O0 000 O0 9E809~ fid [Sd 0000000000 89 9 T ~ ~ 0 O0 000 O0 9E80~ fid I~d ~HdN 0000000000 89 9 ~ ~ 9 0 O0 000 O0 9E8099 &g £d~ ~m~mm~#m~m#mmmmmmmmmmm#~m~mmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ** N~HD ' SdX~ £3S ** m~m~mm~mmmmmmm~mmmmmmmmmmmmmmm t 99 0 t 99 91 89 99 0 99 89 Ot 99 89 ££ 9 99 OOI £L £ 0 99 0 99 mm~m#~mm~mmmmmmmmmmm~mmmm~m ~mmmmmmmmmmmmmmmmmmmmmmm~mmmmm ~I$ Tape Verification Listing ichlumberger Alaska Computind Center 26-APR-t995 13:10 PAGE~ DATA DEPT. 9085.000 NPHI.PSI 39.075 ENPH,P$1 CFEC.P$1. 404,162 CNEC.PSI 2287.569 ~CEF,PSi TNP~.P$1 34.717 TNRA.PSi 3.546 RTNR.PS1 RCNT.PS1 1101,024 RCFT.PS1 294.866 CNTC,PSX GR.PS~ 119.688 TENS,PSi 1500 000 CCD,PS! RHNT.PSl 1158.480 HTMP.PS1 37~798 HNPO-PSI HCNT.PS1 1139.4J7 DEPT. 8838.000 NPHX.PS1 33 879 ENPH,PSI CFEC,PS~ 621.341 CNEC.PSI 2906:338 RCEF,PSI TNPH,PS~. 29,836 TNRA,PSI 3,26t RTNR"PSI RCNT,PSI 1452,343 RCFT,PSI 4~3.334 CNTC,PS! G~,PS1 78 3].3 TENS.PSi 202~.000 CCD,PS! RHNT,P$~ 1384:972 HTNP.P$! 2~ .898 HNPO.PS1 HCNT,PS1 1457'509 40'472 ENRA.P$! 39~.650 RCEN.PSl .700 NPOR~PSl 108~,907 CFTC,PS! '0.002 RHFT,PB1 37.798 HCFT,P$1 530.~6! ENRA PSI 9~:791 RCEN 744 CFTC,PSI -0.O0~ RHFT,PSl 31.869 HCFT~P$1 34.717 313,909 294,~144 31:3'*~39 462~50 412,726 463,549 ** END OF DATA **** FIDE TRAILER **** FILE NAME : EDIT ,004 SERVICE : FDIC VERSION : 00~C0! DAT~ : 95/04/26 ~AX R~C SIZE : 1024 FILE TYPE : LO LaST FILE : **** FILE HEADER **** FIbF NAME : EDIT ,005 SERVICE :FLIC VERSION : 00lC01 DATE : 95/04/26 MAX REC SIZE : 1024 FIeF TYPE : bO DAST FILE : FILE HEADER FIDE NUMBER 5 R~W CURVES Curves and log header data for each pass in separate P~SS NUMBER: 2 DEPTH INCREMENT: 0.5000 files; raw background pass in last als Tape Verification Listing ~cblumberGer Alaska Computing Center 26-APR-1995 13:10 FILM SUMMARY VENDOR TOOL CODE START DEPTH CNTG ~OG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: STOP DEPTH -';.~-~;--'~ ~ TD DRILLER TD LOGGER(FT): TOP LOG INTERVAL (FT): ~OTTOM LOG ~NTERVA5 (FT): LOGGING SPEED (FPHR): DEPTH CONTROL U~ED (YES/NO): 09-$EP-93 CP 32,6 ~100 09-$EP-93 9084.0 9078.0 8550~0 9072,0 600.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYRE -.-.-..-----.---~------~ C~TG ~SING LLAR LOG CNTG TELEMETRY CARTRIDGE CNTG COMPENSATED NEUTRON $ TO0~ NUMBER · CAL-UB ~269 ATC-CB 199 CNTG 65 80REHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 6139.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G}: SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPN): FLUID LEVEL, (FT): FLUID RATE AT WELLHEAD (BPM}~ WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEL): BRINE 11,00 164.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: NATRIX DENSITY: HOLE CORRECTION (IN): BOTH SANDSTONE 2,65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): RLUELINE COUNT ~ATE SCAD~S SET BY FIELD ENGINEER PAGE: 14 0000000000 Bg D t ~ S 0 O0 000 O0 9[BO~D lid ~Bd ~OdN 0000000000 8g ~ ~ I S 0 O0 000 O0 9~BO~ 0000000000 89 ~ ~ ~ 6 0 O0 000 O0 9~0~ ~d ~N& 0000000000 89 ~ t t ~ 0 O0 000 O0 9E~O~ ~d ~aN3 0000000000 89 [ ] I ~ 0 O0 000 O0 9E~O~ ~d3 ~d N3D~ 0000000000 8g ~ ~ t S 0 O0 000 O0 g£80~ SaD 0000000000 89 ~ ! I S 0 O0 000 O0 9£80~ gdD 0000000000 89 } i t ~ 0 O0 000 O0 9180}} Sda ~d 0000000000 89 9 I I 6 0 O0 000 O0 9[809~ ad ~d HdN3 0000000000 Bg ~ I I ~ 0 O0 000 O0 g£flO~ fid 0000000000 89 ~ I t ~ 0 O0 000 O0 9E80~ fid t~d IHdN 0000000000 89 ~ t I ~ 0 O0 000 O0 9£80~ ~ ~~.m~m~m~mmm~mm~mm~~mmmm~mmmmmmmm~mmmmmmmmmmm~mmmmmmmmmmm~m~mmm~mmmmm~m~mm (%3M) ~00~ N~q3 dN~ ~NflN 00~ S~VqD 2dA~ ~oq # ~GBO i 99 89 99 0 99 89 Ol 99 8 t 99 OOt ~L 0 99 0 99 :(NI) ~JOGN~ riO0~ 0 :-(~dD) 3q~DS MOq 3~VH ~N~OD BVSN OI:E~ g66t-adV-gz 9~1~01§6 1 109{00 ~ ~ga:~&DH 9L8°tt :gd'OdNX LS['Tt ggd'.~JHa £00'.9 ~d'q33 O00'~T6T ~gd'dN£H ~d~D~ND ~d IHdN Sd,*dNSH ~gd ~Da ~d IHdN gS[*T6TT [90'96 tLg'TSTl 8L6'DOS 000'6E98 ~9g' ~8E' 9) oo : OSOI 890T 80! 6EOt 9 ~0 dN3 ** gSd ~Sd'~BN3 &dg~ ~Sd'£NDH ~Sd'gND8 ~Sd'~BN3 £d~ 0000000000 89 D T T g 0 O0 000 0000000000 89 ~ t t $ 0 O0 000 0000000000 B9 ~ T T S 0 O0 000 0000000000 89 t I T S 0 O0 000 0000000000 89 t T T S 0 O0 000 0000000000 89 ~ I I S 0 O0 000 0000000000 89 ~ I I S 0 O0 000 0000000000 89 ~ I T S 0 O0 000 0000000000 89 ~ I I S 0 O0 000 0000000000 89 ~ I I ~ 0 O0 000 0000000000 89 ~ T T S 0 O0 000 0000000000 89 ~ I I g 0 O0 000 0000000000 89 t I I S 0 O0 000 O0 9E80)~ gdo g O0 9E80)~ gdo g O0 9£80P~ Ad g O0 9E80~ nd g O0 9[80~ gdo g O0 9E~O~ SdD ~ O0 9E80~ A ~ O0 9E80~ 8q ~ O0 9E80g~ IdV~ ~ O0 gESO)) g83 g O0 9E80~ g~3 ~ O0 9E80~) gd~ g O0 9E80~ g~D ~ Sd ~NDH Sd OdNH ~d dN&H Sd Sd ~MHH Sd qOD Sd SNM$ Sd gd 9 T OI:ET S66T-BdV-9~ ~e3ue3 buT~ndmoD e~selv ~ab~aqmnlqOi 0°~9I 00'11 0'6£I9 ag D£ND ~2B~nN qOO& ON 0*009 O:~L06 0,0558 0,8L06 0 ~806 E6=d~9-60 OOT~ 9'~£ dD ~6-d~S-60 tt. lse! ut Ssed punolb~eq ~'ez isettt ~ - S.OItI~.Oa aqoH~aO~ $ 3d!~ qO0~ 3OOD qO0~ ~OQN3A ( WOlf08 Oi dOi) DNI~I~ 0'8£88 mmm,~mmmmmmm~mm~mm~ :(ON/S2A) O~gfl qOHSNOD :(~HdA) daadS DNIDDOq :(&~} rI~A~2$NI DOq WO~O~ :(12) q~Aa2£NI Doq dO£ :.0~$0~ NO aa~oq :NOI~H2A $ 8°~806 Oq : ~dX£ 3qIA ~0[ : SZlS D3H TOOIO0 : NOIS~SA 900' tIOM : 3NYN MqlJ OI:EI S66i-ad¥-gz Tape Verification Listing ~chlumberger AlasKa ComPuting Center 26-APR-1995 13:10 FLUID LEVEL FtUID RATE A WELL EAD WATER CUTS (PCT): GAS/OIL RATIO: C~OKE {DEG): NEUTRON TOOL TOOL TYPE (EP!THERMAL OR THERMAL): MATRIX: MATRIX DEN$ITY~ HOLE CORRECTION (IN): BOTH SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS)~ 0 FAR COUNT RATE HIGH SCALE (CPS): 7500 NEAR COUNT RATE LOW SCALE (CPS)= 0 NEAR COUNT RAT~ HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): # REM~RKS~ TIED INTO SWS CET DATED 16-AUG-1993. HIGH RESOLUTION LOGGING MOD ~E, DPPM HIRS $ LIS FORMAT DATA .PAGE: ¸18 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 4 66 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 28 13 66 0 14 65 15 66 68 16 66 0 66 ,IS Tape verification Listing ;chlumberger AlasKa Computing Center 26-APR-~995 13:10 PAGE{: 19 ** SET TYPE - CHAN ** NAME S~RV UNIT SERVICE AP1 APl APl APl FILE NUmB NUNB SiZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) DEPT FT 440836 O0 000 O0 0 6 i 1 4 68 RHFT CNTG CPS 440836 O0 000 O0 0 6 1 I 4 68 RMNT CNTG CPS 440836 O0 000 O0 0 6 I I 4 68 HTNP CNTG PU 440836 O0 000 O0 0 6 1 t 4 68 HNPO CNTG PU 440836 O0 000 O0 0 6 1 1 4 68 HCFT CNTG CPS 440836 O0 000 O0 0 6 1 I 4 68 HTAL CNTG 440836 O0 000 00 0 6 2 ! 4 68 RHGR CNTG GAPI 440836 O0 000 O0 0 6 1 I 4 68 HGR CNTG GAPI 440836 O0 000 O0 0 6 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 D~PT. 9085.834 RHFT.CNTG 294,144 RHNT,CNTG 1158.480 HTNP*CNTG HNPO.CNTG 37,798 HCFT.CNTG 313'139 HTAh,CNTG 0.540 RHGR'CNTG HGR.CNTG 118.490 DEPT 88]8.000 RHFT.CNTG 422.726 HNPO:CNTG 31,869 HCFT.CNTG 463.549 HG~,CNTG 76,163 END OF DATA RHNT.CNTG HTAb,CNTG 1380:570 RHGR NTG 37,798 114,725 29'.898 77,520 **** FILE TRAILER **** FILE NAME = EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/04/26 ~AX REC SIZE : 1024 FILE TYPE : LO **** FILE HEADER **** FILE NA~E : EDIT ,007 SERVICE : FLIC V~RSION : 001C01 DATE : 95/04/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : Tape Verification Listing ~chlumberger AlasKa Computing Center 26-APR-1995 13:10 PAGE~ 20 FIL~ HEADER FILE NUMBER 7 Ra~ CURVES Curves and log header data for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: 0,1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 90~3.3 $ LOG HEADER DATA DATE 50GGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOm: TD DRILLER TD LOG~ER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO}~ TOOL STRING (TOP TO BOTTOM) S~OP D~PTH 8539,0 VENDOR TOOL CODE TOOL TYPE CNTG CASING COLLAR LOG CNTG TELEMETRY CARTRIDGE CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE fiN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY SURFACE TEMPERATURE (DEGF)~ BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITMERMAL O~ THERMAL)~ ~ATRIX: M~TRIX DENSITY: HOLE CORRECTIO~ (IN): files; raw background pass in last 09-SEP-93 CP 32,6 2100 09-SEP-93 9084,0 9078,0 8550,0 907~-0 600-0 NO TOOL NUMBER A -UB 1269 ATC-CB 1199 CNTG 65 6139.0 BRINE 11,00 164.0 BOTH SANDSTONE 2.65 0000000000 89 ~ ! ~ £ 0 O0 000 O0 9E80~ fid 0000000000 89 ~ t ~ L 0 O0 000 O0 9£80~ ~d D£ND 0000000000 89 ~ T I L 0 O0 000 O0 9E90~ ~dD DiND 0000000000 89 9 ~ t L 0 O0 000 O0 gEnOa9 gdD 0000000000 89 9 ~ ~ L 0 O0 000 O0 9E80~9 £~ (X3H) ~OOD N~q~ dna9 ~NflN OON ~qD 3dX£ DOq # a3d~O t 99 0 R9 99 0 99 89 8~ 99 &~ g9 6 991'0 89 8 ~£ 9 99 g£ £L 0 99 0 99 # O000g :(gdD) MqYD9 MDiH MIVM £N~OO O0~L :CgdO) 2qVD~ HDIH 3£V~ IN~OO 0 :(gdO) 3qVOg MOq 3ira &NflOD 833NIDN3 0~3I~ A~ £3~ ~30~DS 3I~M £NflOD 3NIq3Rq~ :(&~) MOONI~ 9NiZI'IYN~ON 3SV~ :C£~) ~OONiM 9NIZIq~dON dOi O~:E) S66~'MdV-9g ~,IS Tape Verification Listing ~chlumberger AIaska Computing Center 26-APR-1995 13:10 PAGEt .22 NAME SE V ICE API API APl API FILE NUMB NUMB SIZE RE P ESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) .-.-,..-...-...---.--,,,..-,---,,,-.--.---.-.-,-....-.-.....-..-....-....-.-.-.-,--.,-- HCF CNTG CPS 440 0 O0 0 1 I 4 68 00000 000 HTAL CNTG 440836 O0 000 O0 0 7 1 I 4 68 0000000000 R~G~ CNTG GAPI 440836 O0 000 O0 0 7 1 I 4 68 0000000000 MGR CNTG GAPI 440836 O0 000 O0 0 7 I I 4 68 0000000000 DATA DEPT, 9083,334 RHFT,CNTG 294,144 RHNT'CNTG 106n8,~43 HTNP CNTG HNPO.CNTG 33.205 HCFT.CNTG 313.!39 HTAb'CNTG v.~47 RHGR~CNTG MG~,CNTG 132,109 ** END OF DATA ** 1191,256 HTNP.CNTG 0.638 RMGR.CNTG 127'912 **** FILE TRAILER **** FILM NAME : EDIT ,007 SERVICE : FLIC VERSION DATE : 95/04/26 MAX REC SIZE : 1024 FILE TYPE t LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/04/26 ORIGIN : FLIC TPPE NAME t 93423 CONTINUATION # : ] PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, KUPARUK RIVER 1Y-18, API #50-029-22190-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : ~5/04/26 ORIGIN : FLIC REEL NAME : 93423 CONTINUATION ~ : PREVIOUS REEL COMMENT : ARCO ALASK~ INC, KUPARUK RIVER IY-18, AP1 #50-029-22390-00
