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183-122
STATE OF ALASKA eLASKA OIL AND GAS CONSERVATION COMMIS • WELL COMPLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil ❑ Gas 0 SPLUG 0 Other ❑ Abandoned ® . Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development B Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Abend.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 7/18/2017 • 183-122 " 317-214 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/5/1983 • 50-029-20999-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 8/24/1983 PBU 14-32 • Surface: 40'FSL,1292'FEL,Sec.04,T1ON,R14E,UM • 9 Ref Elevations KB 69.00 17. Field/Pool(s): Top of Productive Interval: 2114'FSL,2436'FWL,Sec.03,T1ON,R14E,UM GL 38.93. BF 41.49 • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 2199'FSL,2717'FWL,Sec.03,T1ON,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10225'/8717' ADL 028312 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 675148. y- 5940379 • Zone - ASP 4 • 10900'/9326' " 77-043 TPI: x- 678822 y- 5942540 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/TVD: Total Depth:x- 679101 y- 5942632 Zone - ASP 4 None (1900'Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No H 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary NOVt� (�q] GR/FDC/CNL/Caliper,BHCS/GR,CBL,Gyro sNNEO NOV 32012 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 31' 111' 31' 111' 30" 1800#Poleset 13-3/8" 72# L-80 30' 2493' 30' 2493' 17-1/2" 2350 sx Fondu,400 sx PF'C' 9-5/8" 47# L-80 27' 10088' 27' 8593' 12-1/2" 500 sx Class'G',300 sx PF'C' 7" 29# N-80 9758' 10802' 8298' 9238' 8-12" 360 sx Class'G' 4-1/2" 12.6# 13Cr85 9477' 10500' 8059' 8967' Scab Liner 184 sx Class'G' 24. Open to production or injection? Yes 0 No ® • 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MDfTV Size and Number): 5-1/2"17#13Cr85 9487' 9288'/7905' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? . 0°'N Per 20 AAC 25.283(i)(2)attach electronic and printed Yes 0 No -t=('"9 Pci- -t.00 RECEIVED E. v E information ri 6 IT - /�� �� AUG1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -(c:`-rr_ 10421' Set Whipstock(Fell downhole) LV AOGCC 10248' Set CIBP 10225' Set 2nd Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .�► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only VYI 9/Zo`l AP/4?" •/7 JG ,,9 gr/r-0//7 RBDMS i,L AUG 1 7 2017 28. CORE DATA • Conventional Core(s) Yes ❑ No 121 • Sidewall Cores Yes ❑ No I If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes ❑ No 0 • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10218' 8711' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 10218' 8711' CGL-Zone 3 10401' 8877' Base of CGL-Zone 2 10518' 8983' TDF-Zone 1 10787' 9225' Kavik-Base of Sadlerochit 10850' 9281' Formation at total depth: Base of Sadlerochit 10850' 9281' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Tempel,Joshua Authorized Title: Inform ' and Data Controller Contact Email: Joshua.Tempel@bp.com Authorized Signature: e: t/16/1 Contact Phone: 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.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and ND for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • Daily Report of Well Operations 14-32 ACTIVITYDATE SUMMARY T/I/O= 2495/145/50 Temp= S/I Assist E-Line w/Load & Kill, Attempted MIT-T, (CTD) Pumped 3 bbls 50/50 spear followed with 348 bbls 135*fresh water. Freeze protected tbg with 2 bbls 50/50 methanol and 58 bbls diesel. MIT-T= Pumped 23.4 bbls diesel down TBG to reach test pressure, As soon as we isolated well to monitor pressures the TBG pressure dropped to a vac, Pumped a total of 52 bbls diesel down TBG to establish a LLR of 5 bpm @ 6/15/2017 1024 psi for 20 bbls, E-Line still on well @ departure, Tags hung on well, FWHP= ***WELL SHUT IN UPON ARRIVAL***(SLB E-LINE WHIPSTOCK) PJSM, RU, PT. RUN 1: RIH W/ BAKER45KB PACKER WHIPSTOCK. TOP OF WHIPSTOCK SET AT 10223'. CCL TO TOW= 14.1'. CCL STOP DEPTH = 10208.9'. WHIPSTOCK ORIENTED TO 3 DEG LOHS. LOGS CORRELATED TO HALLIBURTON RMT DATED 26-APR-2014. MIT ON WHIPSTOCK FAILED. LRS ESTABLISH LLR OF 5 BPM AT 1024 PSI. (see Irs wsr for details) WELL SI ON DEPARTURE. FINAL T/I/O =0/135/0. PAD OP NOTIFIED. 6/15/2017 ***JOB COMPLETE 15-JUN-2017*** ***WELL S/I UPON ARRIVAL SWCP 4518***(ctd) RAN 5-1/2"X-LINE W/5-1/2"X-CATCHER & LOCATE LOWEST X-NIP © 9,422' SLM (9,434' MD) 12' CORRECTION. RAN 3.80" CENT& 3.50" LIB TAG TOP OF WHIPSTOCK @ 10,409' SLM (10,421' MD). RAN CALIPER FROM 10,320' SLM TO 8210' SLM (good data). 6/19/2017 ***WELL LEFT S;I ON DEPARTURE*** T/I/O= 970/135/33 Temp= S/I (LRS Unit 70 -Assist E-line: Load &Test) Loaded TBG with 5 bbls 50/50 meth spear followed by 87 of 350 bbls of 120*fresh water. 6/25/2017 WSR continued on 06-26-17*** ***JOB STARTED 25-JUN-2017*** (SLB ELINE CIBP/WHIPSTOCK) INITIAL T/I/O = 925/0/0. MIRU, LPT/HPT= PASS. DHD SHOOT FLUID LEVEL AT— 1600' MD. RIG UP LRS TO PIS. LRS BEGIN PUMPING 350 BBL OF FRESH WATER FOR L&K. 6/25/2017 ***JOB CONTINUED 26-JUN-2017*** T/I/O = 950/100/0. Temp= SI. T FL(E-line request). T FL @ 1560' (36 bbls). 6/25/2017 SLB in control of well. 21:20. ***JOB CONTINUED FROM 26-JUN-2017*** LRS FINISHED PUMPING 350 BBL OF FRESH WATER AND 58 BBL'S OF DSL. RIH W/ HEAD/ERS/WEIGHT/UPCT(GR/CCL)/BAKER-10 SETTING TOOL/4.5" BAKER SET BOTTOM OF BAKER 4.5" CIBP AT 10248'; CCL TO BOTTOM OF PLUG = 8.3'; CCL STOP DEPTH = 10239.7'. LRS PERFORM PASSING MIT-T TO 2000 PSI, BLED TBG BACK TO 500 PSI. RIH W/ HEAD/ERS/SWIVEL/CENTRALIZER X2/WPMOT/CCL/GR/WPST/BKR 10/3.625" BKR WHIPSTOCK. SET TOP OF WHIPSTOCK AT 10223', CCL TO TOW= 14.0', CCL STOP DEPTH = 10209.0'. WHIPSTOCK ORIENTATION = 3 DEG ROHS. ALL LOGS CORRELATED TO PDS JEWELRY LOG DATED 29-AUG-2015. 6/26/2017 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** • • Daily Report of Well Operations 14-32 ***WSR continued from 06-25-17*** (LRS Unit 70 -Assist E-line: Load &Test) Pumped 87 bbls of 120*fresh water prior to midnight, continued on with remaining 273 bbls fresh water today, for a total of 360 bbls down TBG to load. Freeze protected tubing with 58 bbls of 50*F diesel. Safety drill MIT-T***PASSED***to 2174 psi, Max Applied Pressure=2250 psi, Target Pressure = 2000 psi. Pressured TBG to 2233 psi with 23.1 bbls of 50*diesel. TBG lost 52 psi in 1st 15 minutes and 7 psi in 2nd 15 minutes, for a total loss of 59 psi during 30 minute test. Bled TBG to 500 psi, returned -3 bbls. 6/26/2017 FWHP's 456/136/38 T/I/O= 150/0/0. (Pre CDR2) Set 6" J TWC#421 @ 135" Good set. Performed LTT on TWC. (Passed) R/D 6" CIW upper tree. Installed CDR Tree #1 configuation. Torqued FCxMV to 907 ft lbs.(L7M NC). PT'd CDR tree assemby against TWC Low 300psi, High 5000psi. 7/6/2017 (Passed). RDMO ***Job Complete*** FWHP= TWC/0/0. See log for details. T/I/O = TWC/140/30. Temp = SI. IA FL (Pre Rig). WH and flowlines removed. IA FL @ 2400' (105 bbls). 7/8/2017 SV, WV= C. MV= 0. IA, OA= OTG. 14:00 T/I/0=50/140/34 Temp=Sl Load IA for rig work. Pumped 50 bbls of diesel down the IA to 7/10/2017 load. **WSR continued on 7-11-17** **WSR continued from 7-10-17** Load IA for rig work. Pumped 50 bbls (100 bbls total) 7/11/2017 diesel down the IA to load. SV=closed IA,OA=OTG FWHP=50/222/38 AFE sign hung by T/I/0 = TWC/220/30. Temp = SI. WHPs (pre RWO). No AL. Wellhouse, flowline, SSV removed. 7/13/2017 MV= O. IA,OA= OTG. 04:00 T/I/0 =TWC/220/30. Temp = SI. Bleed WHPs to 0 psi (Pre rig). No AL, SSV, wellhouse, scaffold, or flowline. IA&OA FLs near surface. Bled IAP to slop tank from 220 psi to 0 psi (all gas) in 1 hr 15 mins. OAP unchanged. Bled OAP from 30 psi to 0 psi (all gas) in 10 mins. Monitored for 30 mins. WHPs unchanged. Final WHPs =TWC/0/0. 7/13/2017 SV, WV= Unk. MV= 0. IA, OA= OTG. 12:40. • North America-ALASKA-BP Page 1 opke Operation Summary Report Common Well Name:14-32 1AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:7/15/2017 End Date:7/26/2017 1X3-018HR-C:(2,814,936.20) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:CDR-2 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:7/28/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000829 Active datum:KB©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) ! (usft) 7/15/2017 12:00 - 15:30 3.50 RIGU P PRE RIG RELEASED FROM MAINTENANCE AT 12:00 -PREPARE FOR MOVE —PERFORM PRESPUD WITH VAN CLEVE CREW. -LEAVE PRICE PAD AT 15:30 15:30 - 17:30 2.00 RIGU P PRE MOVE RIG TO DS14 ARRIVE LOCATION AT 17:30 17:30 20:30 3.00 RIGU P PRE PREPARE LOCATION TO MOVE RIG OVER WELL -VERIFIED PRESSURES ARE BELOW 50# -VERIFIED ALL VALVES CLOSED -PJSM,PEAK,NABORS,AND WSL -DISCUSS CHOCK BLOCK USAGE,DISCUSS RADIO COMMUNICATION AND ASSIGN SPOTTERS -AGREE"ALL STOP"WILL BE COMMAND TO STOP OPS. I-MOVE SUB MODULE OVER WELLAND SET DOWN. SET DOWN. TAKE MEASUREMENTS TO LINE UP PIT MODULES THROUGH PUTZ. 20:30 - 00:00 3.50 RIGU P PRE RIG ACCEPTANCE AT 20:30 -PJSM,GO OVER PUNCH LIST FOR RIGGING RIG UP FOR OPS. PERFORM PRESPUD WITH COYNE CREW. 7/16/2017 00:00 - 01:00 1.00 RIGU P PRE FINISH RIGGING CELLAR PERFORM PASSING LTT BETWEEN MASTER/ SWAB TO 3500# 01:00 - 04:00 3.00' RIGU P PRE NIPPLE DOWN TREE CAP. NIPPLE UP MANAGE PRESSURE LINE. HAD TO REPOSITION 90 ON HOSE. 04:00 - 05:00 1.00 BOPSUR P PRE . NIPPLE UP BOPE STACK. FUNCTION BOTH SETS OF BLIND SHEAR RAMS. INSTALL TEST JOINT. TEST FUNCTION ON ALL VALVES DUE TO ALL HYDRAULIC LINES WERE DISCONNECTED DURING MAINTENANCE. 'STAB INJECTOR 05:00 - 08:00 3.00 RIGU P PRE CIRCULATE COIL OVER TO FRESHWATER TO TIGER TANK. 08:00 - 11:30 3.50 RIGU N PRE ATTEMPT TO TEST BOPE -TROUBLESHOOT LEAK,ISOLATED TO LEAKING MASTER VALVE -MOBILIZED GREASE CREW AND VERIFY THE 'VALVE WILL HOLD PRESSURE 11:30 - 21:30 10.00 BOPSUR P PRE TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -TEST WITH CDR2 MULTI JOINT(2-3/8",3", 3-1/2"JOINTS) TEST ANNULAR AND VARIABLES WITH BOTH 2-3/8"AND -3-1/2"JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESS WAIVED BYAOGCC REP I LOU LAUBENSTEIN Printed 8/11/2017 10:09:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 2epft Operation Summary Report Common Well Name:14-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/15/2017 End Date:7/26/2017 X3-018HR-C:(2,814,936.20) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:CDR-2 Spud Date/Time:8/5/1983 12:00:00AM ,Rig Release:7/28/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000829 Active datum:KB @69.0ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:30 - 00:00 2.50 BOPSUR P PRE PERFORM ACCUMULATOR DRAWDOWN TEST I PULL TEST JOINT. PRESSURE TEST NEW BACKSIDE LINE TO 4200#. NO LEAKS INSTALL BLIND SUB TO TEST IRV /REPLACE PACKOFFS. 7/17/2017 00:00 - 01:00 1.00 BOPSUR P PRE PRESSURE TEST IRV/PACKOFFS TO 300PSI LOW/3500#HIGH FOR 5 MINUTES EACH. PASS 01:00 - 02:30 1.50 BOPSUR P PRE PJSM,WITH VALVE CREW/GREASE CREW. TORQUE TREE/GREASE SWAB PERFORM TEST ON SWAB VALVE TO 3500#. HELD SOLID INSTALL FLOATS IN UQC. PRESSURE TEST CTC AND UQC TO 3500#. 02:30 - 05:00 2.50 BOPSUR N I PRE UQC BODY LEAKED. SWAP BODY OUT. STILL LEAKED. I LOOKING AT WIRE, BREAK IN INSULATION. BOOT E-LINE AND PUMP FORWARD TO GET ENOUGH E-LINE FOR REHEAD. STAB ON WITH STINGER.PUMP E-LINE FORWARD TO REHEAD. 05:00 - 07:30 2.50 BOPSUR P PRE PULL TWC -PJSM WITH ALL PERSONNEL INVOLVE WITH TASK,NABORS RIG CREW AND CH2 VALVE CREW -REVIEWED PRESSURE CROSS CHECK CARD -LEAK TIGHT TEST LUBRICATOR WITH METHANOL TO 3100 PRESS,GOOD TEST -ENGAGE TWC AND PULL WITHOUT ISSUES, 65 PSI ON TUBING AFTER UNSEATING TWC -PURGE LUBRICATOR TO FLOW BACK TANK -RIG DOWN LUBRICATOR AND CLEAR THE EQUIPMENT FROM THE RIG 07:30 - 09:30 2.00 BOPSUR N PRE INSTALL COIL CONNECTOR,UQC AND FLOATS -PRESSURE TEST TO 300PSI LOW/3500# HIGH FOR 5 MINUTES EACH. PASSING TEST 09:30 - 11:30 2.00 BOPSUR P PRE DISPLACE COILTO1% KCL SLICK -TEST QTS,GOOD TEST 11:30 - 12:00 0.50 BOPSUR P PRE SERVICE RIG CHOKE,BOP STACKAND ROMEO VALVES 12:00 - 13:30 1.50 KILLW P PRE RIH WITH BHA#1 NOZZLE FROM SURFACE TO 2000'MD -RATE:0.57.BPM IN,0.72 BPM OUT.CIRC PRESSURE:142 PSI -MUD WEIGHT:8.4 PPG IN,6.5-7.04 PPG OUT VERIFING STRAPS AT FLOWBACK TANK EVERY 1000'MD Printed 8/11/2017 10:09:09AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP • Page 3d- Operation Summary Report Common Well Name:14-32AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/15/2017 End Date:7/26/2017 IX3-018HR-C:(2,814,936.20) Project:Prudhoe BayT Site:PB DS 14 Rig Name/No.:CDR-2 Spud Date/Time:8/5/1983 12:00:OOAM Rig Release:7/28/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000829 Active datum:KB©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:30 - 14:30 1.00 KILLW P 2,000.00 PRE CONDUCTED A UNANNOUNCED KICK WHILE TRIPPING DRILL I-WELL SHUT IN 95 SECONDS -COMPLICATED THE DRILL BY INITIATING AN H2S ALARM AFTER THE WELL JUST GOT SHUT IN. -100%OF PERSONNEL RESPONDED TO THE MUSTER AREA INA TIMELY MANNER, 210 SECONDS AFTER START -CONDUCT THE AAR AFTERWARD CAPTURING THE LESSONS LEARNED. -AFTER THE DRILL VERIFIED LINES OF COMMUNICATION WITH NO DEFICIENCIES 14:30 - 17:00 2.50 KILLW P 10,223.00 PRE RIH WITH BHA#1 NOZZLE FROM 2000'TO 10242'MD -RATE:0.57.BPM IN,0.72 BPM OUT.CIRC PRESSURE:142 PSI -MUD WEIGHT:8.4 PPG IN, 7.04-8.2 PPG TOUT -VERIFING STRAPS AT FLOWBACK TANK EVERY 1000'MD TAG AT 10,242'UNCORRECTED 17:00 - 22:30 5.50 KILLW P 10,223.00 PRE SWAP WELL TO 8.4 PPG 1%SLICK KCL RATE:1.5 BPM IN,GASEOUS FLUIID BPM OUT -MUD WEIGHT:8.34 PPG IN,GASEOUS FLUID PPG OUT -BLEW MM DOWN. FOUND DEBRIS. -CIRCULATE 1.5 TIMES WITH 1%KCL AT 5 BPM -SHUT DOWN TO EMPTY TIGER TANK -FINAL CIRCULATING PRESSURE WITH WELL DISPLACED TO KCL:602 PSI AT 4.90 BPM 22:30 - 23:30 1.00 KILLW P 10,223.00 PRE SWAP WELL TO 9.0 PPG MUD -RATE:4.3 BPM IN,4.30 BPM OUT -MUD WEIGHT:9.08 PPG IN,8.4 PPG OUT -CIRC PRESSURE:3800#, SURFACE TO SURFACE. 23:30 - 00:00 0.50 KILLW P 10,223.00 PRE MONITOR WELL FOR 10 MINUTES:STATIC 7/18/2017 00:00 - 02:00 2.00 KILLW P 10,223.00 PRE POOH MUD WEIGHT:9.02 PPG IN,8.95 PPG OUT RATE:3.47 BPM IN,2.97 BPM OUT 02:00 - 04:30 2.50 KILLW P 10,223.00 PRE MONITOR WELL FOR 10 MINUTES AT BHA: STATIC -TAG UP. -INJECTOR OFF:02:20 -MAKE UP BHA WHILE MAINTENANCE PERFORMED ON REEL 04:30 - 05:00 0.50 STWHIP P 10,223.00 WEXIT MU MILLING BHA -PJSM ON MU BHA,ABLE TO PULL BHA ABOVE ALL BOP COMPONENTS -RIH WITH BHA#2 -PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:04:25 Printed 8/11/2017 10:09:09AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4011 Operation Summary Report Common Well Name:14-32 1 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/15/2017 End Date:7/26/2017 X3-018HR-C:(2,814,936.20) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:CDR-2 1 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:7/28/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000829 Active datum:KB©69.00usft(above Mean Sea Level) Date 1 From-To 1 Hrs Task Code NPT Total Depth Phase Description of Operations (hr) j (usft) 05:00 - 07:00 2.00 STWHIP P 10,223.00 WEXIT RIH WITH MILLING BHA FROM SURFACE TO 19000'MD j-RATE:0.45 BPM IN,0.995 BPM OUT.CIRC PRESSURE:1092 PSI -MUD WEIGHT:8.9 PPG IN,8.9 PPG OUT 07:00 - 07:30 0.50 STWHIP P 10,223.00 WEXIT CONDUCT H2S/EVACUATION DRILL -SECURED WELL IN 55 SECONDS -FULL MUSTER IN 240 SECONDS AFTER THE 'START OF THE ANNOUNCEMENT 07:30 - 08:00 0.50 STWHIP P 10,223.00 WEXIT RIH WITH MILLING BHA FROM 9000'MD TO PINCH POINT AT 10,238'MD I-RATE:0.58 BPM IN,1.02 BPM OUT.CIRC PRESSURE:1372 PSI MUD WEIGHT:8.9 PPG IN,8.9 PPG OUT q 08:00 - 18:00 10.00 STWHIP P 10,223.00 WEXIT MILL 3.80"WINDOW IN 4.5"X 7"CASING/LINER PER BAKER REP FROM 10238'MD TO 111-324. 10,247.7'MD -RATE:2.72 BPM IN,2.72 BPM OUT MUD WEIGHT:8.9PPG IN,8.9 PPG OUT 1-DWOB:2.0-3.8 KLBS -CIRC PRESSURE: 3115 PSI 18:00 - 21:00 3.00 STWHIP P 10,223.00 WEXIT MILL 3.80"WINDOW IN 4.5"X 7"CASING/LINER PER BAKER REP FROM 10,247.7'MD TO 10,249.5'MD -RATE:2.77 BPM IN,2.76 BPM OUT 1-MUD WEIGHT:8.96 PPG IN,8.99 PPG OUT DWOB:3.9-4.1 KLBS -CIRC PRESSURE: 3220 PSI -CASING EXITAT 10,249.5'BASED ON MILLING PARAMETERS. 21:00 - 23:30 2.50 STWHIP P 10,223.00 WEXIT MILL RATHOLE FROM 10,249.5'TO 10,260'. 1-RATE:2.76 BPM IN,2.76 BPM OUT -MUD WEIGHT:8.96 PPG IN,8.99 PPG OUT DWOB:3.0-4.1 KLBS -CIRC PRESSURE: 3,100-3,320 PSI 'I-PUMP 10 BBL HI VIS SWEEP AROUND. REAM WINDOW PERFORM REAMING PASS UP THEN DOWN AT 1 FT/MIN. -VERY SLIGHT MOTOR WORK SEEN AT 110,247',NOTHING ON DWOB. DEPTH CORRESPONDS TO TRANSITION BETWEEN 4-1/2"AND 7"CASING. -DO ANOTHER PASS,SIMILAR SLIGHT MOTOR WORK WITH NO DWOB. DRY DRIFT IS CLEAN,NOTHING SEEN ON DWOB. 1-OPEN EDC,FLAG PIPE AT 10,200'(10,090' EOP) -BOTTOMS UP SAMPLE IS 40%FORMATION. 23:30 - 00:00 0.50 STWHIP P 10,223.00 WEXIT POOH. '-MONITOR WELL FOR 10 MINUTES AT WINDOW WITH DYNAMIC FLOW CHECK: ,STATIC -MUD WEIGHT:8.96 PPG IN,8.98 PPG OUT -RATE:3.52 BPM IN,3.01 BPM OUT OPEN EDC,POH FROM 10,200' -CIRC PRESSURE:3,230 PSI 7/19/2017 00:00 - 01:30 1.50 STWHIP P 10,260.00 WEXIT CONTINUE POOH WITH WINDOW MILLING BHA. Printed 8/11/2017 10:09:09AM *All depths reported in Drillers Depths* r WELLHEAD- GRAY GENS • 1 4-32 SIY NOTES:CHROME TBG$LNR ACTUATOR= BAKER C I I OKB.REV= ----_-69" / EI:EV_ _--_--- 69 20"CONE), H 110' BF. 2207' H5-1/2"HES X NP,ID=4.562" ELEV= KOP= _41.49' 91.5#,H-40,3200' p=19.124" Max Angle= 47"@ 6913' Datum M3= 10397 Datum TVD= 8800'SS GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80,ID=12.347" -I 2493' 6 3499 3485 18 MMG DOME RK 16 04/03/17 5 5625 5200 37 MAG SO RK 20 04/03/17 4 7014 6288 43 MMG DMY RK 0 08/20/15 Minimum ID = 3.920" @ 9507' 3 7743 6805 46 MMS DMY RK 0 08/20/15 7" X 4-1/2" XO 2 8755 7503 44 MMG DMY RK 0 08/20/15 1 9157 7802 39 MAG DMY RK 0 08/20/15 ' 9269' H 5-112"HES X N1,ID=4.562" M �_, 9288' H9-5/8"X 5-1/2"HES TNT PKR,ID=4.811" 9434' H 5-112"HES X NIP,0=4.562" TOP OF 9-5/8"X 7"TEBACK LNR,ID=6.180" H 9477' 5-1/2"TBG, 17#,13CR-85 VA M TOP HC, H 9487' 9477' -9-5/8"X 7"BKR 2RH PKR w/TIEBACK .0232 bpf,O=4.892 L i • I D=6.180" 0 09487' -15-1/2"WLEG,ID=4.892" 9-5/8"X 7"LNR HGR w/TIEBACK,ID=6.84" - 9758' ' 9497' -19-5/8"X 7"BKR FLEX LOCK HGR =6.170" 9-5/8"CSG,47#,L-80 BTC XO TO S0095 -J 9996' •• 9507' 7"X 4-1/2"XO, =3.920" . „, 9-5/8”CSG,47#,S00-95 BTC,ID=8.681" -1J 10088' or I 10186" -17"MARKER JOINT PERFORATION SUMMARY REL LOG:BRCS ON 08/25/83 . ` 10225'ELM -4-1/2"BKR MONOBORE WHIPSTOCK ANGLE AT TOP PERF:25"@ 10364' 4• w/2 RA PIP TAGS(06/26/17) Note:Refer to Production DB for historical perf data r 10248' -14-1/2"BKR CIBP(06/26/17) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ■ 3-1/8" 4 10318-10348 S 04/01/84 06/04/87 . 3-3/8" 4 10353-10373 S 09/10/97 07/30/98 ' I. 3-3/8" 6 10364-10377 C 08/31/15 10421' �4-1/2"BKR WHIPSTOCK w/PP TAG(06/15/17) 3-1/8" 4 10367-10377 S 04/01/84 06/04/87WHIPSTOCK MOVED DH,SL TAGGED 06/19/17 3-3/8" 6 10385-10395 C 08/31/15 3-3/8" 4 10450-10460 S 05/29/87 06/04/87 ill 3-3/8" 4 10470-10490 S 03/19/89 09/13/89 3-3/8" 4 10470-10500 S 09/22/89 07/30/98 •+ 3-3/8" 4 10475-10505 S 08/15/98 08/19/15 1 op 3-3/8" 4 10500-10510 S 02/28/92 07/30/98ili 3-1/8" 4 10518-10528 S 05/13/87 06/04/87 Iw 3-3/8" 6 10518-10550 S 06/29/87 09/13/89 "4:-- j- 10510'CTM H PBTD ell, 4-1/2"SCAB LNR,12.6#,13CR-85 VAM TOP, H 10500' 107bb' -I 7"FOC .0152 bpf,0=3.958' 7"LNR,29#,N-80 BT&C,.0371 bpf,ID=6.184" -+ 10802' DATE REV BY COMMENTS DATE REV BY COMvBNTS PRUDHOE BAY UNIT 09/01/83 PKR 176 IMTIAL COMPLETION 04/05/17 CJWJMD GLV C/O(04/03/17) WELL: 14-32 08/24/15 D-14 RWO 05/25/17 JNL/JMD ADDED FEF&BF ELEV PERMIT No:'1831220 08/26/15 JMD DRLG Ii0 CORRECTIONS 06/21/17 NXW/JME SET BKR WHPSTOCK(06/15/17) AR No: 50-029-20999-00 08/27/15 CK/JMD FINIAL ODE APPROVAL 07/03/17 KFS/JM)SET WS,MOVE WS,SET CNP SEC 4,T1ON,R14E,40'FSL&1292'FEL 09/01/15 DJS/JMD GLV CIO(08/28/15) 08/15/17 ZB/JMD CORRECTED WS DEPTH 09/03/15 JCMUMD ADFERFS(08/31/15) BP Exploration(Alaska) • • v OF Tit 4,*���1 y/y.s, THE STATE Alaska Oil and Gas Of f T /tsKA Conservation Commission „OM i� 333 West Seventh Avenue t'" ' GOVERNOR BILL WALKER '07-‘-T'.', Anchorage, Alaska 99501-3572 Main: 907.279.1433 F ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin CTD & RWO SDE BP Exploration(Alaska), Inc. SCANNED ,1U N 0 5217 PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-32 Permit to Drill Number: 183-122 Sundry Number: 317-214 Dear Mr. McLaughlin: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, is i Daniel T. Seamount, Jr. Commissioner DATED this f s day of June, 2017. RBDjyJB IA, JUN - 2 2U17 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROV 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0- Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 183-122 • Exploratory 0 Development 0• 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20999-00-00 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 14-32 • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028312 • PRUDHOE BAY,PRUDHOE OIL• MAY 25 2017 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): AOGCC 10900 ` 9326 . 10510 8975 2453 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31-111 31-111 1490 470 Surface 2463 13-3/8" 30-2493 30-2493 4930 2670 Intermediate 10061 9-5/8" 27-10088 27-8593 6870 4760 Liner 1044 7" 9758-10802 8298-9238 8160 7020 Scab Liner 1023 4-1/2" 9477-10500 8060-8966 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10364-10395 8843-8871 5-1/2"17# 13Cr85 25-9487 Packers and SSSV Type: 5-1/2"HES TNT Packer Packers and SSSV MD(ft)and TVD(ft): 9288/7905 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 - Service 0 14.Estimated Date for Commencing Operations: June 5,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel,Joshua be deviated from without prior written approval. Contact Email: Joshua.Tempel@bp.com Authorized Name: Mclaughlin,Sean M Contact Phone: Authorized Title: CTD&RWO SDE Authorized Signature: e/! '_ 1\114—....,........ Date: 5/15/ f 7 Vw �_ COMMISSION USE Y I Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31-7- 21 -{ Plug Integrity 0 BOP Test I Mechanical Integrity Test 0 Location Clearance 0 �1 I, t Other: ,8G/� rfS'r 3 S0O ,v� '�l 1tnn�1 Kpvr-✓e"� �— P-,ye ZS l� �1uct�►,tN� of iso✓l .� �y L ✓ L Post Initial Injection MIT Req'd? Yes 0 No �/ v' '1 J p t V 26)A- 1—C 2.7 i)12Z Spacing Exception Required? Yes 0 No r Subsequent Form Required: `b —4-o I APPROVED BYTHE 9 Approved by: COMMISSIONER COMMISSION Date /9 V17,6/i/1 --- RBDMS L tUN - 2 2017 QP ! UIA 4, Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate APAA j..,,,Zb _ST 2c-(7 • • ' To: Alaska Oil &Gas Conservation Commission bp From: Josh Tempel RECEIVED CTD Engineer MAY 252017 Date: May 25, 2017 (� Re: 14-32 Sundry Approval ,A0`"`°(�(�(`� �" Sundry approval is requested to plug the 14-32 wellbore as part of the drilling and completion of the proposed 14-32A CTD sidetrack. Well was initially drilled and completed in 1983 and worked over in 2015. The parent bore is currently producing at the facility marginal GOR and there are no remaining wellwork opportunities. Proposed plan: Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on or around July 15th, 2017. E-line unit will set a CTD whipstock. CDR 2 will mill a 3.80"window in the production liner and drill a well in the Ivishak. The lateral will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 13Cr85 liner which will be cemented and perforated. This Sundry covers plugging the existing 14-32 perforations via the 14-32A liner cement lob or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)) The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin June 5th, 2017) S 1 Drift. GLV work. F 2 A/SL: Load IA and TBG E 3 Set Packer Whipstock ✓ 4 Set TWC Rig Work: 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,453 psi. 2. Mill 3.80" window plus 10' of rathole. Swap the well to 8.5-9.5 ppg drilling fluid. 3. PU drilling BHA and drill 4.25" hole to TD. 4. Run open hole logs. _ fir a(� 5. Run 3-1/2" x 3-1/4" x 2-7/8" 13Cr85 liner. CO4Cuf 4 j'e .v,��<<1" c"�Q� 6. Pump primary cement bringing TOC to TOL. 7. Test liner lap to 2,400 psi. Gd/ 2-3 fern% 44Afr1 1 v 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO /��a( a„r,Q o/ /5G cod #4lii� h t �" J J' Post Rig: l�,l-t'je rec h Otte whci C7 G1C1, // v 1. Drift. Run 2. Perforate RPM log. Ti 1 WI L(1 W r re* Jl Vo ') Ct'l0 6. /of 3. Contingency: Set liner top packer /Nic vvt o� NO v€2, gyro ,µ fi f /-114 *Approved alternate plug placement per 20 AAC 25.112(i) t ' Josh Tempel �F rpt 1 .5-41%9 CTD Engineer 891-5930 CC: Well File Joe Lastufka TREE= CIW �, 14-32 S NOTES:CHROME TBG LNR WaLHEAD= GRAY GEN3 ACTUATOR- BAKB-C ' ) .0143.REV= 69' e REF REV= 69' 20"CON), H 110' BF.B-EV=---- 41.49' 91.5#,H-40, , , 11 2207' —I 5-112"HES X NP.D=4.562" KOP= _ 200' D=19.124" Max Angle= 47°@ 6913' Datum ND= 10392' Datum TVD= 8800'SS GAS LFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80,D=12.347" H 2493' —...d 6 3499 3485 18 WAG DOME RK 16 04/03117 5 5625 5200 37 Mu13 SO RK 20 04/03/17 4 7014 6288 43 WIG DMY RK 0 08/20/15 Minimum ID = 3.920" @ 9507' 3 7743 6805 46 MNG DMY RK 0 08/20/15 7" X 4-1/2" XO 2 8755 7503 44 MMG DMY RK 0 08/20/15 1 9157 7802 39 AIG DMY RK 0 08/20/15 i i 9269' H5-1/2"HES X NP,D=4.562" 9288' H9-5/8"X 5-1/2"HES TNT PKR,D=4.811" i 9434' —15-1/2"HES X NP,D=4.562" TOP OF 9-5/8"X 7"TIEBACK LNR,D=6.180" H 9477' 5-1/2"TBG, 17#,13CR-85 VAM TOP HC, — 9487' 9477' —9-5/8"X 7"BKR 2RH PKR w/TIEBACK .0232 bpf,ID=4.892 D=6.180" 0 C9487' --15-1/2"WLEG,D=4.892" 9-5/8'X 7"LNR I-GR w/TRACK,D=6.84" —I 9758' / 1 F 9497' —j 9-5/8"X 7"BKR FLIX LOCK HGR,13=6.170" { ...;" _ 9607' -I T.X 4-1/2"XO,D=3.920" [9-5/8"CSG,47#,L-80 BTC XO TO S0095 —I 9996' • kii 9-5/8"CSG,47#,S00-95 BTC,D=8.681" -H 10088' yG i PRORATION SUMMARY RB LOG:BHCS ON 08/25/83 10186' —17"MARKER JOINT ANGLE ATTOP PERF:25°@ 10364' 1 Note_Refer to Production DB for historical perf data SIZE SPF EVTB2VAL Opn/Sqz SHOT SQZ . 3-1/8" 4 10318-10348 S 04/01/84 06/04/87 3-3/8" 4 10353-10373 S 09/10/97 07/30/98 1 ■ 3-3/8" 6 10364-10377 0 08/31/15 3-1/8" 4 10367-10377 S 04/01/84 06/04/87 .F. itir 3-3/8" 6 10385-10395 0 08/31/15 P. 3-3/8" 4 10450-10460 S 05/29/87 06/04/87 3-3/8" 4 10470-10490 S 03/19/89 09/13/89 • i 3-3/8" 4 10470-10500 S 09/22/89 07/30/98 . 3-3/8" 4 10475-10505 S 08/15/98 08/19/15 O. 3-318" 4 10500-10510 S 02/28/92 07/30/98 3- 4,e, 1/8" 4 10518-10528 S 05/13/87 06/04/87 + y' 3-3/8" 6 10518-10550 S 06/29/87 09/13/89 a 10610'CTM --I PSTD • dr lir 4-1/2"SCAB LNR,12.6#,13CR-85 VAM TOP, — 10500' .0152 bpf,ID=3.958' . 4 10765' —I 7"FOC 7"LNR,29#,N-80 BT&C,.0371 bpf,ID=6.184" H 10802' DATE REV BY COMMENTS DATE REV BY CONIN NTS PRUDHOE BAY UNIT 09/01/83 PKR 176 IMTIAL COMPLETION 04/05/17 CJN/JMD GLV C/O(04/03/17) WELL: 14-32 08/24/15 D-14 RWO 05/25/17 JNL/JMD ADDED REF&BF REV PERMIT No:'1831220 08/26/15 JMD DRLG HO CORRECTIONS API No: 50-029-20999-00 08/27/15 CK/JMD FINAL ODE APPROVAL SEC 4,T1ON,R14E,40'FSL&1292'Fa 09/01/15 DJS/JMD GLV C/O(08/28/15) 09/03/15 JCMJMD ADFERFS(08/31/15) BP Exploration(Alaska) PROPCED TREE= D= GRAY GENS 14-32 S NOTES:CHROME TBG& LNR ACTUATOR= REV 1 OKB.ELEV= 69' BF EL EV- 20"COM), H 110' 71 ' t 2207' I5-112"HES X NP,D= 562LI KOP= 3200' 91.5#,H-40. Max Angle= ;cr D=19.124" Datum MD= Datum ND= 8800'SS GAS LFT MANDRELS . 4111 MD 1VD DEV TYPE VLV TCH RT t _ ST 3499 3485 WING DOME ARK X16 04/03/17 TE 13-3/8'CSG,72#,L-80,0=12.347LIH 2493' I 5 5625 5200 37 MMG SO RK 20 04/03/17 4 7014 6288 43 MING DMY RK 0 08/20/15 3 7743 6805 46 MMG DMY RK 0 08/20/15 Minimum ID =2.377" 2 8755 7503 44 MMG DMY RK 0 08/20/15 1 9157 7802 39 MIG DMY RK 0 08/20/15 3-3/16" X 2-7/8" XO 9269' —1511/2 HES X NP.D=4.562" , 1 9288' I—I9-5/8"X 5-1/2'HES TNT PKR,D=4.811' 9434' H -" HES X NP,D=4.562" TOP OF 3-1/2"X 3-114"X 2-7/8"LNR —I 9477' I TOP OF 9-5/8"X 7"TR D ACK LN =6.180" —I 9477' 9477' +.70"DEPLOYMENT SLEEVE,D=3.00" 947T J-9-5/8'X 7'BKR 2RH PKR w/TEBACKK 5-1/2"TBG,17#,13CR-85 VAM TOP HC, 9487' D=6.180" .0232 bpf,D=4.892 L L- ��� 9487' H5-1/2"WLEG,D=4.892" `1 9497 _-19-5/8-X 7"BKR FLEX LOCK HGR D=6.170" ] •441 9607' —I7'X 4-1/2"XO,D=3.920 1 I•I [9-5/8"X 7"LNR HGR w/TEBACK,D=6.84" H 9768' k.::: .eve. i► 9-5/8"CSG,47#,L-80 BTC XO TO S0095 9996' I9-5/8"CSG.47#,S00-95 BTC.D=8.681" —I 10088' i!► , I. f 10189'A-13-1/2"X 3-3/16"XO,D=2.786" 3-1/2"LNR_#, ,—I 10180' - _bpf,D- ► 4. 4-1/2"PKR WHPSTOCK(XX/XX/XX) H 10230' i► 4-1/2"SCAB LNR,12.6#,13CR-85 VA TOP, —I —10230' 4 MLLOUT WN0OW(14-32A)10230'-_' .0152 bpf,0=3.958' 7"LNR 29#,N-80 BT 8 C,.0371 bpf.D=6.184' --I —10230' 3-1/4"LNR,6.6#,L-80 TCI1, i \ / 3-3/16"X 2-7/8"XO,D=2.377" .0079 bpf,D=2.85' ,____L i--13-3/16"I ___ 1 PERFORATION SUMMARY REF LOG:BHCS ON 08/25/83 ANGLE AT TOP FERE:_"@ ' Note:Refer to Production DB for historical perf data • I i---LPUP JT w IRA TAG 1 SIZE SPF LATER IAL Opn/Sqz SHOT SQZ I — PBTD — 2-7/8'LNR 6.5#,13-CR STL,.0058 bpf,D=2.441' —I 12366' DATE REV BY COMMENTS DATE REV BY COMMENTS PRIJDHOE BAY INT 09/01183 PKR 176 INITIAL COMPLETION WELL. 14-32A 08/24/15 0-14 RWO _ PERMT No: _/ /_ CTD SIDETRACK(14-32A) AR No. 50-029-20999-D1 04/12/17 JM) BIJLT PROPOSED SEC 4,T1ON,R14E,40'FSL&1292'FEL 04/18/17 JT/JMD BUILT PROPOSED REV 1 BP Exploration(Alaska) Well Blank CDR2-AC BOP Schematic Date _ • • • Quick Test Sub to Otis 1.1 ft Top of 7"Otis 0 CDR2 Rig's Drip Pan Distances from top of riser n Excluding quick-test sub dociroi Top of Annular I 0.0 ft v ► Io �I 7-1/16"5k Flange X 7"Otis Box c C Hydril 7 1/16" Top Annular Element 0.7 ft Annular 1 Bottom Annular 2.0 ft ► j ca®c�� CL Blind/Shears I 3.3 ft I. "' 0 0 0 0 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft B5 I B6 ' " ' "" -7 I#8101 Deployment Line _ "1114:4 ": 7-'ne" "� 4+ s+e �I IA! " t 5k Mud t � t.1- i- l N 6 �. 1* is Cross al, YIY y6 IIII Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft 2.3/8"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft ► B1 I B2 I Choke Line Kill Line' ��' �a+ x, R" ww 0 4* 4 d 14."4 F 111 t iMYMiliviso :if ft Ai . S ----_—�ar .. dux tli it Blind/Shear III CL Blind/Shears 10.0 ft 0- ' lil 2-3/8"Pipe/Slips dri CL 2-3/8"Combi's 10.7 ft 0 �40 • CL of Top Swab 13.3 ft N +-Swab 2 Test Pump Hose 01404 � 4/Swab 1 CL of Bottom Swab 14.8 ft 014 i T1 je T2 CL Flow Tee 16.2 ft ��• : _ BOP2 CL of SSV 17.5 ft N _ i Master 2 } Fusable Itlit CL of Master Valve 19.0 ft BOP1 = . . Master 1 LDS 20.5 ft —ter._ _ rte* II II 1. at 11 II II I II I, Gound Level •4 II II 1. II II 11 11 11 n It 1 • • o Thousand Cubic Feet of Gas ("MCF") per Day or rsi Gas-Oil Ratio (MCF per Barrel) Ln 0 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 o O O o oO ri 01 00 I. l0 Ll1 Cr M N ri O • _rrrs - ° - 44) 0 0 1 1 E I sl 1 (o _ _ C ...... VILi) co ----- — __ - 1oc. - -a a ll0 u a M — _,--- 1 �4�'P o 0 IIIIIIIIIIIIIIIIIIIIII I CU 6 a liqr Ce E �, t-1 O o0 1n ? 24 70 �' fC vni rn v O ----- S V1 in rn •M -- �'� a �f v on_ as y o '6 0 w .. .. ------1 ++ • _i a g �_ - 4P/ a CO 0 ;� ': °O� I E W o o c ---'' 6 I3L° 6• �� .eta_ !6, 0 u CI s- �{/ C' S p V ��// ' 6614 �o Y. _ CO C1 F� Q CLQ 1' x`66 ,--i-5 �.-- 64 ii y 16 a C3 6861 o 4P/, -o o u rcs 1, 1/4 ,` 1 5861 443 1 t __.__._. ''. I F o o o 0 0 0 0 0 0 0 0 861 o o o 0 0 0 0 0 0 0 44 /' O 01 c0 r' tD U, V M N r-1 Aea _lad JaleM Jo shine Jo Aea aad Ho to slaneg u 0 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or / "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA 41INLASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIS 1. Operations Performed Abandon 0 Plug Perforations lI Fracture Stimulate 0 Pull Tubing lI Operations shutdown 0 Suspend 0 Perforate lI Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Iv! Re-enter Susp Well 0 Other: Scab Liner II 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 183-122 3. Address: P.O.Box 196612 Anchorage, Development Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20999-00-00 7. Property Designation(Lease Number): ADL 028312 8. Well Name and Number: PBU 14-32 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: GR/CCL PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10900 feet Plugs measured None feet SEP; 17 2015 true vertical 9326 feet Junk measured None feet Effective Depth: measured 10500 feet Packer measured 9288 feet (gym ;/�@� true vertical 8966 feet Packer true vertical 7905 feet ` ' Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31-111 31-111 1490 470 Surface 2463 13-3/8" 30-2493 30-2493 4930 2670 Intermediate 10061 9-5/8" 27-10088 27-8593 6870 4760 Liner 1044 7" 9758-10802 8298-9238 8160 7020 Scab Liner 1023 4-1/2" 9477-10500 8060-8966 9020 8540 Perforation Depth: Measured depth: 10364-10377 feet 10385-10385 feet NOV1 lnt1�1 True vertical depth: 8843-8855 feet 8862-8871 feet SCANKE,V I`6 V y 2`V 15 Tubing(size,grade,measured and true vertical depth) 5-1/2"17#13Cr85 25-9487 25-8068 Packers and SSSV(type,measured and 5-1/2"HES TNT Packer 9288 7905 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: Cut&Pull 5-1/2",17#,L-80 from 9616'.Mill and Fish packer and 4-1/2",12.64,L-80 from 9791'.Run 4-1/2",12.6#,13Cr85 Scab Liner from 9477'-10500'.Cement Scab Liner w/38 Bbls 1.16 yield(184 sx)Class'G'.Run 5-1/2",17#,13Cr85 Tubing to 9487'.Perforate 10364'-10377',10385'-10395'w/3-3/8"Gun Diameter,6spf. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 75 851 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations a Exploratory 0 Development ll Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil lI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-129 Contact Kirchner,Carolyn J Email Carolyn.Kirchner@bp.com Printed Name Joe Lastufka Title Drilling Technologist Signature 1 Phone +1 907 564 4091 Date q/j i/1 /'�L Form 10-404 Revised 5/2015 � C0.41/- 0j/�� RBD""� VEP 2 2 2O1 Submit Original Only • • 14-32, Well History (Pre-Rig Workover) T/I/O=SSV/0/0, Temp=SI. PPPOT-T(FAIL), PPPOT-IC (PASS), pre RWO. PPPOT-T: RU to Hoke valves installed on test ports (0 psi). Monitored for 10 min, no change in pressure. Unable to pump through void because of furminite treatment. Functioned LDS, one is stuck in the out position, the rest moved freely(1"). Pressured void to 5000 psi for 30 min test, lost 4000 psi in 10 min. Torqued LDS to 600 lb/ft. Re-pressured void to 5000 psi, lost 4000 psi in 10 min (FAIL). Bled void to 0 psi, very little returns. PPPOT-IC: Stung into test port(150 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely(1"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min 5/17/2015 (PASS). Bled void to 0 psi. T/I/0 =SSV/120/30. Temp =SI. Assist Cameron Bleed TP & IAP to 0 psi, hold open bleed. AL disconnected. IA has an integral installed =inspection not current. TBG & IA FL's near surface. Bled TP from 20 psi to 0 psi in —1 min (gas). Bled IAP from 120 psi to 0 psi in 1 hr(gas). Held open bleed on IA for 30 min. Increased TP from 0 psi to 1920 psi in 25 min with AL from 14-43, IAP increased to 1730 psi during TP increase. Bled TP to 250 psi (gas), IAP decreased to 80 psi during TBG bleed. Monitor for 30 min, during monitor WHP's unchanged. Final WHP's =SSV/80/30. SV, 6/2/2015 WV, SSV=C. MV=0. IA, OA=OTG. 16:45. T/I/0=0/0/30, Temp=SI. PPPOT-T(FAIL), LPE-TBG. DHD Bled TBG and IAP to 0 psi. TBG hanger test void has been Furminite treated, Hoke valves installed in test ports. RU to Hoke valves(0+ psi in void). DHD peressured TBG to 1920 psi, no change in test void pressure. IAP tracked with the TBG to 1730 psi, Monitored for 30 min. Test void pressure did not increase. DHD bled TBG and 6/2/2015 IAP. Pressured test void to 5000 psi, lost 4000 psi in 10 min (Fail). Bled void to 0 psi. DRIFT W/4.515" G.RING TO 5-1/2" RBP @ 9640' SLM (9667' MD). PULL 5-1/2" RBP FROM 9640' 6/4/2015 SLM (9667' MD). RUN 4.50" 3-PRONG WIRE GRAB, TO 5 1/2 XO @ 9676' SLM/9701' MD. RUN 3.70"3-PRONG WIRE GRAB OUT TTL 10,200' SLM. DRIFT TBG W/3.50"CENT, 3-3/8" DUMMY GUN TO 10,000' 6/5/2015 SLM. T/I/O = 1540/1140/30. Temp= SI. TBG & IA FL's (E-line request). AL spool removed. TBG FL @ 4020' (1034' above#2 DMY, 93 bbls). IA FL @ 3150' (1904' above#2, DMY, 138 bbls). SV, WV, 6/6/2015 SSV= C. MV= 0. IA, OA= OTG. 2000 hrs. T/I/0=1550/1470/27 Temp=S/I Assist E-line (Pre RWO) CMIT-TxIA to 3000 psi postponed due to E-line can't get to MD. Pumped 3 bbls of meth followed by 230 bbls of 100*F crude down Tbg to 6/8/2015 load. Pumped 165 bbls of 60*F crude down Tbg to assist E-line downhole. 440/1245/40. INITIAL T/I/O = 1550/1480/0. LRS PERFORMED L&K ON TBG W/230 BBLS OF CRUDE. RIH W/ ELINE LOGGING TOOLS & BAKER 3-3/8" IBP. SIT DOWN @ 9677' (POSSIBLY MISSING ELEMENT FROM RBP THAT WAS PULLED BY SLICKLINE ON 6/4/15). LRS PUMPED 50 BBLS OF CRUDE (5 BPM) IN AN ATTEMPT TO FLUSH TBG CLEAR, BUT AFTER PUMPING RIH & SET DOWN 10' DEEPER @ 9687'. LRS PUMPED AN ADDITIONAL 100 BBLS OF CRUDE (5 BPM) IN AN ATTEMPT TO FLUSH TBG CLEAR OF DEBRIS, WAS ABLE TO PUMP DEBRIS DOWN TO 9759' MD IN THE 4-1/2"TBG BUT UNABLE TO WORK PAST. DECISION MADE TO POOH AND RIG DOWN TO ALLOW SLICKLINE TO RETURN AT A LATER DATE TO CLEAR UP TBG. POOH W/ IBP (ONLY SLIGHT DAMAGE TO ELEMENT, BUT NOTHING LEFT DOWNHOLE). FINIAL 6/8/2015 TI/O =450/1100/0. WELL LEFT SHUT IN - NOTIFIED PAD OP OF WELL STATUS. RUN 4.50" 3-PRONG WIRE GRAB, TAG 4-1/2"XO ©9,676' SLM/9,701' MD. RUN 3.75" 3- 6/10/2015 PRONG WIRE GRAB, TAG HARD BOTTOM @ 10,460' SLM. IH W/3.70"4-PRONG WIRE GRAB. RUN 3.70"2-PRONG WIRE GRAB, TAG BOTTOM @ 10,460' SLM. RUN 3.30"WIRE GRAB CENTER SPEAR, TAG BOTTOM @ 10,460' SLM. DRIFTED TBG w/3-3/8" D. GUN, 3.80" G. 6/11/2015 RING, FROM SURFACE TO TD @ 10,465' SLM @ 80FPM. • • 14-32, Well History (Pre-Rig Workover) INITIAL T/I/O= 1400/1400/0. MIRU. PT. LRS RU AND PT. RIH WITH 3-3/8" BAKER IBP. NOT GETTING COLLARS. POOH TO SWAP TOOLS. SECOND ATTEMPT RESULTED IN INTERMITTENT CCL RESPONSE. DECISION MADE TO COME OUT OF HOLE AND SWAP ERS 6/12/2015 AND WEIGHT BARS. RIH AGAIN AND EVERYTHING APPPEARS TO BE WORKING. T/I/0=1400/1427/27 Temp=S/I Assist SEL ( RWO) Speared in with 2 bbls neat followed by 6/12/2015 230 bbls crude to L&K TBG for E-Line. T/I/0=1400/1427/27 Temp=S/I Assist SEL ( RWO) Job postponed Eline in control of well 6/13/2015 upon LRS departure. DSO notified of well status. CV's= OTG FWHP's= 1100/1050/38. CONTINUE TO RIH W/ELINE LOGGING TOOLS AND 3-3/8" IBP. ATTEMPT TO SET IBP AT 9860', BUT UNABLE TO FULLY INFLATE AND SET. MOTOR APPEARED TO SHORT OUT 15 MIN INTO THE SETTING SEQUENCE. PULLED UP INTO TUBING TAIL @ 9792'AND UNABLE TO PULL PAST THE DB-NIPPLE @ 9779'. DECISION MADE TO SHEAR OFF OF BELLVILLE DISCONNECT LEAVING PARTIALLY INFLATED IBP IN THE DB-NIPPLE' (BELLVILLE DISCONNECT SPECS = 2.0 OAL/2.13"OD/ 1.375" JDC FISH NECK). (IBP SPECS = 11.40' OAL /3.375" MAX OD/ 1.375" JDC FISH NECK-2-6" SEALING ELEMENTS & 1- 1" STIFFENER RING). (ENTIRE LENGTH OF BOTH IBP & BELLVILLE DISCONNECT= 13.64"). FINAL T/I/O = 6/13/2015 1100/1100/0 PSI. T/I/O =1061/1076/31 Assist Slickline, (Secure) Loaded TBG with a 5 BBL Neat Spear followed by 147 bbl Crude.SD, SL latched onto plug, Pumped 8 bbls crude down TBG to assist SL in breaking 6/14/2015 free IBP, FWHP=200/650/30, IA/OA=open, SSL in control of well at departure. RAN 3.80" CENT& 3.50" LIB TAG IBP AT 9,741' SLM. RAN 4.0" BLIND BOX TO 9,700' SLM (no visible fluid level). PULL BELLVILLE & IBP FROM 9,735' SLM W/3.60" BELL GUIDE, 2.0" JUC (2" piece of top element missing & 1"stiffener ring). RAN 4-1/2" BRUSH & 3.711 (WG-42) TO 10,475' 6/14/2015 SLM (nothing recovered). INITIAL T/I/O = 700/700/0 PSI. PERFORM PASSING DUAL BARRIER TEST. RIGGED UP, PT 6/16/2015 LUB. RIH WITH BAKER IBP SETTING TOOL AND 3 3/8" IBP. CORRELATE TO TBG TALLY. SET IBP WITH MID ELEMENT AT 9860'. DISTANCE FROM CCL TO MID ELEMENT= 39.66'. CCL STOP = 9820.3'. (2-6' SEALING ELEMENTS, 1- 1" STIFFENER RING, OAL 11.04'). RDMO, LRS IN 6/17/2015 CONTROLL OF WELL TO CMIT. T/I/0=800/740/27 Assist E-Line (Pre RWO) Loaded Tbg w/5 bbls meth, 230 bbls 1% KCL Freeze protect w/60 bbls crude. E-Line set IBP. Bled gas off TxIA. Pumped 125 bbls crude down IA to reach 6/17/2015 test pressure. CMIT TxIA PASSED to 3500 psi. (Pre RWO) Pumped 1 bbl crude (125 bbls total) down IA to reach test pressure. Loss of 20/23 psi 1st 15 min. Loss of 18/19 psi 2nd 15 min, FWHP=490/495/0 6/18/2015 SV,WV,SSV shut. MV,IA,OA Open Tags hung AFE sign hung on master. T/I/O= 300/175/0 Set 5" CIW Gray BPV#613 @130"; Performed LTTon BPV(passed); Pumped up IA from 175 psi to 306 psi; Tree has 2 psi on it above the BPV: Performied a 30 minute In-Flow test 6/27/2015 for Pack off(passed); Set 5" Grey Test Dart#621 FWP=BPV-Test Dart/306/0. T/I/O = 300/175/0, Temp: SI, PPPOT-T (Incomplete) Barrier test for RWO. Hoke valve's installed on tubing test void. RU manifold to hoke valve's, (0+ psi) bled void to 0 psi. Valve shop set BPV. Pressured up IAP to 300 psi. Monitored test void for 30 minutes while valve shop tested BPV. Test 6/27/2015 void stayed at 0 psi. RD manifolds, will complete job tomorrow. • • 14-32, Well History (Pre-Rig Workover) T/I/O= BPV/300/0, Temp: SI, PPPOT-T(FAIL) Barrier test for RWO. RU to both hoke valve's on tubing test void, (0 psi). Test dart has been set. Monitor test void while valve shop pressured up tree to 3,500 psi. test void stayed at 0 psi. Monitored for 30 minutes. Test void stayed at 0 psi. Bled tree to 500 psi. Pumped through test void, able to pump out furmanite material from void and achieve clean returns. Pressured test void to 5,000 psi, decreased to 4,100 psi in 15 minutes. Tree increased to 2,670 psi. Pressued void back to 5,000 psi multiple times to let it settle. Pressured test void back to 5,000 psi and monitored for 30 minutes. Lost 500 psi in 15 minutes, lost 250 psi in second 15 minutes. Tree pressure increased to 3,050 psi. (FAIL) Bled test void to 0 psi and tree pressure 6/28/2015 decreased to 300 psi. Primary seal appears to be holding and secondary seal appears to be leaking. T/I/O= BPV-Test Dart/300/0 PT tree against Grey BPV/Test Dart to 300 psi-low& 3500 psi-High for 5 min each (passed) Tests charted and retained; CIW performed PPPOT test; On the completion of 6/28/2015 CIW test we Pulled Grey Test Dart#621 & Grey BPV#613 @ 130". FWP=300/300/0. TAG 3-3/8" BKR IBP W/3.50" LIBP @ 9842' SLM. MAKE 3 RUNS TO EQUALIZE& PULL IBP FROM 9841' SLM(missing 2 sealing elements&stiffener ring). RUN 5-1/2" BLB&3.50"WIRE GRAB TO XO @ 9686' SLM(recover 1 sealing element). RUN 4-1/2" BLB &3.753"WIRE GRAB TO 7/12/2015 DB NIP @ 9753' SLM(recover 2nd sealing element). RUN 4-1/2" BLB &3.753"WIRE GRAB, TAG TD @ 10471' SLM(no recovery). DRIFT W/4.25" CENT&3.753"WIRE GRAB, TAG 7"x4-1/2"XO @ 9672' SLM/9701' MD(clear drift, no recovery). ****1 - 1" STIFFENER RING FROM 3-3/8" BKR IBP LEFT IN HOLE, BOTH SEALING ELEMENTS 7/13/2015 RECOVERED**** INITIAL T/I/O = 920/100/0. MIRU. RIH W/CCL/4.15 POWER CUTTER. CUT TUBING AT 9616'. CCL TO CUTTER = 16.3'. CCL STOP DEPTH = 9599.7'. CORRELATED TO SLB LEAK DETECTION LOG. DATED 03-OCTOBER-2003. POOH. CONFIRMED SHOT AT SURFACE. 7/13/2015 RDMO. FINAL T/I/O= 1100/ 150 I 0. T/I/O=SSV/1160/30. Temp = SI. Cement Balance& Control lines. (Pre-RWO). Balance & Control lines @ 1160 psi. Integral flange installed on IA casing valve =inspection not current, AL spool removed & no companion valve on IA. Pumped 2 gallons of"Squeeze Crete"down Balance line (Front). Control line (Rear)would not flow Hyd fluid during injectivity test& pressured up to 2550 psi, Pressure decreased 150 psi to 2400 psi in 2 hours. Final WHP's = SSV/1160/30. Balance line (front) @ 1050 psi & Control line (rear) @ 2400 psi. SV, WV& SSV= C. MV= 0. IA& OA= OTG. 7/17/2015 Balance &Control lines = OTG. NOVP. 14:10. T/I/0=1807/1798/27 Temp=Sl MIT-OA PASSED to 1200 psi. Pumped 6.8 bbls of crude to reach test pressure, 1st 15 min OA lost 73 psi, 2nd 15 min OA lost 25 psi, total loss of 98 psi in 30 min test. 7/21/2015 FWHP=1815/1806/15 Hung fluid packed annulus sign. SV,WV,SSV=closed IA,OA=OTG. T/1/0= SSV/1890/40. Temp= SI. PT B&C lines (Pre RWO). No AL. Balance/Control lines @ 1890 psi. Integral installed on IA=inspection not current. After 4 failing attempts & pumping an estimated 3-4 gals hydraulic fluid down the Control line (rear), obtained a passing 5 min test to 2545 psi (2545- 2370 psi). Made 4 attempts to PT the Balance line (front)to 3500 psi but was unable to get above 3000 psi (estimated 2 gals pumped). On final attempt, pressure decreased from —3000 psi to 1890 7/22/2015 psi in <10 secs. Final WHPs= SSV/1900/40. SV, WV& SSV=C. MV=O. IA& OA=OTG. 1510 hrs. T/1/0= SSV/2200/50, Temp= SI. Cement B&C lines(Pre RWO). AL spool removed No wellhouse or floor grating. Balance&Control lines @ 2200 ipsi. IA FL @ 8530', beween Sta#5  (374 bbls). Pumped —1 gal SqueezeCrete down balance line. Bled control line to 0 psi to slop tank in 5 secs & it repressured to 2200 psi in 30 secs. Job Complete Final WHPs= SSV/2200/50. SV, WV& 7/25/2015 SSV=C. MV=O. IA& OA=OTG, 1615 hrs. • • 14-32, Well History (Pre-Rig Workover) TWO = SSV/2445/50. Temp=SI. P.T. B&C lines to 3500 psi (RWO Prep). No AL, FL, Scaffold, or well house. Used 3/4 gal hydraulic fluid on Balance line to attain 3500 psi. Balance line pressure lost 340 psi in 5 min (PASSED). Bled Control line pressure to 0 psi in <1 min. Control line pressure increased to 2457 in —1 min. Pumped 1/4 gal of hydraulic fluid down control line. Pressure to 3500 psi in — 1 sec. Control line pressure lost 1050 psi < 10 sec(FAILED). Job complete. Final WHPs=SSV/2453/50. Balance line pressure=10 psi/Control line pressure=2453 ps. SV=?. 7/27/2015 WV=LOTO. SSV=Closed. MV=Open. IA,OA=OTG. (1500 hrs). T/I/O= 2468/2468/40 Set 5" Grey BPV#604 @ 128"; Removed upper tree& installed 5"temp valve #37, torqued to API specification & PT to 300 psi-low&5000 psi-high (passed) 7/29/2015 FWP=BPV/2468/40. RDMO. T/I/O = SI/2468/50. Installed IA and OA piggybacks. IA#42 , OA#18 . Torqued and PT'd to API 7/29/2015 specs. (PASSED). RDMO. Final WHP's = SI/2468/50. T/I/O = SI/2460/40. Temp= SI. WHPs (Eval high OAP). IA FL near surface. IAP has not changed since 7/29/15. Dry hole tree is installed. No well house or scaffolding. Well is disconnected from 8/3/2015 flow lines. (Pre Rig). SV, MV= C. IA, OA= OTG. 1000 hrs. • • North America-ALASKA BP (� Page 1 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. i UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/8/2015 21:00 - 22:00 1.00 MOB P PRE PJSM AND SKID RIG FLOOR INTO MOVING POSITION. 22:00 - 23:00 1.00 MOB P PRE PJSM AND PULL OF 14-08. -HOLD PJSM WITH CREWS. I-JACK UP RIG.TEST MOVE SYSTEM ESD. PULL OFF WELL AND STAGE ON PAD. -BP WSL,TOOLPUSHER,TOURPUSHER,AND DOYON SUPERINTENDENT PRESENT WHILE BACK OFF WELL. 23.00 - 00:00 1.00 MOB P PRE PJSM AND MOVE RIG TO 14-32. -MOVE RIG TO NORTH PAD EXTENSION. -PULL ONTO RIG MATS AND LINE UP WITH WELL 14-32. 8/9/2015 00:00 - 01:30 1.50 MOB P PRE PJSM AND BACK RIG OVER 14-32. -LINE UP RIG ON MATS WITH WELL 14-32. 1-IA HAS 2460 PSI.RECEIVE APPROVAL FROM BP SUPERINTENDENT AND WTLTO MOVE ;OVER WELL WITH PRESSURE ON IA. • 1-HOLD PJSM,WITH CREW.DISCUSS IA PRESSURE AND ACTIONS TO MITIGATE RISK _ 'WHILE BACKING OVER WELL. •-SET DRIVE SYSTEM TO"CREEP"MODE. -TEST MOVE SYSTEM ESD 20'FROM WELL. BACK OVER WELL AND LINE UP ROTARY TABLE WITH WELL CENTER. SET RIG DOWN ON MATS. 01.30 - 09:00 7.50 MOB P • PRE RU FOR OPERATIONS ON 14-32. -SHIM AROUND CELLAR AND PREP CELLAR FLOOR.MARK EXCLUSION ZONES. -STAGE ROCK WASHER AND CHOKE SKID. -SKID RIG FLOOR TO DRILLING POSITION. -RU TIGER TANK HARDLINE. -PREP TO BRING FLUID INTO PITS. -RU SERVICE LINES TO RIG FLOOR. RU BEAVER SLIDE. -CALIBRATE GAS ALARMS. -LINE UP TO SPLIT PUMPS AND CIRC DOWN IAAND TUBING. ACCEPT DOYON 14 ON DS 14-32 AT 0600 HRS 08/09/2015. 09:00 - 12:00 3.00 MOB P PRE RU CELLAR FOR OPERATIONS ON 14-32. -BRING GRAVEL IN FOR CELLAR AREA. -REMOVE DUNNAGE IN CELLAR AND LAY PLYWOOD. SPOT BLEED TRAILER FOR OA MONITOR. SIMOPS:MOBILIZE DSM LUBRICATOR TO RIG FLOOR. 12:00 - 14:00 2.00 WHSUR P DECOMP RU LUBRICATOR TO PULL BPV. MOBILIZE LUBRICATOR AND EXTENSIONS TO RIG FLOOR. ;-BRING PUMP IN SUB TO RIG FLOOR. MU EXTENSIONS,PUMP IN SUB,AND LUBRICATOR TO TREE. Printed 9/14/2015 10:11:33AM • 23 s �� • North Americo AL $� ;' ale o Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date.8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 14:00 - 15:00 1.00 WHSUR P DECOMP HOLD H2S EVAC DRILL. -SIMULATE H2S IN THE PITS. -FUNCTION TEST RIG ESD. -AAR FOLLOWING DRILL WITH ALL PERSONNEL ON LOCATION. 15:00 - 21:30 6.50 WHSUR P DECOMP PULL K-TYPE BPV. -PJSM TO PULL BPV. RU TEST HOSES AND ALL CIRCULATING LINES. -TEST CIRCULATING LINES TO 250/3500 PSI FOR 5/5 CHARTED MIN. -TEST LUBRICATOR TO 250/4000 PSI FOR 5/5 CHARTED MIN. -PULL BPV WITH TESTED LUBRICATOR. -BREAK OFF LUBRICATOR.LD BPV. 1-MU LUBRICATOR AND PRESS TEST QTS TO 250/3500 PSI FOR 5/5 MIN. 21:30 - 00:00 2.50 KILLW P DECOMP PJSM AND BULLHEAD KILL WELL. -HOLD PJSM:WSL,TOOLPUSHER,SCS, TRUCK DRIVERS,AND RIG CREW IN ATTENDANCE. -REVIEW DDI WELL KILL SOP.DISCUSS VALVE ALIGNMENT. DRILLER DISCUSSED ROLES AND RESPONSIBILITIES OF PERSONNEL. WSL VERIFY VALVE ALIGNMENT. -BULLHEAD DOWN 5-1/2"TBG AND IA SIMULTANEOUSLY. -BULLHEAD WITH 120 DEGREE 8.5 PPG SEAWATER. -STAGE UP PUMPS TO 6.0 BPM DOWN TUBING AND IA(12.0 BPM TOTAL). -WITH TUBING SWEPT,DECREASE TUBING RATE TO 5.5 BPM AND INCREASE IA RATE TO 7.0 BPM(12.5 BPM TOTAL). -TUBING:ICP=2580 PSI AT 6.0 BPM.FCP= 11170 PSI AT 5.5 BPM. -IA:ICP=3270 PSI AT 6.0 BPM.FCP=2220 1PSI AT 7.0 BPM. 1-BLEED DOWN OA 2X FROM 750 PSI TO 0 PSI DURING WELL KILL.BLED MOSTLY GAS WITH 1 SOME DIESEL.VOLUME BLED<1 BBL. -800 BBLS TOTAL PUMPED AT 00:00. 8/10/2015 00:00 - 01:00 1.00 KILLW P DECOMP CONTINUE BULLHEAD KILL WELL. -800 BBLS TOTAL PUMPED AT 00:00. -TUBING:ICP=2580 PSI AT 6.0 BPM.FCP= 1170 PSI AT 5.5 BPM. -IA:ICP=3270 PSI AT 6.0 BPM.FCP=2220 PSI AT 7.0 BPM. -TOTAL PUMPED 1213 BBLS KWF @ 12.0- 12.5 BPM. UMPS OFF AT 00:30 HRS. I-1213 BBLS KWF BULLHEADED TO I FORMATION. -SHUT IN TUBING AND IA TO PRESSURE GAGES. -MONITOR WELL FOR 30 MIN. I-IA AND TUBING BOTH ON VACUUM. Printed 9/14/2015 10:11:33AM i North America-ALASKA-BP , ' Pa 90 3 23 Operation Summary Report Common Well Name 14-32 AFE No Event Type:WORKOVER(WO) Start Date.8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 01:00 - 01:30 0.50 KILLW P DECOMP OBTAIN STATIC LOSS RATE. -CIRC AT 5 BPM AND 530 PSI DOWN IA WITH TUBING SHUT-IN. '-LOST VAC ON TUBING WITH 40 BBLS jPUMPED. -CATCH PRESSURE TO 650 PSI WITH 85 BBLS PUMPED AT 01:05 HRS. -CIRC ADDITIONAL 15 BBLS TO 100 BBLS TOTAL.PRESSURE CONSTANT AT 650 PSI. -STATIC LOSS RATE=93 BPH. 01:30 - 02:30 1.00 WHSUR P DECOMP IRISM AND INSTALL BPV. LINE LIP AND FILL DOWN IA AT 80 BPH WITH CHARGE PUMP. 1-SHUT-IN TREE VALVES. BREAK OFF LUBRICATOR AND MU BPV. -MU LUBRICATOR AND TEST QTS TO 250/ j 3500 PSI FOR 5/5 MIN. -OPEN TREE VALVES AND SET BPV. 02:30 - 03:00 0.50 WHSUR P DECOMP PERFORM ROLLING TEST OF BPV. -CIRC DOWN IA AT 5 BPM AND 530 PSI FOR 5 MIN. DID NOT CATCH PRESSURE.NO INDICATION BPV NOT HOLDING. `-LINE UP AND FILL DOWN IA AT 80 BPH WITH CHARGE PUMP. 03:00 - 05:00 2.00 WHSUR P DECOMP PJSMANDRDLUBRICATORAND EXTENSIONS. RD LUBRICATOR,PUMP-IN SUB,AND EXTENSIONS. -OFFLOAD DSM TOOLS FROM FLOOR AND CELLAR. CLEAN AND CLEAR FLOOR. I-BLEED DOWN OA FROM 500 TO 50 PSI. FILL DOWN IAAT 80 BPH WITH CHARGE PUMP. 05:00 - 09:00 4.00 WHSUR P DECOMP PJSM AND ND DRY HOLE TREE. -ND DRY HOLE TREE/ADAPTER FLANGE. -TORQUE LDS AND GLAND NUTS. -MEASURE LDS:IN=3-1/8",OUT=4-1/2". TEST RUN X-OVER TO HANGER WITH 18-3/4 TURNS TO RIGHT. I-INSTALL DART IN K-TYPE BPV. I I '-FILL DOWN IA AT 80 BPH WITH CHARGE PUMP. 09:00 - 12:00 3.00 BOPSUR P DECOMP PJSM AND NU BOPE STACK. -NU BOPE AND SECURE IN CELLAR. -INSTALL CHOKE/KILL LINES AND RISER. -TAKE RKB MEASUREMENTS. -FILL DOWN IAAT 80 BPH WITH CHARGE PUMP. 12:00 - 15:00 j 3.00 BOPSUR P DECOMP PJSM AND RU TO TEST BOPE. -BREAK FOSV OFF SAFETY JOINT. -MU FOSVS FOR TESTING.MU TOP DRIVE X-OVER TO TESTING. -CATCH FLUID ON IA.DECREASE FILL RATE TO 60 BPH. Printed 9/14/2015 10 11 33A • • North America-ALASKA BP ; "''Q 4/of 23 Operation Summary Report Common Well Name.14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:OOAM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI.500292099900 Active datum:54:32 8/5/1983 00:00 @69.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15.00 - 22:30 7.50 BOPSUR P DECOMP STATE GIVEN NOTIFICATION OF BOPE TEST 08/09/2015 02:30. STATE INSPECTOR BOB NOBLE WAIVE WITNESS PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,SUNDRY#183-122,AND GP 10-45. -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN. -TEST BLOWOUT PREVENTERS AND ALL I ASSOCIATED BOPE. LOWER 3-1/2"X 6"VBR'S TESTED WITH 4" AND 5-1/2"TEST JOINTS. —UPPER 2-7/8"X 5"VBR'S TESTED WITH 4" TEST JOINT. -ANNULAR TESTED WITH 4"TEST JOINT. BLIND/SHEAR RAMS TESTED -TEST CHOKE MANIFOLD VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES. -TEST MANUAL AND HYDRAULIC!BOP'S ON TOP DRIVE. TEST FLOOR AND DART VALVES PERFORM DRAW DOWN TEST OF ACCUMULATOR. FUNCTION BOPE FROM REMOTE PANEL AND MAIN UNIT. -TEST GAS ALARMS. -ALL TESTS WITNESSED BY TOOLPUSHER AND WSL. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 22:30 - 00:00 1.50 BOPSUR P DECOMP RD PRESS TESTING EQUIPMENT. -LD TEST JOINTS,RD TESTING EQUIPMENT. -BLOW DOWN CHOKE/KILL/BLEEDER LINES. -RU WELL CONTROL EQUIPMENT TO PULL TUBING. -MU SAFETY JOINT WITH 4"FOSV. -MU 4-1/2"FOSV TO 5-1/2"8-ROUND X-OVER. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 8/11/2015 00:00 - 01:00 1.00 WHSUR P DECOMP PERFORM SPCC WALK AROUND AND EQUIPMENT CHECKS. -PJSM:SERVICE AND INSPECT TOP DRIVE, BLOCKS,AND DRAW WORKS. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 01:00 - 02.00 1.00 WHSUR P DECOMP HOLD H2S EVAC DRILL. -SIMULATE H2S IN THE CELLAR. -AAR FOLLOWING DRILL WITH PERSONNEL. -DISCUSS H2S ALARMS,AND APPROPRIATE ACTIONS FOR EACH ALARM. -FILL DOWN IAAT 60 BPH WITH CHARGE PUMP. Printed 9/14/2015 10.11.33AM • I North America-ALASKA-BP Page 5 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:00 2.00 WHSUR P DECOMP PJSM AND RU DUTCH RISER AND LUBRICATOR. INSTALL DUTCH SYSTEM. -MOBILIZE DSM LUBRICATOR TO RIG FLOOR. MU LUBRICATOR AND TEST 250/3500 PSI FOR 5/5 MINS. -BREAK LUBRICATOR AT QTS.INSTALL BPV PULLING TOOL. -MU AND TEST LUBRICATOR QTS TO 250/3500 PSI. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 04:00 - 06:00 2.00 WHSUR P DECOMP PULL DART AND BACK PRESSURE VALVE. -PULL BPV DART.BREAK AT QTS AND LD SAME. -MAKE UP LUBRICATOR AND TEST BREAK AT QTS. -PULL BACK PRESSURE VALVE. FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 06:00 - 09:00 3.00 WHSUR P DECOMP PJSM AND LD DUTCH RISER AND LUBRICATOR. -RD LUBRICATOR AND DEMOB FROM RIG 'FLOOR. BOLDS BELOW ANNULAR AND LD DUTCH RISER.DEMOB FROM RIG FLOOR. -FILL DOWN IAAT 60 BPH WITH CHARGE PUMP. 09:00 - 09:30 0.50 PULL P DECOMP PJSM AND MU SPEAR BHA. MU SPEAR AND X-OVER TO JT 4"DP. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 09:30 - 10:30 1.00 PULL P 1 DECOMP PJSM AND PULL TUBING HANGER. -KELLY UP ON SPEAR ASSEMBLY. -RIH WITH SPEAR TO NO-GO. -PU TO 80K TO CONFIRM ENGAGED.SO TO NEUTRAL. -PJSM WITH CAMERON REP AND BOLDS ON TUBING HANGER. -PU TO 243K#AND HANGER COME FREE.PU 5'.PUW=202K#. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 10:30 - 12:00 1.50 PULL P DECOMP PJSM AND BULLHEAD 650 BBLS DOWN TBG/ IA. -PUMP DOWN IA AT 5.5 BPM WITH 1050 PSI. -PUMP DOWN TBG AT 3.0 BPM WITH 400 PSI. -FILL DOWN IA AT 60 BPH WITH CHARGE PUMP. 12:00 - 13:30 1.50 PULL P DECOMP MONITOR AND OBTAIN LOSS RATE. -MONITOR WELL 10 MIN.WELL ON VAC. -OPEN ANNULAR.PUMP DOWN TBG TO OBTAIN LOSS RATE. -PUMP 7.5 BPM FOR 100 BBLS AND CANNOT CATCH RETURNS. Printed 9/14/2015 10:11:33AM • ", NorthArnenca ALASKA BP ,' I s Page 6 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date.8/24/2015 X4-011 FM-E:(3,450,000.00) —: Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 l Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 1 (hr) (usft) 13:30 - 14:30 1.00 PULL P + DECOMP PJSM AND PULL HANGER. I '-PULL HANGER TO RIG FLOOR.PUW= ' 200K#. -BREAK OFF HANGER.LD HANGER AND SPEAR ASSEMBLY. -TERMINATE CONTROL LINES. I-C/O ELEVATORS.RU POWER TONGS AND HAND SLIPS. PREP SAFETY JOINT AND FLOOR VALVE X-OVERS FOR TUBING. '-INCREASE FILL RATE TO 80 BPH DOWN i HOLE FILL LINE. 14:30 - 16:30 2.00 PULL P DECOMP 'PJSM AND LD 5-1/2"17#J-55 8RD TUBING F/ 9616'T/9308'MD. -SLB REP SPOOL CONTROL LINE. -WSL ON FLOOR FOR FIRST 30 JTS TO j VERIFY TRIP PARAMETERS. I HOLD KICK WHILE TRIPPING DRILLAND I I STAB FLOOR VALVE. -HOLE FILL ON AT 80 BPH. 16:30 - 19:00 2.50 PULL P DECOMP I SUSPEND OPERATIONS FOR BP VISITORS. !-FOSV INSTALLED.CONTINUE FILL HOLE AT ;80 BPH. 19:00 - 21:00 2.00 PULL P I DECOMP CONTINUE LD 5-1/2"17#J-55 8RD TUBING F/ 19308'T/8511'MD. -SLB REP SPOOL CONTROL LINE. -WSL ON FLOOR FOR FIRST 30 JTS TO VERIFY TRIP PARAMETERS. -PUMP 40 BBL HI-VIS PILL FOR LOSSES. -HOLE FILL ON AT 80 BPH. 21:00 - 21:30 0.50 PULL N WAIT DECOMP CLEAN AND CLEAR RIG FLOOR. -WAIT ON SLB RELIEF TO GO THRU RIG 1 ORIENTATION. -HOLE FILL ON AT 80 BPH. 21:30 - 23:00 1.50 PULL P DECOMP CONTINUE LD 5-1/2"17#J-55 8RD TUBING F/ 8511'T/8158'MD. -CONTROL LINE BECOME BRITTLE AND BREAK APART ON SPOOLER. -STOP JOB AND RE-GROUP.HOLD PJSM FOR I HANDLING CONTROL LINE. -SLB REP GUIDE CONTROL LINE OUT BY HAND. -BREAK CONTROL LINE INTO 4'LENGTHS AND BAG UP IN SUPER SACK I 1 -LD SSSV.RECOVERED 26 CLAMPS AND 4 STAINLESS BANDS. HISTORICAL RECORDS SHOW 26 CLAMPS AND 4 STAINLESS BANDS. -HOLE FILL ON AT 80 BPH. 23:00 00:00 1.00 PULL P DECOMP PJSM AND RD CONTROL LINE EQUIPMENT. -STAB FOSV. -DEMOB CONTROL LINE SPOOLER AND SUPER SACKS OF CONTROL LINE DOWN BEAVER SLIDE. 1-DEMOB CLAMPS AND BANDS. I 1-HOLE FILL ON AT 80 BPH. 8/12/2015 00:00 - 04:00 4.00 PULL P ' I I DECOMP !CONTINUE LD 5-1/2"17#J-55 8RD TUBING F/ 8158'T/4850'MD. -LD 2X GLM'S. 1-HOLE FILL ON.LOSSES AT 80 BPH. Printed 9/14/2015 10 11 33AM ,. North America-ALASKA BP Page 7 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date 8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00 00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task 1 Code I NPT 1 NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:00 2.00 PULL P i j DECOMP I PJSM AND MU RTTS. I -MOB RTTS TO RIG FLOOR THRU PIPE SHED. -PU RTTS AND MU X-OVER FROM 8RD TO 4-1/2"IF. -WHILE MU RTTS,GET RETURNS TO SURFACE.STOP AND FLOW CHECK FOR 10 MIN.WELL ON LOSSES. L RE-TAKE STATIC LOSS RATE=80 BPH. -SHUT OFF HOLE FILLAND ALLOW STACK TO DRAIN BEFORE RUN RTTS.SEE LARGE PIECES OF CONTROL LINE IN BETWEEN I TUBING AND BOP STACK.CALL AND MAKE NOTIFICATIONS TO ODE AND SUPERINTENDENT.AGREE TO CONTINUE I PULLING TUBING. H LD RTTS AND MU X-OVER TO FLOOR VALVE. 06.00 - 10.30 4.50 PULL P DECOMP I PJSM AND CONTINUE LD 5-1/2"17#J-55 8RD TUBING F/4850'MD. -RECOVER 221 FULL JTS,1 CUT JT,11 GLM'S AND SSSV FROM WELL. CUT OD=6.25"-6.50".CUT JT LENGTH= 4.28'. -HOLE FILL ON.LOSSES AT 80 BPH. 10:30 - 11:30 1.00 PULL P DECOMP RD FROM PULLING TUBING. -DEMOB CASING EQUIPMENT FROM RIG FLOOR. I-MOB FISHING TOOLS TO FLOOR. I-HOLE FILL ON.LOSSES AT 80 BPH. 11:30 - 15:00 3.50 PULL PI DECOMP PJSM AND FISH CONTROL LINE FROM STACK. ALTERNATE WIRELINE SPEAR AND MILL I ! ASSEMBLY THRU STACK. -RECOVER-25'OF CONTROL LINE IN 2-4' 1 SEGMENTS. -FLUSH BOP STACK AT 9.2 BPM AND 20 RPM. -HOLE FILL ON.LOSSES AT 80 BPH. 15:00 16:00 1.00 PULL P DECOMP GOT RETRUNS TO SURFACE.MONITOR WELL. -STOP AND FLOWCHECK-STILL ON LOSSES. -TAKE NEW LOSS RATE=60 BPH. 16:00 - 17:00 1.00 I PULL P DECOMP PJSM AND RD FROM CONTROL LINE FISHING. DEMOB FISHING TOOLS FROM RIG FLOOR. BLOW DOWN TOP DRIVE. -HOLE FILL ON.LOSSES AT 60 BPH. 17:00 - 18:00 I 1.00 PULL P DECOMP PJSM AND C/O DERRICK CLIMBER CABLE. -HOLE FILL ON.LOSSES AT 60 BPH. 18:00 - 18:30 0.50 PULL N RREP DECOMP CONTINUE C/O DERRICK CLIMBER CABLE. LUBRICATE RIG. -HOLE FILL ON.LOSSES AT 60 BPH. 18:30 - 21:00 2.50 WHSUR P 1 DECOMP j PJSM AND INSTALL WEAR RING. -WEAR RING ID=8-15/16"/OD=13-5/8". -ATTEMPT TO RILDS.LDS NOT MOVING. -CALL OUT CAMERON.CAMERON RILDS X4. -LDS MEASUREMENT ON WEAR RING= 3-3/4". -HOLE FILL ON.LOSSES AT 60 BPH. Printed 9/14/2015 1011:33AM S le '" N Ort AmericaALASKA BP Pageof 23 Operation Summary Report ''' Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 1 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 23:30 2.50 FISH P DECOMP PJSM AND MU DRESS OFF/OVERSHOT BHA. I-MU DRESS OFF GUIDE SHOE AND 'OVERSHOT. -MU BUMPER AND OIL JARS. -PU 9X 6-1/4"DC'S. I-MU INTENSIFIER AND PUMP OUT SUB. -LOSSES DECREASE WITH BHA IN HOLE. 'MONITOR WELL. -TAKE NEW LOSS RATE=30 BPH. 23:30 - 00:00 0.50 FISH P DECOMP PJSM AND RIH WITH OVERSHOT 336'-420' MD. -SINGLE IN ON 4"DP FROM PIPESHED. ' I LOSSES INCREASE TO 60 BPH ONCE BHA PAST WELLHEAD. HOLE FILL ON.LOSSES AT 60 BPH. 8/13/2015 00:00 - 03:30 3.50 FISH P DECOMP PJSM AND TEST CONTROL LINE ', I TERMINATION PORTS TUBING SPOOL. I-PU RTTS AND RIH ON 3 JTS OF 4"DP. -SET RTTS AND CLOSE UPPER PIPE RAMS. -TEST TO 250/3500 PSI FOR 5/5 MIN,GOOD TEST. -POOHANDLD3JTS4"DP. LD RTTS AND OFFLOAD FROM PIPE SHED. -CIRC DOWN DRILLSTRING AT 1.5 BPM WHILE TEST PORTS. 03:30 - 09:30 6.00 FISH P DECOMP j PJSM AND RIH WITH OVERSHOT 420'-3963' MD. -SINGLE IN ON 4"DP FROM PIPESHED. -CIRC DOWN DRILL STRING EVERY 30 JTS AT 8 BPM FOR 10 MIN TO ENSURE DRILLSTRING CLEAR. -HOLE FILL ON.LOSSES AT 60 BPH. IF 09 30 10:00 0.50 FISH PDECOMP HOLD SAFETY STANDDOWN WITH RIG CREW. -DISCUSS REMAINING FOCUSED ON TASK AT HAND. -EMPHASIZED STAYING SAFE IN THE MOMENT. 10:00 - 12:00 2.00 FISH P DECOMP CONTINUE RIH WITH OVERSHOT 3963'-6020' MD. -SINGLE IN ON 4"DP FROM PIPESHED. -MW IN/OUT=8.5 PPG. -CIRC DOWN DRILL STRING EVERY 30 JTS AT 7 BPM FOR 10 MIN TO ENSURE DRILLSTRING CLEAR. 1-HOLE FILL ON.LOSSES AT 60 BPH. 12:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG. -GREASE EQUIPMENT. 12:30 - 17:00 4.50 FISH P DECOMP CONTINUE RIH WITH OVERSHOT 6020'-8869' MD. SINGLE IN ON 4"DP FROM PIPESHED. ' '-MW IN/OUT=8.5 PPG. -CIRC DOWN DRILL STRING EVERY 30 JTS AT 7 BPM FOR 10 MIN TO ENSURE DRILLSTRING CLEAR. -HOLE FILL ON.LOSSES AT 60 BPH. 17:00 - 17:30 0.50 FISH P DECOMP SERVICE TOP DRIVE AND HOISTING EQUIPMENT. Printed 9/14/2015 10 11 33AM • • North America-ALASKA-BP Page 9 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 18:00 0.50 FISH N RREP DECOMP PIPE HANDLER NOT FUNCTIONING ON TOP DRIVE. RIG MECHANIC ON LOCATION AND REPAIR TOP DRIVE. 18:00 - 19:00 1.00 FISH P DECOMP CONTINUE RIH WITH OVERSHOT 8869'-9533' MD. -SINGLE IN ON 4"DP FROM PIPESHED. MW IN/OUT=8.5 PPG. CIRC DOWN DRILL STRING EVERY 30 JTS AT 7 BPM FOR 10 MIN TO ENSURE DRILLSTRING CLEAR. 1-HOLE FILL ON.LOSSES AT 60 BPH. 19:00 - 21:00 2.00 FISH P DECOMP FISHING OPERATIONS ON K-ANCHOR PER BAKER REP. OBTAIN PARAMETERS:PUW=21OK, SOW=165K,ROT=185K. -20 RPM W/3K TORQUE,CIRC 258 GPM W/ 520 PSN. -WASH DOWN F/9596'MD.TAG AT 9622'MD WITH 5K WOB. -PU ADDITIONAL JT#295 OF 4"DP. CONT.RIH TO 9626'MD WITH 15K WOB. PRESSURE UP TO 720 PSI. -PU TO 30K OVERPULL TO VERIFY LATCH. SO TO 150K. -PU TO 240K AND JAR.SO TO 150K -PU TO 250K AND JAR.SO TO 150K. -PUT 7-8K TORQUE IN STRING AND WORK PIPE 220-250K. RELEASE TORQUE.SO TO 20K WOB.PU TO 250K AND JAR. -SLOWLY INCREASE TORQE TO 10K AND WORK PIPE 220-250K. -TORQUE RELEASE AND STRING WT DROP I TO NEUTRAL 210K. LD ADDITIONAL JT#295 OF 4"DP. 21:00 - 21:30 0.50 FISH P DECOMP MONITOR WELL FOR 30 MIN. OBTAIN NEW LOSS RATE=20 BPH. 21:30 - 00:00 2.50 FISH P DECOMP PJSM AND POOH WITH OVERSHOT 9596'- 6685'MD. -STAND BACK 4"DP IN DERRICK. -MW IN/OUT=8.5 PPG. 1-HOLE FILL ON.LOSSES AT 20 BPH. 8/14/2015 00:00 - 03:30 3.50 FISH P DECOMP PJSM AND POOH WITH OVERSHOT 6685'- 420'MD. -STAND BACK 4"DP IN DERRICK. -MW IN/OUT=8.5 PPG. -HOLE FILL ON.LOSSES AT 30 BPH. 03:30 06:00 2.50 FISH P DECOMP �PJSM AND LD OVERSHOT BHA.K-ANCHOR �RECOVERED. -FLOW CHECK 10 MIN BEFORE PULL NON SHEARABLES THRU STACK -RACK BACK LAST STAND 4"DRILL PIPE. -LD INTENSIFIER AND PUMP OUT SUB. -RACK BACK 3 STANDS 6-1/4"DRILL COLLARS. -LD FISHING JAR AND BUMPER JAR. -BREAK BOTTOM CONNECTION OF CUT JOINT. -LD OVERSHOT AND CUT JOINT. -LD PUP JTS,PBR,AND K-ANCHOR. -HOLE FILL ON.LOSSES AT 30 BPH. Printed 9/14/2015 10:11:33AM • North America-ALASKA ¢P ,Pere 10 of 23 Operation Summary Report '„ /,',4%mx%ovio,114glasnIMOvratV. Common Well Name 14-32 AFE No Event Type:WORKOVER(WO) Start Date 8/8/2015 End Date:8/24/2015 X4-011 FM-E.(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To 1 Hrs Task Code I NPT NPT Depth Phase Description of Operations — — (hr) (usft) 06:00 - 07:00 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. -DEMOB ALL FISHING TOOLS AND RECOVERED WELLBORE EQUIPMENT. -CLEAN RIG FLOOR. -HOLE FILL ON.LOSSES AT 30 BPH. 07:00 - 08:00 1.00 FISH P DECOMP 1PREP TO PU BHA FOR MILLING PACKER. MOB BAKER MILLAND JUNK BASKETS TO F [FLOOR. -PREP BACK SAVER SLIPS FOR INSTALL. ,-HOLE FILL ON.LOSSES AT 30 BPH. 08:00 - 09:30 1.50 FISH P DECOMP PJSM AND MU MILLING ASSEMBLY. -MU 8-1/2"X 3-1/2"PACKER MILLAND JUNK BASKETS. -MU BUMPER AND OIL JARS. -PU 3 STANDS 6-1/4"DC'S. -MU INTENSIFIER AND PUMP OUT SUB. -HOLE FILL ON.LOSSES AT 30 BPH. 09.30 - 13:00 3.50 FISH P DECOMP RIH-WITH MILLING ASSEMBLY 336'-9640'MD. -RIH ON STANDS FROM DERRICK. -MW IN/OUT=8.5 PPG. -FILL PIPE AND BREAK CIRC EVERY 20 STANDS. HOLE FILL ON.LOSSES AT 30 BPH. 13:00 - 17:00 4.00 FISH P DECOMP !SLIP-N-CUT 50'OF DRILLINE. SERVICE RIG HOISTING EQUIPMENT. 17:00 - 22:30 5.50 FISH P DECOMP PJSM AND MILL PACKER. OBTAIN PARAMETERS FOR MILLING: -PU=215K,SO=125K,ROT=185K.TAKE SPR'S. -MILL AS PER BAKER REP.TAG TOP OF PKR IAT9688'MD. -MILL FIRST 1 FT AT 60 RPM,5-6K WOB,6 BPM WITH 500 PSI. -INCREASE TO 80 RPM AND 8-10K WOB. 1-SLOWLY INCREASE WOB TO-15K. -MILL DOWN TO 9696'MD AND PKR COME Lj FREE. 22:30 - 23:00 0.50 FISH P DECOMP I BULLHEAD 75 BBLS OF SEAWATER. -PU ABOVE PKR AND SHUT-IN WELL. LINE UP TO PUMP DOWN KILL LINE AND DRILL STRING. -STAGE UP PUMPS TO 7 BPM. -7 BPM WITH 950 PSI PUMP PRESSURE AND 1910 PSI SICP. -8 BPM WITH 1010 PSI PUMP PRESSURE AND 1950 PSI SICP. -9 BPM WITH 1060 PSI PUMP PRESSURE AND 1010 PSI SICP. FCP AT 9 BPM WITH 1020 PSI PUMP I PRESSURE AND 980 PSI SICP. -MONITOR WELL FOR 10 MIN.WELL ON VAC. 23:00 - 23:30 0.50 FISH P DECOMP 1ATTEMPT TO CIRC BU.DYNAMIC LOSSES AT 120 BPH. I-LINE UP TO TAKE RETURNS THRU MGS.FILL 1 MGS. I ' -STAGE UP TO 5 BPM WITH 360 PSI AND (CATCH RETURNS. CIRC 5 BPM FOR 15 MIN(75 BBL PUMPED) AND LOSE 30 BBLS. -SHUT DOWN PUMPS AND MONITOR WELL 10 MIN-ON VAC. Printed 9/14/2015 10:11:33AM North America-ALASKA-S1,' 'te1 of 23 $ r Operation Summary Report 1 Common Well Name: 14-32 AFE No Event Type.WORKOVER(WO) Start Date:8/8/2015 End Date 8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00(g69.00usft(above Mean Sea Level) Date From-To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 ' FISH P DECOMP I PUSH PACKER DOWN TO 7"LINER TOP. -COME ONLINE WITH 60 RPM AND 2.5 BPM I DOWN DRILL STRING. -RIH AND TAG PACKER AT 9696'MD. -PUSH PACKER DOWNHOLE WITH 6-8K WOB. I I-TAG LINER TOP AT 9737'MD.SET DOWN 20K. PU AND RE-TAG AT 9737'MD.SET DOWN 20K TO CONFIRM PACKER DEPTH. 8/15/2015 00:00 - 01:00 1.00 FISH P DECOMP RU TO POOH ON 4"DRILL PIPE. -SERVICE IRON ROUGHNECK,DRAWWORKS, I AIR SLIPS. -MOITOR WELL:30 BPH STATIC LOSSES. + , 01.00 - 04:00 3.00 FISH P DECOMP IPJSMAND POOH WITH MILLING BHA 9737'- 1430'MD. I-STAND BACK 4"OP IN DERRICK. 1-MW IN/OUT=8.5 PPG. — t — -HOLE FILL ON.LOSSES AT 30 BPH. 04:00 - 05:00 1.00 FISH P I DECOMP PJSM AND LD MILLING ASSEMBLY. -FLOW CHECK 10 MIN BEFORE PULL NON I SHEARABLES THRU STACK -RACK BACK LAST STAND 4"DRILL PIPE. -LD INTENSIFIER AND PUMP OUT SUB. --RACK BACK 3 STANDS 6-1/4"DRILL COLLARS. I-PULL FISHING AND BUMPER JARS,BOOT BASKETS,AND MILLS OUT OF HOLE. -HOLE FILL ON.LOSSES AT 30 BPH. 05:00 - 06:30 1.50 FISH P DECOMP 1PJSMAND CLEAN OUT BOOT BASKETS. I-BREAK BOOT BASKETS OFF JARS.LD JARS. ' -CLEAN OUT BOOT BASKETS. -RECOVER-10 GAL SMALL METAL DEBRIS. -DEMOB BOOT BASKETS AND MILLS FROM RIG FLOOR. -HOLE FILL ON.LOSSES AT 30 BPH. 06 30 - 07:00 0.50 FISH P DECOMP 1SERVICE RIG HOISTING EQUIPMENT. -SERVICE TOP DRIVE,DRAWWORKS, I (BLOCKS. i-BLOW DOWN TOP DRIVE AND CHOKE/KILL LINES. I HOLE FILL ON.LOSSES AT 30 BPH. r 07:00 - 08:30 i 1.50 FISH I P I DECOMP I PJSM AND MU 4-1/16"ITCO SPEAR !ASSEMBLY. iI -PU BUMPER AND OIL JARS AND MU SEAR. -PU 3 STANDS 6-1/4"DC'S. I MU INTENSIFIER AND PUMP OUT SUB. -HOLEFILL ON.LOSSES AT 30 BPH. 08:30 12:00 3.50 FISH P DECOMP RIH WITH 4-1116"ITCO SPEAR ASSEMBLY 336' -6017'MD. ' ;-RIH ON STANDS FROM DERRICK -MW IN/OUT=8.5 PPG. -FILL PIPE AND BREAK CIRC EVERY 20 ;STANDS. -HOLE FILL ON.LOSSES AT 25 BPH. I***HOLD KICK WHILE TRIPPING COMPLEX , DRILL."** ; I-ADD MAN DOWN IN MOTOR ROOM. -ADD COMPLEXITY WITH LEAKING ANNULAR. Printed 9/14/2015 10.11 33AM • North America-ALASKA? /,':47'!,r/:/12.9f2/3 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) 12:00 - 12:30 0.50 FISH P DECOMP SERVICE PIPE HANDLING EQUIPMENT. -SERVICE TOP DRIVE,DRAWWORKS,IRON ROUGHNECK AND AIR SLIPS. -HOLE FILL ON.LOSSES AT 25 BPH. 12:30 - 14:30 2.00 FISH P DECOMP CONTINUE RIH WITH 4-1/16"ITCO SPEAR ASSEMBLY 6017'-9720'MD. -RIH ON STANDS FROM DERRICK MW IN/OUT=8.5 PPG. FILL PIPE AND BREAK CIRC EVERY 20 STANDS. -HOLE FILL ON.LOSSES AT 25 BPH. 14:30 - 15:30 1.00 FISH P DECOMP PJSM AND SPEAR PACKER. OBTAIN PARAMETERS BEFORE ENGAGING PACKER: -PU=220K,SO=165K,ROT=188K.TAKE SPR'S. i-WASH DOWN AT 4 BPM AND 330 PSI. ENGAGE PACKER AT 9737'MD. -SET DOWN 15K.PU 15K OVER AND VERIFY SPEAR SET. SET DOWN 15K.PU 25K OVER AND PULL FREE. -MONITOR WELL BEFORE POOH.STATIC LOSS RATE=20 BPH. 15:30 - 18:00 2.50 FISH P DECOMP PJSM AND POOH WITH SPEAR ASSEMBLY 9717'-8770'MD. -WORK FISH THRU CASING COLLARS FOR FIRST 10 STANDS. -WORK PIPE WITH 45K#DOWN AND 120K# OVERPULL. -BREAK CIRCULATION WITH 5 BPM AND 480 PSI. -PERFORM DERRICK INSPECTION AFTER JARRING OPERATIONS. -STAND BACK 4"DP IN DERRICK. -MW IN/OUT=8.5 PPG. -HOLE FILL ON.LOSSES AT 20 BPH. 18.00 - 23:00 5.00 FISH P DECOMP PJSM AND POOH WITH SPEAR ASSEMBLY 8770'-417'MD. -STAND BACK 4"DP IN DERRICK. -MW IN/OUT=8.5 PPG. -HOLE FILL ON.LOSSES AT 20 BPH. 23:00 - 00:00 1.00 FISH P DECOMP PJSM AND LD 4-1/16"ITCO SPEAR ASSEMBLY. -FLOW CHECK 10 MIN BEFORE PULL NON SHEARABLES THRU STACK -RACK BACK LAST STAND 4"DRILL PIPE. -LD INTENSIFIER AND PUMP OUT SUB. -LD 9X 6-1/4"DRILL COLLARS. -HOLE FILL ON.LOSSES AT 20 BPH. 8/16/2015 00:00 - 02:00 2.00 FISH P DECOMP CONTINUE LD 4-1/16"ITCO SPEAR I ASSEMBLY. LD 9X 6-1/4'DRILL COLLARS. LD FISHING AND BUMPER JARS. -RECOVER SPEAR AND FISH.PACKER BODY RECOVERED. -4-1/2"TAILPIPE NOT RECOVERED. -LD SPEAR AND PACKER BODY. -HOLE FILL ON.LOSSES AT 20 BPH. Printed 9/14/2015 10 11 33A II North America ALASKAP Page 13 of 23 Operation Summary Report Common Well Name.14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 I End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00(g69.00usft(above Mean Sea Level) Date i From-To Hrs Task I Code NPT NPT Depth Phase I Description of Operations (hr) (usft)02:00 - 03:30 1.50 FISH P DECOMP MOBILIZE FISHING TOOLS TO LOCATION. CALL AND NOTIFY ODE.DECIDE TO PU 3-1/4"ITCO SHOULDER TYPE SPEAR ASSEMLBY. -BAKER FISHING MOBILIZE 3-1/4"SPEAR AND 5-3/4"OVERSHOT TO LOCATION. -BRING FISHING TOOLS TO FLOOR. 03:30 - 05:00 1.50 FISH P DECOMP PJSM AND CLEAR RIG FLOOR OF FISHING TOOLS. -DEMOB 4-1/16"ITCO SPEAR AND FISH. -DEMOB 6-1/4"JARS AND TOOLS. MOB 3-1/4"ITCO SPEAR TO FLOOR. -MOB 4-3/4"FISHING AND BUMPER JARS TO FLOOR. 05:00 - 06:00 1.00 FISH P DECOMP I-MU 4-3/4"FISHING AND BUMPER JAR TO 3-1/4"ITCO SPEAR. WSL VERIFY GRAPPLE SIZE NOMINAL 3.946". -MU PUMP OUT SUB. -MU 4-3/4"DRILL COLLARS. 06 00 - 11:00 5.00 FISH P DECOMP RIH WITH 3-1/5"ITCO SPEAR ASSEMBLY 209'- 10,377'MD. -RIH ON STANDS FROM DERRICK. -MW IN/OUT=8.5 PPG. I-FILL PIPE AND BREAK CIRC EVERY 20 STANDS. TAG UP ON TUBING AT 10,377'MD. -HOLE FILL ON.LOSSES AT 20 BPH. 11.00 12:00 1.00 FISH P DECOMP PJSM AND SPEAR TUBING TAIL. !-OBTAIN PARAMETERS BEFORE ENGAGING PACKER: -PU=207K,SO=167K,ROT=188K.TAKE SPR'S. WASH DOWN AT 3.5 BPM AND 500 PSI. ENGAGE TUBING AT 10,377'MD. -SET DOWN 5K PUMP PRESS INCREASE TO 610 PSI. -PU 25K OVER AND VERIFY SPEAR SET. -SET DOWN 10K.PU 40K OVER WITH PUMP AT 3.5 BPM AND PULL FREE. MONITOR WELL BEFORE POOH.STATIC LOSS RATE=15 BPH. 12:00 - 12:30 0.50 FISH P DECOMP PJSM AND SERVICE RIG. -LUBRICATE AND INSPECT DRAWWORKS AND IRON ROUGHNECK. -HOLE FILL ON.LOSSES AT 15 BPH. 12:30 - 18:00 5.50 FISH P DECOMP PJSM AND POOH WITH SPEAR ASSEMBLY 10,270'-304'MD. STAND BACK 4"DP IN DERRICK. i-MW IN/OUT=8.5 PPG. -HOLE FILL ON.LOSSES AT 15 BPH. Printed 9/14/2015 10.11.33AM • North America-ALASKA-BP Pa - la of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) I Start Date:8/8/2015 End Date:8/24/2015 !X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:OOAM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code 1 NPT NPT Depth Phase I Description of Operations (hr) (usft) 18:00 - 20:30 2.50 FISH P I DECOMP PJSM AND LD 3-1/4"ITCO SPEAR ASSEMBLY. -FLOW CHECK 10 MIN BEFORE PULL NON SHEARABLES THRU STACK. -RACK BACK LAST STAND 4"DRILL PIPE. -RACK BACK 2 STANDS 4-3/4"DRILL COLLARS. -LD FISHING AND BUMPER JARS. RECOVER SPEAR,2 FULL JTS,12FT PUP JT. -SHEAR-OUT BULLNOSE NOT RECOVERED. -NOTIFY ODE AND AGREE TO CLEANOUT RUN AS PER WELLPLAN. I -LD SPEAR AND TUBING. -HOLE FILL ON.LOSSES AT 15 BPH. 20:30 - 22:00 1.50 FISH 1DECOMP CLEAN AND CLEAR RIG FLOOR. I-DEMOB FISHING TOOLS AND TUBING. -RD POWER TONGS AND DEMOB SAME. -CLEAN FLOOR. HOLE FILL ON.LOSSES AT 15 BPH 22.00 - 00:00 2.00 WHSUR P DECOMP 1PJSM AND PULL WEAR RING. -FLUSH STACK AT 10 BPM FOR 10 MIN. -EMPTY STACK AND SEE CONTROL LINE IN UPR CAVITIES. -CLOSE BLIND RAMS WITH AIR PUMP ONLY. CLEAR OF DEBRIS. -FISH CONTROL LINE WITH RIG VAC. -CLOSE UPR WITH AIR PUMP ONLY.CLEAR OF DEBRIS. -CAMERON REP BOLDS AND TORQUE ALL GLAND NUTS TO SPEC. —�- PULL WEAR RING.INSTALL TEST PLUG. 8/17/2015 100:00 - 02:00 2.00 BOPSUR P DECOMP RU TO TEST BOPE. -CLOSE LPR WITH AIR PUMP ONLY TO ENSURE CLEAR OF DEBRIS. -RIG UP BOPE TEST EQUIPMENT. ! LINE UP TO FILL DOWN IA.STATIC LOSSES IAT 15 BPH. 1-FILL STACK. Printed 9/14/2015 10:11:33AM North America-ALASKA BP ,Page15 of 23 Operation Summary Report '' Common Well Name 14-32 AFE No Event Type WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011FM-E (3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 Qj69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 02:00 - 08:00 6.00 BOPSUR P DECOMP I STATE GIVEN NOTIFICATION OF BOPE TEST 108/15/2015 12:30. STATE INSPECTOR JEFF JONES WAIVE I WITNESS 08/15/2015 21:00. IPRESSURE TEST ALL BOP EQUIPMENT. -TEST BOPE TO 250/3500 PSI FOR 5/5 ICHARTED MIN. -TEST BLOWOUT PREVENTERS AND ALL ASSOCIATED BOPE. -LOWER 3-1/2"X 6"VBR'S TESTED WITH 4" AND 5-1/2"TEST JOINTS. -UPPER 2-7/8"X 5"VBR'S TESTED WITH 4" AND 4-1/2"TEST JOINTS. -ANNULAR TESTED WITH 4"TEST JOINT. -BLIND/SHEAR RAMS TESTED -TEST CHOKE MANIFOLD VALVES,CHOKE I AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES. -TEST MANUAL AND HYDRAULIC(BOP'S ON TOP DRIVE. -TEST FLOOR AND DART VALVES. -PERFORM DRAW DOWN TEST OF ACCUMULATOR. --FUNCTION BOPE FROM REMOTE PANEL AND MAIN UNIT. -TEST GAS ALARMS. -ALL TESTS WITNESSED BY TOOLPUSHER AND WSL. -WSL PERFORM PRESSURE CROSSCHECK CHECKLIST PRIOR TO SHELL TEST. -NO FAILURES FILL DOWN IAAT 15 BPH WITH CHARGE PUMP. 08:00 - 08:30 0.50 BOPSUR P DECOMP 1RD BOPE TEST EQUIPMENT. -RIG DOWN TEST MANIFOLD. -PULL TEST PLUG. 08:30 - 09:00 0.50 WHSUR P DECOMP PJSM AND INSTALL WEAR RING. -WEAR RING ID=8-15/16". -CAMERON REP RILDS. 09:00 - 10:00 1.00 FISH P DECOMP RU FOR CLEANOUT RUN. BLOW DOWN TOP DRIVE,CHOKE/KILL LINES. MU SAFETY JOINT.TEST GAS ALARMS. -PERFORM DERRICK INSPECTION. -HOLE FILL ON.LOSSES AT 15 BPH. 10:00 - 12:00 2.00 FISH P DECOMP ';PJSM AND MU CLEANOUT ASSEMLBY. -BRING BAKER TOOLS TO RIG FLOOR. -MU JUNK MILL,BOOT BASKETS,STRING MILL,STRING MAGENTS. -MU JARS AND X-OVER TO 4"DRILL PIPE. -HOLE FILL ON.LOSSES AT 15 BPH. 12:00 - 13:30 1.50 FISH P DECOMP PJSM AND RIH WITH CLEANOUT ASSEMBLY '260'-1586'MD. -RIH ON STANDS FROM DERRICK. -MU 9-5/8"CASING SCRAPER AFTER 6 STANDS. -MW IN/OUT=8.5 PPG. -HOLE FILL ON.LOSSES AT 15 BPH. Printed 9/14/2015 10:11.33AM North America-ALASKA-BP Page 16 of 23 Operation Summary Report Common Well Name.14-32 AFE No Event Type WORKOVER(WO) I Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 16:30 3.00 WHSUR N SFAL DECOMP MOBILZE EQUIPMENT TO REPLACE INSIDE IA VALVE. -WHILE RIH,FIND INSIDE IA VALVE LEAKING OUT VALVE STEM. CALL AND NOTIFY ODE,BP SUPERINTENDENT AND WTL. OBTAIN LEVEL 2 OCN TO SET RTTS AND REPLACE IA VALVE. I-MOBILIZE RTTS AND REPLACEMENT IA VALVE TO LOCATION. -HOLE FILL ON.LOSSES AT 15 BPH. 16 30 - 19:00 2.50 WHSUR N SFAL DECOMP PJSM AND SET RTTS. -TAKE PARAMETERS:PU=80K/So=82K WITH BLOCKS. PU RTTS AND MU TO DRILL PIPE. -RIH 90'DOWN AND SET RTTS AS PER HALLIBURTON REP. -TEST RTTS TO 250/3500 PSI FOR 5/5 MIN. -FILL DOWN DRILL PIPE THRU RTTS.LOSSES 15 BPH. 19 00 19:30 0.50 WHSUR N SFAL DECOMP PJSM AND INSTALL NEW INSIDE IA VALVE. -BREAK OFF OLD OUTSIDE AND INSIDE IA VALVE. INSTALL NEW INSIDE IA VALVE. i-RE-INSTALL OLD OUTSIDE IA VALVE. -VALVE SHOP TORQUE ALL FLANGES TO ,SPEC. FILL DOWN DRILL PIPE THRU RTTS.LOSSES 15 BPH. 19:30 - 21:30 2.00 WHSUR N -- SFAL DECOMP PJSM AND TEST IA VALVES. -TEST INNER IA VALVE TO 250/3500 FOR 5/5 MIN-GOOD TEST. -TEST OUTER IA VALVE TO 250/3500 FOR 5/5 MIN-FAIL. -OUTER IA VALVE LEAKING THRU VALVE. -NOTIFY SUPERINTENDENT.AGREE TO REPLACE VALVE. -FILL DOWN DRILL PIPE THRU RTTS.LOSSES 115 BPH. 21:30 - 22:30 1.00 WHSUR N SFAL DECOMP MOBILIZE VALVE SHOP PERSONNEL AND NEW VALVE TO LOCATION. -FILL DOWN DRILL PIPE THRU RTTS.LOSSES '15 BPH. 22:30 - 23:00 0.50 WHSUR N SFAL DECOMP REPLACE OUTER IA VALVE. -REMOVE OLD OUTSIDE IA VALVE. -INSTALL NEW OUTSIDE IA VALVE. -FILL DOWN DRILL PIPE THRU RTTS.LOSSES 15 BPH. 23:00 - 00:00 1.00 WHSUR N SFAL DECOMP PJSM AND TEST OUTSIDE IA VALVE. -TEST OUTER IA VALVE TO 250/3500 FOR 5/5 MIN-GOOD TEST. -RD PRESSURE TESTING EQUIPMENT. -FILL DOWN DRILL PIPE THRU RTTS.LOSSES 115 BPH. 8/18/2015 00:00 - 01:00 1.00 WHSUR N SFAL DECOMP PJSM AND PULL RTTS. RACK BACK 1 STAND. -LD RTTS AND DEMOB FROM RIG FLOOR. 01:00 - 01:30 0.50 WHSUR P DECOMP MONITOR WELLBORE. -LINE UP HOLE FILL. TAKE STATIC LOSS RATE:12 BPH. Printed 9/14/2015 10:11 33AM • . North America-ALASKA-BP Page 17 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) j Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 I Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) ! Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations — (hr) 1 (usft) 01:30 - 04:30 3.00 WHSUR P DECOMP PJSM AND RIH WITH CLEANOUT ASSEMBLY I1586'-9750'MD. -RIH ON STANDS FROM DERRICK. -MW IN/OUT=8.5 PPG. -FILL PIPE AND BREAK CIRCULATION AT 50 STANDS. -LOSSES 15 BPH. 04:30 - 07:00 2.50 WHSUR P DECOMP 'I'PJSM AND SLIP-N-CUT DRILL LINE. '-HANG BLOCKS.SLIN-N-CUT 50'OF DRILL LINE. I [-CALLIBRATE BLOCK HEIGHT.CHECK I CROWN-O-MATIC. SERVICE TOP DRIVE,BLOCKS,AND DRAWWORKS. 07:00 - 08:00 1.00 WHSUR P DECOMP PJSM AND RIH WITH CLEANOUT ASSEMBLY 9750'-10319' -RUN SCRAPER PAST 9350'AND 9500',30' EITHER SIDE OF EACH 5 TIMES 08:00 - 09:30 1.50 WHSUR P DECOMP WASH DOWN 10319-10507' -TAGGED AT 10450'MILLED JUNK 10450'- 10507' -TORQUE=5-12K,ROT 80-110 RPM,WOB= 1-5K 09:30 - 14:30 5.00 WHSUR P DECOMP .CIRCULATE HOLE CLEAN. -PUMP 30 BBL HIGH VIS SWEEP AT 8 BPM I I 1 I AND 1610 PSI SURFACE TO SURFACE -OBTAIN SPRS -PUMP 30 BBL HIGH VIS PILLAND SPOT ON BOTTOM 14:30 - 20:00 5.50 WHSUR P DECOMP PJSM,POH FROM 10507'TO 353' I I -DROP 2.0"DRIFT AT 9750'. -FLOWCHECK WELL PRIOR TO PULLILNG NON SHEARABLES INTO STACK-GOOD 20:00 - 22:30 2.50 WHSUR P DECOMP !PJSM,LAY DOWN BHA RETRIEVE 2.0"DRIFT FROM FIRST COLLAR STRING MAGNETS RETURNED 1.5 GALLONS OF METAL SHAVINGS -BOOT BASKETS CONTAINED 1.5 GALLONS 110F METAL SHAVINGS,SMALL METAL DEBRIS AND SMALL STONES 1 1 -CLEAN AND CLEAR RIG FLOOR,REMVOVE 1 BHA FROM RIG 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM,RIG UP TO RUN SCAB LINER REMOVE WEAR BUSHING 1 � RIG UP LINE TO FILL PIPE. 8/19/2015 00:00 - 01:30 1.50 RUNCOM P RUNCMP FINISH RIGGING UP SCAB LINER RUNNING EQUIPMENT. HOLD PJSM FOR RUNNING SCAB LINER 101:30 - 02:00 I 0.50 RUNCOM P , RUNCMP PU 4 1/2"SHOE TRACK -RUN IN SHOE TRACK AND 1 JOINT,TEST FLOATS-GOOD TEST 02:00 - 05:00 ! 3.00 RUNCOM P RUNCMP I RUN 4-1/2"12.6#13Cr-85 VAM TOP SCAB I LINER I -FILL EVERY 5 JOINTS MU LINER HANGER/LINER TOP PACKER I- MIX UP ZANPLEX-D AND POUR INTO TIE BACK SLEEVE -RIH WITH LINER ON DRILL PIPE 05:00 - 06:00 1.00 RUNCOM P RUNCMP DEMOB DOUBLE STACK TONGS FROM RIG FLOOR Printed 9/14/2015 10:11:33AM • • North America-ALASKA-BP Page 18 of 23 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:OOAM Rig Release:8/24/2015 Rig Contractor DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 15:00 9.00 RUNCOM P RUNCMP PJSM,CONTINUE TO RUN SCAB LINER ON DRILL PIPE FROM DERRICK FROM 1035'TO 8631' -RUNNING SPEED 90 SECONDS PER STAND -FILL PIPE EVERY 10 STANDS PASS THROUGH 7"LINER TOP WITH NO PROBLEM -PU WT=210K,S/O WT=155K AT 10435' -SET DOWN 4K AT 10450',MU TOP DRIVE AND WASH DOWN TO 10507'AT 4 BPM AND 240 PSI OBTAIN SPRS 15:00 - 18:30 3.50 RUNCOM P RUNCMP LAND LINER AND PREPARE TO CEMENT -CIRCULATE BOTTOMS UP AT 6 BPM,ICP= 510 PSI,FCP=430 PSI SPACE OUT DRILL PIPE,INSTALL PUP JOINT AND ROTATING CEMENT HEAD -CIRCULATED DOWN AT 3 BPM AND 140 PSI, TAG BOTTOM,SET DOWN 10K,PU TO NEUTRAL WEIGHT PLUS TWO FEET AND PARK LINER FOR CEMENT JOB AT 10505' 18:30 - 21:00 2.50 RUNCOM P RUNCMP CEMENT 4-1/2"12.6#13CR SCAB LINER AS FOLLOWS: FILL LINES WITH WATER AND PRESSURE TEST TO 250 PSI LOW FOR 5 MINS/4500 PSI HIGH FOR 5 MINS-GOOD TEST -PUMP 5 BBLS FRESH WATER SPACER -PUMP 38 BBLS OF 15.8 PPG GLASS G CEMENT AT 5 BPM,EXCESS VOLUME 11.5 BBLS -FLUSH LINES WITH 10 BBLS SEAWATER LAUNCH DRILL PIPE/LINER WIPE DART -DISPLACE CEMENT USING SEAWATER WITH SCHLUMBERGER PUMPS -93 BBLS DISPLACED AT 5 BPM,ICP=800 PSI,FCP=450 PSI -15 BBLS DISPLACED AT 3 BPM,ICP=490 PIS,FCP=570 PSI -LATCH UP CONFIRMED AT 98.5 BBLS AWAY AND 1700 PSI -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP,FCP=633 PSI -BUMP PLUG,1600 PSI -CEMENT IN PLACE AT 20:35 -TOTAL DISPLACEMENT VOLUME=113.3 BBLS -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE=0 BBLS Printed 9/14/2015 10:11:33AM • North America-ALASKA,-E.3P r 4Pale 19 of 23 Operation Summary Report Common Well Name 14-32 AFE No Event Type.WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 RUNCOM P RUNCMP SET LINER HANGER AND LINER TOP PACKER AS FOLLOWS: I-INCREASE PRESSURE TO 2500 PSI TO SET HANGER AFTER PLUG BUMP -SET DOWN 80K ON HANGER TO CONFIRM SET -STAGE UP DP PRESSURE WITH RIG PUMPS TO 3000 PSI,3400 PSI,THEN 4000 PSI. GOOD INDICATION OF LINER TOP PACKER SET AT 3300 PSI. -CHECK FLOATS-GOOD,1.5 BBLS RETURED 'THEN NO FLOW OBSERVED ROTATE AND RELEASE FROM RUNNING TOOL INCREASE DP PRESSURE TO 500 PSI AND PU UNTIL DOGS ARE EXPOSED,INCREASE RATE TO 2 BPM -SET DOWN ON DOGS 60K,CONFIRM PACKER IS SET PU TO NEUTRAL,SET BACK DOWN 10K AND ROTATE INTO DOG SUB INCREASE PUMP RATE TO 8 BPM t-PU OUT OF ZXP PACKER BORE WITH -SETTING TOOL 35' _-CIRCULATE BOTTOMS UP TO PITS WHILE RECIPROCATING PIPE 20' -CEMENT RETURNS OBSERVED,DIVERT TO ROCK WASHER,RETURN 65 BBLS OF CEMENT AND SEAWATER -CONFIRM CLEAN RETURNS AND DIVERT BACK TO PITS -SHUTDOWN PUMPS,FLOWCHECK WELL FOR 10 MINS-GOOD -RIG DOWN CEMENT HEAD AND PUP JOINT -CIRCULATE 1 MORE BOTTOMS UP WHILE RECIPROCATING 90'AT 15 BPM AND 2050 PSI, NO CEMENT RETURNS OBSERVED 8/20/2015 00:00 - 00:30 0.50 RUNCOM P 10,505.00 RUNCMP RIG UP FOR CASING PRESSURE TEST 00:30 - 01:30 1.00 RUNCOM P 10,505.00 RUNCMP PJSM,PRESSURE TEST 9-5/8"CASING X 4-1/2"SCAB LINER 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH- C GOOD TEST -TOOK 8.8 BBLS TO REACH TEST PRESSURE, 8.0 BBLS BLED BACK 01:30 - 06:00 4.50 RUNCOM P 10,505.00 RUNCMP PJSM,POH LAYING DOWN DRILL PIPE SINGLES TO THE PIPE SHED FROM 9707'TO 3015'. PICKUP HES RTTS. 06:00 - 07:00 1.00 RUNCOM P 10,505.00 RUNCMP RIH WITH RTTS ON ONE STAND OF DRILLPIPE PUW=92K -1/4 TURN RIGHT TO ENGAGE SLIPS,SLACK OFF TO SET BACK OUT STAND 21 TURNS AND RACK BACK 07:00 - 07:30 0.50 RUNCOM P I 10,505.00 RUNCMP 'PJSM,PRESSURE TEST ABOVE RTTS -250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-GOOD TEST 07:30 - 08:00 0.50 RUNCOM P 10,505.00 RUNCMP PJSM,SUCK OUT STACK,BLOW DOWN CHOKE AND KILL LINES,HELD SPILL DRILL. Printed 9/14/2015 10:11:33AM ® • North America-ALASKA-BP Page 20 of 23 IIIIUIIIIIIIIIPIIPt1I1J ; Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) I Start Date:8/8/2015 End Date:8/24/2015X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay ' Site:PB DS 14 Rig Name/No.:DOYON 14 I Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. U M:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) 1 08:00 - 12:00 4.00 RUNCOM P 10,505.00 RUNCMP PJSM,ND STACK,CLEAN AREA,REMOVE I RISER,TURNBUCKLES,KILLAND CHOKE LINES. MONITORING OA PRESSURE _ 12:00 - 23:30 11.50 RUNCOM P 10,505.00 RUNCMP CAMERON REPLACE TUBING SPOOLAND 9-5/8"IC PACKOFF BLEED CASING HANGER VOID TO ZERO, VERIFY 0 PSI ON OA F-ND GEN III TUBING SPOOL ' -MU PACKOFF PULLING TOOL,MU TO PACKOFF AND PULL-CAME FREE AT 10K -PULL PACKOFF TO RIG FLOOR,CLEAN AND INSPECT HANGER NECK AND RING GROOVE -INSTALL NEW BX-160 AND INSTALL NEW STAPOF RILDSNDARD TORQUEACKTO F450 FT-LBS,GLAND NUTS TO 500 FT-LBS -NU GRAY NEW STANDARD TUBING SPOOL AND TORQUE TO 2000 FT-LBS -PPPOT-IC 250 PSI LOW/3500 PSI HIGH FOR 1 30 CHARTED MINUTES-GOOD TEST -BLEED IC VOID TO ZERO 23:30 - 00:00 0.50 RUNCOM 'P 10,505.00 RUNCMP PJSM,RIG UP TO TEST BREAKS ON STACK IA PIGGY BACK VALVE,AND KILL LINE. 8/21/2015 00:00 - 00:30 0.50 ._ RUNCOM P RUNCMP ,RIG DOWN TEST EQUIPMENT,PREPARE TO LAY DOWN RTTS 00:30 - 01:00 0.50 - RUNCOM P RUNCMP PJSM,BLOW DOWN CHOKE AND KILL LINES 01:00 - 02:00 1.00 RUNCOM P RUNCMP PJSM,PULL HES RTTS TOOL -MU HES RTTS RUNNING TOOL,RIH ON 1 G STAND OF DP -ATTEMPT TO SCREW INTO RTTS BUT APPEARS TO BE DEBRIS ON TOP 1 I -OPEN FOSV CIRC ON TOP OF RTTS AT 4 1 BPM,10 PSI FOR 10 MINS I-SCREW INTO RTTS 21TURNS I-CLOSE ANNULAR I-PU 1'AND ALLOW ELEMENTS TO RELAX -CHECK FOR PRESSURE IN DP AND BELOW ,BAG-0 PSI I-OPEN ANNULAR,PULL RTTS TO FLOOR, I I I RACK BACK STAND AND LD RTTS 02:00 - 02:30 0.50 RUNCOM i P RUNCMP PJSM.RIH WITH DP FROM DERRICK 02:30 - 06:00 3.50 ' RUNCOM 11 P RUNCMP PJSM,LAY DOWN DRILL PIPE FROM 3797'IN SINGLES TO THE PIPE SHED UP TO LINER RUNNING TOOL 06:00 - 06:30 0.50 RUNCOM P RUNCMP PJSM,BREAK DOWN BAKER LINER RUNNING TOOLS AND LAY DOWN TO PIPE SHED -CLEAR PIPE SHED OF DRILL PIPE AND I BAKER TOOLS 06:30 - 10:00 1 3.50 RUNCOM I P RUNCMP 1PJSM,PREP FOR 5-1/2"COMPLETION RUN I !-PULL WEAR RING CHANGE ELEVATORS,PICK UP 1 JNT DP, STACK WASHER AND FLUSH STACK WITH BLACK WATER PILLAT 15 BPM,FUNCTION i ALL RAMS 10:00 13:30 ' 3.50 RUNCOM I P I RUNCMP INSTALL MOUSE HOLE,MU SAFETY JOINT I FOR 5-1/2"VAMTOP COMPLETION,MOBILIZE ICASING HANDLING EQUIPMENT TO RIG __ FLOOR 13:30 - 18:00 4.50 RUNCOM f N RREP± RUNCMP TROUBLESHOOT AND REPAIR OFF DRILLER'S SIDE PIPE SKATE ELEVATOR Printed 9/14/2015 10:11:33AM • • North America-ALASKA-BP Page 21 of 23 Operation Summary Report Common Well Name.14-32 AFE No Event Type WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 1 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM !Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 00:00 6.00 RUNCOM P RUNCMP PJSM,PU AND RUN 5-1/2"17#13 CR-80 VAMTOP COMPLETION AT 90 FPM PER HES REP -ALL CONNECTIONS BELOW PACKER BAKER LOC'D -STABBING GUIDE USED FOR ALL CONNECTIONS TORQUE TURN SERVICES UTILIZED FOR EACH CONNECTION-OPTIMAL MAKE UP TORQUE=6580 FT-LBS -ALL PINS HAND STARTED JET LUBE SEAL GUARD USED ON ALL CONNECTIONS 8/22/2015 00:00 - 06:00 6.00 RUNCOM P RUNCMP !RUN 5-1/2 17#13 CR-80 VAMTOP !COMPLETION AT 90 FPM PER TALLY TO 5200' 06:00 - 07:00 1.00 RUNCOM P RUNCMP I PERFORM KICK WHILE DRILLING DRILL WITH 1AAR 07:00 - 10:00 3.00 RUNCOM N RREP RUNCMP TROUBLESHOOT GAS ALARM ON RIG FLOOR, REPLACE SENSOR AND HEAD UNIT. USE A PORTABLE GAS MONITOR DURING CALIBRATION. 10:00 - 15:00 5.00 RUNCOM P RUNCMP j PJSM,CONTINUE RUNNING 5-1/2"17#13 CR-80 VAMTOP COMPLETION TO 7702' 15:00 - 16:30 1.50" RUNCOM P RUNCMP HOLD GAS IN PITS DRILL W/RIG EVAC AND AAR 16:30 - 19:00 2.50 RUNCOM P RUNCMP PJSM,CONTINUE RUNNING 5-1/2"17#13 CR-80 VAMTOP COMPLETION 19:00 - 00:00 5.00 RUNCOM P RUNCMP PJSM,SPACE OUT AND LAND COMPLETION 1-PUW=205K,SOWr=155K -SET DOWN 5K ON LINER TOP TWICE, ROTATE TUBING 1/2 TURN,ENTER LINER TOP -CONTINUE TO RIH,SET DOWN 5K TWICE AT 9511' -CALCULATE SPACEOUT -PICK UP PUPS A,B,AND D -MU JOINT 222 ON TOP OF PUPS AND MAKE UP HANGER -LAND HANGER 8/23/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM,CAMERON RUN IN AND TORQUE LOCK DOWN SCREWS,500 FT-LBS ON GLAND NUTS,450 FT-LBS ON LDS 00:30 - 02:30 2.00 RUNCOM P RUNCMP PJSM,RIG UP TO REVERSE CIRCULATE 02:30 - 03:30 1.00 RUNCOM P RUNCMP PJSM,CIRCULATE IN 230 BBLS 120 DEGREE SEAWATER AT 5 BPM AND 700 PSI DOWN THE INNER ANNULUS TAKING RETURNS TO THE PITS.1 FOR 1 RETURNS. 03:30 - 03:45 0.25 RUNCOM P RUNCMP SWAP TRUCKS FOR CORROSION INHIBITED SEAWATER. 03:45 - 05:15 1.50 RUNCOM P RUNCMP CIRCULATE IN 410 BBLS CORROSION !INHIBITTED 120 DEGREE SEAWATER AT 5 BPM AND 700 PSI DOWN THE INNER ANNULUS TAKING RETURNS TO THE PITS.1 _ !FOR 1 RETURNS. 05:15 - 06:00 0.75 RUNCOM P RUNCMP I BLOW DOWN LINES,RIG UP TO SET PACKER. Printed 9/14/2015 10:11:33AM • • North America-ALASKA-BP Page 22 of 23 Operation Summary Report � � , Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date.8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM I Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00 @69.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) i I— I - 10:00 4.00 RUNCOM P I RUNCMP PJSM,SET HES 9-5/8"X 5-1/2"TNT PACKER I PUMP 5 BBLS OF SEAWATER DOWN TUBING TO CLEAR RHCM SEAT INSTALL LANDING JOINT AND DROP 1-7/8" BALLAND ROD,ALLOW TO FALL FOR 10 MINS -PRESSURE TEST TUBING 250 PSI LOW/ 13700 PSI HIGH FOR 30 CHARTED MINUTES '-SEE INDICATION OF PACKER SET AT 2200 1 PSI ON TUBING -PRESSURE TEST INNER ANNULUS 250 PSI LOW/3700 PSI HIGH FOR 30 CHARTED I IMINUTES i ' 1 -DISCUSS PRESSURE TEST RESULTS WITH I WTL -BLEED PRESSURE OFF TUBING AND SHEAR DCR VALVE. PUMP 5 BBLS DOWN TUBING AT I 3 BPM AND 250 PSI AND 5 BBLS DOWN INNER ANNULUS AT 3 BPM AND 430 PSI TO VERIFY SHEAR 10.00 - 12:00 2.00 RUNCOM P I RUNCMP I P,ISM,RIG UP CHOKE SKID FOR FREEZE 1 ,PROTECTION,PT LINES 250 PSI LOW/3500 PSI HIGH 12:00 - 16:00 4.00 RUNCOM. I P RUNCMP .PJSM,FREEZE PROTECT WELL TEST LRS LINES 250 PSI LOW/4000 PSI HIGH FOR 5 MINS -REVERSED CIRCULATE 165 BBLS OF DIESEL DOWN INNER ANNULUS AT 5 BPM AND 500 I PSI -U-TUBE DIESEL TO TUBING THROUGH f I JUMPER LINE FOR 1 HOUR I -MONITOR WELL-NO PRESSURE BUILD UP ,-DRAIN LINES BACK TO LRS,RIG DOWN U-TUBE LINES 16:00 - 22:30 6.50 RUNCOM P RUNCMP PJSM,INSTALLAND TEST TWC -DRAIN WATER FROM STACK,REMOVE LANDING JOINT AND INSTALL DUTCH RISER -BRING VALVE SHOP LUBRICATOR TO RIG FLOOR AND INSTALL ON DUTCH RISER -PRESSURE TEST LUBRICATOR 250 PSI LOW I /3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-GOOD TEST INSTALL TWC WITH LUBRICATOR -PRESSURE TEST TWC FROM BELOW 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES-GOOD TEST -RIG DOWN LUBRICATOR,DUTCH RISER, AND LRS 22:30 - 00:00 1.50 RUNCOM P RUNCMP PJSM,BEGIN NIPPLING DOWN BOPS -BLOW DOWN CHOKE,KILL,HOLE FILL,AND BLEEDER LINES NIPPLE DOWN EQUIPMENT FROM RIG 1 i FLOOR WORKING TO CELLAR 8/24/2015 00:00 - 01:00 1.00 RUNCOM P -rRUNCMP 1,PJSM,BLOW DOWN CHOKE SKID AND INJECTION LINE,PERFORM HOUSEKEEPING I 'IN CELLAR,REMOVE HOSES AND OTHER TRIP HAZARDS FROM CELLAR PRIOR TO CHANGING RAMS Printed 9/14/2015 10:11 33AM • • North America ALASKA BP Page 23 of 23 • •, � / 6 Operation Summary Report Common Well Name:14-32 AFE No Event Type:WORKOVER(WO) Start Date:8/8/2015 End Date:8/24/2015 X4-011 FM-E:(3,450,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:8/5/1983 12:00:00AM Rig Release:8/24/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292099900 Active datum:54:32 8/5/1983 00:00©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 01:00 - 06:00 5.00 RUNCOM P RUNCMP PJSM,CHANGE OUT RAMS -CHANGE OUT TOP RAMS TO SOLID BODY 9-5/8"RAMS. CEMENT FOUND BEHIND TOP 2-7/8"X 5"RAMS WHEN CHANGING OUT. CLEAN OUT CEMENT,FUNCTION TEST. -CHECK SHEARS RAMS,CEMENT FOUND BEHIND SHEAR RAMS,CLEAN OUT CEMENT. FUNCTION TEST GOOD CHECK BOTTOM RAMS FOR CEMENT 06:00 - 07:30 1.50 RUNCOM P RUNCMP I REMOVE CEMENT FROM LOWER RAMS. TOTAL CEMENT REMOVED FROM ALL RAMS -4.GALLON 07:30 - 09:00 1.50 RUNCOM P RUNCMP PJSM,NIPPLE DOWN BOP STACK 09:00 - 12:00 3.00 RUNCOM P RUNCMP PJSM,NIPPLE UP ADAPTER FLANGE -PPPOT-T 250 PSI LOW,5000 PSI HIGH FOR 30 CHARTED MINUTES-GOOD TEST 12:00 - 14:30 2.50 RUNCOM P RUNCMP PJSM,NIPPLE UP DRY HOLE TREE -PT WITH DIESEL 250 PSI LOW,5000 PSI HIGH FOR 5 MINUTES EACH,VISUAL LEAK TIGHT TEST GOOD. ***RIG RELEASED AT 14:30*** Printed 9/14/2015 10:11:33AM • • 14-32, Well History (Post-Rig Sidetrack) 014504 01%514;41.11067,10ZWIMM00-0V7 0000 T/I/0=TWC/0/0 Removed 2" FMC Piggy back(2nd IA)temp valve#73 and installed tapped blind flange; Removed 3" CIW Piggy back (2nd OA)temp valve#18 and installed tapped blind flange; Removed 6" CIW Temp SV#55 (dry hole tree) & Installed upper tree and torqued to API spec.; PT Tree connection against 6"CIW TWC to 300 psi-low& 5000 psi-high (passed); Pulled 6"TWC#423 8/25/2015 @ 135" ***FWP= 0/0/0. T/I/O = 0/0/0. Set 3"VR Plug. C/O 3" Gray OA GV W/3" CIW. Torqued and PT'd to API specs. (PASSED). Pulled VR Plug. Installed Blind Torqued and PT'd to API specs. (PASSED). RDMO. Final 8/26/2015 W H P's = 0/0/0. 8/27/2015 PULL B&R FROM 9,409' SLM. STBY DUE TO HIGH WINDS. PULL RK-DGLV FROM ST#5 @ 5,613' SLM/5,625' MD. PULL RK- DGLV FROM ST#6 @ 3,485' SLM/3,499' MD. SET RK-LGLV IN ST#6 @ 3,485' SLM/3,499' MD. 8/28/2015 SET RK-OGLV IN ST#5 @ 5,613' SLM/5,625' MD. PULL 5-1/2" RHC BODY FROM 9,415' SLM/9,434' MD. DRIFT W/20'x3-3/8" DUMMY GUN, S/D HIGH @ 10,156' SLM. RAN 10'x3" PUMP BAILER DOWN TO 10,432' SLM. (recovered chunks of cement). DRIFT w/20'x3-3/8" DUMMY GUN, S/D @ 10,446' SLM. RAN PDS GR/CCL. LOGGED 8/29/2015 FROM 10,446' SLM TO SURFACE. (good data). INITIAL T/I/O = 500/50/0. RIH W/ ELINE & 10'X 3-3/8" GUN - PERFORATED INTERVAL @ 10,385' - 10,395' (3-3/8" POWER JET HMX GUN). RIH 13'X 3-3/8" GUN & PERFORATED INTERVAL @ 10,364' - 10,377' (3-3/8" POWER JET HMX GUN). TIED INTO HES RESERVOIR MONITORING LOG DATED 26-APRIL-2014 & PDS JEWELRY LOG DATED 29-APRIL-2015 FINIAL T/I/O = 50/50/0. 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(h In N H W co W H i O O z O Z a coLo 0 � z g o > W co w EE m 7 H z 2 o 0 Na CV aTOO W2a coO oE m Zpw U W a maOZ 8 o >- g gwOO F- Z NiO � us 5 2 a ° j c a 0. O o W -I H E N a EiO H m )n jaw - -' E'o ' c ' 0 H H a` 0 a W 0I:.D am0HH TREE= ClVU • 14-32 4_32 NOTES:CHROME TBG 8+LNR WELLHEAD= GRAY GENS ACTUATOR= BAKER C OKB.ELEV= 69' BF.ELEV= KOP= 3200' ' ' 2207' —5-1/2"HES X NP,ID=4. Max Angle= 47"@ 6913' Datum MD= 10392' Datum TVD= 8800'SS 20"CONDUCTOR,91.5#,H-40,13=19.124" 110' ' GAS LFT MANDRELSj ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8'CSG,72#,L-80,D=12.347" H 2493' I 6 3499 3485 18 MAG DOME RK 16 08/28/15 ..___d5 5625 5200 37 A/MG SO Po( 20 08/28/15 4 7014 6288 43 MG DMY RK 0 08/20/15 Minimum ID = 3.920" @ 9507' 3 7743 6805 46 MMG DMY RK 0 08/20/15 7" X 4-1/2" XO 2 8755 7503 44 MAG DMY RK 0 08/20/15 1 9157 7802 39 MAG DMY RK 0 08/20/15 ' ' 9269' —15-1/2"HES X NP,D=4.562" 7. x 9288' H9-5/8"X 5-1/2"I-FS TNT FKR,D=4.811" I 9434' —15-1/2"I IIS X NP,D=4.562" TOP OF 9-5/8"X 7"TIEBACK LNR D=6.180" —I 9477' 5-1/2"TBG,17#,13CR-85 VAM TOP HC, —{ 9487' 9477' —9-5/8"X 7"BKR 2RH PKR w/TIEBACK .0232 bpf,D=4.892 0=6.180" c94$7' H 5-1/2"WLEG,D=4.892" 9-5/8"X 7"LNR HGR w/TIEBACK,D=6.84" H-9758' �t. 9497' —9-5/8"X 7"BKR FLEX LOCK HGR,D=6.170" .r• --4, 9507' —I 7"X 4-1/2"X0,D=3.920" ti 9-5/8"CSG,47#,L-80 BTC XO TO S0095 H 9996' Si 9-5/8"CSG,47#,S00-95 BTC,D=8.681" —I 10088' i 4 x it §I & PERFORATION SUMMARY r ow REF LOG:BHCS ON 08/25/83 It 10186' —17"MARKER JOINT ANGLE AT TOP FERF:25"@ 10364' Note:Refer to Production DB for historical perf data it SIZE SPF INTERVAL Opn/Sgz SHOT SOZ :it ■ 3-1/8"' 4 10318-10348 S 04/01/84 06104/87 3-3/8" 4 10353-10373 S 09/10/97 07/30/98 N ■ 3-3/8" 6 10364-10377 0 08/31/15 ;111 3-1/8" 4 10367-10377 S 04/01/84 06/04/87 3-3/8" 6 10385-10395 0 08/31/15 Ng 0 1. 3-3/8" 4 10450-10460 S 05/29/87 06/04/87 .+ 3-3/8" 4 10470-10490 S 03/19/89 09/13/89 "�l 3-3/8" 4 10470-10500 S 09/22/89 07/30/98 .+ 3-3/8" 4 10475- 10505 S 08/15/98 08/19/15 3-3/8" 4 10500-10510 S 02/28/92 07/30/98r. 3-1/8" 4 10518- 10528 S 05/13/87 06/04/87 3-3/8" 6 10518-10550 S 06/29/87 09/13/89 4` 4 10510'CTM —I PBTD 4-1/2'SCAB LNR,12.6#,13CR-85 VAM TOP, 10500' NIP .0152 bpf,D=3.958" ,*. 10755' —17"FOC 7"LNR,29#,N-80 BT&C,.0371 bpf,ID=6.184" 10802' DATE REV BY COMVENTS DATE REV BY COPRA NTS PRUDHOE BAY UNIT 09/01/83 PKR 176 IMTIAL COMPLETION WELL: 14-32 08/24/15 D-14 RINO PERMIT No: 1831220 08/26/15 AU DRLG HO CORRECTIONS AR No: 50-029-20999-00 08/27/15 CK/JMD FINAL ODEARTROVAL SEC4,T1ON,R14E,40'FSL&1292'FEL 09/01/15 DJS/JND GLV C/O(08/28/15) 09/03/15 JCMJM)ADPERFS(08/31/15) BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, August 27, 2015 1:36 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: OPERABLE Well 14-32 (PTD# 1831220) MIT-IA Passed Post RWO All, Producer 14-32 (PTD#1831220) underwent a rig Workover completed on August 24, 2015. The tubing was replaced during the rig Workover. A MIT-T and MIT-IA both passed on August 23, 2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A SSSV is not required Please use caution while placing the well on production due to fluid packed annuli and the possibility for annular fluid expansion. Thank you, Kevin Parks Mtevnnte Whitney Pettus' SEWED SEP 2015 BP Alaska-Well Integrity Coordinator `A V Gt A! Global Wells V V Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, April 27, 2014 11:11 AM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; 'chris.wallace@alaska.gov'; Chou, Irwin Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'jim.regg@alaska.gov' Subject: NOT OPERABLE Well 14-32 Sustained InnelAnnulus Casing Pressure Above MOASP All, Not Operable Producer 14-32 (PTD#1831220) was reported to have sustain inner annulus casing pressure above MOASP on 04/24/2014. The pressure were 2360/2010/60 psi. The well was made Not Operable on 12/23/2013 due to poor tubing condition. A tubing patch was pulled on 04/03/2014. While preparing the well to be secured the inner 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, July 26, 2015 9:49 AM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE Producer 14-32 (PTD #1831220) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer 14-32 (PTD #1831220) TIO Plot.docx All, Not Operable Producer 14-32 (PTD#1831220) was reported to have sustained inner annulus casing pressure above MOASP on 07/25/2015. The pressure were T/I/0=SSV/2200/50 psi. The well was made Not Operable on 12/23/2013 due to poor tubing condition. A downhole plug was pulled on 07/12/2015 in prep of a upcoming Rig work over. The well status remains Not Operable. A copy of the TIO plot is included for reference. Thank you, SCANNED JUL 2 7 2015 Kevin Parks 11'! p, PE'tt(! BP Alaska-Well Integrity Coordinator Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 • Producer 14-32 (PTD#1831220)TIO Plot M• O 1.� 0411. 0e .d • Ire Nx.5 wex., m»n 00, av,s arm ewm stn emv,s MILIS meta nnm mane nan rI OF �� j, sA THE STATE Alaska Oil and Gas �.�' ofALASIc:A Conservation Commission _ � 333 West Seventh Avenue nti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �F ALA6' Fax: 907.276.7542 www.aagcc.alaska.gov Dave Bjork Engineering Team Leader BP Exploration(Alaska), Inc. 'SCA tie) P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-32 Sundry Number: 315-129 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P,oerster Chair DATED this 1g day of March, 2015 Encl. • STATE OF ALASKA RECEIVED ALASF OIL AND GAS CONSERVATION COW/II-010N APPLICATION FOR SUNDRY APPROVAL MAR 10 2015 20 AAC 25.280 1. Type of Request: AOGGO ❑Abandon ❑Plug for Redrill 0 Perforate New Pool ®Repair Well 0 Change Approved Program ❑Suspend ®Plug Perforations• 0 Perforate . 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other Scab Liner 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory ❑Stratigraphic 183-122 • 3. Address: 0 Development ❑ Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-20999-00-00 7. If perforating. 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 341 D PBU 14-32 Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designator 10 Field/Pool(s). ADL 028312 + Prudhoe Bay/Prudhoe Bay r 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft). Effective Depth MD(ft)• Effective Depth TVD(ft): Plugs(measured): Junk(measured) 10900' • 9326' • 10750' 9192' 9667' Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 31'- 111' 31'- 111' 1490 470 Surface 2463' 13-3/8" 30'-2493' 30'-2493' 4930 2670 Intermediate 10061' 9-5/8" 27'- 10088 27'-8593' 6870 4760 Production Liner 1044' 7" 9758'- 10802' 8298'-9238' 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10475'- 10505' 8944'-8971' 5-1/2", 17#x 4-1/2", 12.6# L-80 9791' Packers and SSSV Type. 9-5/8"x 5-1/2" Baker SAB Packer Packers and SSSV 9689'/8239' MD(ft)and TVD(ft): 12. Attachments. 13.Well Class after proposed work: 0 Description Summary of Proposal 0 BOP Sketch El Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work. Commencing Operation. July 1,2015 . 0 Oil ❑WINJ 0 WDSPL ❑ Plugged 16. Verbal Approval: Date 0 Gas ❑GINJ 0 GSTOR ❑Abandoned Commission Representative: 0 WAG 0 SPLUG El Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Carolyn Kirchner,564-4190 Printed Name Dave Bjork Title. Engineering Team Leader Email: Carolyn Kirchner@bp com Signature: %���j��' Phone: 564-5683 Date: ai/ 1/4s Commission Use Only Conditions of approval. Notify Commission so that a representative may witness 1 _ lack Sundry Number: ❑Plug Integrity 6 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other. 00p tc5 f to 3560 p5 ; (4/1/25P 15 23/(0 p 5', ,q-nJJv/ aa— pr�cVC vt ft-� ?c5t to 25DQ p5I - Spacing Exception Required? 0 Yes LI No Subsequent Form Required: / g Q 4__ APPROVED BY / . 0 Approved By: C�� j � `/,7�\ COMMISSIONER THE COMMISSION Date:3— < --/-5 Form 10-403 Revised 10/2012 Approved application i al' o 1 I a �fr he date of approval #13-19-45 Submit In Duplicate VTL 3/11/1� - I i•/�/�-- ' -3-,6,. is— RBDMS APR 2 20 by 0 Date: 2/2/2015 From: Carolyn Kirchner,RWO Engineer Subject: 14-32 RWO MSPS:2316 psi V Background: Well 14-32, located on the north side of DS14, borders the gravity drainage area of Prudhoe Bay. It relies heavily on pressure support from injector 14-13 but still produces at a high GOR. The well was drilled in 1983 and maintains its original completion of 5-1/2" L-80 tubing with a 4-1/2" L-80 tailpipe.The perforations have been squeezed three times (06/04/87, 09/13/89, and 07/30/98). The well currently has a 30' section perforated in Z3,however all production is coming from a failed squeeze in Z4. 14-32 has a history of hard tags at 10,446'. There are no tools noted as lost there, making it likely a cement node. A variety of tools have made it past this spot and a variety have been stopped by it. Last drift was a wire grab to TD at 10,510' MD with no elements recovered on 04/03/2014. The well was SI December 2013 for suspected TxIA.On 12/15/2013,the DSSSV was pulled&reset and a caliper log from 9902'to surface was run.The 5.5 inch tubing appears to vary between good to poor condition with respect to corrosive/mechanical damage,with a max recorded wall penetration of 73%wall thickness in a line of corrosion in joint 145 (6,115 ft). Wall penetrations ranging from 40%to 73%wall thickness are recorded in 128 of the 248 joints analyzed. The 4.5 inch TT appears to be in poor condition with respect to corrosive/mechanical damage. A hole is recorded in joint 1 from —9,690 ft to ^'9,694 ft and in pup joint 2.2 from^'9,778 ft to^'9,781 ft,where the caliper also recorded cross-sectional wall loss of 52%(9,693 ft)and 43% (9,778 ft) respectively. The 7 inch liner logged appears to be in good condition with respect to corrosive/mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss, or ID restrictions recorded. • The well failed an MIT-IA to 2000 psi on 12/5/2013.Another MIT-IA was completed on 12/18/2013 where the results were inconclusive due to lack of differential pressure during the test because of derated tubing.Given the high GOR, a patch, and degraded tubing, it was recommended to secure well for RWO. • An RMT/Borax log was run on 4/26/2014, and the field results show channeling observed @ 10340'-10348'& from 10422' to TD @ 10482'. Based on this information, we will be running a scab liner to isolate the leaky perfs/channeling. After obtaining the borax log, a 5.5" Baker RBP was set @ 9669' Mid Element (Top set @ 9666.75')to secure the well.Two CMIT-TxIA to 2000psi were attempted shortly after and both failed. Pre Rig Prep Work: W 1 Check the tubing hanger lock down screws for free movement. PPPOT-T&IC. S 2 Pull RBP from 9967'MD. E 3 Set 3.38"Baker IBP at^'9818'MD,mid-joint in first full joint below tubing tail. F 4 CMIT well to 3500 psi. S 5 Pull IBP.Set RBP in tubing at 9667'MD,midway in pup joint above packer. F 6 CMIT-TxIA to 2000 psi. E 7 Jet cut tubing at^'9616'MD,4 ft below top of first full joint above packer and RBP at 9667'MD. O 8 Plug control and balance lines with squeeze-crete cement. O 9 Pressure test control and balance lines after waiting on cement to 3500 psi. F 10 EL assist:CMIT-TxIA to 1000 psi.Circulate well w/1%KCI. FP w diesel to 2200'MD.Bleed T/I/O to 0 psi. ✓ 11 Set Type K BPV.Install Dry Hole Tree.Configure Annular Valves. Rig Scope of Work: • MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6" VBR's, blind shears, mud cross and 3-1/2"x 6"VBR's). Test the VBR's to 3,500 psi and the ,/ annular to 3,500-psi. • Pull 5-1/2' L-80 tubing from tubing from cut at 9,622' MD. • Run RTTS and test casing to 3500 psi. • Overshot the stub and recover seals and stub. • Release K-anchor and pull to surface. • Mill and recover SAB packer and tailpipe. • Make a casing scraper run in 9-5/8"&7". - • Run and cement 4-1/2"condition B chrome scab liner from PBTD to^'9500' MD. • • Update tubing spool to Gray New Standard and replace IC pack-off. • Run 5%"17#13Cr VamTop tubing with HES TNT packer.Set the packer at 9,400' MD. • Test tubing and IA to 3,500-psi. Freeze protect to 2,500'MD. • Set TWC. ND BOPE. NU and test tree. RDMO. Post Rig Work: W 1 ND dry hole tree, NU production tree, Pull BPV. 5 2 Pull ball and rod and RHC.Set generic GLD. E 3 Perforate. Borax log to confirm channels are isolated. Expected perforation depths: Top Base Depth Depth Top Depth Base Depth (ftMD) (ftMD) (ftTVDSS) (ftTVDSS) 10364 10377 8774.3 8786.0 10385 10395 8793.3 8802.3 TREE= FMC WELLHEAD= GRAY GEN3 1 4.-3 I� S Y NOTES:**CHROME PATCH** .ACTUATOR= BAKER OKB.ELEV= 69' BF.ELEV= KOP= 3200' 2190' H5-1/2"CAM BA L-0 SSSV NP,D=4.562" Max Angle= 47'©7900' Datum MD= 10392' Datum TVD= 8800'SS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 20"CONDUCTOR,91.5#,11-40,D=19.124" 110' 1 2903 2903 4 MMIC DMY RK 0 07/11/08 2 5050 4742 39 WAG DMY RK 0 07/11/08 13-3/8"CSG,72#,L-80,ID=12.347" —f 2493' 3 6649 6012 38 PUG DMY FE 0 06/14/98 4 7881 6900 47 MING *MY RK 0 07/11/08 5 7959 6953 47 MMG DMY RK 0 01/01/60 Minimum ID = 2.78" c 2190' • 6 8701 7465 45 WIG DMY RK 0 01/01/60 5-1/2" DSSSV 7 8776 7518 44 MING DMY RK 0 09/02/92 8 9184 7823 39 IANG DMY RK 0 01/01/60 9 9263 7885 37 MING DMY RK 0 01/01/60 10 9505 8083 33 WIG DMY RK 0 01/01/60 11 9583 8148 32 MAAG EO DMY NO PRONG 06/12/09 5-1/2'BKR RBP(04/27/14) H 9667' *ST#4=MY HAS DETEMED PACKING **ST#11=DMY HAS BROKEN LATCH 9675' -1A5-1/2 " {5 1/2"BKR F R ASSY w/K-22 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" H 9694' l J f A NCi iOR SEAL NF D=4.75" 9689' -19-5/8"X 5-1/2"BKR SAB PKR,D=4.75" J _ 9694' H7"MFLLOUT EXTENSKA,ID=6.00' 9701' H7"X 4-1/2'XO,I D=3.958' 9-5/8"X 7'LNR HGR w/TRACK,D=6.84' H 9758' �® ' I 9779' H4-1/2"CAM D8-6 LAND NP,D=3.813" 4-1/2"TBG-PC,12.6#,L-80,.0152 bpf,ID=3.958" H 9792' 9791' 14-1/2"BKR SHEAROUT St16,ID=4.125" 9792' H4-112"WLEG,D=3.958' 9-5/8'CSG,47#,L-80 BTC X0 TO S0095 —{ 9996' �� 9781' —i EiMD TT LOGGED 05/13/87 ? Fr FISH-B_E3ANTS FROM PATCH- 9-5/8"CSG,47#,L-80 BTC,D=8.681' H 10088' A 1/2'W x 1"THICK&5"OD(04/03/14) 10186' --17"MARKER JOINT PERFORATION SUMMARY REF LOG:BRCS ON 08/25/83 J e h a n l/ / le' 310-to i f y ANGLE AT TOP PERF:25'@ 10475" Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ /0 q 2 2 H 1�r 3-1/8" 4 10318-10348 S 04/01/84 06/04/87 Gt et. l fry 3-3/8' 4 10353-10373 S 09/10/97 07/30/98 3-1/8' 4 10367-10377 S 04/01/84 06/04/87 3-3/8" 4 10450-10460 S 05/29/87 06/04/87 3-3/8" 4 10470-10490 S 03/19/89 09/13/89 10446'ELMD HOW NODE-LOGGED(07/20/02) 3-3/8" 4 10470-10500 S 09/22/89 07/30/98 3-3/8" 4 10475-10505 C 08/15/98 3-3/8' 4 10500-10510 S 02/28/92 07/30/98 3-1/8' 4 10518-10528 S 05/13/87 06/04/87 ree.vve.ve 10510'CTM —{ FSTD 3-3/8" 6 10518- 10550 S 06/29/87 09/13/89 1444.4 14441.x...1 .41...1 10755' �7'F ` 1 7"LNR,29#,N-80 BTC,.0371 bpf,ID=6.184" H 10802' DATE REV BY COMMENTS DATE REV BY COM1vINTS PRUDHOE BAY UNIT 09/01/83 IMTIAL COMPLETION 05/01/14 JCPAJMD SET RBP(04/28/14) WELL: 14-32 09/28/09 W/SV SET PATCH(08/04/09) PERMT No: 1831220 12/09/13 PJC FERFS/GLV CORRECTION AR No: 50-029-20999-00 02/03/14 TJINJMD SET DSSSV(12/16/13) SEC 4,T1 ON,R14E,40'FSL 8 1292'FEL 02/03/14 AVID COM CTED COORDINATES 04/10/14 TBD/PJC RLL DSSS/FISH DH(04/03/14) BP Exploration(Alaska) TREE- Mt 1432 WELLHEAD= GRAY GENS S NOTES: 1 ACTUATOR= BAKER Proposed RWO OKB.ELEV= 69' p BF.REV= KOP= 3200' Max Angle= 47°@ 7900' Datum MD= 10392' Datum TVD= 8800'SS , I 00' —15-1/2"HES'X'NIPPLE, ID=4.562" 1 20"CONDUCTOR,91.5#,1-1-40, 0=19.124" —1 110" A 13-3/8"CSG,72#,L-80,ID=12.347" —1 2493' 1-1 5-1/2"TBG, 17#,13Cr-85 VamTopHC —1 9,264' I-- ♦ / --------- ( 9,264' —5-1/2"x 4-1/2"crossover ' —. 9,320' —14-1/2"HES'X'NIPPLE,ID=3.813" >< 9,351' —19-5/8"X 4-1/2"HES'TNT PKR, ID=3.88" ----- 9,385' —14-1/2"HES'X'NIPPLE,ID=3.813" ' --. __ 9,458' -J4-1/2"HES'XN'NIPPLE,ID=3.725" — 9,508' H4-1/2"WLEG,ID=3.958" —9,500' —19-5/8"X 4-1/2"ZXP/FLEXLOCK HANGER J 9-5/8"X 7"LNR HGR w/TEBACK,ID=6.84" H 9758' — 4-1/2"12.6#13Cr PBTD-'9,50011 4 e 4-1/2"TBG-PC, 12.64,L-80,.0152 bpf, D=3.958" H 9792' • 9 9-5/8"CSG,47#,L-80 BTC XO TO S0095 H 9996' 1— x 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H 10088' a ,• 10186' —17"MARKER JOINT PERFORATION SUMMARY • REF LOG:BRCS ON 08/25/83 ANGLE AT TOP PERF:25° @ 10475' Note:Refer to Production DB for historical perf data t SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-1/8" 4 10318-10348 S 04/01/84 06/04/87 3-3/8" 4 10353-10373 S 09/10/97 07/30/98 a 3-1/8" 4 10367-10377 S 04/01/84 06/04/87 "I 3-3/8" 4 10450-10460 S 05/29/87 06/04/87 3-3/8" 4 10470-10490 S 03/19/89 09/13/89 3-3/8" 4 10470-10500 S 09/22/89 07/30/98 tit] 3-3/8" 4 10475-10505 C 08/15/98 3-3/8" 4 10500-10510 S 02/28/92 07/30/98 i .. 3-1/8" 4 10518-10528 S 05/13/87 06/04/87 0004 10510'CTM H STD 3-3/8" 6 10518-10550 S 06/29/87 09/13/89 1 M. 1••►•�•1•1•�•1 1�♦�♦�♦�'01_ 10755' H 7"FOC 7"LNR,29#,N-80 BTC,.0371 bpf, D=6.184" H 10802' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/01/83 INITIAL COMPLETION 05/01/14 JCIvVJMD SET RBP(04/28114) VVELL: 14-32 09/28/09 MV/SV SET PATCH(08/04/09) PERMIT No: 1831220 12/09/13 PJC FERFS/GLV CORRECTION API No: 50-029-20999-00 02/03/14 TJM'JMD SET DSSSV(12/16/13) SEC 4,T1ON,R14E,40'FSL&1292'FEL 02/03/14 JMD CORRECTED COORDINATES 04/10/14 TBD/PJC FULL DSSS/FISH DH(04/03/14) BP Exploration(Alaska) • gl •11g O • a'6 cnt Ny • E■ i w Wz 6 FS DO g¢ b �o \ 1 HHIIHIlk— - R. Z LIE li p , , 0 0 -ix< o Z y ct — w Www \. ,•§ •� - _ a a N w a a 3 SU. s 0 CC 3 6 a Z O N O Z e000©oo g - r� co ii 1.WM — 401=141 n. P. cc a-� Io -11.111.11.- iii ono liAil in r7 —� Vi xQ1 as m — 1.. . -4•______,1 IMIO1 411.111M cc � N • I 0 ddb w g aJ -� Sa Awan z zd o a,- CI c W N - _ o N 'O U i 4� �0 0 a x PT s y W _2 m = = §E,,,1 E 25 y 7 $g g o=' o ! 0* N i $ Ao 6 z 10 S T_ �(I >m 8 - y� IIIOW _ • a WIll Q Q of N N Z p Y] h N fn (1 cc In A O N I I $ Z. Zi z Z _ ,1 o .tcp> U - -- 77 . . .. 1 2. �� II U) o E g N c o N= U o\ m h N M n age Project Well History File er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ,~ ~~ - '~,~~ Well History File Identifier Organizing I~c~n~~ ^ Two-Sided III IIIIIIIIIII ILIA ^ Rescan Needed III IIIIIIIIII III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ^ Color items: ^ Diskettes, No. ^ Maps: ^ Grayscale items:.. ^ Other, No/Type ^ Other items scannable by large scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds NOTES: ^ Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: (S/ P ,K,Proo,;~ wiiuimmiu BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Scanning Preparation ~ x 30 = + ~ = TOTAL PAGES BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Production Scanning Stage ~ PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO BY. VE Y BREN VINCENT SHERYL MARIA LOWELL DATE:' I~~ ~~~ /S/ Stage 2 IF NO IN STAGE 'I, PAGES} DISCREPANCIES WERE FOUND: YES NO BY. BEVERLY BREN VINC SHERYL ARIA LOWELL DATEj® 9 ~ O /9S/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS // ~~, ~ /" DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) III II I I II I I III I I III ReScanned (1i§(xkYt~Ef%mB ~~P~B ~S(3f?rli~~e?21~td tjt7Yl~,~.'Cr5PZ1Yd#Yi~£:Cl#7dj3~!?~E;Le~s` III (I'III IIII III III RESCANNED BY. BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISI General Notes or Comments about this file: Quality Checked (aarre} IIIIIIIIIIINIII'° STATE OF ALASKA Ilk. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS A 1. Operations Abandon p �] Repair Well U P lug Perforations U Perf orate ❑ Ot U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ ' Stimulate - Other El Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 • Exploratory ❑ 183 -122 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20999 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028312 PBU 14 -32 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL. 11. Present Well Condition Summary: Total Depth measured 10900 feet Plugs measured None feet true vertical 9326.05 feet Junk measured None feet Effective Depth measured 10510 feet Packer measured 9689 feet true vertical 8975.33 feet true vertical 8238.7 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" 91.5# H-40 30 - 111 30 - 111 1490 470 Surface 2463 13 -3/8" 72# L -80 29 - 2492 29 - 2491.92 4930 2670 Intermediate None None None None None None Production 10060 9 -5/8" 47# L -80 28 - 10088 28 - 8592.52 6870 4760 Liner 1044 7" 29# N -80 9758 - 10802 8298.35 - 9238.18 8160 7020 Perforation depth Measured depth See Attachment feet SCANNED JUN 1 7 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker SAB Packer 9689 8238.7 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10475' - 10505' Treatment descriptions including volumes used and final pressure: 75 BBL 3% NH4CL, 36 BBL 12% HCL 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 584 34896 5506 2 1276 Subsequent to operation: 485 28102 5058 2 1495 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Ei . Gas L] WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 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 Nita Summerhays Email Nita.Summerha s • BP.com Printed Name Nita Summerha s Title Petrotechnical Data Technician / Mr Si., atur- 1409Y, f r.- -� / ��� Phone 564 -4035 Date 6/12/2013 RBDMS JUN 14 201 J\� l Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028312 ** *Job continued from 4/14/13 WSR * ** Pumped 3 bbls meth spear and 65 bbls crude down IA to achieve 3000 psi test pressure.(MIT -IA ** *PASS * * *) Rig to TBG. Pump 5 bbls neat meth spear followed by 255 bbls dead crude to load TBG. Perform Injectivity test down TBG @ 1 bpm, 2 bpm, and 3 bpm for 5 min to 15 min each. RDMO ( See Awgers for details. ) FWHP= 95/443/480 wing =shut / swab =shut / ssv =open / 4/15/2013 master =open / IA and OA open to gauges. Operator notified of departure. ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 ** *WSR 5/12/13 " "" Spot Unit EOP, 5/12/2013 Standby per DSO, permit up ** *Continue on WSR 5/13/13 * ** ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 ** *WSR 5/12/13'""' S/B per DSO, S/B 5/13/2013 for QC Crew to perform Work, S/B for Grease Crew ** *Continue on WSR 5/13/13 * ** ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid Stimulation ** *WSR 5/13/13 * ** S/B for CH2MHILL, Troubleshoot Equipment, MIRU 5/14/2013 ** *Continue on WSR 5/15/13 * ** ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid 5/15/2013 Stimulation ** *WSR 5/1413 * ** Continue R /U, P/T ** *Continue on WSR 5/16/13 * ** T /I /0= 1300/1100/700 Temp =Hot Freeze protect flowline for Well Testers (Aid Job) Pump 5 bbls ambient meth, 93 bbls 110* crude down Flowline for freeze protect. Pressure up Flowline to 1500 psi. 5/15/2013 FWHP = 1300/1100/700 WV, SSV, SV= CLOSED MV =OPEN CV =OTG ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid Stimulation ** *WSR 5/1513 * ** P /T, S/B for FBC, S/B for Soda Ash, Tanks Charged 5/16/2013 ** *Continue on WSR 5/17/13 * ** T /I /0= 2506/616/260 Temp =SI Assist ASRC testers (ACID STIM) Spear in to TBG w/5 bbls of amb. meth followed by 45 bbls of 110* 3% NH4CL followed by 36 bbls of 100* 12% HCL flushed lines with 1 bbl of amb. diesel pumped an additional 30 bbls of 110* 3% NH4CL tailed by 150 bbls of 120* crude. ASRC Well Testers in control of well per 5/16/2013 LRS departure. FWHP's 0/550/280 SV SSV, WV =C MV =O CV's =OTG T /I /O= 2500/660/360. Temp. - SI Assist SLB Pump crew (Acid Stim.) Pumped 3 bbls neat spear and 242 bbls of crude to displace tubing after acid treatment. Final 5/17/2013 WHP - 60/478/360. SLB /ASRC on well at departure. ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid Stimulation ** *WSR 5/16/13 * ** Tanks Charged, Flow Back Pickle, SB for full bore, flow 5/17/2013 well ** *Continue on WSR 5/18/13 * ** T /I /0= 2509/657/360 Pump 66 bbls 12% HCL Acid & 66 bbls of 9:1 MUD Acid with a wax bead diversion between stages in an attempt to increase the gross fluid rate produced from the well. Displace with 245 bbls of Crude (see LRS AWGRS report). Well testers in 5/17/2013 control of Well upon SLB departure to flow back acid. Final WHP= 60/478/360. ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid Stimulation * ** Continued from WSR 5/17/13 * ** Tanks Charged, Flow Back Pickle, SB 5/18/2013 for full bore, flow well ** *Continue on WSR 5/19/13 * ** ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid Stimulation * ** Continued from WSR 5/18/13 * ** flow well, complete 8 hour test, blow 5/19/2013 down, RD ** *Continue on WSR 5/20/13 * ** ASRC Test Unit #4 Inlet DS14 -32 Outlet DS14 -41 Objective: Tubing Pickle w /Acid Stimulation ***Continued from WSR 5/19/13 * ** Flow well ** *Completed on WSR 5/20/2013 5/20/13 * ** • • Daily Report of Well Operations ADL0028312 FLUIDS PUMPED BBLS 21 METH 877 CRUDE 75 3% NH4CL 36 12% HCL 1 DIESEL 1010 TOTAL Perforation Attachment ADL0028312 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 14 -32 8/2/2009 BPP 10315 10317 8798.86 8800.68 14 -32 8/2/2009 BPP 10319 10349 8802.5 8829.72 14 -32 8/2/2009 BPP 10353 10368 8833.34 8846.91 14 -32 8/2/2009 BPP 10368 10373 8846.91 8851.42 14 -32 8/2/2009 BPP 10373 10378 8851.42 8855.94 14 -32 8/2/2009 BPP 10450 10460 8920.9 8929.95 14 -32 8/2/2009 BPP 10470 10475 8939.01 8943.54 • 14 -32 8/2/2009 BPP 10475 10490 8943.54 8957.16 14 -32 8/2/2009 BPP 10490 10500 8957.16 8966.24 14 -32 8/2/2009 BPP 10500 10505 8966.24 8970.78 14 -32 8/2/2009 BPP 10505 10510 8970.78 8975.33 14 -32 8/2/2009 BPP 10518 10528 8982.59 8991.67 14 -32 8/2/2009 BPP 10528 10550 8991.67 9011.6 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADLOO28312 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 20" 91.5# H -40 30 - 111 30 - 111 1490 470 LINER 1044 7" 29# N -80 9758 - 10802 8298.35 - 9238.18 8160 7020 PRODUCTION 10060 9 -5/8" 47# L -80 28 - 10088 28 - 8592.52 6870 4760 SURFACE 2463 13 -3/8" 72# L -80 29 - 2492 29 - 2491.92 4930 2670 TUBING 9667 5 -1/2" 17# L -80 27 - 9694 27 - 8243 7740 6280 TUBING -91 4 -1/2" 12.6# L -80 9701 - 9610 8249.02 - 8171.24 8430 7500 • • f TREE = FMC • WELLHEAD =GRAY GEN3 • SAFETY NOTES: * *CHROME PATCH** ACTUATOR= BAKER 14 -32 KB. ELEV = 69' 1:lg KOP= 3200' I ' I 2190' I -15- 1 /2 " CAM BAL -OSSSV NIP, ID = 4.562" Max Angle = 47 @ 7900' GAS LIFT MANDRELS Datum MD = 10392' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800' SS 1 2903 2903 4 MMIG DMY RK 0 07/11/08 2 5050 4742 39 MMIG DMY RK 0 07/11/08 120" CONDUCTOR, 91.5 #, H-40, ID = 19.124" H 110' 3 3 6649 6012 38 MMIG DMY RK 0 06/14/98 4 7881 6900 47 MMIG *DMY RK 0 07/11 /08 113-3/fr CSG, 72 #, L -80, ID = 12.347" H 2493' 5 7959 6953 47 MMIG DMY RK 0 01/01/60 6 8701 7465 45 MMIG DMY RK 0 01/01/60 Minimum ID = 2.987" @ 9590' . 7 8776 7518 44 MMIG DMY RK 0 09/02/92 LI 8 9184 7823 39 MMIG DMY RK 0 01/01/60 5 -1/2" HES DWP PATCH 9 9263 7885 37 MMIG DMY RK 0 01/01/60 10 9505 8083 33 MMIG DMY RK 0 01/01/60 5 -1/2" HES DWP(CR) PATCH, ID= 2.987" (08/04/09)1-1 9590' -9610' -= 8 11 9583 8148 32 MMIG **DMY PRONG PULLED 06/12/09 *ST #4 = DMY HAS EXTENDED PACKING S **ST #11 = DMY HAS BROKEN LATCH (RKED & EQ DMY) 9675' 1- 5-1/2" BKR PBR ASSY w / K -22 15 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" 1 9694' ANCHOR SEAL NIP, ID = 4.75" 9689' 1- 19 -5/8" X 5 -1/2" BKR SAB PKR, ID = 4.75" I 5 I 9694' 1-17" MILLOUT EXTENSION, ID = 6.00" I 9701' 1-17" X 4-1/2" XO, I D= 3.958" I 9 -5/8" X 7" LNR HGR w / TIEBACK, ID = 6.84" H 9758' 1 • I 9779' 1 -14 -1/2" CAM DB -6 LAND NIP, ID = 3.813" I 1 9791' 1-14-1/2" BKR SHEAROUT SUB, ID = 4.125" I 14-1/2" TBG -PC, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9792' 1 . ------- 9792' 1- 14 -1/2" WLEG, ID = 3.958" I 19 -5/8" CSG, 47 #, L -80 BTC XO TO S0095 H 9996' I-- x ( 9781' H ELMD TT LOGGED 05/13/87 I 19 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" H 10088' I • • I 10186' 1-17" MARKER JOINT I PERFORATION SUMMARY REF LOG: BHCS ON 08/25/83 ANGLE AT TOP PERF: 25° @ 10475' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -1/8" 4 10318 - 10348 S 06/04/87 3 -3/8" 4 10353 - 10373 S 07/30/98 3-1/8" 4 10367 - 10377 S 06/04/87 3 -3/8" 4 10450 - 10460 S 06/04/87 1 10446' ELMD]H CMT NODE - LOGGED (07/20/02) I 3 -3/8" 4 10468 - 10488 S 09/13/89 I 3 -3/8" 4 10470 - 10510 S 07/30/98 3 -3/8" 4 10475 - 10505 0 08/15/98 3 -1/8" 4 10518 - 10528 S 06/04/87 r 10510' CTM h PBTD I 3 -3/8" 6 10518 - 10550 S 09/13/89 1••0v•f ••••••1 10755' 1-17" FOC 17" LNR, 29 #, N -80 BTC, .0371 bpf, ID = 6.184" 1-1 10802' 1 VAtt•Att1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/01/83 ORIGINAL COMPLETION 06/17/09 JLJ/TLH GLV C/O (06/12/09) WELL: 14 -32 01/09/08 RM/SV TREE C/O (12/30/07) 07/25/09 OOB /PJC GLV CORRECTIONS PERMIT No: 1831220 02/07/08 PJC DRAWING CORRECTIONS 09/28/09 DMS /SV PULL WRP (08/02/09) AR No: 50- 029 - 20999 -00 07/18/08 JA /JMD GLV C/O (07/11/08) 09/28/09 MV /SV SET PATCH (08/04/09) SEC 4, T10N, R14E, 2560.7' FEL & 3079.61' FNL 12/13/08 JCM/SV SET WRP (07/20/08) 02/09/09 OOB /PJC WRPDEPTH CORRECTION BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 . ~, r bP LEC ~ °~ ~Q09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, ~' ~ ... ~~ ,. ~A~~Y2liaaa9 Ul~5~ ~ ~._3~- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # 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 na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-o6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-098 1820340 500292053402 Sealed Conductor NA NA to-10 1801300 500292052800 Sealed Conductor NA NA 14-itA 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-18B 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 1a-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA t4-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 t4-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 STATE OF ALASKA '" ALASKA~ AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS ~ ~~` ~~~~'~ ~ a ~/~-A? , . ~ ~~~~~f~" ^~ k f,C,3~;;J 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimutate~ Other TUBING PATCH Perforrned: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ "~ ' ' Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~ 183-1220 3. Address: P.O. Box 196612 StrBtigraphlC 1~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20999-00-00 7. KB Elevation (ft): 9. Well Name and Number; 69 KB 14-32 8. Property Designation: 10. Field/Pool(s): ADLO-028312 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10900 feet Plugs (measured) 10452' tagged PBTD true vertical 9326.05 feet Junk (measured) None Effective Depth measured 10452 feet true vertical 8293 feet Casing Length Size MD ND Burst Collapse Conductor 81 20# 91.5# H-40 Surface - 81 Surface - 81 1490 470 Surface 2424 13-3/8" 72# L-80 Surface - 2492 Surface - 2493 4930 2670 Production 10019 9-5/8" 47# L-80 Surface - 10088 Surface - 8593 6870 4760 Liner 1044 7" 29# N-80 9758 - 10802 8298 - 9238 8160 7020 Perforation depth: Measured depth: see attached - _ _'~ ,,'~~ ~~'" ~my ~ ~~ ~ ~ =§~ Z ~ ~ j _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" Single set chrome patch 9590' - 9610' OD=4.535" 0 - 5-1/2" 17# L-80 Surface - 9694' 4-1/2" 12.6# L-80 9701' - 9792' Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BKR SAB PKR 9689' 5-1/2" Haliburton Single set Chrome patch 9590' - 9610' 0 0 0 0 12. Stimulation or cement squeeze summary: t-~ ~~~ ~ ~y Intervals treated (measured): `~~~ ~ ~`Z'~7S 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: SI Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ De~elopment ~ Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas I~ WAG N~ GINJ ~ WINJ ~ WDSPL I~ 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 Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/11/2009 '~l~gli~=? ! . 1 ~E`-" r~'''~'% =/C~; ~ 14-32 183-122 PERF ATTACHMENT n l, J ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 14-32 4/1/84 PER 10,315. 10,317. 8,798.86 8,800.68 14-32 4/1/84 PER 10,319. 10,349. 8,802.5 8,829.72 14-32 4/1/84 PER 10,368. 10,378. 8,846.91 8,855.94 14-32 5/13/87 APF 10,518. 10,528. 8,982.59 8,991.67 14-32 5/29/87 APF 10,450. 10,460. 8,920.9 8,929.95 14-32 6/4/87 SQZ 10,315. 10,528. 8,798.86 8,991.67 14-32 6/29/87 APF 10,528. 10,550. 8,991.67 9,011.6 14-32 6/29/87 RPF 10,518. 10,528. 8,982.59 8,991.67 14-32 3/19/89 APF 10,470. 10,490. 8,939.01 8,957.16 14-32 9/13/89 SQZ 10,315. 10,550. 8,798.86 9,011.6 14-32 9/22/89 APF 10,490. 10,500. 8,957.16 8,966.24 14-32 9/22/89 RPF 10,470. 10,490. 8,939.01 8,957.16 14-32 2/28/92 APF 10,500. 10,510. 8,966.24 8,975.33 14-32 9/10/97 APF 10,353. 10,373. 8,833.34 8,851.42 14-32 7/30/98 SQZ 10,353. 10,550. 8,833.34 9,011.6 14-32 8/15/98 RPF 10,475. 10,505. 8,943.54 8,970.78 14-32 7/1/02 FIL 10,451. 10,750. 8,921.8 9,191.55 14-32 6/25/03 BPS 9,670. 10,550. 8,222.4 9,011.6 14-32 7/4/03 BPP 9,670. 10,550. 8,222.4 9,011.6 14-32 7/10/03 SPS 10,037. 10,550. 8,546.35 9,011.6 14-32 11/29/03 SPR 10,037. 10,475. 8,546.35 8,943.54 14-32 11/29/03 SPR 10,475. 10,505. 8,943.54 8,970.78 14-32 11/29/03 SPR 10,505. 10,510. 8,970.78 8,975.33 14-32 12/23/07 BPS 9,642. 10,315. 8,198.47 8,798.86 14-32 1/23/08 BPP 9,642. 10,315. 8,198.47 8,798.86 14-32 7/20/08 BPS 9,642. 9,652. 8,198.47 8,207. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ • 14-32 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY "**"WELL S/I ON ARRIVAL**"* RUN 4.50" LIB TO 9626' SLM ( RIH 5-1/2" WFD WRP W/OUT SLM. (2181' SLM). *''''*CONT JOB ON 8-2-09"** ION OF SHEAR STUD ON ' TO EQUALIZE 5 1/2" WRP D MOVED UP TO SSSV 81' SLM AND BEGIN 8/2/2009;"**CONT JOB FROM 8-1 ini ii i ~ ~ inn ~nirn ~einn ~ DRIFT W/ 5 1/2" HES DWP PATCH DRIFT TO 9701' SLM *'`'`WELL S/I ON DEPARTURE*"'' ( DISCUSSED VALVE POSITION W/ DSO) **"WELL SHUT IN ON ARRIVAL*** (ELINE - SET PATCH) SSV=O,MV=O,SV=C,WV=C, IA/OA=OTG INITIAL T/I/O: 800/400/20, RU ELINE. RIH WITH HALIBURTON 5-1/2" SINGLE SET CHROME PATCH, MAX OD = 4.535". HAD TROUBLE IN GLM #2 AT 5050' (REFERENCED TUBING TALLY) ; DATED 29-JULY-2008). PATCH OD = 4.535", ID = 2.987" 3SSV = C, MV = O, WV = C, SV = C, IA/OA = OTG, ;FINAL T/I/O = 750/400/0, DSO NOTIFIED OF POSITIONS. WELL SHUT IN ON ; DEPARTURE. ~**JOB COMPLETE*"* 8/8/2009 ~ *"*W ELL S/I ON ARRIVAL*** ~ ~~~~~ ~~~~~~~~~~~~~~~~~ ~ ~~ ~~~~~~~ ~SET 5 1/2" DSSSV (68" OAL, 2.80" MIN ID, 2 SETS STD PKNG) IN BAL-O NIP ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED"""' ' ~ ~ ~ ~~~~ ~-~~8/9/2009~T/I/O = SSV/440/100. Temp = SI. IA FL (FB). No A/L. IA FL @ 350' (16 bbls). ? ~ Integral flange installed. ~ SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. ~ ~ ~ , ~ j ~ ~ ~.~ _ ~ _ ~_.~ _..._ _. _ ~ ~ ____~_ ~ ~ ~~_____~,,~,~._....~ 8/10/2009~T/I/0=1200/400/100 Temp=Sl MIT IA 3000 psi PASSED ( Restore tubing ~ ; integrity to unsecure well, POP, & eval for possible SC Leak) Pumped 25.6 bbls ~ ~of 70* crude down IA to reach 3000 psi for MIT IA 1st test 1st 15 min lost 120 psi ~ ~2nd 15 min lost 20 psi for a t toal of 140 psi in 30 min bleed IA psi down bleed ~ ~back aprox. 10 bbls Final Whp's=1240/440/100 ~ wing shut swab shut ssv shut casing vlalves open to gauge's ~ ~ ~ ~ [ ~ 3 ~ i FLUIDS PUMPED BBLS 3 diesel 3 Total os/18ios ~~ SchC~~berger N0.4887 Alaska Data & Consulting Services _ Company State of Alaska 2525 Gambell Street, Suite 400 t'r` ~ ~Si } P1 `~ Alaska Oil & GeS Cons Comm Anchorage, AK 99503-2838 t"' ~1~ ~`~~' ~ `` ~ r ~ ~ ~~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wnll L.h ~ ~ __ n___- M-04 11978480 MEM GRADIOMANOMETER LOG ~ ~~ 08/25/08 1~ 1 14-32 12031498 LDL 07/29/08 1 H-20 11962621 USIT - ^°• '~- LJ 08/28/08 1 1 3-35/L-36 11999039 INJECTION PROFILE ~ T 09/04/08 1 1 3-37/L-35 11970845 FLUID LEVEL DETERMINATION (~ X51 09/07/08 1 1 3-37/L-35 11968960 PRODUCTION PROFILE 08/30/08 1 1 NK-38A 12017515 SBHP SURVEY ~~ _ ~ ~0 09/02/08 1 1 L-215 12031512 INJECTION PROFILE d ~;,~' _. ~ 09/03/08 1 1 B-05B 12096914 MCNL 08/17/08 1 1 L-205L3 40016985 OH MWD/LWD EDIT 06/21/08 2 1 BP Exploration (Alaska) Ina ~ ~~ `'~~~~° P~ ~r h~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. i tt~~ Anchorage, Alaska 99508 ~,"%t_t ~ i C~ ~~I!fS Date Delivered: ~~_ ,'na . : , . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATfN: Beth ~ Received by: ~.,.-- • • NOT OPERABLE: 14-32 (PTD #1831220) TxIA Communication Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ ~ j~i~~ Sent: Saturday, July 19, 2008 8:52 PM I To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 14-32 (PTD #1831220) TxIA Communication All, Well 14-32 failed an MITIA post-DGLVs on 07/18108. The wellhead pressures have been bled to safed out levels. The well as been reclassified as Nat Op, enable and the plan forward is to set a WRP for secure. ~-- Please tali with any questions ar concerns. Thank yau, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~~~ A~1 G ~ '~ ~0~~ From: NSU, ADW Well Integrity Engineer Sent: Tuesday, June 24, 2008 6:07 AM To: 'jim.regg@alaska.gov'; 'tom.maunder@alaska.gov'; GPB, Area Mgr Central (GCl/3/F53); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Paula J; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Wellman, Taylor T; Townsend, S. Eliot Subject: UNDER EVALUATION: 14-32 (PTD #1831220) TxIA Communication All, Well 14-32 (PTD #1831220) has been found with sustained casing pressure on the IA. The TIOs were 2450/2390/170 psi on 06/22/08 and a subsequent TIFL failed. The well has been classified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. S: C/O LGLV (STA #1 & 2) 3. D: Re-TIFL A wellbore schematic and TIO plot have been included for reference. Please call with any questions or concerns. Thank you, 7/31/2008 NOT OPERABLE: 14-32 (PTD #1831220) TxIA Communication Page 2 of 2 • Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907} 659-5100 x1154 7/31/2008 o cl 'o ~ cl o O cl 0 1= cl o r C,.} ~.. N rls Q CI.J O O 1~ t O cl .p hJ 1-_~ fj l CI t fll "w O 0 n_~ m rjl ~U 0 rJt O ~~ ~,.. C? m 0 C_n 0 1„ r-1 r_TI ~.! O 8.1 0 r11 tv ~. O W CI CSI W O CO O IT 0 cl 1 1 rSJ fi o ~1 r~ i W N N ~REE = FMC WELLHEAD=GRAY GEN3 ACTUATOR = BAKER KB. ELEV = 69' BF. ELEV = __ _~ _ _~ _ KOP = 3200' Max Angle= 47 @ 7900' p Datum MD - 10393' Datum TVD = 8800' SS 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" 13-318" CSC, 72#, L-80, ID = 12.347" • 14-32 I 110' Minimum ID _ 3.813" @ 9779° 4-112" CAM DB LAND NIPPLE ~ 5-1 /2" TBG-PC, 17#, L-80, .0232 bpf; ID = 4.892" ~ 5-112" CAM BAL-O SSSV NIP, ID = 4.562"' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2916 2916 4 MMIG DOME RK 16 01!29,08 2 5063 4752 37 MMIG SO RK 20 01/29/08 3 6712 6061 38 MMIG DMY RK 0 06!14198 4 7894 6909 47 MMIG *'°DM Y RK 0 07(02104 5 7973 6963 47 MMIG DMY RK 0 01101 160 6 8714 7474 45 MMIG DMY RK 0 01/01160 7 8790 7528 44 MMIG DMY RK 0 09!02192 8 9197 7834 39 MMIG DMY RK 0 01 /01760 9 9276 7896 37 MMIG DMY RK 0 01 P01160 10 9518 8094 33 MMIG DMY RK 0 01101/60 11 9596 8159 32 MMIG EQ DMY RKP 0 01101!60 ""STATIUN ~F4 = UMY HAS EJC1 F~VUFJ.I PACKING 112"BKRPBRASSY /K 22 9675' S - w - ANCHOR SEAL NIP, ID = 4.75" 9689' 9-5/8" X 5-1;2" BKR SAB PKR, ID = 4.75" 9694' 7" MILLOUT EXTENSION, ID = 6.00" 9701 ~ 7" X 4-1I2" XO, I D = 3.958" 9-5/8" X 7" LNR HGR w J TIEBACK, ID = 6.84" ~--~ 9758' ~4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ( 9792' 9-518" CSC, 47#, L-80 BTC XO TO 50095 9996" 9-5f8" CSC, 47#, L-80 BTC; ID = 8.681" 10088' PERFORATION SUMMARY REF LOG: BHCS ON 08/25!83 ANGLE AT TOP PERF: 25 @ 10318' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-1/8" 4 10318 - 10348 S 06fR4f$7 3-3/8" 4 10353 - 10373 S 07f30198 3-118" 4 10367 - 10377 S 06/04/87 3-3/8" 4 10450 - 10460 S 06!04/87 3-318" 4 10468 - 10488 S 09/13/89 3-318" 4 10470 - 10510 S 07/30!98 3-318" 4 10475 - 10505 08/15198 3-118" 4 10518 - 10528 S 06/04!87 3-3/8" 6 10518 - 10550 S 09(13189 7" LNR, 29#, N-80 BTC, .0371 bpf, ID = 6.184" 10802' 91 779' 1~4-112" CAM DB-6 LAND NIP, ID = 3.813" 9791' 4-1/2" BKR SHEAROUTSUB, ID = 4.125" 9792' 4-112" WLEG, ID = 3.958" 9781' ELMD TT LOGGED 05/13/87 10186' ~-~ 7" MARKER JOINT 10446' ELTD LOGGED (07120!02} CMT NODE? 10510' CTM PBTD 10755" 7" FOc DATE REV BY '! COMMENTS 09101!83 ORIGINAL COMPLETION ,,,,,,,, .~.~~. ~~.....~ 10J02107 DAV!TLH G LV GO 01/09108 JCNUSV SET WFD WRP {12!23107} 01109(08 RNUSV TREE C/O { 12130107) 02102!08 GS(SV WRP PULLED {Oif31l08) 02107108 PJC DRAWING CORRECTIONS DATE ~ REV BY ~ CC 02J08r'08 KSBiPJC GLV Ci0 {01 PRUDHOE BAY UNIT WELL: 14-32 PERMIT No: 1831220 API Na: 50-029-20999-00 SEC 4, T10N, R14E, 2560.7' FEL & 3079.61 ` FNL BP Exploration (Alaska) SAFETY NOTES: 12/19/07 ~~ill~~~~~i~~~s~ NO. 4525 Alaska Data & Consulting Services Company: State of Alaska '- - 2525 Gambell Street, Suite 400 ("~: ~ ~~~ ~, ; ~~ ~ ~ ~; ~~uf Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Lisburne Well .Inh # Inn 1'leerrintinn flnfc RI Cnlnr Rrl 15-39A 11661174 MCNL '~ ~'" 09/24/07 1 1 14-32 11676961 RST 09/14/07 1 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOG '} t y 10/06/07 1 03-36A 11745217 CH EDIT PDC GR (USIT) ~ U1'C- 05/03/07 1 15-30A 11767139 MCNL - ~ 09!05107 2 1 18-726 11216204 MCNL 07/04/06 2 1 E-21 B 11133205 MCNL -/G( $ 12/07/05 2 1 P2-56 11686777 RST - ~ 08/08!07 2 1 H-33 11686792 RST CjC .. ~ 10/20/07 2 1 06-16 11686797 RST _ < 11/15/07 2 1 L2-16 11626482 RST 05/10/07 2 1 D-226 11661167 MCNL Q - i5 08/26/07 2 1 03-14A 11212846 CH EDIT SDCL GR (USIT- ~f3(p - d~ ~ ~ ~ 04/24/06 2 1 MPB-21 PROD 11628749 MCNL (MEM PPROF) ~f -~~ ~`~ 4~_ 01/15!07 2 1 C-22A 40013486 OH MWD/LWD EDIT (~ -p 7 '~ ~~ 05/10/06 2 1 E-15C 40013555 OH MWD/LWD EDIT ~O - (~ 'rt "~~~ 06/03!06 2 1 YLCAAt HI.RrvVWLtUIat Ktl;tlYl 13T 51C~NINCi ANU Kt1UKNINti UNt LUNY tAGH tU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 a r3' Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 10/07/03 NO. 2984 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD IP2-11 I ~:~ '"lq ~, SBH TEMP & PRESSURE SURVEY 10103/07 1 GNI-01 '~ -~ 'c-~'~:"~' TEMP & PRESS SURVEY t0104/03 1 D.S. 13-27~ i~ ~ I~ t~ LDL 10101/07 1 D.S. 6-21A ~-~F~ LDL 10101/03 1 D.S. 14-32 l~')~ LDL 10/03103 1 C-23B ~-~ ~O~ MEM PPROF & IPROF LOG 09/01103 I ~ F-11A '~~ n ~ MEM PPROF & IPROF LOG 09109103 I ~ M.S-0= .aecr o...OF e 10 04 0= MPS-20 ~~q ~ 10559234 SCMT 03/03/03 2 _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 P"~ ii .... .¢"% ~' il'~,, ,¢L~ Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A-I-I'N: Beth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (Cement Sqz) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 69 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Ser~ce__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5238' FNL, 1290' FEL, Sec. 4, T10N, R14E, UM 14-32 At top of productive interval 9. Permit number / approval number 2114' FSL, 2435' FWL, Sec. 03, T10N, R14E, UM 83-122 At effective depth 10. APl number 50-029-20999 At total depth 11. Field / Pool 3080' FNL, 2561' FEL, Sec. 3, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 10900 feet Plugs (measured) Tagged PBTD @ 10452' MD (12/10/1998) true vertical 9326 feet Effective depth: measured 10452 feet Junk (measured) true vertical 8923 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 81' 20" 1800# Poleset 81' 81' Surface 2424' 1 3-3/8" 2350 Sx Fondu & 400 Sx PFC 2493' 2493' Production 1 001 9' 9-5/8" 500 Sx Class G & 300 Sx PFC 10088' 8593' Liner 1044' 7" 360 sx G 10802' 9238' Perforation depth: measured 10475' - 10505'. "~ true vertioa18944' - 8971' Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80 PCT @ 9694' MD; 4-1/2', 1~).6#, L-80 PCT @ 9792' MD. Anch0ra~3 Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BAKER SAB PACKER @ 9690' MD. 5-1/2' CAMCO BAL-O SSSV @ 2191' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (seeattached) 0 NA Treatment description including volumes used and final pressureRIGI L 14. Representative Daily Average Production or Injection Data OiFBbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure · Prior to well operation 1889 40733 - 4114 - 1172 Subsequent to operation 596 3813 3550 268 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil .__X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~ ~ 'ritie Arco Engineering Supervisor Date Erin Oba *' Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 14-32 DESCRIPTION OF WORK COMPLETED ACID WASH / LARC SQUEEZE & REPERFORATION Date Event Summary 5/30/1998: 7/27/1998: 7/30/1998: 8/10/1998: 8/15/1998: 12/10/1998: A CTU Acid Wash/LARC Squeeze for Gas Shutoff were performed as follows: MIRU CTU. PT'd equip to 4000 psi. Killed well w/1% .KCL Water & Crude. RIH & tagged PBTD @ 10553' MD. Reciprocated an Acid Wash across the open perforation intervals listed below: 10353' - 10373' MD (Zone 4) Reference Log: BHCS 8/25/1983. 10470' - 10510' MD (Zone 3) Pumped: (a) 25 bbls of 2% NH4CL w/Citric Acid, followed by (b) 15 bbls of 50% Diesel, 40% Xylene, 10% Musol, followed by (c) 75 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 2.5 bpm, followed by (d) 25 bbls of 6% HCL - 0.75% HF, & 3% Acetic Acid @ 2.5 bpm, followed by (e) 25 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 2.5 bpm, followed by (f) 5 bbls of 1% KCL Water, followed by (g) 91 bbls of 2% NH4CL w/50 Ib/Mgal Citric Acid, @ 2.5 bpm, followed by (h) 55 bbls of 1% KCL Water @ 0.5 bpm, followed by (i) shutdown. Pumped 10 bbls of Neat Latex Acid Resistive Cement, followed by 10 bbls of LARC w/20 PPB Aggregate, followed by 24 bbls of Neat LARC to squeeze off the open perforations listed above. Unable to build & maintain sqz pressure of 2500 psi. Contaminated Cement w/ Biozan & cleaned out to 10552' MD. POOH w/CT leaving 500 psi on wellhead. RD. RIH & UR'd to 10550' MD. A CTU LARC Re-squeeze for GSO wsa performed as follows: MIRU CTU & PT'd equip. Killed well. RIH &tagged TOC @ 10547'. Pumped 10 bbls of Neat LARC, followed by 20 bbls of LARC w/Aggregate, followed by 10 bbls of Neat LARC to re-squeeze off the open perforations listed above. Placed 6 bbls of Cement behind pipe at a max sqz press of 2300. Contaminated Cement w/Biozan & cleaned out to 10520'. POOH. RD. RIH & UR'd f/10435' to 10510' MD. MIRU ELU. PT'd equip. RIH w/perf guns to PBTD @ 10506' MD & reperforated f/: 10475' - 10505' MD (Zone 3) Reference Log: BHCS 8/25/1983. Used 3-3/8" HSD carrier & shot all perfs @ 4 SPF, 60° phasing, random orientation, & balanced pressure. POOH w/guns. ASF. RD. RIH &tagged PBTD @ 10452' MD. Returned well to production & obtained a valid well test. Oil rate decreased by 1293 BOPD, but the decrease in gas rate provided an incremental rate benefit,~ E~L~(I~[~;),~.. e~.ulting in an NOB of 467 BOPD. ~~. . 2,E ]999 AJaska 0ii & Gas Cons. Anchorage 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__ 6. Datum of elavation (DF or KB feet): 69' RKB 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0,360 4. Location of well at surface: 40' FSL, 1292' FEL, Sec 4, T10N, R14E, UM. At top of productive interval: 2114' FSL, 2435' FNL, Sec 3, T10N, R14E, UM. At effective depth: At total depth: 2199' FSL, 2564' FEL, Sec 3, T10N, R14E, UM. 5. Type of Well: Development_X Exploratory__ Stratagrapic __ 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 14-32 9. Permit number/approval number: 83-122 10. APl number: 11. Field/Pool: Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: Effective Depth: measured 10900 feet Plugs (measured) line vertical 9325 feet measured 10548 feet Junk (measured) true vertical 9010 feet PBTD Tagged at 10548' MD (9/10/97). ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 2(7' 180C~ Poleset 81' 81' Surface 2424' 13-3/8" 2350 Sx Fondu & 2493' 2492' 400 S× PFC Production 10019' 9-518" 500 Sx Class G & 10088' 8592' 300 Sx PFC Liner 1044' 7" 360 Sx Class G 10802' 9237' Perforation Depth measured 10353 - I0373'; 10470 - 10510' t~ue vertical 8833 - 8851'; 8939 - 8975' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9694' MD; 4-1/'Z', 12.6#, L-80, PCT @ 9792' Packers and SSSV (type and rneasured depth) Baker SAB Packer @ 9689' MD; CamcoBaI-O SSSV@2190'MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see attached OiI-Bbl Pdor to welt operation 1471 Subsequent to operation 2382 14. 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations._X Representitive Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 26651 3146 1298 27355 2724 1461 i i6. Status of well classification as: O~ _X Gas ~ Suspended __ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Engineering Supervisor Date ~UE~I~IIT IN DUPt-lt~A'I'E 14-32 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/10/97: MIRU & PT equipment. Added Perforations: Reperiorated: RIH w/perforating guns & shot 20' of perforations as follows: 10353 - 10368' MD (7_2) Ref. Log: BHCS 8/25/83. 10368 - 10373' MD (7_2) Ref. Log: BHCS 8/25/83. Used 3-3/8" carriers & shot the peris at 4 spf at 60-120 degree phasing at under balanced pressure. POOH w/peri guns. Noted all shots fired. Rigged down. Retumed the well to production & obtained a valid well test. Drill Site: 14 Well: 32 Sat Jan 22 20:22:32 1994 K-VALVE DESIGN COS~-~NTS: i SET PRESSD~E: 645 PSIG @ 60 DEG F CLOSE (PSIG): 820 PSIG ' i . ::::::::::::::::::::::::::: : CC: ENGiNEERiNG FiLE / COORDINATOR PRB 24 ,**n ATTACHmeNTS) J.C. o~.~ / M.G. SHOEMJ~LE PRB 20 (WITHOUT A?TAC~%~NTS) James Fausett / Scott Piggott PRB 13 (CO~R ONLY) Rydeii Reints ATO 15 (WITHOUT ATTACH~.~NTS) STATE OF ALASKA (COVER ONLY) .DESIGNED BY: ~~ Drill Site: 14 Well: 32 'CK LGR FTP OIL %~TR 82 83 83 83. 83- 83 83 83 82 82 W~LL TEST DATA Sat Jan 22 20:22:33 1994 ~OR GLR LiQ PWF Pi SEPARATOR DATE SEL T~ PRES 0 914 986 77.6 10429 2332 4407 1995 2.79 161 833 01/16/94 Y 0 980 1081 75.9 10390 2501 4490 0 0.00 161 899 i2/31/93 0 990 1177 75.9 10551 2536 4896 0 0.00 163 884 12/17/93 0 939 1026 76.5 10230 2402 4369 2019 0.00 160 888 i2/01/93 950 1201 74.3 11109 2847 4685 995 1278 72.8 11090 3011 ,,u,~"~" 993 1342 71.9 11489 3218 4790 1004 1342 71.6 11663 3302 4739 922 1295 71.0 11198 3237 4479 973 1472 70.4 8370 2475 4978 9~ ,u 1468 71.8 7915 2228 5215 o o.oo 1~1 87s 11/o9/93 0 0.00 161 921 10i31/93 0 0.00 160 898 10/22/93 0 0.00 161 906 10/20/93 0 0.00 158 796 10/02/93 o o.oo 160 853 09/1019~ 0 0.00 163 850 08/28/93 ESC=EXiT; Fl=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSiTiVITY TABLE; P6=CHECKLIST; ~lu ACcePt, SFS=RESTORE W~LL TEST; CFg=CYCLE D~TA, SSSV DEPTH (~&EAS): 2190 FTP @ CLOSE (PSiG): 820 PRESS ADJUST~.~NT: 102 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROP USES BM TF~ AND WELL PI W~S C= ..01937e-3 N= 1.000000 NEW C= ..0365ie-3 ENTERED N= 1.000000 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~FINALS ~- ~5 1-19 ~10-1-93 * 1-22 ~2- I-/q /10-1-93 f~-t~ 1-29 / 10-8-93 2-16A c~y-i\ ~ ,"9-29-93 3-9 ~10-6-93 3-29 ~¢4~ 7q /10-6-93 3-31 ~10-5-93 3-32 ~t~o~/ ~10-5-93 3-33 ~0-10-93 4-4 ~-~ ~0-9-93 4-12 ~ 10-2-93 6-13 10-1-93 7-5 7~-~ 10-6-93 -28 10-9-93 -28 10-9-93 9-11'?t~"~ /10-4-93 9-13 /10-3-93 9-20 "77~ ~ ,- 10-7-93 ~10-1-93 12-22 ~0/-t~O /'9-28-93 /13-20 ,'10-2-93 ~, 13-20 ~' 10-10-93 14-3 lX5 ?:~-~ ~ ~ ~-25-93 14-3 Y ~-28-93 ~5-tZ~ 14-32 ~10-2-93 15-22 ~-~ ~9-30-93 ~%-~016-17 ~10-8-93 16-22 qO~ ~10-10-93 ~?~0 17-15 ~ 10-8-03 17-21qL~ ~10-4-93 Perf Record Run Ee~.Ji.e. aox d Run Prod Profile/<~oi~--~el ,~la~ Run Perf Record l~t~-~/~7 R~ Perf Record ~ ~ - ~ ~ R~ Completion R~ Pe~ Record R~ ~ak ~tect]5~a]~~/~ R~ 1, Pe~ Record ~100~- ~1~ R~ 1, Pe~ ~pth Con~ol/~/~ R~ 1, Completion R~ 1, /Completion R~ 1, ~od ~offie[~l~~i~ R~ 1, ~D~ B~t T~P R~ 1, ~ ~ct~N~l~i~a R~ 1, ~J ~offie i~l~el~/~a R~ 1, D~ Bmr T~P R~ 1, ~tch ~t~ i~-5~ R~ 1, CNTG/GR/CCL R~ 1, HLDT/~lc~ R~ 1, ~od ~offie/~a[~?~i~ R~ 1, Completion It~vq ~~ R~-L Completion R~ 1, ~od ~offiei~n]T~]~~ R~ 1, Inj ~offi~}~~6}~ R~ 1, ~ 6~-~%~ R~ 1, ~oduction~,~}~~/~ R~ 1, l"&5" q~So -%qCSch Flease sign and return th~ attached copy as r~ceipt of data. RECEIVED BY ~ Have A Nice Day! Sonya Wallace ATO-1529 ** # CENTRAL FILES # CHEVRON #BPX # STATE OF ALASKA The correct APl# for 1-22 is 50-O29-20848-00. The correct API# for 11-166T is 50-029-21581-00. The correct API# for 17-16 is 50-O29-22286-00. ARCO Alaska, Inc. P.O,Box 100360 Anchorage, Alaska 99510 DATE: 9-17-93 2-3 8-24-93 2-8 8-27-93 2-12 8-28-93 2-16 8-27-93 3-9 8-21-93 ~~ [33-15A 8-17-93 15A 8-28-93 4-78T 8-22-93 4-24 8-25-93 4-26 8-22-93 4-39 8-23-93 {5-15A 8-19-93 ~5-15A 8-19-93 5-17A 8-26-93 / :1o 10 8-20-93 6-19 8-24-93 ~6-24 8-2O-93 7-15 8-27-93 9-1 8-21-93 II1-1A 8-18-93' !11-1A 8-19-93 14-32 8-21-93 17-14 8-25-93 Prod Proffie/~l~-~ey~ Run Prod ProflleleeC~i~l~0 Run Pezf Record ~00-1 Pe~ Record ~-~z~ R~ Pe~ Record ~z~ ~od ~offie 1, 5" ~*~l~ch 1, 5" ~$-~ Sch 1, 5" 8ch 1, 5"~0-~t~ Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5"~~a~ Sch Prod Proffie/~~~R;;,, 1, 5" &~o~o---Sch l~,fll Burst TDTP Run 1, 5" Pe~ Reco~ ~z~-I~o~ R.~ 1, 5" Sch ~ ~r R.n 1, 5" ~~ Sch C~l~Z%~ ~r 11o7~ R~?n 1, 5'*~ch' ~,~1B~t ~ R-n 1, 5" ~7o ,. ScherZi P~ Record R~n I, 5" ~ ~ct/~}~~ Rim 1, 2" ~ml ~t ~ R.n 1, 5" ~od ~offie ~ ~l~~.n 1.5" ~%~ Sch Please sign and return ~/e attached copy as .receipt Of data. Have A Nice Dayt Sonya Wallace # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA Sch ATO-1529 ~oo---- 8ch~Z~6 t~zoo--- 8ch sch ~v0? 8ch~-J~z Sch The correct tPI# for 4-24 is 50-029-21508-00. The tPI# for 5-17A is 50-029-20271-01. Drill Site: 14 Well: 32 K-VALVE DESIGN Mon Dec 28 16:25:33 1992 DOME SET PRESSURE: 395 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 400 PSIG K-VALVE CLASS ( A, B, C ): B COMMENTS: K-valve might be dumped by openin9 the drain system and/or going to a depressured test sep. If this doesn't work, the k-valve will have to be bench tested. CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) J.E. FAUSETT / C.W. SHUMWAY PRB 13 (COVER ONLY) T.L. RUT ATO 1578 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: MMM Drill Site: 14 Well: 32 CK LGR FTP OIL %WTR 83 83 83 51 83 83 83 66 65 83 65 78 WELL TEST DATA Mon Dec 28 16:25:39 1992 GOR GLR LIQ PWF PI SEPARATOR DATE SEL TEMP PRES 0 532 1868 71.0 9808 2836 6459 1555 3.16 156 251 12/22/92 Y 0 759 1672 73.0 10005 2700 6195 1836 0.00 157 247 12/13/92 0 788 1704 72.4 9497 2613 6192 1885 0.00 158 250 12/12/92 0 1466 377 59.4 8677 3521 929 2596 0.00 116 242 12/10/92 0 534 1847 74.8 8714 2190 7347 1678 0.00 163 242 11/30/92 0 928 988 78.5 2263 485 4608 0 0.00 161 909 11/23/92 0 953 1042 77.8 3170 700 4713 0 0.00 162 936 11/19/92 0 820 1377 74.1 9535 2463 5330 1874 0.00 155 229 10/19/92 0 912 1320 73.4 9052 2399 4981 2006 0.00 154 225 10/05/92 0 588 1946 73.3 9727 2594 7295 1735 0.00 160 239 09/23/92 0 909 1242 76.4 9385 2209 5275 2061 0.00 155 228 09/15/92 0 571 1664 77.1 9106 2077 7295 1735 0.00 163 235 09/14/92 ESC=EXIT; Fi=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2190 FTP @ CLOSE (PSIG): 400 PRESS ADJUSTMENT: 114 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI WPS C= ..14227e-3 N= 1.000000 NEW C= ..14079e-3 ENTERED N= 1.000000 Drill Site: 14 Well: K-VALVE DESIGN Sctn Nov 01 10: ..-'..,~.-' .... .-' DOME SET PRESSURE: 480 PSIG ~ 60 DEG F' FTF' Q CLOSE (F'SIG): 520 F'SIG K-VALVE CLASS (A,B,C): B COMMENTS: CC: tCeih~edy / Lash J.C. SMART / M.G. SHOEMAKE J-E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE Well currently operated in LF'. If switched, this should be redesigned. Designed here to dump at a full open choke, depending on GOR. May have to operate this high GOR well slightly pinched back. T. L. RUT F'RB 20 PRB 13 5/~_, ATO i ~o STATE OF ALASKA (COVER) DESIGNED BY: ~~ RECEIVED NOV O Y 1992 Alaska Oil & Gas Oons. Commission Anchorage STATE OF ALASKA ALASK'--~ -" AND GAS CONSERVATION ~ iISSIO_I~J~ ~.~ REPOR't = SUNDRY WELL OPP.:HATION I § ! ! 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM At top of productive interval 2114' FSL, 2435' FNL, Sec. 3, T10N, R14E, UM At effective depth At total depth 2199' FSL, 2564' FEL, Sec. 3, T10N, R14E, UM 5. Type of Well Development X Exploratory Strafigraphic RECEIVED N 0V - 6 1992 Alaska 0il & Gas Cons. Commission Anchorage 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-32 9. Permit number/approval number 83-122 10. APl number 50 - 029-20999 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10900 feet Plugs(measured) 9325 feet Effective depth: measured 10750 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1800# Poleset 81' 81' Sudace 2424' 13-3/8" 2350 sx Fondu & 400 sx PF 'C' 2493' 2492' Production 10019' 9-5/8" 500 sx Cl 'G' & 300 sx PF 'C' 10088' 8592' Liner 1044' 7" 360' CI 'G' 10802' 9237' Perforation depth: measured 10470-10490'; 10490-10500'; 10500-10510' true vertical 8939-8957'; 8957-8966'; 8966-8975' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9694' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9792' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9689' MD; 5-1/2", Camco BaI-O SSSV @ 2190' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 896 8956 949 2500 1697 ~.~ 9017 5448 1357 Tubing Pressure 1745 387 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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 ~~~'~ ~' ~r Title Senior Engineer Form 10-404 Rev 06/15/88 ~ ~.n-R Wnlln~.~./l').~ l=nnr/.I W P~_irn~_ SUBMIT IN DUPLICATE SUMMARY OF WELL OPERATIONS ARCO Alaska, Inc. perforated DS 14-32 over a selected interval in Zone 3 of the Prudhoe Bay Unit on 2/28/92 (10500'-10510'MD Ref Log: BHCS 8/25/83). Produced fluids were in the wellbore at the time of perforating. A short summary of the work is given below. - Began perforating operation on 2/28/92. - RU perforating unit and pressure tested equipment to 3500 psi. - RH-I w/gun #1, tied-in, and shot #1' 10500'-10510'MD @ 4 spf - POOH. All shots fired. - Secured well. RD. RE6EIVED NOV - 6 1992 Alaska Oil & Gas Cons. (;ommission Anchorage TLR 9/29/92 K-VALVE DESIGN Sun May 10 14:23:05 1992 DOME SET PRESSURE FTP @ CLOSE (PSIS): K-VALVE CLASS -(A,B,C) 680 PSI~ @ 60 DE~ F 875 PSI~ A COMMENTS: Re-run valve following add-perfs in late February. FTP has risen with GOR. Well is very stable in HP. CC: C.P. FARMER / W.D. COOPER J.C. SMART / M.G. SHOEMAKE J. E . FAUSETT / C . W. SHUMWAY EN~INEERIN~ WELL FILE PRB 24 PRB 20 PRB 13 J.L. BACAK ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: ~4s Printing contents of current screen - wait for message to clear RECEIVED MAY 2 1 1992: Alaska Oil & Ga~ Cons. Commission Anchorage Drill Site: 14 Well: 32 Sun May 10 14:23:34 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2190 FTP @ CLOSE (PSIG): 875 PRESS ADJUSTMENT: 181 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI ' CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 83 0 1053 1803 61.2 9205 3563 4657 2056 2.99 157 0 05/07/92 Y CONDITIONS AT CLOSURE: 83 0 875 2026 61.2 9205 3563 5235 1856 2.99 157 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 176 177 PRESSURE @ SSSV: 1267 1087 DOME SET PRESSURE: 680 PRIOR DESIGNS: DATE: 10/26/91 SET PRESSURE: 550 FTP @ CLOSURE: 850 Ol/O1/81 o o Ol/Ol/81 o 0 TEMP: PIPROF NA NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..43656e-5 N= 1.374860 NEW C= ..31436e-5 ENTERED N= 1.374860 Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 32 CK LGR FTP OIL %WTR 83 84 76 77 84 84 84 84 61 75 60 WELL TEST DATA Sun May 10 14:23:39 1992 GOR GLR LIQ PWF PI SEPARATOR DATE SEL . ~- ~ TEMP PRES 0 1053' 1803 6'1.2 9205 3563 4657 2056 2.99 157 910 05/07/92 Y 0 1021 2400 53..6 8911 4132 5175 2032 0.00 158 893 04/18/92 0 11.67 1989 57.2 9275 3967 4650 2192 0.00 155 930 04/06/92 0 1131 2071 55.1 8588 3851 4619 2144 0.00 156 901 03/26/92 0 '977 1850 6'1.8 8107 3089 4855 0 0.00 158 847 03/21/92 0 980 1862 63.6 7913 2876 5123 0 541 1957 80.1 7443 1480 9843 0 449 1822 73.0 6548 1764 6764 168 387 1697 76.2 5313 1285 7145 0 1745 896 51.4 9996 4854 1845 0 1172 1889 55.3 9619 4293 4232 0 1845 820 54.4 10692 4865 1802 0 0.00 160 907 03/12/92 0 0.00 158 232 03/05/92 0 0.00 162 238 03/04/92 0 0.00 165 234 03/02/92 0 0.00 131 874 01/05/92 0 0.00 151 888 01/02/92 0 0.00 128 875 01/01/92 ESC=EXIT; Fi=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2190 FTP @ CLOSE (PSIG): 875 PRESS ADJUSTMENT: 181 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI WPS C= ..43656e-5 N= 1.374860 NEW C= ..31436e-5 ENTERED N= 1.374860 Printing contents of current screen - wait for message to clear ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 3-35 4-3 4-3 4-7ST 5-14 6-21 9-43 ?/-~-z~, 1 I-3A ~3--I zz~ 14-32 2-19-92 GR/Perf Rnn 1, 5" HLS 2-25-92 Collar R,m 1, 5" HI~ 2-21-92 CCL/Perf R-n 1, 5" HLS 2-9-92 Perf Record R-n 1, 5" HI~ 3-2-92 Perf Record R~_m 1, 5" HI~ 3-2-92 Perf Record R~_m 1, 5" ItLS 2-11-92 Perf Record R~_m 1, 5" HLS 2-22-92 CCL/Perf Rnn 1, 5" ~ 2-12-92 Perf Ru_n 1, 5" HLS 2-23-92 CCL/Peff Run 1, 5" HLS 2-28-92 Perf Record Run 1, 5" HLS ~--~/k/17-11 2-28-92 Perf Record R~_m 1, 5" HLS Please sign and return the attached copy as receipt of data.~ ~ C ~ ~ ~ ~ 0 RECEIVED BY Have A Nice Dayl Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILF~ R&D # BPX # STATE OF ALAS~ TEXACO * The correct APl# for 11-3A is 50-029-20666-01. ARCO ALASKA, INC. F'.O, BOX i00368 ANCHORAGE, ALASKA .995 DATE' ii-27-9i REFERENCE.: ARCO CASEB HOLE FINALS ~JS i i-24-9i TUBING CUTTER ~~4-39 i i-t 7-9i CET ~¥-39 ii-,7-~i SPIN/TEHP INJECTION ~~ ii-i6-~ti t-i 6-9iCOLLAR-F'ERFGR ~xi3 i i-i 3-9i VERTILOG /~-3 ti-2~-9i CCL (PERF) -i4 t~,-2~,-9t INJ PROFILE -3i ii-24-9i CCL (F'ERF) ~3-4 i i -~-9 t COLLAR-F'~F ~-2 ie-27~9i PROD F'ROFILE RUN t, RUN t, 5" RUN t, RUN t, 5" RLIN i, RUN t, 5' RUN RUN i, 5" RUN i, 5" ~UN i, RUN i, '~"&5" ...4 -3 iO-ig-9i LEAK DETECT RUN i, -32 i,~-i8-9i PROD PROFILE RUN i, PLEASE SIGN AND RE.T, JS~.'N THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED SONYA WALLACE DEC 0 2 1991 APPROVED ATO-i 52~ TRANS~ DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION . ~ ~ BPX EXXON ~ ~ STATE OF ALASKA MARATHON .TEXACO MOBIL ATLAS $CH ~CH ATLAS ATLAS ATI_A~ ATLAS CAMCO ATLAS ~TI_A£ CAMCO CAMCO CAMCO Drill Site: 14 tWell: 32 K-VALVE DESIGN Thu Oct 17 09:28:11 1991 DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A,B,C): 550 PSIG @ 60 DEG F 850 PSIG A COMMENTS: Initial K-Valve design. CC: C.P. FARMER / W.D. COOPER~' K.M. KENNEDY / L.D. LASH Ralph / Brassfield PRB 15 ENGINEERING WELL FILE PRB 24 PRB. 20 Larry Bacak ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: Matt Maguire Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 32 Thu Oct 17 09:19:47 1991 K-VALVE DESIGN SSSV DEPTH (MEAS): 0 FTP @ CLOSE (PSIG): 850 PRESS ADJUSTMENT: 141 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 84 0 993 2105 48.6 8142 4184 4096 1881 2.35 151 0 10/01/91 Y CONDITIONS AT CLOSURE: 84 0 850 2308 48.6 8142 4184. 4491 1720 2.35 151 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 157 159 PRESSURE @ SSSV: 995 853 DOME SET PRESSURE: 550 PRIOR DESIGNS: DATE: 01/01/81 SET PRESSURE: 0 FTP @ CLOSURE: 0 TEMP: NA 01/01/81 0 .-.. 0 NA 01/01/81 0 0 NA ESC=EXIT; FI=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVI-TY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 32 Thu Oct 17 09:26:41 1991 SENSITIVITY TABLE P.I.. 2.35 2.35 2.35 2.35 %WTR 48.0 48.0 70.0 70.0 ~OR 8142 9500 8142 9500 LGR 0 0 0 0 FTP 1 900 903 904 901 901 FTP 2 850 853 854 851 852 FTP 3 100 130 100 134 145 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; FI=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; Printing contents of current screen - wait for message to clear STATE OF ALASKA ~'" !/ ! '~' ' ALASKA - .. .~- .. ,A, ND GAS CONSERVATION CC llSSION REPORT Or SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM At top of productive interval 2114' FSL, 2435' FNL, Sec. 3, T10N, R14E, UM At effective depth At total depth 2199' FSL, 2564' FEL, Sec. 3, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-32 9. Permit number/approval number 83-122/90-288 10. APl number 50 - 029-20999 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10900 feet Plugs(measured) 9325 feet Effective depth: measured 10750 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1800# Poleset 81' 81' Surface 2424' 13-3/8" 2350 sx Fondu & 400 sx PF 'C' 2493' 2492' Production 10019' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 10088' 8592' Liner 1044' 7" 360' Cl 'G' R E ¢ E IV E [ 3802' 9237' MAR - 7 t991 Perforation depth: measured 10470-10490';10490-10500' Alaska 0il & 6as Cons. Commission Anchorage true vertical 8939-8957'; 8957-8966' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9694' MD; 4-1/2", 12.C::~, L-80, PCT tail @ 9792' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9689' MD; 5-1/2", Camco Bal-0 SSSV @ 2190' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 161 222 291 3435 3326 2800 Tubing Pressure 223 285 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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 ,~w.,_-_ - f ~4,Jl~ J,~,~., Title Sr. Area Operations Engineer Form 10-~r04 Rev 06/15/88 DS 14-32 DESCRIPTION OF WORK COMPLETED SELECTIVE HCL ACID STIMULATION TREATMENT 6/20/90: A selective HCl Acid Stimulation using an inflatable packer was performed as follows: MIRU CT & PT equipment to 4000 psi. Loaded wellbore w/225 bbls of Dead Crude. RIH w/CT mounted inflatable packer & set packer at 10464' MD (middle of element), to isolate squeezed perforation intervals at: 10315 - 10317' MD (Z4) 10319 - 10349' MD (Z4) 10368 - 10378' MD (Z4) 10450 - 10460' MD (Z3) Ref. Log: BHCS 8~25/83. Treated open perforation intervals below the packer at: 10470 - 10490' MD (Z3) Ref. Log: BHCS 8/25/83. 10490 - 10500' MD (Z3) Pumped: a) 50 bbls 12% HCI w/10% Xylene, followed by b) 15 bbls OSR Diverter, followed by c) 48 bbls 12% HCl w/10% Xylene, followed by d) 5 bbls Diesel Flush, followed by e) 30 bbls Crude, followed by f) 20 bbls Diesel. POOH w/packer assembly. Rigged down. Obtained a valid production welltest. REEEIVED Alaska Oil & Gas Oons. Anchorage ALASKA OJ.L. AND GAS CONSERVATION CO~U4,~4ISSION REPORT ': SUNDRY WELL OPt_ :ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X , ~ Pull tubing Alter casing .~. Repair well Other X 2. Name of Operator ARCO Alaskat Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM At top of productive interval 2114' FSL, 2435' FNL, Sec. 3, T10N, R14E, UM At effective depth At total depth 2199' FSL, 2564' FEL, Sec. 3, T10N, R14E, UM 5. Type of Well Development X Exploratory Stral~graphic 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-32 9. Permit number/approval number 83-122/9-673 10. APl number 50 - 029-20999 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10900 feet Plugs(measured) 9325 feet Effective depth: measured 10750 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor ' 81' 20" 1800 sx Poleset 81' 81' Surface 2424' 13-3/8" 2350 sx Fondu & 400 sx PF 'C' 2493' 2492' Production 10019' 9-5~8" 500 sx CI 'G' & 300 sx PF 'C' 10088' 8591' Liner 1044' 7" 360 sx CI 'G' _10802' 9236' RECEIVE D Perforation depth: measured 10470-10490'; 10490-10500' {~,~y 1 0 !990 true vertical 8938-8956'; 8956-8966' Alaska 0il & Bas Cons, Commission Anch0ra~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9694' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9792' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9689' MD; 5-1/2", Camco Bal-0 SSSV @ 2190' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 1'5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Reoresentative Daily Averaoe Production or Injection Data _ OiI-Bbl Gas-Mcf Water-Bbl 801 11720 1014 625 578 502 16. Status of well classification as: Oil~ Gas . Suspended Casing Pressure .. Service Tubing Pressure 1390 230 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic, lned Title Date Form 10-404 Rev 06/15/88 _":l~cl I~! .I Rrnwn ~.~.: J_ ~mber. ATO-1478 P1{14,32)W1-3 SUBMIT IN DUPLICATE DS 14-32 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER & GAS SHUT-OFF 9/8/89: MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. RIH w/CT & pumped 188 bbls of crude, then washed perforations at: 10470 - 10490' MD Ref. Log: BHCS 8/25/83. 10518 - 10528' MD 10528 - 10550' MD Pumped the following treatment: 25 bbls Diesel, followed by, 47 bbls 12% HCl w/10% Xylene, followed by, 47 bbls 12-3% HCI-HF, followed by 48 bbls 12% HCl. Displaced CT w/50 bbls of Diesel. POOH. Rigged down. 9/10/89: MIRU & RIH to run a Spinner/Temp survey. No tubing leaks were detected. POOH. RD. 9/13/89: A cement squeeze and same day cleanout were performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater and diesel. Pumped 41 bbls of acid resistive cement, squeezing perforations: 10470 - 10490' MD Ref. Log: BHCS 8/25/83. 10518 - 10528' MD 10528 - 10550' MD Placed 7 bbis of cement behind pipe, at 2000 psi squeeze pressure. Pumped 221 bbls of 1-1/2# Biozan and 285 bbls of 1/2# XCD to contaminant and circulate cement out of the wellbore. POOH while displacing CT w/Meth - Water. RD. 9/14/89: MIRU, and RIH to tag bottom at 10574' MD. POOH. Rigged down. 9~20~89: MIRU, and RIH to change out DGLV at station #1. POOH w/DGLV, then RIH and set OGLV into station #1. POOH. Rigged down. 9/22/89: Reperforated: 10470- 10490' MD Ref. Log: BHCS 8/25/83. Added perforations: 10490 - 10500' MD Ref. Log: BHCS 8/25/83. Returned well to production and obtained valid production test. NoT~ ." Oil rate decreased by 176 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1393 BOPD, resulting in a net oil benefit of 1217 BOPD. ARCO Alaska, Ir Prudhoe boy I=ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 · Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 1, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-32, Permit No. 83-122 Dear Mr. Chatterton: Attached is the Application for Sundry Approval in triplicate detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 14-32)W1-3 RECEIVE '?- ?'/IA\' o 2 Oil & 6as Cons. C0rnrniss/0~ Anch0rag~ ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASF'-"-'" AND GAS CONSERVATION --'"/IISSION/3 ~ APPLIC,. ', iON FOR SUNDRY APHROVAE. S 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approv--=~ program "~ull tubing Vadance perforate Othe'r 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM At top of productive interval 2114' FSL, 2435' FNL, Sec. 3, T10N, R14E, UM At effective depth At total depth 2199' FSL, 2564' FEL, Sec. 3, T10N, R14E, UM 8. Well number 14-32 9. Permit number 83-122 10. APl number 50 - 029-20999 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10900 feet Plugs(measured) 9325 feet Effective depth: measured 10750 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1800 # Poleset 81' 81' Sudace 2424' 13-3/8" 2350 sx Fondu & 400 sx PF 'C' 2493' 2492' Production 10019' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 10088' 8592' Liner 1044' 7" 360 sx CI 'G' 10802' 9237' Perforation depth: measured 10470-10490'; 10490-10500' true vertical 8939-8957'; 8957-8966' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9694' MD RECEIVE ..'J~ska.Ojl & Gas Cons, C0mr~issi0r~ ' ~ ~ch0rag~ Packers and SSSV (type and measured depth) Baker SAB packer @ 9689' MD; 5-1/2", Camco Bal-0 SSSV @ 2190' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby certify that th_e foregoing is true and correct to the best of my knowledge. Signed ~d.-'/~~/2~~____.~~ Title Operations Engineering Manager FOR COMMISSION LI~I:: ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- 15. Status of well classification as: Gas Suspended Date Approved by order of the Commissioner Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 Commissioner App[uvucl Cupy R~..eturned ~ SUBMIT IN TRIPLICATE D.S. #14-32 Full-Bore HC]/Xylene Si:imul~tion Preliminnry Proced~ Objective: Remove near wellbore damage (suspected to be calcium carbonate) with a full-bore acid job. Target interval will be the open Zone 3 perforations. 1. RU slickline unit. RIH with TTL and tag fill. Dummy off GLMs. NOTE: If level of fill is above 10515', a coiled tubing FCO is recommended before proceeding with the acid job. 2. RU acidizing equipment. Run hardline to the companion valve and pressure test same to 4000 psi. Pump the following sequence of fluids: a) 300 bbls of dead crude pumped at 5-6 BPM to fluid pack the well b) 150 bbls of 12% HC1 - 10% dispersed Xylene c) 250 bbls of dead crude displacement (to the top perfs) Ensure that acid transport is rolled immediately before pumping. When pumping the acid and dead crude displacement, limit injection pressure to 1000 psi to limit pumping rates and maximize contact time with the scale. 3. After acid is displaced into the formation, RD acid equipment and prep well for flowback. 4. Return well to production with gas-lift (if necessary). Test well frequently after stabilization. . If production rates increase dramatically, a full-bore scale inhibitor pump-in will be recommended to inhibit future calcium carbonate deposition. '_AnchoTa~ 6 ,5 4 2 COILED TUBINg UNIT BOP EOU l PI, ENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLAI~0E 2. 5000 PSI 4 1/16" PIPE RAMS ,1. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ~g)0 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/1~6" STUFFING BOX H]REL]NE BOP EOUIPMENT _ 1. 5000 PSI 7" WELLHEAD CONN£CIOR FLANGE :2. 5000 PSI WIRELIN[ RAIaS (VARIABLE SIZE) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC. P.O. BOX I~0360 ANCHORAGE, ALASKA 995t0 DATE: 4-6-9~ REFERENCE' ARCO CASED HOLE FINALS ~-3'~~. 3-t 9-90 3-20 3- t 5-90 3-27 3-t 4-90 7-8 3-~9-9~ 7-~7 ~-~ 8-98 7-2 ~ 3- ~ 8-9~ t3-6 3-1 7-9~ ~ 4-32 3-~ 7-9~ ~4-3~ 3-~ 6-9~ J6-J9 S-~ 6-9~ PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION PRODUCTION PROFILE INJECTION PROFILE/F'IT~ GAS LIFT SURVEY LEAK DETECTION LEAK DETECTION RUN RUN RUN RUN RUN ~, 2'&5' RUN RUN RUN RUN RUN F'LEA~E SIGN AND RETURN THE ATTACHED COPY A~' RECEIPT OF' DATA HAVE A NICE DAY, RECEIVED SALLY HOFFECKER AF'F'ROVED~ .TRAN ~-$ 9 35 DISTRIBUTION CENTRAL FILES CHEVRON D & M' EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES BF'X STATE OF ALASKA TEXACO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ARCO ALASKA, INC F'. O. BOX i ANCHORAGE, ALASKA 995i DATE' ~0-9-89 REFERENCE: ARCO CASED HOLE FINALS t-? i -22 5-2i 7-'2S i i-8 ii-9 i 4-25 i4-27 i 4-S'~ .. iT-S i8-24 NGI-i NGI-8 9-27-89 F'ERF RECORD 9-2'7-89 PERF RECORD 9-30-89 CBT 9-20-89 PITS 9-24-89 LEAK DETECTION 9/24-25/89 INJECTION PROFILE i 0- i -89 9-25-89 · --- S-89 9-i ,~3-89 9-25-89 9-28-89 9-28-89 9-29-89 F'ERF RECORD INJECTION PROFILE INJECTION F'ROFILE LEAK DEl'ECl'ION--REV. F'RODUCTiON F'ROFILE COMF'LETION RECORD INJECTION PROFILE INJECTION PROFILE RUN i, RUN RUN t, 5' RUN RUN i, RUN i, 5' RUN RUN i, RUN i, 5' RUN t, ~'&5' RUN t, RUN i, 5' RUN i, 5' RUN t, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 DISTRIBUTION CENTRAL FILES $ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION $ BPX EXXON $ STATE OF ALASKA MARATHON ~- TEXACO MOBIL /S SCH SCH CAMCO CAMCO CAMCO $CH CAiqCO CAMCO CAMCO CAMCO SCH $CH $CH * THE CORRECTED AF'I~ F'OF.' ii-9 IS 5~-029-2i402. ARCO ALASKA, INC. F'.O. BOX i,30560 ANCHORAGE, ALASKA 995 t 0 DATE' 9-29-89 REFERENCE' ARCO CASED HOLE FINALS 5-t8 9-5-89 INJECTION PROFILE 4-S 9- t 8-89 CE'[ 4-20 9-t-89 INJECTION F'ROFILE 5-1 9 9-i 3-89 CET 6-5 9-t 0-89 LEAK DETECTION 6-9 9-9-89 PROD'UCTION PI;:OF' II_E 7-28 9-7-89 PRODUCTION PROFILE t t-25 9-24-89 COLLAR/PERF ~t-24 9-6-89 F'RODUCTION PROFILE ~ t-26 9-2i-89 COLLAR/PERF t4-S2 9-iG-89 LEAK DETE'CTION ~ 4-.S2 9-'2'2-89 PERF RECORD t6-4 9-t -89 LEAK DETECTION f7-t 9-4-89 PRODUCTION PROFILE i7-i 9-8-89 PITS RUN i ,.,-"'"' RUN t, 5' RUN i , 5' RUN t, ':~.," RUN t , i'&5' I;,'IJNt, 5" RUN i , RUN i , 5;' RUN I, 5" RUN t, 5' RUN t , i ' &5" RUN t, 5' RUN 1 , L".',"&5" RUN 1, 5" F<UN i , 5' PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIF'T OF DATA. HAVE A NICE DAYI ' iCTn -~' APPROVE' SALLY HOFFECKER $ ~ ATO i529 Oil&.asOon.Com ¢O - - TRAN$~ An~omge DISTRIBUTION CENTRAL FILES ~ F'HILLIF'$ CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION $ BPX EXXON ~ S'TATE OF ALAS'KA MARATHON ._ ~- TEXACO MOBIL [;ANCO L,.' C H C A ts C 0 ~' C I--i CAMCO CAMCO CAMCO A'FLA;S' CAMCO ATLAY CAMCO $CH CAMCO CAMCO CAMCO ARCO ALASKA.. F'~ 0 · BOX i ANCHORAGE: ALASKA 995 i 0 DATE' '9-6-89 REFERENCE' ARCO CASED HOLE FINALS i-2 8-i6-89 TEMP/FLL~ID DENSITY RUN i, t-J4 8-i7-89 PRODUCTION PROFILE RUN t.. 2-2,'5 8-24-89 COLLAR/F'ERF RUN i , S-6 8-28-89 COLLAR/PERF RUN t , S-28 8-i9-89 F'RODUCTION PROFILF RUN i, 6-2 8-i4--89 F'RODUCTZON PROFILE RUN t, ii-i~] 8-i8-89 INJECTION PROFILE/TEMF' RUN i , t 1-i8 8-2t -89 PRODUCTION PROFILE RUN t , i2-28 8-i3-89 F'RODUCTION PROFILF RUN i , i4-~2 8-i3-89 LEAK DETECTION RUN ~ , i 5-25 8-20-89 F']:TS RUN i , iT-ii 8-i8-89 F'RODUCT]~'ON PROFILE RIJN i , F't..FASE SIGN AND RETURN THF ATTACHED COPY AS RECE"IPT OF DATA, ii 5' 5' 5' 5' 5' 5' 5" 5' /I CAMCO CAMCO ATLAS A FI_AS C A hi C' 0 CAMCO CAMCO CAMCO [.'.ANCO CAMCO [;AMC[) CAMCO RECEIVED BY DISTRIBUTION CENTRAL FILES ~ ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL * THE CORRECTED AF'I~ FOR 1-.° IS 50-0..," o~_~{)053o ARCO Alaska, Inc. -- Prudhoe Bay .;ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 4, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-32 Permit No. 83-122 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/MJB/jp Attachment J. S. Dietz, BP J. Gruber, ATO-1478 PI(DS 14-32)W1-3 &!aska Oil & Gas Cons. Ar~charaga ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/'--'~". AND GAS CONSERVATION Cr""-"AISSION 0 ~ I ~ j ~ A [ APPLICA, ION FOR SUNDRY AF,-,ROVALS 1. Type of Request: Abandon Suspend Operation shutdown __ Alter casing Repair well Plugging Change approved program Pull tubing Vadance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM At top of productive interval 2114' FSL, 2435' FNL, Sec. 3, T10N, R14E, UM At effective depth At total depth 2199' FSL, 2564' FEL, Sec. 3, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other X 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-32 9. Permit number 83-122 10. APl number 50 - 029-20999 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10900 feet Plugs(measured) 9325 feet Effective depth: measured 10750 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 81' 20" 1800 sx 81' Su dace 2493' 13-3/8" 2350 sx 2493' Intermediate 10088' 9-5/8" 500 sx 10088' Production 10802' 7" 360 sx 10802' True vertical depth 81' 2492' 8591' 9236' Perforation depth: measured 10470-10490'; 10518-10550' true vertical 8939-9012' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, @ 9791' MD, pastic-coated tubing Oas Cons, Anchorage Packers and SSSV (type and measured depth) Baker SAB packer @ 9689' MD; Camco Bal-0 SSSV @ 2190' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation September 1, 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby,Aertify that the foregoing is true and correct to the best of my knowledge. Signed .~/~~ Z~ Title Operations Engineering Manager FOR COMMISSION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Original Signed By David W. Johnston Approved by order of the Commissioner L Form 10-403 Rev 06/15/88 15. Status of well classification as: Oil x Gas Suspended Commissioner Date Y .h7 Approved copy Returned SUBMIT IN TRIPLICATE Well 14-32 Coiled Tubing Unit Cement Squeeze Project AFE # AP 1107 Preliminary Procedure 1. Make a slickline tag run to verify PBTD. 2. RIH with CT. Wash the perforations with full strength mud acid. Flow well to produce out all the acid. Test the well. 3. RIH with coiled tubing and pack the wellbore with filtered seawater. 4. Pump 40 bbls cement followed by 2 bbls of water and 80 bbls contaminant. Hold 3000 psi surface squeeze pressure for 60 minutes. Squeeze off the following perforations: Zone P~rf0rati.on~ 3 10470-10490 2 10518-10550 (Ref. B H CS 8/25/83) e week. Immediately jet or reverse out the contaminated cement. Let cement cure for I 6. Perforate as follows: Post-Squeeze (Ref. BHCS 8/25/83) Zone in~rvo1 SPF Comment 3 10470-10490 FSD Reperf 3 10490-10500 FSD Add perf 7. Test the well. Other Well Information Current status: Shut in. Expected static bottomhole pressure: 3688 psi. @8800' SS Expected fluid in wellbore at reperforation: seawater. 6 ,5 4 2 C01LED IUBING UNIT BOP EOUIP~I~ 1. ~)OC)0 PSi?" WELLHEAD CONNECTOR FLANGE 2. SO00 PSI 4 1/16" PIPE RAIDS 3. ~K)O0 PSI 4'1/6" HYDRAI,R. IC SLIPS 4. ~)000 PSI · 1/6" ~ RAMS 5. SO00 PSI 4 1/6" BLIND KUdS 6. 5000 PSI 4 1/16" STUIrlrlI~ BOX 2 HIRELINE BOP EOUIPMENT 1. ~000 PSI ?" WELLHEAD CONNEC:1OR IrLANG[ 2. 5000 PSI WIRELIN[ RAUS (VARIABLE SIZE) :~.~)000 PSI 4 1/6" LUBRICAIOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF (.-'li-<E. LJ ~L.l-~,~.l~.~, .LI'.~U., F'-. O. BOX i ':)0366) ,"-'-' ~' "i "' : 9(;~ ~-ir,!t.,I--tCIF;,'AC-E ALASKA . ·. DATE' 4-26-89 REFERENCE' ARCO CASED HOLE FINALS i-5 4-7-89 i-!~ 4-7-89 i-t2 4/5-6/89 i-iT 4-8-89 5.--i0 3-27-89 5-ii 4-t-89 6-3 4-i-89 7--~'~ S-31-89 9-ii 3-23-89 il-8 4-5-89 i~-i8~ 4--i~-8~, i4-32 3-3e'-89 I5-6 4-9-89 t8-2¢ 4-3-89 PRODUCTION PROFILE PRODUCTION PROFILE/PITS F'RODUCTION PROFILE PRODUCTION PROFILE TEMF'/GAMMA RAY GAMMA RAY/i'EMF' SURVEY GAMMA RAY/TEMF' SURVEY GAMMA RAY/TEMP SURVEY F'RODUCTION F'ROF]:LE INJECTION PROFILE PITS GAMMA RAY/T'EMF' SURVEY LEAK DETECTION GAMMA RAY/TEMP SURVEY F'L_EAS'E SIGN AND REI'URN THE ATTACHED COPY AZ RUN t , RUN ~ , RUN 2, RUN i , RUN i, RUN i, RUN i, RUN t , RUN t, RUN i, RUN i, RUN t , RUN i , RUN I , .- RECEIPT OF' DA'FA,; RECI:'IVED BY ~~ HAVE A NICE ' --- ~ALLY HOFFEC AF'F'ROVED _ ATO- i 529 Alsska Oil & Gas Cons. Comm[ssioll TRAN$~ 89 t"~'6 Anchorage 5" 5" 2"&5" 2"&5" 2"&5" 5" 2" 2"&5" CAMCO CAMCO CAMCO CAMCO CAMCO C A M C 0 CAMCO C A M C 0 [;ANCO CAM(](') CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ~ ~ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTEN~'ION. EXPLORATION ~ BF'X EXXON ~- 3'TATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL * THE CORRECT AF']:~ FOR i-5 IS 50-,(-2':29-2r'.;,~76. ARCO ALA.".'KA, INC. F'.O. BOX t08368 ANCHORAGE, AL'ASKA 97510 DATE: 4-?-8? REFERENCE': ARCO PRESSURE DATA 2-2 3-26-89 BHF'--STATIC GRADIENT OTIS' 2-t3 3-26-89 BHP--$TATIC GRADIENT OTIS 2-16 3-23-89 BHP--£TATIC GRADIENT CAMCO 2-~ ? 3-22-89 BHF'--$TATIC GRADIENT OTI,~ 2-~8 3-30-89 BHF'--$TATIC GRADIENT OTI3' '7-3 3-38-89 BHP--$TATIC GRADIENT CAMCO 7-~7 3-~-89 BHP--£TATIC GRADIENT CAMCO 7-22 3-3t -89 BHP--S'FATIC GRADIENT CAMCO 7-29 3-30-89 BHF'--£TATIC GRADIENT CAMCO 7-38 3-3~ -89 BHP--£TATIC GRADIENT CAMCO i2-4 3-28-89 BHF'--FLOWING GRADIENT CAMCO ~2-J2 3-t 9-89 BHF'--FLOWING GRADIENT CAMCO t3-J4 3-~I-89 BHP--STATIC GRADIENT' OTIS t4-32 3-30-89 BHP--£TATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY A£ RECEIF'T OF DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER . ~~7",,.. (j;~ ~AF'PROVED ~.~__ ATO-t 529 ' Alaska Oil & (~as Cons. 6ommissioa ~chorage QIS'TRIBUTION CENTRAL FILES ' ~ ~ PHILLIPS CHEVRON F'B ~ELL FILES ..D&M ~ R&D EXTENSION EXPLORATION $- BF'X EXXON -.. ~ STATE OF ALASKA MARATHON ~ $ TEXACO MOBIL ARCO ALH~KA, INC. F'~O~ BOX ~00~60 ANCHORAGE, ALASKA DATE' ii-i0-88 REFERENCE' ARCO PRESSURE DATA t -i i 0-24-88 ~ -~ ? i t]-20-88 2-4 i 0-24-88 4-i ? t O-i.-~-88 4-3~. 9-'~ -88 4-32 °-~i, ~ -88 5-i i i ~-i 9-88 5-i ~ i ~-i 9-88 ~-i.~ i ~-i o-88, 6-i ? i ~-i 0-88 7-2 i 0-9-88 7-8 i ~-9-88 9-5 i 0-5-88 9-29 8-28-88 9-33 8-28-88 i 2-3 i ()-i 4-88 i 2-6 t 0-i S-88 i 2-i 0 i (3-i 2-88 i~o-'~, i ~--i 9-88 i 3-i i i 0-6-88 t 3-26 i ~3-6-88 i ~-28 i 0-6-88 i 4-i ~ 7-i 0-88 i 4-i~, ~ 6-~-88_ i 4-i 7 i 0-20-88 i 4--i 8 i ~,-7- ~o i 4-32 i ~-7-88 i~:~-7 i ~-8-88 i 5-i ~ i ~-9-88 i 5-i 5 i ~-8-88. i 5-i 9 i ~-8-88 i5-'~°~.~ i0-i7-88 i 5-25 i 0-20-88 i 6-7 i ~-22-88 PWDW3-i i~-i3-88 BHP--S'¥A'FIC BHP--STAi'IC BHP--$TATIC BHF'--PRESSU BHP--S'FATIC BHP--STATiC BHP--STA'FIC BHP--STATIC BHP--$TATIC BHP--$TATIC BHP--$TATIC GRADIENT GRADIENT GRADIENT RE FALL-OFF GRADIENT GRADIENT GRADIENT GRADIENT GRADIENT GRADIENT GRADIENT BHP--STATIC GRADIENi' BHP--FLOWING GRADIENT BHP--$TATIC GRADIENT BHP--STATIC GRADIENT BHP--FLOWING GRADIENT BHF'--FLOWING GRADIENT BHP-~F'LOWING GRADIENT BHP--STATIC GRADIENT BHF'--$TATIC GRADIENT BHF'--$TATIC GRADIENT BHP--$TATIC GRADIENT BHP--F'LOWING BHP--STATIC ~HF'--$'¥AT lC BHF .... STATIC BHF'--STATIC BHP--$TA'FIC BHP--STATIC BHP--$TATIC BHP--$TATIC BHP--$TATIC GRADIEN'F GRADIENI' GRADIENT GRADIENT GRADIENT GRADIENT GRADiEN'F GRADIENT GRADIENT GRADIENT BHP--$TATIC GRADIEN'F BHF'--FLOWING GRADIENT BHP--STATIC GRADIENT F'LEASE SIGN AND RETURN I'HE ATTACHED COPY AS RECEIF'T OF DISTRiBU'FION F: c ~ ~'RA L_.,_., -., F I L E:'i' ~ !::'H I I... L. -.,-'"' D & M .~ F.: ~: D EXTEN~ I Oi'-~ EXPLORA'f' i Oi'"~ '~ .S' A I'-" C -¢,- EXXON .~ STAi'E OF AI_A,'~'KA iqAR A TH;Oi'.4 ~ TE×AG0 ~ HOBIL CAMCO CAMCO CAMCO CAMCO OTIS OTIS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DATA · y ~. .. ~.:~ 'i/', ....-'~ .... :::, .i ,.." '2 '2' o ~:~ I:.~... t ''~ : 4 "~ (-'.'..i') i .... i:~ ~.:~ __.~- . '1- ,..3 .-: !"~ , . -,- .~ -- I ........ i'l I I . . :- · i /';':::' ."~ '::..: ...... ;--. f:',' I::' t ,.'.'-, ..... 4 :. ............ ,..;,.., K! ~'; T --- % .4 ..... '::'-' '7 .-.. :::~ :::~, !::'b.I I".',1:.t ''~ i ~:: "' .... '~ '-':~ .-.. '-' ~"- ..~- f'! !.,.! l) b.I .... i',J b.I 4- · ? "2 .-. c:, :::'.,, I:L' I:.!' Ii: I:' T V !:' 1') R Y PF'f';IT, Y I~ F' F:' I:~' (.! V F: l)~. ,. 1) ]' .~'¥ R' T R I.I T T [I :~ !i.'. I:.~ N T R ¢~ L F' '[ I.. F.~ · .'~' I': 14 F'.' V I'1' fl.. N I) A M ~ EXXDN '"' · #. .. I::' I.-I T I...I .. :[ F',.g' F'R LIFI.. L F T I. F',~ R & I) ,~ T ATF..: .r. IF. , AI.,.AXK ¢~ 'rExnc[) ARCO Alaska, Inc. Prudhoe Bay ,b.,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 28, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re' DS 14-32 Approval Number 8-165 Enclosed is the Report of Sundry Well Operations and Well Completion Report detailing work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/MRC/sd Enclosures CC' Standard Alaska Production Company File' P1(DS14-32)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/-..,~L AND GAS CONSERVATION COMMI,..,ON REPORT OF SUNDRY WELL OPERATIONS Operation shutdown ~ Stimulate [] Plugging ri, Perforate,~ Pull tubing 1. Operations performed: Alter Casing ~ Other © 2. Name of Operator ARCO Ala~ka~ Tn¢_ 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 40'FSL, 1292'FEL, Sec. 4, T10N, R14E, UM At top of productive interval 2114'FSL, 2435'FWL, Sec. At effective depth 2180'FSL, 2626'FEL, Sec. At total depth 2199'FSL, 2564'FEL, Sec. 11. Present well condition summary Total depth: measured true vertical 3, TION, R14E, UM 3, TION, R14E, UM 3, TION, R14E, UM 10900 feet 9325 feet Plugs (measured) Effective depth: measured 10750 feet true vertical 9191 feet Junk (measured) 5. Datum elevation (DF or KB) 6q ' RKR Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 14-32 8. Approval number 8-165 9. APl number 50-- 029-20999 10. Pool Prudhoe Bay 0il Pool Casing Length Size Conductor 81' 20" Surface 2493' 13-3/8" Intermediate 10088' 9-5/8" Producti on 1044' 7" Cemented Measured depth 1800# Pol eset 81' 2350 Sx Fondu & 2493' 400 Sx PFC 500 Sx Class G & 10088' 300 Sx PFC 360 Sx Class G 10802' ~ue Vertical depth 81' 2493' 8593' 9238' Perforation depth: measured 10470-10490' 10518-10550' true vertical 8939-9012' Tubing (size, grade and measured depth) 5½"; 17#, L-80 @ 9694'; Plastic coated tubing; 4½" tubing tail, L-80 @ 9792' Pa..ckers an..d SSSV ltvpe and measured depth) bamco ~a]-0 S$SV @ 2190'HD; Baker "SAB" Packer @ 9689'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure N/A 258 N/A 317 Copies of Logs and Surveys Run ~ 42 2300 150 2288 3200 2750 !4. Attachments Daily Report of Well Operations 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Submit in Duplicate 14-32/STAT17 Sharon K. Allsup-Drake (263-4247) Began perforating operation on 3/19/88. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 10470-10490'MD, (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Secured well. RD. Ref: BHCS 8/25/83 STAT17:SN 4-29 STATE Of ALASKA '"~' /'~, .2 ALASKA ulL AND GAS CONSERVATION CCtv, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] OIL 2. Namel' of Operator 7. Permit Number ARCO Alaska, Inc. 83-122 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20999 4. Location of well at surface 9. Unit or Lease Name 40'FSL, 1292'FEL, Sec. 4, T10N, R14E, DM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2114'FSL, 2435'FWL, Sec. 3, T10N, R14E, UM 14-32 At Total Depth 11. Field and Pool 2199'FSL, 2564'FEL, Sec. 3., T10N, R14E, DM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 69 ' RKB ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 08/05/83 08/24/83 09/08/83 N/A feet MSL ' 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+'FVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10900'MD, 9325'TVD 10750'MD, 9191'TVD YES~ NO []I Nipple La 219deetMD 1900' (Approx.) 22. Type Electric or Other Logs Run GR/FDC/CNL/Cai~ BHCS/GR~ CBL~ Gyro 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 S~rf. 81' 30" 1gOO~ pm1 13-3/8" 72.0~A L-80 Surf, 2493' 17~" 2350 sx Fondu & ~00 mx t'F "C" 9-5/8" 47.0~ L-80 Surf, 10088' 12~" 500 .~x C]mm~ G & 300 .~× PF "C" 7" 29.05A L-80 9758' 10,802' 8%" 360 sx Class G , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5~ q6qf+' q~,Rq 10470-10490 'MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10518-10550'MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8939-9012'TVD 9922-992&' 1(~O .~× P.I~.q.~ Ref: BHCS 8/25/83 ]01~a-lOlaO' ~ ~w P.~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 4/04/84 Gas Lift Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO 4/08./88 8.0 TEST PERIOD I~ 763 1065 91 &~. R";° 1400 F'10w Tubing Casing Pressure C'ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 317 24-HOUR RATE ~ 2288 3195 2750 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . ,. Form 10-407 Submit in duplicate// Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARIZ,:~-RS 'I~ORMATION TESTS . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10218' 8710' N/A O/W Contact 10627 ' 9080 ' Base Sadlerochit 10850' 9281' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~~~ ~~ Title Opr. Engr. Mgr, Date ~//Z ~/~" ~''' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO AI...A,.~KA: IN.P, F'., O, BOX ANCHORAGE, AI...A,.~K A 995t DATE' REFERENCE' ARCO CA.~ED HOLE FINAl... PI...F.;A,~F..,_¢,.'I(.;N AND RF'I"I..IF,'N THE ATTAI-:HFD t-:FIF'Y AX' RFRETF"I' FIF' DATA.. o ommission Anchorage F'IE¢; f.7, Y B Ei'JNF..'.T T ATO- ~ ..%. 79 TRAN,~ '~:..c.18...?~)t ~ AF'F'RF, IVEO DI~TRTRUTION ,? [.'. N .~EN ATI...A..? AI'I..AY; ATI .A~ f.] EiN T F-,' A t_.. F:' l I.._F..~ CHEVRON ~: F%TEN,.ST[IN EXF'I..ORATION ~ F¥¥fJH H A F,'A'T I-I 0 t'J ,,.-"'H O F{ T I .. F'H I !..I...T. F'.~.;' F'R I,JFI.. I FTI. I:',~ .?APE .STATE F}F AI...A,~KA ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 8, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: DS 14-32 Permit Number- 83-122 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/SKA'sd Enclosures cc' Standard Alaska Production Co. File P1(14-32)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE Of ALASKA ALASKA ,.,,L AND GAS CONSERVATION COMM~,_.,i'ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program I~. Plugging ~ Stimulate ~ Pull tubing -~ Amend order ' Perforate 3( Other 2. Name of Operator ARCO Alaska. Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 40'FSL, 1292'FEL, Sec. 4, T10N, R14E, UN At top of productive interval 2114'FSL, 2435'FWL, Sec. 3, T10N, R14E, UN At effective depth 2180'FSL, 2626'FEL, Sec. 3, T10N, R14E, UM At total depth 2199'FSL, 2564'FEL, Sec. 3~ TION, R14E, UN 5. Datum elevation (DF or KB) 69' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 14-32 8. Permit number R3-!22 9. APl number 50-- fl?g-?nqq9 lO. Pool Prudhoe B~y 0il Pool 11. Present well condition summary Total depth: measured true vertical 10900feet feet 9325 Effective depth: measured 10750 feet true vertical 9191 feet Casing Length Size Conductor 81' 20" Surface 2493' 13-3/8" Intermediate 10088' 9-5/8" Production 1044' 7" Perforation depth: measured true vertical Tubing (size, grade and measured depth) 10518' 8983' Plugs (measured) Junk (measured) Cemented Measured depth 1800# Poleset 2350 Sx Fondu & 400 Sx PFC 500 Sx Class G & 300 Sx PFC 360 Sx Class G 81' 2493' - 10550' - 9012' 10088' 10802' ~,?i;:',i ',.' "o ~ue Vertical depth 81' 2492' 8593' 9238' ~, ~oo!.'.~ Oil & Gas Cons. Anchora~o 5½"; 17#, L-80 @ 9694'; Plastic coated tubing; 4½" tubing tail, L-80 @ 9792' Packers and SSSV(type and measured depth) Camco Bal-0 SSSV @ 2190'MD; Baker "SAB" Packe~ ¢ 96Rg'Nn 12.Attachments Description summa~ of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation March 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~f,)certify ~,~ Signed Conditions of approval Approved by x~the~f~and correct to the best of my knowledge ~'/g"--~./ Title Operations Engineerin9 Manager Date, Commission Use Only Notify commission so representative may witness I Approval No. ~ Plug integrity i~ BOP Test ©..Location clearanceI ~ -"f ~-/,,-./"' Approve(~ L;opy Returned ORIGINAL SIGNED BY by order of LONNIE C. SMITH Commissioner the commission Date Form 10-403 Rev 12-1-85 1/t_'~9/(;TAT17 qhnv-nn k' Al'lq~n-13rRl~p (263-4247~ t.~/~-') Submit in triplicate ~. D.S. 14-32 PROPOSED ADDITIONAL PERFORATIONS ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit intervals in well 14-32. The proposed perforation intervals are as follows: Existing Perforations Proposed Perforations 10518-10550' (32') 10470-10490'MD (20') A 5000 PSI WP wireline lubricator and BOP, tested to 4000 PSI working pressure prior to the job, will be utilized for this operation. Ref. BHCS 8/25/83 STAT17'SN 4-29 4 3 I iI iiI ! ! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF HIRELINE BOP EQUIPMENT ARCO Alaska, In? Prudhoe Ba= Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 5, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-32 Permit No. 381 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/CMH/jp At t a chmen t cc: Standard Alaska Production Company Pi(DS 14-32)W1-3 detailing work per- WELLS 2 / 12 ARCO A~aska, ~.¢. is a $-b$idia~y o~ AHanfi¢~ichfieldCompa.¥ AR3B--6132-C '"--' '~ STATE OF ALASKA '-- AL, ,, ,.)IL AND GAS CONSERVATION CO .... .)SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other I~r 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 69' RKB Feet 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4 T10N R14E UM At top of productive interval ' ' ' 2114' FSL, 2435' FNL, Sec. 3, , T10N, R14E, UM At effective depth At total depth 2199' FSL, 2564' FEL, Sec. 3, T10N, R14E, UM 11. Present well condition summary Total depth: measured 10900 feet true vertical 9325 feet Plugs (measured) 6. UnitorPropertyname Prudhoe Bay Unit 7. Wellnumber 14-32 8. Approval number 9. APl number 50-- 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 10750 feet true vertical feet 9191 Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 81' 20" 1800 Sx 2493' 13-3/8" 2350 Sx 10088' 9-5/8" 500 Sx 7" 360 Sx Junk (measured) Measured depth True Vertical depth 81' 81' 2493' 2492' 10088' 8591' 10802' 9236' 10518-10550' true vertical 89~3=90,12' ~uD~ng~s~ze, grade and measured depth) 5½" 17#, L-80 9694'MD & 4~"2 , 12.6# L-80, 9792' MD Packers and SSSV(type and ~easured depth) Camco Bal-0 SSSV @ 2190' MD; Baker SAD packer @ 9689' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumesAutste~necftfinal pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1195 6888 1105 -- 1801 Subsequent to operation 16 1886 358 -- 269 GL 14. Attachments Daily Report of Well Operations I~ Copies of Logs and Surveys~,-R/u~n ?----~_ _ 1 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~'- O~"--~-4~I' ~~~~~ Operations Engineer Manager ~__~//~/~.JJ Signed Title Date / Form 10-404 Rev. 12-1-85 ~7~,T,T..~?/12 C. M. H~_~htower. ATO-1500, 263-4713 Submit in Duplicat~.~,-. DS 14-32 CTU CEMENT SQUEEZE PROCEDURE (4/6/87) AFE #698075 1. RU WLU and made gauge run to PBTD @ 10748' MD. 2. Perforated the interval 10518-28' BHCS for precautionary squeeze (5/13/87). Flowed and cleaned well. Rigged up CTU and performed HC1/mud acid wash of perforations 10310-349', 10368-78' and 10518-28' BHCS (5/14/87). 4. Rigged up ELU and ran CET to evaluate existing cement job (5/20/87). 5. Perforated the interval 10450-60' BHCS for precautionary squeeze based on CET (5/29/87). 6. Squeezed cement perforations with 38 bbls Class G cement using CTU (6/4/87). Contaminated cement in wellbore and WOC. 7. Jetted wellbore clear to 10680' MD. 8. POH and rigged CTU down. 9. Perforated the following interval (6/29/87): 10518-50' BHCS 8/25/83 6 SPF 10. Brought well in and tested. Well tested very high watercut. Currently under evaluation for additional perforating. 0 WELLS2/12 I) ~-:~'l'~ El ' ._J u. I. '~/ 2 -9, I ? Ei:'? r4EV£~q~'NC£' I)RGc'3 Cas ~=1 HoPe ~'~1. ot: dat'a, ARCO Ala~'ka, Inc l',.O. Box 'i00360 Anchormge, ALms'La 99510 DATE' July 8, t987 REFERENCE' ARCO Cram'ed Hole Final S-t8 6--28-87 Perf. Reco¥'d 5-t 0 5-29-87 Ver $ i Log 6-24 7-3-87 Perf. Record 9-t4 6-.-27-87 Perf. Record- t4-t7 6-29-87 Perf. Record t4-S2 6--29-87 F'erf. Record 16-ti 6-2'7-87 F'erf. Record R un Run R u n Run Run R ~; n Run t, t, t, t, t, t, 1 5' 5' 5" 5' 5" 5' $ch ,Y)r e.s' s' $ch Sc h $ch Sc I') $ch PLease sign and r ,~ py cei,? rec e i red( By ~_ ~,.~ ~__.;:'_ ....... ~ HAVE A NICE DAY~ ' ' .' ~ Ro~anne Peek ATO-t 529 TRAN$ $87S48 Approved · .-'"' Centra t Fi Les $ Chevron I) & M $ Exfen_~ion Exp tora't ion -.-~' Ex XOl'! Mara t'hon ,..~- Mob i t ARCO A[m~'km, Inc F'.O. Box te-(336(~ Anchorage, Alaska 995t DAI'E' June 9, t98'7 REFERENCE' ARCO Cased Hole F inmL 4--Si 5-t6-87 CH CNL (CORRECTED COPY) Run 2, 5' 6-22 6-2-87 CBT Run t, 5' 6-.-22 6--t-87 CET Run ~, 5' 7-1'3 6-i-87 CET Run t, 5' it-'4 5-t6-87 CH CNL (CORRECTED CDPY) Run 2, 5' i4-32 5-29-B'7 Perf. Record Run t, 5' ~'ch $ c h $c h $c h ,'.,.':,:. h I:'l. ease sign and re~urn ~he ak~ached copy as receip$ of da~a. Received By HAVE A NICE DAY! Ro~anne Peek A'rO-t529 TRAN~ Approved DISTRIBUTION - Central Fi Les Ch eYr on I) & M · "- Ex'len~ion Explorai'ion -ir - Ex xon ).. . ! ~ ~ . Mob i I. 'I' · ,-'"' F'hi L L ip~' PB WeLL Fi Le~ R & D $ $oh i o Sta~e of ALaska -ir ~~r T~2¢ ~co ARCO ALazka, Inc P.O. Box Anchorage, ALaska DATE: June t , REFERENCE: ARCO i-ia 4-25-87 i -28 i 2-28-86 i -29 5-i 4-87 2-8 5-2-8? 3-7 5-9-87 3-t0 t~- ----7 86 9-7 4-27-87 t t - t t 2-25-86 t 4-J2 5-t 3-87 t 8-~ t 2-2~-86 t987 Cased HoLe Final FLoweret/FLuid I.D./GR Run t, 5" Camco Perf. Record Run t, 5" ,~ch Collar &Perf. Log Run t, 5" Gear Collar Log (PLug) Run t, 5" Gear Collar & Perf. Log Run t, 5" Gear EPL Run 2, 5" $ch Collar & Perf. Log Run t, 5" Gear Perf. Record Run I, 5" $ch Collar & Perf. Log Run t, 5" Gear Tubing Puncher Run t, 5' $ch Please sig~ and Received By_ HAVE A NICE DAY! Ro~anne Peek AT0-t529 return ~he ad ~y az receipt of data. ,- · .~.~ U~J a GaS C"~ ~ -- . ~ ~ TRAN$ ~87279 Approved DISTRIBUTION '- Central Fi Le:s Chevron D & M Exfenzion Exploration EXXOI~ Mara fhon · '" Mob i l 1' · "--.. Phi LLips: F'B WeLL Fi Les .............. ~' Texaco ARCO ALas:ka, Inc. F'~O. Box 100360 Anchormge, ALaska DATE: May 28, t987 REFERENCE' ARCO Cased HoLe FinaL 8-3 5-t 8-87 CH CNL Run t, 5;' $ch 4-32 5-20-87 CET Run t, 5' $ch F'l. eas:e s:ign and return the attached copy as receipt of data. Received By HAVE A NICE DAY! Rosmnne Peek A'¥0-t 529 'rRAN$ '~ ~-87~.77 Approved Anchorafle DISTRIBUTION -.- Central Fi Les: '"'-.. Chevron D & M · ~ Ex1'ens:ion ExpLorm¢ion Exxon M a r a ~ h o n Phi L tips: F'B WeLL Fi Le~ R & D Sohio State of ALms:ka Texsco ARCO Almska, Inc, I"-',0, Bo× 100360 Anchorage, Alaska 99510 DATE: February t 9, t987 REFERENCE: ARC. O Magnetic Tape.s w/i.i.'.~t '-~ 6-.t 8 t2-2t-86 ', 7-t 0 t t-t 5-84 -,, t 4-30 t --2~-'87. ~ t 4-32 t 2-22-86 l)res's Dr ex..~' l)r es's' Dress Please sign and re~urn the a+.tached copy as receip~ of dala~ Received By___ HAVE A NICE DAY! Ro~anne Peek A'FO.- t 529F' - ]'RAN~' ~87t04 ~ Approved ...... FEB23 · Alagl~ Oil & Gas Cons. Commission Anchorage DISTRIBU'FION · '., (2)CenSra. [ F'i Les Chevron I) & M ~'"' (t)F',McPheeter~ ~~ Ex XOl~ Marathon Mob i L Phi l lips' PB Well Fi Les R & D Texaco ARC;O Ala.~ka, Inc, I::'~0~ Box ~00,S60 Anchorage, AI.a~l~a 995~0 DATE:' F:'ebr ~.~a r y l '~ ........ ~1" '" RI::.I" FZRE. NCE ' AF;,'C(] 9, t 98'7 C a .'-: e d I'-I o L e F i n a L £;l';T ]Direc'l'ional. ~" '" _ . .., ~ vey I:;:unt ,~ cl'~ CBI... VariabLe Density Run t, .,"~" ,~'(:h CI'.I CNL Run t, 5' ,?ch CH CNL Run t, 5" Sch ~CBL/VDL.,Ze[GN/(;R., Run F'DK-~ ~ Run F:'Lease ~igo and ret urn Rece i red By HAVE A NICE DAY! F;:o.,..: a n ne Peek A'T'O..- t 529 TRAN~ ~:8'7t 4) 7 /~] Ap p roved ........... j.~ ..................... D :[ ,S' '11" R I B U T I 0 N ~he attach I copy a~ receipt of data, FEB _~_~__ ~aska Oil & Gas Cons. Commission Anchorage CentraL IZi Les Chevron D & M Exten.~;ion ExpLorafion. Exxon M a r a t h o n Mob i L :,":. Phi LLips PB WeLL F'i Les R & D '~' :~ o h i o ¢ 5'tare ~f ALaska · .""'T e x 8 c o ARCO Alaska, Inc. "'~ Prudhoe Bay ._ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 14-32 Permit No. 83-122 Dear Mr. Chatterton: Enclosed is the "Intention" Sundry Notice detailing work proposed the above mentioned well. Very truly yours, D. F. Scheve DFS/CMH/aja cc: Standard Alaska Production Company Pi(DS 14-32) W5-4 on RECEIVFD S E P 0 9 1986 Alaska Oil & Gas Anchora9o CLv~/28 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ./ STATE OF ALASKA ALAS. , .3IL AND GAS CONSERVATION COM~,,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing © Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate J~ Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 69' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay Unit 4. Location of well at surface 40' FSL, 1292' FEL, Sec 4, T10N, R14E, UM At top of productive interval 2114' FSL, 2435' FNL. Sec 3, T10N, R14E, DM At effective depth At total depth 2199' FSL, 2564' FEL, Sec 3, T10N, R14E, UM 7. Well number 14-32 8. Permitnumber 83-122 9. APInumber 50-- 029-20999 10. Pool Prudhoe Bay Pool 11. Present well condition summary Total depth: measured true vertical 10900 feet 9325 feet Plugs (measured) Effective depth: measured 10750 true vertical 9191 feet feet Junk (measured) Casing Length Structural Conductor 81 Surface 2493 Intermediate 10088 Production 10802 Liner Perforation depth: measured 10319 - 10349; 1036 - 10378 true vertical 8801 - 8829; 8846 - 8855 Size Cemented 20" 1800 SX 13 3/8" 2350 SX 9 5/8" 500 SX 7" 360 SX Measured depth 81 ~D 2493 MD 10088 MD 10802 MD ~bing(size, grade and measured depth) 5 1/2"; 17# L'80; @ 9791; Plastic coated tubing Packers and SSSV(type and measured depth) CAMCO BAL-O SSSV @ 2190 MD; Baker "SAB" Packer @ 9689' MD ~ue Verticaldepth 81' ri'VD 2492' TVD 8591' TVD 9236' TVD RFCFIVFD S EP 0 9 1986 Alaska 0il & Gas Cu~s. uummission Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~certify thc4 the forggoing is true and correct to the best of my knowledge Signed ~/'~ j,~~ Title 4~,,},,, ~ .~/~.. ,/~,~, Commission Use Only " Date Conditions of approval Approved by Notify commission so representative may witness I Approval No~,. [] Plug integrity [] BOP Test [] Location clearanceI ~¢ -~ Commissioner the commission Form 10-403 Rev 12-1-85 Submit in triplicate DS 14-32 Prudhoe Bay Field CTU Cement Squeeze Intended Procedure AFE No. 698075 1. RU WLU and make gauge run to PBTD @ 10748'MD. 2. Perforate the interval 10518-28' BHCS for precautionary squeeze. Flow and clean well. 3. R~g up coiled tubing unit (CTU) and perform HC1/mud acid wash of perforations 10319-349, 10368-78, and 10518-28' BHCS. 4. Squeeze~ cement perforations with 23 bbl Class "G" cement using CTU. Contaminate cement in wellbore and WOC. 5. Jet wellbore clear to 10748'MD. 6. POH & rig CTU down. 7. Perforate the following interval: 10518-50' BHCS 8-25-83 8. Bring well in and test. Return well to production. RECEIVED S EP 0 9 1986 Alaska Oil & G~s Cuns. commission Anchorage CMH/29 5 4 3 2 I. SC)DO PS, I?" W£LLHF. AD CONN£CI'OR FLANG£ 2. 5DDO PSI 4 1/16" PiP[ 3. ~DDO PSI 4 1/6" HYDRAULIC SLIPS 4. 50DO PSI 4 1/6" SHEkR 5. ~)OO PSI 4 1/6" BLIND RAI~$ 6. 5DO0 PS1 4 1/16" STUFFING BOX COILED TUBING I.,INIT BOP EOU]PHENT 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) ,.3.5000 PSi 4. 1/6" LUBRICATOR 4. 5000 PSI 4. 1/6" FLOW TUBE PACK-OFF RECEIVED SEP 0 9 1986 , Alaska Oil & fi~,s ~:;,.,~,s. uummiss~o~ Ar~chora,3e HIRELINE BOP EOUIPMENT STATE OF ALASKA 1. Status of Well Classification of Service Well REV i S I ON OIL [~]X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20999 4. Location of well at surface 9. Unit or Lease Name 40' FSL, 1292' FEL, Sec.4, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2114' FSL, 2435' FWL, Sec.3, T10N, R14E, UM 14-32 At Total Depth 11. Field and Pool 2199' FSL, 2564' FEL, Sec.3, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 69' RKB ADL 28312 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No. of Completions 08/05/83 08/24/83 09/08/83I N/A feet MS L 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+TVD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 10900'MD,9325'TVD 10750 'MD ,9191'TVD YESd(x NO []I Nipple @ 219~eetMD 1900' (approx) 22. Type Electric or Other Logs Run GR/FDC/CNL/Cal, BHCS/GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2U" 91.5# H-40 Surf 81 ' 30" 1800# Pol eset 13-3/8" 72.0# L-80 Surf 2493' 17-1/2" 2350 sx Fondu & 400 sX PF "C" 9-5/8" 47.0# L-80 Surf 10088' 12-1/4" 500 sx Class G & 300 ~x PF "C" 7" 29.0# N-80 9758' 10802' 8-1/2" 360 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2" 9791 ' 9689 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9922' - 9924' 100 sx C1 ass G 10,138' - 10,140' 100 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None F. ..-. : ALASKA f~,- AND GAS CONSERVATION CO,~,MISSION ~-..~. Ii,ILL' COMI LI:TIOI, I OR ltI COMI LI!TION ItI=I OIIT &ND LOO Form 10-407 GRU13/WC09 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. i .: - 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 Sad1 erochi t 10,218' 8710 ' N/A 0/W Contact 10,627 ' 9080 ' Base Sadlerochit 10,850' 9281 ' . 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .~ Associate Engineer INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALa~km, Inc F'~O. Box i00360 Anchorage, 995f0 DATE: November 20, t985 REFERENCE: ARCO Magnetic Tape DS 14-32 t0-24-85 CH/CNZ tape w/List GO PLea~:e .s~ign and return the attached copy a:s' receipt Received By .................................... ~ . ATO-~ 479F / ~ - Alaska Oil & Gas A!asl 'i-RAN~:., ~4E;6 data, D I ~'TR l BUT I ['.IN Cl~evro'n Phi L L i p~ g & H F:'B WeLL F:'i Les' ExpLoration ~;'ervice.s' R & D Exten.'..;io¥~ ExpLc)ration 3'ohio Exxon State of ALaska Marathon Texaco ARCO Al_as-ka, Inc F'~O. Box t00360 Anchorage, ALaska DATE' November.-'~0, t985 REFERENCE' ARCO Cas.ed Hole Fina L D ~ t 4-.-3 '~ t 0 '-~ ~'" -.-.4-8.~ r'.H CNL R. un t ";" F'Leas.e :.:.-ign and re!:urn The attached copy a.s receip't of ,:l,'..~ta~ HAYE A NICFZ DAy!Received By .................................... ~~~~qE ? I<eLLy McFar Land a Oii& ua5 cui,~, b ...... ~;ssi0ri A T 0-- 1 429 I-- Anchorage TRAN£' '~'~' . DIYTRIBUTION Ch err on D Exp [ora-t'ion ~ervi(::es' Ex+.ension Exptorat'ion Exxon Mnh i I Phi t tips' F:'B Wel. I. F'i t e.s' R & D ~;'oh i o State of ALaska Texaco ARCO Alaska, Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Pressure Data DoS. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. _ __ D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. 1--4 f 1-25 1-26_f- 3-19 3-22 3-23 6-17~-- 7-7A 7-13 7-14 7_16~- 7_16 ~--- 9-18~ 12-16J 12-17f 13-33-~ 14-8>-" 3-15-84 PBU/CDBR Otis 5-25-84 PBU/CDBR Camco 5-30-84 PBU/CDBR GO 5-25-84 PBU/CDBR Camco 6-29-84 PBU Camco 5-24/25-84 CDBR GO 6-16-84 Static Survey GO 6-15-84 Static Survey GO 6-14-84 Static Survey GO 6-14-84 Static Survey GO 6-30-84 PBU GO 7-2-84 PBU/CDBR GO 6-20-84 Static Survey Camco 6-20-84 Static Survey Camco 6-21-84 Static Survey Camco 5-19-84 CDBR 5-20-84 CDBR 6-22-84 PBU/CDBR Camco 6-28-84 Static Survey Camco CDBR CDBR CDBR CDBR -84 CDBR CDBR 14-23,4--5-16-84 14-24~ 5-17-84 14-25 5-18-84 14-32j 5-20-84 14-33f 4-29/30 14-34 f 5-19-84 /'/Please sign and v data. return the attached copy as receipt of Kelly McFarland _ATO-1429F Trans. ~290 DISTRIBUTION ~hevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon ! Mob i~ MobLl E & ? AnChor.~¢s' ~,ue C°mmissio~ Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska · - ' /--. STATE OF ALASKA --'- ALASKA~ . AND GAS CONSERVATION CC vIISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLXI~ OTHER [] 2. Name of Operator. ARCO Alaska, Inc. 3. Address P.O. Box 100360: Anchorage: Ala.qka 99510 41 Location of Well 40' FST., 1292' FET,, Sec. 4, T10N, R14EUN 7. Permit No. 83-122 8. APl Number 50-029-20999 9. Unit or Lease Name Prudhoe Bay Unit 2114' FSL, 2435' FWL, Sec. 3, T10N, R14E, UM 2199' FSL, 2564' FE, Sec. 3, T10N, R14E, UM 5. Eievationinfeet(indicateKB, DF, etc.) 69'' 6. Lease Desigpation and Serial No. ADL 28312 10. Well Number DS 14-32 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforation operation 4/1/84. RU perforation unit, pressure test. RIH with gun 91, shot 10318-10338' MD (20', Ref: CBL 4/1/84), flowed, SI well, POH, all shots fired. PIH with gun #2, shot 10338-10348' and 10367-10377' MD (20', Ref: CBL 4/1/84), flowed well, SI well, POH, all shots fired. RD and secure well. RECEIVED JUN2 81 B4 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~Z~*~_// Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~- · Prudhoe Bay _,neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 253 4248 Donald F. Scheve Regional Operations Engineer July 9, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-27 Permit No. 83-170 DS 14-32 Permit No. 83-122 Enclosed are the Completion Reports for work done on the above mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Enclosures CC: SOHIO Alaska Petroleum Co. File PI(DS 14-27)W4-3 File Pi(DS 14-32)W4-3 ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany STATE OF ALASKA '~-' " ALASKA _~,L AND GAS CONSERVATION C ,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO C~assification of Service Well 1. Status of Well . OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-122 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20999 4. Location of well at surface 9. Unit or Lease Name 40' FSL, 1292' FEL, Sec 4, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2114' FSL, 2435' FWL, Sec 3~ TiON~ R14E, UM DS 14-32 At Total Depth 11. Field and Pool 2119' FSL, 2564' FEL~ Sec 3~ TiON~ R14E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 69' RKBI ADL 28312 12. Date Spudded8/5/83 13. Date T.D. Reached8/24/83 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns9/8/83 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey / 20. Depth where SSSV set I 21. Thickness of Permafrost 10900'MD - 9325'TVD 10750'MD - 9191'TVD YES~ NO []m ~ipple @ 2190 feet MDI 1900' (approx) 22. Type Electric or Other Logs Run GR/FDC/CNL/Calip, BHCS/GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE ,TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-B/8" 77.~4~ L-gO R111-~. ?AqB' 17~" P. med w/2350 sxs Fond,_, + 4~0 sxs PF "C" q-~/R" 47:0~ L-RD .q,~rF_ I~DRR, 12¼" C.m..td w/500 s-".s Class "G" ~ 300 s×s PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Per¢'d ~/4s~ SIZE DEPTH SET (MD) PACKER SET (MD) 10319 - 10349'MD (30') 8801 - 8855'TVD 5~ 9791' 9689' 10368 - 10378'MD (10') ~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ' 10315 - 10317 10O sx 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 4/4/84I Flowing Date of Test Hours Tested PRODUCTION FOR OIL,BBL . GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO 4/24/84 4,0 TEST PERIOD I~, 404 ~ 3~R 0 32° 928 Flow Tubing Casing Pressure . CALCULATED~1~ OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1058 24-HOUR RATE ~ 2808 2~,0¢, 0 98.7 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONERECEIVED gtaska Oil & Gas Cons. Cornnli$$ior~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. i GEOLOG.IC 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 Sadlerochit 10218' 8710' NONE O/W Contact 10627' 9080' Base Sadlerochit 10850' 9281' 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed · _ . Title Regional Eng'~n~r Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, In,.. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 10, '1984 Reference: ARCO Pressure Data D.S. 1-26 .-~ 5-20-84 Stat ic D. S 3-23~ 5-24-84 PBU D.S. 12-16~' 5-20-84 PBU D.S. 12-17. 5-20-84 PBU ~ D.S. 13-3~- 5-27-84 PBU f~ 5-27-84 Common Data Base Report D.S..14-23J' 5-16-84 PBU D.S. 14-24~f 5-17-84 PBU D.S. 14-25~t 5-17-84 PBU D.S. 14-32 -~ 5-20-84 PBU D.S. 14-34 ~ 5-19-84 PBU GO GO DA Otis Camco GO Camco GO GO Camco P~~lcase sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO-1429F Trans. #261 DISTRIBUTION Chevron Drilling Exp. Services Ext. Exploration Marathon Mob i 1 Mobil E & P Phillips -Prudhoe Bay Well Files R&D Carolyn Smith ;'.S~hio'~ , ~St:a~e of Alaska. · . . ARCO Alaska, Inc." Prudhoe Bay r-,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer Ak, June 25, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-32 Permit No. 83-122 Enclosed is a "Subsequent" Sundry Notice detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/WT/la Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 14-32)W1-3 RECEIVED 8 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference: ARCO Cased Hole Finals ~- D.S. 1-21 5-4-84 ~D.S. 1-25 5-26-84 ~D.S. 2-17 3-28-84 ~D.s. 3-13 5-21-84 ,-D. S. 3-27 5-18-84 ,~ D.So 4-1 5-6-84 jD.S. 4-4 5-14-84 ,-D.S. 5-8 ~-5-84 ,-D.S. 6-4 5-30-84 ~D~S. 7-20 4-18-84 ,,D.S. 12-16 5-20-84 ,-D.S. 9-4 5-7-84 ~D.S. 7-25 4-22-84 ,-D.S. 7-22 4-20-84 ~D.S. 12-18 6-1-84 ,,~D. S. 12-23 5-19-84 ~D.S. 14-2 5-3-84 ~-D. S. 14-25 5-18-84 ~D.S. 14-32 5-20-84 ~D.S. 14-34 6-5-84 ~,D.S. 17-1 5-24-84 Epilog Spinner Log Spinner Log/Basket Flowmeter CFS/Spinner ACBL/VDL/Signature/GR Epilog CH CNL Epilog CP1/TDT-M w/listing Spinner PLS Epilog Spinner Spinner CPL/TDT,M w/listing ACBL/VDL/Signature/GR Epilog CFS/Spinner CFS/Spinner CPL/TDT-M w/listing Collar/Perf Log ' P/~lease sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Run 2 5" DA Run 1 5" Camco Run 2 5" Camco Run 1 5" GO Run 1 5" DA Run 2 5" DA Run 1 5" GO Run 1 5" DA 5" Sch Run 1 5" Camco Run 1 5" DA Run 1 5" DA Run 1 5" Camco Run 1 5" Camco 5" Sch Run 1 5" DA Run 3 5" DA Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO Kelly McFar land ATO-1429F Trans. # 242 DISTRIBUTION ~Tevron Dr i 11 ing Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office B~"~360 Anchorage, A .a 99510 Telephone 907 277 5637 April 26, 1984 Reference: ARCO Cased Hole Finals / D.S. 1-25 j 3-18-84 / PFC/GR D.S. 3-19f 4-7-84 ,~ Collar/Perf _. D.S. 3-22J 4-7-84 ~ Collar/Perf Log D.S. 3-23~-~4-7-84z'~ Collar/Perf Log D.S. 5-9/ 4-8-84-~' CFS/Temp Survey DoS. 7-16~ 3-10-84f EPL D.S. 9-14f 4-6-84~~'~ Collar/Perf Log D S. 9-17f 4-6-84/~ Collar/Perf Log D S. 9-20 ~"~4-6-84j Collar/Perf Log D S. 9-21/ 1-11-84~ ACBL/VDL/Signature/GR D S. 9-23f 3-8-84f/ ACBL/VDL/Signature/GR D S. 9-25~ 4-2-84/ ,Epilog/Sandstone Analysis D S. 12-26~-~2-19-84j ACBL/VDL/Signature/GR D S. 12-27f ~f~-6-84 / ACBL/VDL/Signature/GR D S. 12-28j 3-28-84 ~ ACBL/VDL/Signature/GR D S. 12-28~ 3-30-84 Collar Log (used to cut tubing) ---D S. 13-11 4-4-84~' Collar/Perf Log ~D S. 13-11 ~D.S. 13-98 D.S. 13-98 D.S. 13-98 D.S. 13-98 D.S. 13-98 D.S. 13-98 D.S. 13-98 iD.S. 13-98 iD S. 13-98 iD S. 1-3-98 5" DA Run ALL 5" GO Run 1 5" GO Run ALL 5" GO Run 3 5" GO Run 1 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" DA Run 1 5" DA 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" GO Run 1 5" GO 4-4-84 ~ Diff Temp Run 1 5" GO 5-8-83 ? Epilog/Carbon-Oxygen 5-pass overlay5" DA 3-16-84/ CPL/GST/DIL (3 runs) w/listing 5" Sch no date/ Epilog/overlay avg. CO, SI/CA, SW 5" DA 11-12-83" Epilog/Carbon-Oxygen 6-pass overlay5" DA no date., 2-13-84" 2-19-84' 2-18-84' · 3-30-84 ~ 2-14-84 '? Epilog/Compare Induction Curves 5" DA EPilog/Carbon-Oxygen 5-pass overlay5" DA GST Inelastic & Stations Run 3 5" Sch GST Capture & Activiation Run 3 5" Sch CH DIL Run 11 5" Sch CH CNL Run 4 5" Shc ~ 13-98 2-16-84~' CH DIL Run 10 5" Sch D]~. 14-32~ 4-1-84/' Collar/Perf Log Run 1 5" GO · . 16-5 -- 3-10-84/ Completion Record Run 2 5" Sch ~/Please sign and return the attached copy as receipt of data. DISTRIBUTION Have a Nice Day! · Mobil ~",i-~;,";' ,- . ..~~ Mobil E & P '" ' "-'~:".: . . I .,-~ i~ 2 .... Phillips . . . Prudhoe Bay Well Files Kelly McFarland ATO-1429F Chevron D&M Trans. #171 Dallas Drilling Ext. Exploration Exxon Getty R& D Carolyn Smith Sohio Marathon State of Alaska ARCO Alaska, Inc, Post Office B~--'360 Anchorage. /- xa 99510 Telephone 907 277 5637 April 13, 1984 Reference: ARCO Pressure Data D.S. 6-9f 3-23-84 D.S. 6-17 ~ 3-24-84 D.S. 7-16 ~ 3-10-84 D.S. 12-8B- 3-22-84 D.S. 12-19 j3-21-84 D.S. 14-8 f 3-23-84 D.S. 14-27j 4-2-84 D.S. 14-32f 4-2-84 D.S. 14-34f 3-25-84 D.S. 15-4j 3-15-84 3-15-84 D.S. 15-13'~ 3-11-84 3-11-84 Static Static Horner Plots w/listing Static Static Statzc Statzc Statzc Statzc PBU Common Data Base Report PBU Common Data Base Report Camco Camco Sch Camco Camco Camco DA GO DA Camco Camco gn and return the attached copy as receipt of data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFarla~evr°n ATO-1429F Trans. # 148 DISTRIBUTION D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files Sohio State of Alaska ~-' ;'''~ ARCO Alaska, Inc Prudhoe Bay c2ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 27, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 14-27 DS 14-32 Permit No. 83-170 Permit No. 83-122 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/WT/lmh Attachments cc: Sohio Petroleum File (DS 14-27)W1-3 File (DS 14-32)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ~"-'-STATE OF ALASKA ALASK, .... AND GAS CONSERVATION C .... ~vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-122 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20999 4. Location of Well 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM 2114' FSL, 2435' FWL, Sec. 3, T10N, R!4E, UM 2199' FSL, 2564' FE, Sec.3, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 69' RKB I ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number DS 14-32 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of star~ing any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 14-32 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10319-10349' MD 10368-10378' MD Ref: BHCS 8/25/83 Subsequent Work Beportecl or~ ~No ~ onF ' 14' I hereb~/~ertify tha~reg°f is t~ ~°,~ect to the best of my knowledge- Signed.. ~?~~ ~7 ~ Title Rogional EFlginoor The space below for Commission use Conditions of Approval, if any: Approved Approved Copy ~eturned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reporls" in Duplicate ARCO Alaska, Inc.~ Post Office ~x ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 6, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-32 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer GRU5/LiO3'tw Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ¢~. ALASK/- . AND GAS CONSERVATION C ,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20999 OTHER [] 4. Location of Well Surface: 40' FSL, 1292' FEL, Sec.4, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 12. I 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-32 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well ~ 0930 hfs, 08/05/83. Drld 17-1/2" hole to 2520'. Ran, cmtd & tstd 13-3/8" casing w/shoe ~ 2493'. Drld 12-1/4". hole to 10,115'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 10,900'. Ran 7" csg f/9758' - 10,802'. Cmtd 7" csg. Ran CBL; squeezed cmt. Ran 5-1/2" completion assy. Secured well & released rig @ 1500 hfs, 09/01/83. 14. I hereby certify t~.~ue, The space below for Commission use and correct to the best of my knowledge. Title Area Drilling Engineer Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date ...... Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 GRU5/SN57 ARCO Alaska, inc. Post Office Anchorage .... a 99510 'T'eiephone 907 277 5637 November 30, 1983 Reference: Arco Cased Hole Finals D.S. 3-22 8-30-83 D.S, 5-7~ / 9-12-83 D.S. 5-14 '''J 9-23-83 D.S. 5-14 '? 9~22-83 D.S. 14-32 ..... 8-29-83 D.S. 14-32 8-30-83 D.S. 13-98'~/ 11-9-83 D.S. 14-24~,, 8-27-83 D.S. 5-2 ' 8-17-83 D.S. 3-7 8-17-83 D.S. 5-8'-J 8-25-83 D.S. 5-8'/ 9-3-83 CBL/VD GR Production Packer/Collar Log GR CBL/VD CCL & Perf Record Run 1 5" Sch Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" Sch Squeeze Run on 5" Sch CPL/CNT-A (Therman) & CNT-G (Thermal & Epithermal) 5" Sch CET EPL CCL & Perf Log Collar Log for Casing Cutter GR/CCL Correlation Log Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch. Run 1 5" Sch Run 1 5" Sch ign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F /Chevron Trans..~# 649 D & M Dallas Drilling Getsy Marathon DISTRIBUTION ~North Geology · Phillips Prudhoe ~7 ;aro!ine Sx~itk Sohio x... State of Alaska -.~ ARCO AlaSka, inc. Post Office ,~,~'-"'--360 Anchorage. ,a 99510 Telephone 90/ 277 5637 November 30, 1983 Reference: Arco Open Hole Finals D.S. 3-22 '~-~ 8-26-83 8-21-83 8-26-83 8-21-83 8-26-83 " 8-26-83 8-26-83 D.S. 14-32 CPL/Cyberlook BHCS BH Profile D[L/SFL FDC/Cm~/OR (Raw) FDC/CNL/OR (Poro) GR 8-25-83 CPL/Cyberlook 8-25-83 BHCS 8-25-83 DIL/SFL 8-25-83 FDC/CNL/GR (Raw) 8-25-83 FDC/CNL/GR (Poro) 8-25-83 GR Run 1 5" Sc6 Run 1 2" & 5" Run 1 5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" Run 1 5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" ~~~ e as e ' ' sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 635 Chevron Dallas Dr.~ling Getty Marathon DISTRIBUTION North Ge°l~yy Phillio~~7' R & D Ca~c-ime Sohio State of Alaska ' ' ~' STATE OF ALASKA '-'-'. /,~ ALASKA ..... AND GAS CONSERVATION C; -MISSION ~/r ~ WELL COMPLETION OR RECOMPLETION REPORT AND LO Classification of Service Well 1. Status of Well ~--~]'S_~0N OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-122 '~. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20999 4. Location of well at surface 9. Unit or Lease Name 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM Pr'udhoe Bay Unit At Top Producing Interval 10. Well Number 2114' FSL, 2435' FWL, Sec.3, T10N, R14E, UM 14-32 At Total Depth 11. Field and Pool 2199' FSL, 2564' FEL, Sec.3, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 69' RKBJ ADL 28312 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10900'MD,9325'TVD 10750'MD,9191'TVD YES iX] NO [] Nipple (~ 2190 feet MDI 1900' (APPROX) 22. Type Electric or Other Logs Run GR/FDC/CNL/Calip, BHCS/GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5// H-40 Surf 81' 30" Instld w/1800# Poleset 13-3/8" 72.0# L-80 Surf 2493' 17-1/2" Cmtd w/2350 sxs Fondu + ~00 sxs PF "C" 9-5/8" 47.0# L-80 Surf 10088' 12-1/4" Cmtd w/500 sxs Class "G" + 300 sxs PF "C" 7" 29.0# N-80 9758' 10802' 8-1/2" Cmtd w/360 sxs "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) NONE 5-1/2" 9791 ' 9689' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~' Flow Tubing Casing PreSsure . CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC28 CONTINUED ON REVERSE SIDE 29. ~ . 30. --.. GEOLOGIC M~ARKERs 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 Sadlerochit 10218' 8710' NONE O/W Contact 10627 ' 9080 ' Base Sadlerochit 10850' 9281 ' 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) -- 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~' ~" ~'~'~ / Title Area Drilling Engr' Date '~r--~--~'-~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". [::nrm I N_/IN'7 DS 14-32 Drilling History NU 20" hydril and diverter system. Spudded well @ 0930 hrs, 08/05/83. Drlg 17-1/2" hole to 2520'. Ran 63 jts 13-3/8" 72#/ft, w/FS @ 2493'. Cmtd 13-3/8" csg w/2750 sxs total - 2350 Fondu + 400 PF "C". ND 20" hydril. Instld 13-3/8" packoff & tstd to 200 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg ,E,G.- ok. Drld 12-1/4" hole to 10,115'. Ran 225 its 9-5/8" 47#, w/500 sxs cmt. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. DRLD 8-1/2" hole to difficulties w/lost returns & gas cut mud. Drld to 10,900'. Ran GR/FDC/CNL/CAL 10,889'- 10,088". BHCS/GR 10,889' - 2400'. Arctic packed 9-5/8" x 13-3/8" annulus w/300 sxs PF "C" + 175 bbl AP. Ran 24 jts 7" 29#/ft, f/9,758' - 10,802' Cmtd 7" lnr w/360 sxs "G" cmt. Drld cmt to 10,750' PBTD. Run CBL. No goodj Perf.lO,315' - 10,317'. Sqz w/lO0 sxs "G" cmt (2 bbls thru perfs) 10,748' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NEC1. Ran 5-1/2" completion assy w/tail @ 9791' & pkr @ 9689' Tstd itbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to '5000 ps - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 1500 hrs 09/01/83. ' DRN/DH24 09/14/83 ~ '- : '-" STATE OF ALASKA "'"' 01 ~ I G I N J~ !. ALASKA ,LAND GAS CONSERVATION Ct .MISSION (~~_ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .,-~. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20999 4. Location of well at surface 9. Unit or Lease Name 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UN LOCATIONS Prudhoe Bay Unit At Top Producing Interval VERIFIED 10. Well Number 2114' FSL, 2435' FWL, Sec.3, T10N, R14E, UM Surf. ~_ 14-32 . AtTotal Depth ! B.H. ~ - 11. FieldandPool FSL, 2564' FEL, Sec.3, T10N, R14E, UM - Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 69' RKB ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 08/05/83 08/24/83 09/08/83I N/A feet MSL 1 17. TotalDepth (MD+TVD} 18. PIugBackDepth(MD+TVD) 19. DirectionalSurvey I ~l~)~);p~hwhereSSSVset I 21. Thickness of Permafrost 10900'MD,9325'TVD 10750'MD,9191 'TVD YES I~ NO [] N 2190 feet MD 1900' (APPROX) 22. Type Electric or Other Logs Run GR/FDC/CNL/Calip, BHCS/GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 81' 30" Instld w/1800# Poleset 13-3/8" 72.0# L-80 Surf 2493' 17-1/2" Cmtd w/2350 sxs Fondu + ~00 sxs PF "C" 9-5/8" 47.0# L-80 Surf 10088' 12-1/4" Cmtd w/500 sxs Class "G" + 300 sxs PF "C" 7" 29.0# N-80 9758' 10802' 8-1/2" Cmtd w/360 sxs "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) NONE 5-1/2" 9791 ' 9689 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A -,, 27. N/A PRODUCTION TEST Date First PrOduction Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.. . - ,~ ' NONE · :' '.i' ],..'.,i ' ,. .. .. ~' t'.',-; ; ,!, i l_!:':'.t. ;" · . .,,~ .. .'.. -~ Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC28 CONTINUED ON REVERSE SIDE 29. . ~ 30. GEOLOGIC MARKERS ' ' 'FORMATION TESTS NAME Include ir~terval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad] er'ochi t 10218' 8710' NONE 0/W Contact 10627 ' 9080' Base Sadlerochit 10850' 9281' 31. lIST OF ATTACHMENTS Drillin§ History, Gyr,o$copic Sur,vey (2 copies) 32. I hereby certify that the fore§oin§ is true and correct to the best of my knowledge Signed ~. ~-~ 7 TitleArea Drilling Engr' Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Fnrm 1N-~N7 DS 14-32 Drilling History NU 20" hydril and diverter system. Spudded well @ 0930 hrs, 08/05/82. Drlg 17-1/2" hole to 2520'. Ran 63 jt$ 13-3/8" 72#/ft, w/FS @ 2493'. Cmtd 13-3/8" csg w/2750 sxs total - 2350 Fondu + 400 PF "C". ND 20" hydril. Instld 13-3/8" packoff & tstd to 200 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to lbO0 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to-10,115'. Ran 225 its 9-5/8" 47#, w/500 sxs "G" cmt. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. DRLD 8-1/2" hole to difficulties w/lost returns & gas cut mud. Drld to 10,900' Ran GR/FDC/CNL/CAL 10,889'- 10,088". BHCS/GR 10,889' - 2400'. Arctic ~acked 9-5/8" x 12-3/8" annulus w/300 sxs PF "C" + 175,,G,b, bl AP. Ran 24 its 7" 29#/ft, f/9,758' - 10,802' Cmtd 7" lnr w/360 sxs cmt. Drld cmt to 10,750' PBTD. Run CBL. No good~ Perf 10,315' - 10,317'. Sqz w/lO0 sxs "G" cmt (2 bbls thru perfs) 10,748' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran 5-1/2" completion assy w/tail @ 9791' & pkr @ 9689' Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to '5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 1500 hrs, 09/01/83. DRN/DH2g 09/14/83 Eastman/ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY D.S. 14, Well Number: 32 WELL NAME Prudhoe Bay, NOrth Slope, Alaska LOCATION JOB NUMBER A0983R0401-OZ SURVEY BY JAHN/C©RAM TYPE OF SURVEY SIGMA-Gyro DATE 8-SEP-83 OFFICE Anchorage, AlaSka Eastman DATE: October 17, 1983 (907) 563-3650 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 ARCO ~T~V~ INC P.O~ Box 360 Anchorage, Alaska 99510 Well Number: D.S. 14, Well No: 32 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: SIGMA-Gyro Date: 8-SEP-83 Method of Computation: Radius of Curvature Surveyor/Driller: JAHN/CORAM Job Number: A0983R0401-OZ Attn: Mrs BILL ~..ONGDON Dear Mr~ Congdon, We are-enclosing the original and eight copy/copies of SIG~-Gyro survey run on the above mentioned well. To date~ the following distribution has been accomplished: A. 8 copy/copies delivered to drilling for in-house distribution.. B. 0 copy/copies for noted o~ company representstives. 3 co'~4~ for k;.,W cermanent we~I files We wish to take this opportunity to 'thank you for using Eastman .~m-, '.~ _ ~,.~.~.o~ock and look forward to being Of service in the~dture. ~ ~ c~reiy, Distr i~echnica! Coordinator cc/file Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide .I.]?.i; 1 .q., Wli!!]...l_. NO: 32 '.Ei; '[ (}I'"tA.....GYRO ,._IOE~ NO: A () '!? 8 :]i: R () 4. C~ 1 ()-Z I::'F:~I_IIS)I...IOE BAY-, NORTH '.::;I...OPE:, ALASI<A '.!!i; I G I'1A'..- (} Y R Cf., 0 ..... 1 C"? 5 C.:, M D.., S I...I R V E Y 0 R: ,_1A I'"1N / C 0 R A M., D A T E R I...I N: 8-S E F ..... 83 ~-:: I (}MA :ii!:,:]])(]]:, NO: 62'7;, F::'F:~OBE NO: 064 I:::' 0 R E:':'::; I G H T :'. '.~!;7 :i":: 5 (::,. 5 W ~:.'-i: I...11:~ V E Y T'A K E N F:' R 0 I"'1 W E I.... L'.. H E A I} VEI';:'I'ICAI ....SEC:'I"ICml CAL..CI...II.._A'T'E[I IN F:'i..AlxlE ('.'.iF: PROPOSAL D I R E [":'T' 'r 0 N: N 6 0 D El"~ · ~!!: 4 M T N. I::." RFCOR[~ OF SURVEY F;:A.r~II...I!::; 01:: Ci_IRVA'I-URI:' MF'THC~D .... I]:-"[B I',10: AC.)'.?8:})RC)401. 0..... Z I"IE:ASI IRE'r'l DRII:::T ~17'~1:;: ]:1:::*1 .... :FIIF;':i;[:!' Vli':':F:~T:I:...AL. VERT.'I:r':AI... ::;I.IB'.:.i;EAR IE: C 'T' A N G I...I L. A R C [... 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'.!!i; I GMA-GYRO ...If. lB hi(): A(')'.'-;~8:]i:RC.)4() 10'..-'Z F:'RUE~I..~OIF' BAY, NOI'R'TH :":!;I...OF'E, ~L...A'."-;K~ '.i:!: I [:!;MA-GYR(]., 0 ..... 1 ()75C) FID., '..:..!;URVEYCII'4~ ~ ,_IAHN/CORAM ~ ].]ATE RI...IN: ::_::--".'2;[:-':[: ..... :::i;IGMA :300 NO: 627., I:::'F~OBE NO: 064 I:::'ORE'.!ii; I GI'-IT ',: S'78 56,, !iii: I...I R U [:'." Y 'T'A K Ii,:. N I:::' R 0 M N [ L I.... H E ~ D RECORD OF INTERPOLATE:D .'::'i;URVEY F'" R IJ ~i:1H 0 ti!"' B A Y., N 0 R'I' I--'1 ::'":; L. 0 F::' E.: A L. A'S K A JOB NO: A()?~8:F:R()4.01 ()....Z COMPUTAT I ON T :1' M E:' D A T E O:ii!:: 01: ('~!'5 :1. 7--"C,:-:T-8:]i: I:::'A F) E I',10. 4 .............................. CODE .................... MF".':ASL~RED VEFCI"!C:AI... MD-TV[~ VERTIC:AL. R IE C: T A N G I_1 L. A R C L. 0 '...:.: L[ R E VEF:~'T']'C:A-I... .......................... N A Mr.:_' ............................ D El'"' TI.-I g E P ]"FI D F E E 1' F E E T F E E"' T F E E ]" F:' E E T F::'I.::E'T' 1] M .... lB 'T~ 0 F:' F; A I.'.!i R 1%2 E R T I,'.)F:' :i~; H i..,IB L :[ K 'T'OF::' '.:::;A[~LE:RC~C:FI I T TOP Z 0 NE 3 '.'.-'~ 8'?'?. 00 84. 21.84 14'7'7, :.2 8:352,84 20:36. :.38 N :3594. '~:' 5 E ,i. 0104 ,. 00 ::!:/-",06. :36 14'i~7.6 85:37.3/.':, 2060 ,, 6 .i. N :3680.87 E 1. () 135 ,, 0 C~ :":: 634.52 1 ?500, !"=; 8565 ,, 52 2 ("~ 64. :'-2'~ N :369:3. :31 E 1021 ::': ,, 0 (] 8'709. ~.):3 1 .=i O',iii:. 1 8640. ?.~ 3 2074. ,, 19 N :.3'726 ,, 54 E ..... - ,.-., e-, ~rm .-, . ~- - 1. () 4 ?"; .1. 00 F~ 92.1.. ':,.'..I 1 1:52'~.). ~.-',,.:,,: ..... -:. ,, :21 2 :I 02 7 ~--~ N :38:20..:, 0 E-' 4.1:31,,65 N 60:28 E 4218.4.0 N 60 4, '6 E ') '.7.' :-..: 1.0 !5 N 60 4. :..}.': E 42 ./..:,4. ?9 0 N /_':,(] 54. E 4:36,0. '.:.>5 N 61 :1, 0 lie , 'T' 0 P Z CI F. II!!': ':? HOT' 0 / W C (] N T A C:T 'T'r:F' ZONE !D B A'.:i; Ii!!: :!.:..; P, I] L. E: R 0 C I.-I :[ 'r 1 ()5 2 (). 0 0 8'~) 8:3.6 4 15:3,~:,. 4 8',--J 14 ,, 6 4 :.it 1 1 1.16, N :3 8 4. 8.6.'.5 E 1 (_)...:, 6...', ,, 0 (') '? 0:22. =' % Zl ('), ,-":~ ~ '"'' ._, 7 :l. 4 ~ 7 :2:1 l, z. 38 N 3866. :1, IE . . . ,*') .': ._l .,.-. # u . ...... .'1. () 6'.':.il '7 ,, () () ':? () ::: 0, ':: 5 15 z1.6 ,, 6 901..1., :':: 5 2.1. '.':::.' 4. :.3 Zl- N 38'F,' 2, 48 E 107 :E: 2,, C)0 'F' 2:1. '.-.-.', 5 ! :t 562, 5 ? 15 C). 51 214. 4, 25 N :':': 'F-' 5'7.75 E ................. '~'_ ":", 5 1. c) :::: ~=; c) C)c) °?2;E:C), 471 '/',':' '.:.:".T:' i .1. ~-? 2152 'F."6 N :3'?8/_':,./-,C) E 4. :3 8 9.6, 6 FI 6,:l 1:5 E 4 4 0 7.51 N .6.1 1 :i.'-: Iii,': 4 4 :.':i: 4.. 4 4 N 61 2 :.3 lei 4 !5 01,2'.:} N 6.1. ,.1. 5:::0.8 0 N 6 :I. :38 E DATA F[LE~ BI85~ DS 1' pRUDHO£ ~ BAT,: EAST.All WHIPSTOCK,. NO ~ :32 NORTH INC., i SLOPE; ALASKA! ,, HOR I~,ZONT:AL .... [DEPTH PROJECTION I IN.:- 500 FEET INDtCATOR~ TVD FINAL STATION,' DEPTH 10900 HD. 93;~5.22 ;TVD NORTH 2.159.25 EAST i 4.007 CLOSURE: 4552.,}!'? N 6~. ~] 2 E ! ' 7?58 ~' ' , ' ! ' ' ! . ' '. · · i ' ~ : ' ....,- ! 433ci; .,.. ,, ,:~. ..... , ........ i . : .' ','.' '""'-i . ' ! : J · ~ ' , ' ' ! ' · ~ , , , : ! . , i , , .... ." · i ....... i ...... ' ...... {-.- ! SURFACE LOCATION,. ''' ~: "; ~{ , ~'' :'l, ' , '~ :' ;' : '.'i ': :'' '"~ ....... . ' .. 40 FgL, 1292 , SEC.!4, TION, RI:4E..' . : . . . . , , , ~ · . , ' , ' , J , , ..... ~ , · , ..... I ' ' 1 ; [ i - I - ¸,. .. ARGO !ALASKA. INC. : DS' 14; 'WELL NQ~ 32 SIGHA-GYRO ~ PRUD. HQE'B'AY? NORTH. SLORE. ~L^SK'~ EASTHAN WHIPSTOCK, [NC. ,. 2000. ~,,OOO 60QO _ . 80OO.. 10000 .. 'CLOS~RE..i4552~. !.?L,~1..-8]~-~..1. :;3000 : , , ,', 4000 ~ooo ' .~,~' ~ ":'~ I ...... ' ....... . ;- ~ -.~. ~ooo ~ VERTICAL: SECTION i ..... {,,~ I, , .l 'i VERTICAL PROJECTION SCALE I l.N. =, 2000 FEET : 1 J , . i Eastman ~ ~'~ Whipstock LL3 A P~'TROI. ANE C.,OMt~ANY REPORT of SUB-SURF,4CE DIRECTIONAL SURVEY ARCO ALASKA, iNC. COMPANY -.. D. S. 14, Well Nu. mber: 32 ] WELL NAME Prudhoe.Ba_v, North Slope, A!ask.a I..OCATI ON JOB NUMBER (CDC) A-0853-05 TYPE OF SURVEY Directional Single Shot DATE ,4 -AUG- 8 3 SURVEY .. CHAPFL~N OFFICE Alaska F~:[:_'(.'.:l'.'IF~[I I'_lF :::;I.I[:(V[::'Y I:~tI:]IU~; 0[.:--.CURV.q'I'UF~E I'.IETI:-ICID ....................... :::i'E:9 E, ,, ./:, 0 1`4 5::'.4 C) E :'ii:O:;:::l ,. :i':: ]5 I',1 .50 C.) E: ::ii', i ,.1 ~1., :t () t .5 N 53 C.) :3'?./:..7. t:3 i-) Iq 54 I:) E :3 5 /.:. 'P .. :;?0 Z. lfi 1'4 /.':.0 O E '7:Ei:(')]. q/_* () N /,_.0 (.) E :iii::302. ,t/.-,4.5 N 6.0 () E ::3'.:.~:'::4. ".1.:'.-'_' :30 N ./::.:;::' C) .[-Z 46.."5. ../:.:34'i~. 74 '277/.'-.. :?6. · Z:..TSO. 74. · 14. t fi'; .-,;:~. 1'4 .... 2:3:3'~-.). '?'9 E... 2'7.'Z7 ..5'2' N .-, :.,. "::'2 E O 5& .~;,:)1. 'Tl'?.'f";. 4(") :E:I:_--::'?. 6,1 712/_-.. 4.0 155:'/':,. :-~/.::. N ':i:704.0/=. E :=:lZl. O. 2-::1 N :fi'? 2','::. [-:: (). 1.'5 6.:3:2. 7E. 45. lC) ::: .5 :.:i: :3 . 4 2 757/-... t(:) IE:! 1.7:3 N :E:O'?2. '.E:4 l.-: :_:i:5:-_:::3.9¢) I',1 59 :E::.E: [:_- O. 71 [:{O"F"['CIM f lOI...E A:.:.:;:E;EMBL.Y VAI. iI[;:::E I..l'..:.i;E!l'l FI.-.flR I)EPI"H ARE I'II::l l:lE' P'T it I::IAY [:iR I L...I.. I NG I:'~AY?.'; VAI..I..IE.::.:.; i.l.C.;[.:.[~ f:'l':'lF~ I':~EF'"rH AF~E MEi ['iEF"rH (:'l. OC) 2 f:;'2 ~') · i:)C) 2'.:.~ ::.i'/.:,. 0 () 4:3 'q C). 0 · 5020. C)C) 6:E:'.':'~(::). '72 ./:.0, C)C) ::~.' 1 ()(::) · C)C) :iE: ::i:(:)(::J ,. (':) C.) 9~.mr~, (')(:'~ .. ) _...Eastman ~ Whipstock B ,4 t 't': I t~( )1 ANt. (,,,'( ~Mt ~tN'~' , Zl. :7: 4(':),. Zl '.:-'~ 1 Zl ,, (')(:') ?.:,i C):~:: ?, ,. (':)0 ../::,'.!51 '2 ,, (')(7) '7 :~:'?C) ,, 'i?'i:~'.:.'~.,/:'.... OC) '::i:¥;:'.::C.). OO :345:3. OO il :~:Zl.('). ()() ,I 91 4. OC) · '.!:K)C¢.3. O0 /:.~; ! "::'. ()C) 7'.E:9C). :~::/:, 4 ::7.:. OO 'ii~'.:.~'? (!:.. O(') W[:.'i: t (~H't" ON B !1 ']" ............................................... 14E I GH'I" I '.'~; I-41 k,)['ilN [::'[:]:;~ 1 (7)C)() [::'()1 Ih. II'l::':; Vi:~l...I...IEii?~: 1.1::::1:::~i:1 I:'f"ll:~ ['.lli.:::l:::"l"H ~/-'l[:;¢liiil PIll 1,4 Ii!: I G H"I" . . /_..0 ~ (")(':) 1 :~i:),. OC) ..... '1:2:(::) .. (.3(') C). (30 1 '2.:(:). ('-)() I '~:("). C)O 17:(7) .. C)O '!i~O ~ (30 Il¸ Suggested fern to lm inserted in each "Ac well folder to check for timely cC~l±ance with our regulations. ' 'Operat6r, Well' Nan~ and Number . Reports and Materials to be received by:. /~-' '~F~' ~'~ Date Required Date Received Remarks Completion Report Yes Well History .Yes -.. · _Samples /~'-~ / · , '-- ----- o/,' -- ~ . .. F ,, , Core' Chips ..... /X~V~" s~ ,. . Core I~ucr±ption " . ,R. egistered Survey Plat 7*3" · ii Inclination Survey, ' /~/d, " I I- Directional Survey /~~ p / ProddCtidn Test Reports , · ~" ~, ~ ~ Yes ARCO Alaska, inc:-----. Post Offic( , 360 Anchorage. Alaska 99510 Teiephohe 907 277 5637 October 17, 1983 Reference: Arco Directional Data (RE-DISTRIBUTION) The following surveys are being re-distributed due to poor copy quality of the first set distributed. Please replace previous copies with these. D.S. 3-19 7-8-83 Single Shot EW D.S. 3-20 7-18-83 Teleco EW D.S. 3-21 8-8-83 Single Shot EW D.S. 3-22 8-24-83 Single Shot EW D.S. 4-16 9-29-83 Teleco EW D.S. 14-31 8-22-83 Single Shot EW D.S. 14-32 8-24-83 Single Shot EW ease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 563 Chevron D & M Dallas Drilling Getty Marathon Mobil DISTRXBUTION Phillips Pz~/~hoe Bay ' R & D Caroline Smith ti::.. STATE OF ALASKA 1~ ALASKA C'--"AND GAS CONSERVATION CC' 'VIISSION --'MieN HLY REPORT C,,.: DRILLING AND WOR ..OVER OPERATIO IS · Drilling well~[ Workover operation [] ..- 7. Permit No. ~ Name of operator " ARCO Alaska, Inc. . 83-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20999 9. Unit or Lease Name ~0' FSL, 1292' Prudhoe Bay Unit 4. Location of Well FE L, Se c. /+, T 1 0 N, R 1 ~ E, U H at surface 5. Elevation in feet (indicate KB, DF, etc.) 69 ' RKB ' 6. Lease Designation and Serial No. ADL 2831 2 For the Month of. August ,19 83 10. Well No. 14-32 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0tl Pool 12~Depthatend~fm~nth~f~tagedri~ed~fishingj~bs~directi~na~dri~ingpr~b~ems~spuddate~remarks ' Spudded well @ 0930 hfs, 08/05/83· Drlg 17-1/2" hole to 2520'· Ran, cmted & tested 13-3/8" csg. Drld 12-1/~" hole to 10,115'. Ran, cmted & tested 9-5/8" csg. Drld 8-1/2" hole to 10,900'. Ran logs. Ran, cared & tstd 7" csg. Ran logs. Ran 5-1/2" comp1. assy. Secured well & ER @ 1500 hfs, 09/01/83· See Drilling History· 13. Casing or liner run and quantities of cement, results of pr~sur9 tests 20" 91 5#/ft, H-~0, weld conductor set @ 81' Installed w/1800# poleset. 13-3/8" 72#~ft , · · : L-80 BTC csg w/FS @ 2~93'. Cmted w/2350 sxs Fondu + ~00 sxs PF "C" cmt'. 9-5/8" ~7#/ft L-80 BTC csg w/FS @ 10,088'. Cmted w/500 sxs "G" cmt. 7", 29#/ft, N-80, BTC csg f/9758' - 10,802'. Cmted w/360 sxs "G" cmt. See Drflling History. 14. Coring resume and brief description NONE 15. Logs run and d~th where run GR/FDC/CNL/CALIP/ f/10,888' BHCS/GR f/10,888' - 2~93'. - 10,088'. 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.~...~ .. _ ~'~ " Area Dri 11 ing Engi neet ~-/ ' : ~' ;;//'~"~'~ 'TITLE DATE ~,'"~' '~:"' SIGNED A'~,'~'~'''~''~-~:~ . ~ - NOT~por~n this form is r~red for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succe~ing month, unless otherwise directed. Fnrm 1 n~4 D R N / N R 29 Submit in duplicate DS 14-32 Drilling History NU 20" hydril and diverter system. Spudded well @ 0930 hrs, 08/05/83. Drlg 17-1/2" hole to 2520'. Ran 63 jts 13-3/8" 72#/ft, w/FS @ 2493' Cmtd 13-3/8" csg w/2750 sxs total - 2350 Fondu + 400 PF "C" ND 20" 'hydril. Instld 13-3/8" packoff & tstd to 200 psi - ok. NU BOPE & ~std to 5000 psi - ok. Tstd csg to lbO0 psi - ok. Drld FC & cmt. Drld FS & 10' new fora. Tstd fora to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10,115'. Ran 225 jts 9-5/8" 47#, w/500 sxs "G" cmt. Drld FC & cmt. Drld FS & 10' new fora. Tstd fora to 12.5 ppg EMW - ok. DRLD 8-1/2" hole to difficulties=w__/_lo_s__t retur~~as cut mud. Drld to 10,900' Ran GR/FDC~/CAL 10,889'- 10,088'. BHCS/GR 10,889' - 2400'. Arctic ~acked 9-5/8" x 13-3/8" annulus w/300 sxs PF "C" + 17'5 bbl AP. Ran 24 jts 7" 29#/ft, f/9,758' - 10,802' Cmtd 7" lnr w/360 sxs "G" cmt. Drld cmt to 10,750' PBTD. Run CBL. No good~ Perf 10,315' - 10,317'. Sqz w/lO0 sxs "G" cmt (2 bbls thru perfs) 10,748' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran 5-1/2" completion assy w/tail @ 9791' & pkr @ 9689' Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to '5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 1500 hrs, 09/01/83. DRN/DH24 o9/14/83 ARCO Atlask~, Inc. Anchorage, Alaska 99510 Telephone 907 276 1215 September 15, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton: Enclosed are Monthly Reports of Drilling and Workover Operations for the following: DS 4-20 DS 14-32 DS 14-31 DS 3-23 DS 3-22 DS 3-21 Pingut State #1 South Point State #1 Sincerely, ~M,~/A. Major ~~-~-- Area Drilling Engineer MAM/DRN:tw NORTON/45 Enclosures ARCO Alaska. Inc_ is a S~bsidiary of AllantjcRichtieldCompany ARCO Alaska, In~: " Post Office~-.Z:~,.,- 360 Anchorage. Alaska 99510 Teiepho."'e 907 277 5537 September 9, 1983 Reference- Arco Magnetic Tape ~D.S. 14-32 8-25-83 OH tape w/Listing # 68507 Run 1 Sch e sign and return the attached copy as receipt' of data. Ke 1 ly McFar land ATO-1429F Trans. # 504 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil D I S TRIBUTI ON North Geology Phillips Prudho ~-e~y/ Sohio ~las~ Oil &.Gas State of Alaska ARCO Alaska, Inc. .-~--.. Post Office Box., Anchorage. Alas . 99510 meiech.,-,-,e 907 ?7? September 9, 1983 'Reference' Arco Directional Data D.S. 3-19~ 7-8-83 D.S. 3-20f 7-18-83 D.S. 3-21~ 8-8-83 D.$. 3-22J 8-24-83 D.S· 14-24~ 7-8-83 6-17-83 D.S. 14-25'~ 7-18-83 D.S. 14-31,/` 8-22-83 D.S. 14-32--' 8-24-83 Single Shot Teleco Single Shot Single Shot Single Shot -Magnetic Survey Single Shot Single Shot Single Shot EW EW EW EW EW Teleco EW EW EW ase sign and return the attached copy as' receipt of data. - Kelly McFarland ATO-1429F Trans. # 510 Chevron D & M Dallas Drilling Exxcn Getty Marathon Mokii DISTRIBUTION North Geology Phillips P~dhoe Bay Caroling ...... Sohio State of Alaska FROM: MEMORANDUM Stat,¢o,o f Alaska OIL AND GAS CONSERVATION CO~IS. ALASKA 10SA:C1 TO: C ~rton THR[-'..-~ L~nnie C. Smith ~ u Commissioner Edgar W. Sipple ~ Petroleum Inspector FILE NO: TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO ' s Prudhoe Bay DS 14-32 Sec 4,T10N,R145, UM Permit ~-]o. 83-122 Parker Ri9 176. Saturday A~g_us_t~6, 1983: I traveled this date from ARCO's Kuparuk 2X-7, Parker Rig 14i, (subject of another report), to ARCO's Prudhoe Bay DS 14-32, Parker Drilling Rig 176. The drilling Contractor ~s in the process on nippling up. Suday. Aug~ 7,_ 1983: The BOPE test commenced at 4:35 am and was ConClUded at 6:15 am' There were no failures. I filled out the A.O.G.C.c. BOPE Inspection Report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Prudhoe Ba~ DS 14-32, Parker Drilling Rig 176. Attachment 02-00IA(Rev. 10/79) ::':::~.::: ~ .... .. - : . .... . ..:. :>::a~o:~:~',:'-ini~)~:~:~:ion RePot~:''-:..~ :.::~ · · . .. . . -. · ~ . . · : . - - 0~or · Location: Sec ~ V~ R,g~ ~, ~3 ~Casing Se~ ~ ~Z . . Drilling Contractor ~~~ Rig ~/7~ Represe~__.~ta~iv_~~~' ~C'ation, General ~K ACCU~U~TOR S'YSTE~4 Well Sign ~ Full Charge Pressure .~O ps. ig.. General Housekeeping ~, Pressure After Closure /qOO _psig Reserve pit O~ '200 psig Above Precharge Attained: ~ min~ sec . ~ mit ~sec 'Rig ~ Full Ch~ge. Pr~ssu~ Attained: N2~ -- D ~ O Cqntrols: Master ~d~ ~m ~3&~l ~w, . . ' = Remote ' Blinds switch cover _ -- BOPE Stack Test Pres~re Kelly and Floor Safety Valve~ Ann~ar Preventer ~K 30~O Upper Kelly~ ~ Test Pressure ~~ ~ ~~ Lower Kell/ O~<3est Pressure Pipe Rams ~na ~s - . ~ ~aa~ . B~ ~ype~ ~es~ Chok~ Line Valves ~ Inside BO 0~ Test Pressure .C.R.~alve ~Oou Choke Manifold Test Pressure ' I,~$/V~w '0~ ~ ~~ Valves Kill Line .Valves 0~ No. / ~O~U No flanges gD -' Check Valve Ol~ ' ~ /~fl$~~ ~O' ~ II Adjustable Chokes 2- ,H~/F~ OL '~ - 0~ <~ ' ~ ~}lydrau~calty opurated c] ' _! , ,o _.. Repair or Replacement of failed equipment to be made within ~/th ~ays and ins~ctor/Com~ssion office notified. D~str~bution or. ig.' - AO&GCC cc - Operator cc - Supervisor. "// ' / ARCO Alaska, Inc. Post Office bu~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 5, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- DS 14-32 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to change the casing program and KOP. Since this well has spudded, your earliest approval will be appreciated (verbal approval was received from Lonnie Smith on August 4, 1983). If you have any questions, please call me at 263-4965. Sincerely, M. A. Major Area Drilling Engineer JBK/JG'tw GRU4/L06 Enclosures Aiaska. Oi[ & Gas Cons~ [;ommissior~ ,",nchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~- ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20999 OTHER [] 4. Location of Well Surface: 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UH 5. Elevationinfeet(indicate KB, DF, etc.) 69' RKB 12. 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-32 11. FieldandPool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I~X Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] change Plans I~X Repairs Made [] Other [] Pull Tubing [] Other i~X Pulling Tubing [] (Note: Report multiple completions on Form ~0-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes at alter the casing program as follows: 13-3/8" casing will be set to 2500' MD (2500' TVD). 7" liner will be run from 9142' MD to 10,881' MD. Also, the KOP will change from 2500' to 2600'. Estimated Start: August 5, 1983. Work ~epod:ed. on ~o~ ~qo. ~ Verbal approval received from Lonnie Smith, August 4, 1983. 14. I hereby certify that the~f~regoing is true a,nd correct to the best of my knowledge. ~~ Area Drilling Engineer Signed Title The space below for Commission use Date Conditions of Approval, if any: Approved by. Approved Copy Returned By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 GRU4/SN6 Rev. 7-1-80 August 2, 1983 ~r. Mmrk A. ~jor Area Drilling Engineer ARCO'Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 'Re; Prudhoe Bay Unit DS 14-32 ARCO Alaska-, Inc. Permit No. 83-122 Sur. Loc. 40'FSL, 1292'FEL, Sec. 4, T10N, R14E, UM. Btmhole Loc. 1400'FN~L, 2355'EEL, Sec. 3, T10N, R14E, UM. Dear Mr. MAjor: EncloSed is the approved application for permit to drill the above referenced well. If-coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs.for copying except experimental logs, velocity surveys and dipmeter surveys. b~ny rivers in Alaska and their drainage systems have been classified as important for the spawnir~ or migration of anadrom~us fish. Operations in these areas are subject to AS 16.05.870 and the regulations pron~lgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you ~ay be contacted by the Habitat Coordinator's Office, Department of Fish and Game. ~o~lution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal %~ter Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in Scheduling field work, please, notify this office 24 hours prior to commencing installation of the blowout Mark A. ~i~jol Prudhoe Bay Unit DS 14-32 -2- August 2, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, ~please give this office adequate advance notification so that we may have a witness present. Vi trulY s, Chairmah of =v o~:'~ OP '~'BE co~''~'' Alaska ()il and Ga'~' Conservation Com~tis~ ion bet 6:H/A Enclosure cc~ D~partment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. '~'" Post Office B, . 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 1, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 14-32, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 14-32 and the required $100 filing fee. Attachments to the application include va plat det~aj~ing the section and plan views of the proposed wellbore; ~a~proximity plat showings, the subject wellbore's posi- tion to the neares~-.well drilled,~a sketch and description of the BOP equipment; and~a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on August 5, 1983, your earliest approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG4L3' sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ,"~'~ ALASKA U,L AND GAS CONSERVATION CO,,,MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE 0~0( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 40' FSL, 1292' FEL, Sec. 4, T10N, R14E, UM At top of proposed producing interval 2205' FSL, 2548' FWL, Sec. 3, TION, R14E, UM At total depth 1400' FNL, 2355' FEL, Sec. 3, TION, R14E, UM ..... :' '_;' ~ _~ ~,'~ 9. Unit or lease name · '' '; H;., 10. Well number .,., .,.~ t, 14-32 ,dfl¢~O/~,~~' (,'oD 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 69' RKB ADL 28312 Federai insurance Company 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 5 mi. NE of Deadhorse 16. Proposed depth (MD & TVD) 10881 'MD, 9212'TVD 14. Distance to nearest property or lease line miles 1400' @ TD fr/ADL 2R31~9 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 39 o (see 20AAC25.035 (c) (2) 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2500 feet. 21 SIZE Hole I __C_a_sing Weight p0" I zu" ~i .s# 7-1/2" 13-3/8" 72# !2-1/0"I 9-5/8" 47#47# 22. Describe proposed program: Proposed Casing, CASING AND LINER Grade Coupling H-~,0 Welded L-80 BTC L-80 BTC , S00-95 BTC Length 80' 2872' 9413' 1439' Prudhoe Bay Unit 11. Field and pool ./~:Prudhoer,, Bay Fi el d '~'/~rudhoe Bay 0il Pool Amount $500,000 15, Distance to nearest drilling or completed & ~1well 1171 ~ -&~--~ 1.- ..... =u ..... 18. Approximatespud date 08/05/83 3381 4132 feet psig@___~ Surface psig@.9212 ft. TD (TVD) inet and Cementing Program SETTING DEPTH QUANTITY OF CEMENT TVD (include stage data) MD BOTTOM TVD 110'1 110' 2902' II 2900' 9442' 18100' 10881'19212' I I MD TOP 30' I 30' 30' I 30' I 29' ~ 29' 9442' 18100' 1800# Poleset 2300 sx Fondu+400sx PF 500 sx G 1st stage 300 sx PF 1, 2nd stage ARCO Alaska, Inc., proposes to directionally drill this well to 10881'MD (9212'TVD) to produce the Sadlerochit zone.- Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 14-31 will be 117' away from DS 14-32 at the surface. There are no closer wellbores anywhere down hole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLEArOa Drilling Engineer The space below for Commission use CONDITIONS OF APPROVAL DATE Samples required I--lYES ~0 Permit number APPROVED B/ /~/~ Form 10-401 GRU4/PD2 Mud log required I-lYES ~0 Approval date I Directional Survey requ.ired ,[~ES [~]NO APl number 5o- o~-'/- z-o SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE A~m~qt 2, 19R3 by order of the Commission Submit in triplicate PRUD~OE BAY. NORTH SLOFE. ALASK~i ...... ERAOE ANGLE::~ :m · 9000 ' } :: .... · 12680: FT .. ':Z 7{-7- Z 2500 3000 , ',' : ! 221~., ETI ,::'~i:::' ' i .... ; .... ~ .......... :-.--, ....... ~::::,:::':i: I ' ! TARGET .: ::! , ' TVD-BBIg ..... '~ , TI'ID- 1043? , _.~ .............. DEP-4SaO ............. i ~ ~ . 3g~2 5 IN ~E ,. ....... .' ' ~ ' I :~}. !_..~..~ . ~ .... ~.. [VD-8004'- T~.~318. ,DEP-384g - I AG RIVER :TVD"8594 THD-IO081DEP-4334 SHUBL[K.-.TVD-8619 T~D-IO114-DEP-4355 -[ ! --- TOP SRD .TVDo8684 THD"10198 DEP"4408 i .G/O~CONTACT. TVD-SZ49 TUD"I0282 DEP"4461 --TARGET) TVD=8869IT~D=!O437:DEP=4560 oZ~ CONTACT TVD=9096'THD-IOZ3! DEP-4Z4?i ..... ~'-':- :/ ~ . TI'ID-8~3Z :DEP~-32go I i 2500 2600 ~737 ii 4'00 '40:33 ! , . , 1'.10011 ',i)1200 11 300' i 92 15 ~726 ;o 4883 · . '40o ,1 ....... 200 '- ~00 - -O .100 ..... 200 .. 300 "--...400 ; ~ ~ .... ~ .....-' : - .,/I--' : : ...... : ....... ; · ~ :--h- .------~---- ; -----~- ............ : ......... _____:_.. ., ...... ~-- --% .... ~ .... ~ .... {-- · '- ...... : · ~ ,* .... , - ' ; ' i- ' ¢' q ¢ : ' ' ' '-.'-- .... .'- I -f .... : ..... t ........ : ' ' : ~ '' 7~. .... ~ .... i '- ~¢-i-?!- ~ --- i- -~ .... r' ' ' 1--~--- T- : - ; -';--- ? .... ~ - ! :" ' '-q_-_;__~ .... ' ..... : i ,/-__..~._..__ i .... .~. :,-; -T--,-' i: - - ::--4::-'::::: ::: :-.:: :-::: :':: : ~ . -.':.: .... : ':-:. _ .,~ _ ,.___, . 1~_.: ..... :_.. ~- ...... .~ ..... ;~,.~_~.,_ ~._---~ ..... ~::"--:::::~::--::::::F:-:'-:::'-:::; .::':i ~ :.i: ': --i- f ;:: ::i :: ---::::::!~-'--'-' ...... h --- ?---',.-~ ...... ~ ...... ! ......... : ........... ~ . ~ . .......... ~ ....~ .... ,,._ . .'. - r ......... ~' .-. ....... ' ~ '' ' _.~ .... ~_ ......... : ..... .... . : ..... - : - -i- ~R~-O-:^&^SK^.,::[~C. ' :::-.-:--'-, .. i ~ BS-~ ~4~--~ELL--~O:- ~2 - P~OP~E[~ .............. -.. ....... 1 --¢h~dBHOE iB~¥~- .~ORf~ SLOPE, AL.^SK~ .... ~ ...... , ~ ..... ! ...... ; .......... ,. ...... ~i~.~'. - ~'i::::~:~i:~- i::'~- ~:'- :- : i :' : '-::::'-!'::--::'-:-:---:'-- :'-::-:-::': .... ." ' ' '." _ .... .... · ' ~ ....... : ..... '.. ',. :" i:':: : ':?: · _. ANNULAR PREVENTER LIND RAMS _ PIPE RAMS SPOOL PIPE RAMS 13-5/8' BOP STACK DIAGRAM Accumulator Caoacitv Test 1. Check and fill acc~nulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi witl~ 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with cl~arging p~P off. 4. Record on IAOC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8' BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock do~m screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 2S0 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimtm~ of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to SO00 psi and hold for at least 3 minutes. Bleed pres- sure to zero. · 7. Close valves directly upstream of chokes and,/ open chokes. Increase pressure to 5000 psi/ & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to SO00 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey p~np. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Orilling Super- visor. 17. Perform comolete BOPE test once a week and functionally operate BOPE daily. Rev. SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC'. SCHEMATTC ~ IO" HYD. OPR. BALL VALVE / ~ WELL BORE / /~----'lO" HYD. (3PR. BALL VALVE / /,~/x I ALL 90" TURNS ARE "TEE" .~ I CUSHION -I :" I , I WELL BORE RESERVE PIT AREA NOTE' FLOWL INE DR ILL lNG RISER 20" 2OO0 PSI WP ANNULAR PREVENTOR ~ I0" DIVERTER LINE Valves on diverter lines open automati- cally when the annular preventer is closed. -- DR ILL lNG SPOOL 20" CONDUCTO~ PIPE I0" HYDRAULIC OPERATED BALL VALVES "DETAIL" 202601( \, sZ /2_92' 5 8 I0 tG v cl fY <lo H, RI4~ d,~l, i v,i~uL. 51. ¥-- ~,%o,~)5.5o~ cAT' =qo°~"r' 35'. L. ON,~.--.j +8° .3 5' 0-1. ~L.~'-- p F I I I ' ~=-- ''~ · ltlanticRichfleldCompany . DATE/: DRAWING Ho: , ARCO Alaska. Inc. ': : F'osl Ol!ice Go! 360 Anchorage. Ala~,,,~ cj0510 Telephone 907 276 1215 July 5, 1983 Hr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 995'01 SUBJECT' surface Casing Setting Depth Proposal ,_ :~ 4 ..::,.', '.; ---- r'~l S7.AT T~C'- .......... ' CON F-E R;-'-: .-'-~-. /FIEF: Dear Mr. Chatterton' Per your request in our June 29 meeLing, li~ted below are the proposed 13-3/8" casing setting depths for the wells we dis- cussed. DS 3-21 DS 14-31 DS-14-32 DS 14-35 DS 14-A DS 14-B 13-3/8" shoe @ 2900 13-3/8" shoe @ 3500 13-3/8" shoe @ 2900 13-3/8" shoe @ 3500 13-3/8" shoe @ 3200 13-3/8" shoe ~ 3200 These depths are the planned casing points for the wells indicat- ed. However, as additional formation information is acquired, it may be necessary to revise some of the depths. Any changes in the original plan will be indicated on the Permit to Drill. If you-require any additional informat-ion, please contact either myself at 263-4965 or Karl a Lenz at 263-4966. Area Drilling Engineer HAH/KKL49 · sm cc: K. K. Lenz, ATO 1456 R. A. Ruedrich, ATO 1926 P. A. VanDusen, ATO 1476 Appropr!ate l~ell Files K. ~'. ~.v-~m~-~. ATT_> 14 C~ ~ ~ . ... ~-:~,A-:'~:.~ i 4. Mr. 'P. A. Va~sen -~- -:~:~.:~:]~&'::~... ~ ~..-~.AR~-.Alaska,. Inc, --...~ ~ ~ ~/~. Y~ ': :'P- O,-'~ BOx 100360 " '~ ' Anchorase,. Alaska 99510 · Re: Revised Surface Casing SettinE ": -"-' Depths for Selected Wells, Prudhoe ~ :Dear: Pet ~ i -'' i '.~.: '" -':.:-'.. In your letter to Chat ~attert°n and the meeting ~th the ~-'~ ~ ;Co~ssion. on June 29, 1983, you requested administrative ~ ' " approval-for an exception, to Rule 3(c)'of Conservation Order ' No. 145 to allow the Surface casing to be set as deep as 3500' ~ .~:i~ ~.~ ~. ,in~four:wellm to be drilled from DS 14 and one well to be '-x~ ~ .:- .~-~: drilled from DS 3. ,':~'~?''' Administrative approval is not necessary since Rule 3(c) ~lready ' .--~::.;f~ allows the"Co~ission the discretion to approve greater setting '.f:~f;~:~_'~. ~,,:depths:"upon showing" that-no potentially productive pay exists -~,..'~'~:~" 'above,the :proposed casing setting depth, and m~ficient cement -. is used to fill the annulus behind..the, pipe to the surface. ~!- ,~_ ,:i~ --, .- ~ ~ ... . The ¢o~ission will ¢onsider'appr°V~l of this wri~t±o~ in surface casing setting depth for each well as submitted on the "Application fox a Permit to Drill" (10-401). ~ -" I now have a new home phone :~:: ,..: find useful. · .. · ">--4'~ .': f'. ,:_,-" -/:::':': 1"--! '- t : ., _,: ,.: ,,~:' .?-'-.'~' ..... . :: : ::: !:::-: :-> ,. , ' ~::'~:' Commissioner _ be:2~U . - . Thank you again for the informative presentation and discussion on this y~sterday and please call me at any time at 279-1433. number,-274-1822, which you may . ?ZHECK LIS~.~FOKNEW WELL PERMITS · CompanY.:. !?ITEM APPROVE, ,i:'!~,~'DA E (1')!~ Fe.e.. ~~.._~~ i~_%~,.- 1. Is the Permit fee attached ....... ,.. .......... (2) ~o~ r/~.~il;%---'~ .2..Is well.to be located in a defined pool'. ..... ~ thru 8) 3. Is well located proper distance from property 4. Is well located proper distance from other ~wells .. 5. Is sufficient undedicated acreage available in this pool .. 6. Is well to be deviated and is well bore plat. included ..... 7. Is operator the only affected party ....... ~ ................. 8. Can permit be approved before ten-day wait ............ '.... (3) Admin /~'- ' ~'~ ~thru 11) (4) Casg ~ y-2-~_~ - fCiC2 thru 20) . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) BOPE~~__ /~.2-~_~ C~21 thru 24) (6) Add.:~ ~'-2--"~'3 21. '22. 23. 24. 25. .. REMARKS Does operator have a bond in force .................................. IS a conservation order needed ...................................... Is administratiVe approval needed ................................... . Lease & Well NO. *eeele®e®e~Z eeeee.e®ee .ieee. Ieee Is condUctor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... · . Will cement tie in surface and intermediate or ProductiOn strings Will cement cover'all known productive horizons ..... ' ........ Will surface casing pro'tect fresh water zones . ...................... Will all casing give adequate safety in collapse, tension and burst,.~Z2 Is this Well to be kicked off from an existing welibore ...~ .......... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separatiOn proposed ........................... Is a diverter system required ........... . ................. Are necessary diagrams of diverter and BOP equipment ~;;~g~g~ . Does BOPE have sufficient pressure rating -Test to ~oo~ ps~g Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: o Geckl ogy: EngiD~e ring: HWK~ L~S ~ B EW~ WVA~ JK~ HJH ~ rev: 1.2/06/82 INITIAL GEO. UNIT I ON/OFF POOL CLASS STATUS AREA NO.I SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi · .. No Special'effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA INC. Well DS 14-32 ECC# 2585 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA- Date DELIVERY DATE 12-22-86 2-18-87 Curve Name~ (Abbrev.) Standard Curve Name Logs Used Scale . CCL LS SS FILES 1-3 Casing Collar Locator Long Space Short Space PDK- 100 G1 Gate 1 " GLES I G2 Gate 2 " GR Gamma Ray Background Lonq Space Background Short Soace BKL ~ BKS MON Monitor ,' CSS Capture Short Space " ISS MSD SGMA RATO RICS RIN Inelastic Short Space Mean Std. Dev. Sigma Ratio of CaotureCounts Ratio or Inelastic to CaptuJe" Ratio of Inelastics [00-600 -2700 6000-540,00 . ~-72000 t12000. 100 )-300 )-300 ~-0 60-0 33-3 43-0 RBOR Borehole Ratio " 3 to -1 b~ge 2 of 2 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska f Inc. Well DS 14-32 ECC# 25R5 Field Prudhoe Bay County, State North Slope, Alaska Date 12-22-86 .DELIVERY DATE 2-18- 87 Curve Name (Abbrev.) SGAV R~NAV RCAV RTAV GR Standard Cu~*e Name Logs Used Scale FILE 4 · Average Sigma Average RIN Average RICS Average Ratio Gamma Ray Pass 1 PDK- 100 I 60-0 14-4 43-0 33-3 0-100 PP ~5 AA AA CC 111 11 ~CCCCC ~.~OC~- ~-~_"~0~ ~rcccc£co O'GOCCCC-~ CC ' CC CC CCCCC ~ OC COO OO OCC 0£ 3CCOO CC OOOOC COO00 OS OOCC2 CC 6COO O0 OOCC CO ~ CO OO~ CC OCCOCCCO0 OCOOGOOOC · 0 CC3CuOu --C~3O ....u ~ OC C30 O'3 11 1I .... I1 11 11111111 11111111 .... :i.iiiiiii :, iiiii11.1 ~ '''' :?-:--::CO000---O0 11 CCOO O0 11 £C0 O0 11 3CC-CSCCO 11111111 OOCCOOCOO ~.~036C-~ ~ 22222222 CO OS~ .... 08 COOCO 22Z // I// 111 //I 1111 /// 11 III 11 1// 11 11/ 1! /// 11 /// /// i~11111 /// ~1111111 // // 77777777 77777777 77 777 777 ~7~ ! 777 777 777 777 777 111 II/ III -' /II 11/ II1 II/ Itl /// III /I ~::L NAM= : ORIblN : FbYb SERVICE NAME: K~:L CONIiNU~i iON NUM6:R: 01 PK~viwu$ REEL NA~E : TAPE NAN~ : ' OR-GiN : FSYS SfRviC- lAP Coi~TiNU~liO~ ;R~ViOUS T~Pf NAN~ : C OMME N T S: LENGTh: 1~2 6YTES -.. EAF_.,ER ,~' i ~ : B~SEGR.O0i --'/v ~ FiLE H FiLE NAME MAX AECOA ~iLE TYP: -- -- H hi - M W N 14-37. FN : PRUD~OE 5AY bUUN : N.bLCPr STAT ; ALASKA LCC 150.03 :NTF, Y BLOCKS TYP=. ~_ ENTRY OESCR"'--iO!~~.-', ucPTHS DECREASE F P ~.R: E SP$,CiNG FRAMr- S~A,C£NG VAilS ,v~XlNiU;q. . =~A;'i:S/RECOR TERPiN~TOk LEVEL SP~.CiN D~TUM~<F FiFiC~IiON. ~Lu~'K-~ CURVE NAN-- COL SS rODE~ ~¢iZE S~MP~ E.. UNITS N~ME 68 4 I DiM LS 6S 4 1 CPS G1 REmR .~., CC~E iZE SANPLE UNITS 68 4 I CPS 6~ 4 1 C~S CPS ' DATUM SF-C'FIC~TiON CLOCKS i CURVE REPR NAME CODE r~z- 4 -4 D!M RBOR .... 0:~.:::?': ~ ' DIM RiCS 68:: 4 1 =~--- ...... ~ .... _._ : ...... :. T~% ......... : ........... CmS CPS CPS CPS CPS CPS ! EPTI! 10:-4~ ~¢~ FT ~4¢. 22C " ~llililmlililIIililliilllllIII! --13 65525a_,50~, ~ ~'~ O.C00 GR i BKL 3~.996 BKS c!9.;91 CSS ~ ..... _46~7.645 MqD lXI 05=~ .~AT~, -~ ., 39.99¢ --G i 7.28Z MON ~ C,~C iSS 1 .43E REOR O. C:OO ·332 j DEmT:F, IC-/'-."'C-,,..~ .CC, C -T 323'-0.,¢:S60 M · CrL,., C · C "' '"'.,' ',.., LS 3. fl_, "' 4,... Sq- - F__13 -~ 1 i i i . 44 C., G2 2.0 . 3c'~.- ..., Gm,. ~5:<L 27.7~39 5KS 3.145 CSS ':: SGMA ---'-5.4'6 MS:5 4.326 RATO : R 'N 0 S'~ ~'' ~ , . ,..,~, -, uS O-'~ ' 14.0~C G1 I S. 9.36 MGN 12.9C7 4.164 R-OR i '-T.- P TH. 1C"- ¢"... . C*a,.,=T 32~0,~ .436C ~-;. !CrL ~ r~m . ,.. ...,.~,.u ~ S I .117 '- ~ 30 ~---1S 234~_.6,4 2 !EKL $,i56 -KS 34,67! SS GR !4.117 61 1 i, 653 I-'Ok $, "' ,~ ~. C. GC, O 7..SS.'-, ]EPTH 10400.CC0 ~T 3169.9270 M 'CL O.CO0 LS- 8.354 SS 6.987 G1 SEiS 285343.500 b~ i0.352 GR ii.416 MON fiKL ii.274 5KS 38.-567 CSS ~.807 :SS ~iN O.CCO N~CS a.-i-iu C.O00 ,.'. I 1~ ,E~i~, -iC'300.SCO rT 3i39.44bC M llmlilliIil--ll ~LL 35i ~ 9"JO L~ I 2.~0 ~ ~.466 ~'1 '~iS 34~i96.i00 G2 9.414 G~ ?Z.81~ MOi~ $GMA -~0.~17 MSD 2~.500 R~TO i.2~ wSO~ - .-, ?.39g C.OCO I. 1". 1 -;ruTH l OmC'C r:cr' ~T xi'~ 9662, M 'GL v. CO0 LS 22.4!0 S~ i~.744 Gl %~iS 2.77467.400 G2 23.624 G~ 54.353 MON :~L i22.Ci.~ ~ i26.328 CSS 23.85i ~ 5G~i~ -160.7~3 MSD 5.455 ' RATU i.5~d R60R ~iN O.GC3 RICE 1 .~96 34.211 O.CJC 47.55? 1.586 .,'t -2=~~-,,, iOiOO.OnO ~T ~O?8~ .4~6C M UL U. ~ '-3-' LS i7.6ig SS ~,.i,~7 ,~1 b -'i 3'i 270.9C:'u t.,/ I 3.61 3 G~ :-1.55~ mON O.OOO 5KL i00.522 8~K'--S'~?~:i 74.796 CS'q 2].6.6C '-' ZSS O.CO0 LS ~.875 SS 2C.16~ i S i 252.700 ~ ~';~c076. ~:1~;~¥~ ~:-~;~r~77~:;~6 6 ~ %:: 'MON -574.i80 HSD 18.708 RATO :'~.'169.::' RBOR u. O00 RICS 2.C62 STA~TZNG DEptH =106~9'000"F~~ ]ZA$"SZ'20 h~ ..... -'F'~DZNG D~PTm =i~057.500 F? 3005.5~20 H eCL 32.542 0.S70 1G.~63 O.CO0 26.999 0.802 .-_'%.: ,-.7' -. :' ~ riL' IK~iLCK ~* FiLE NAME; ~ASEGR.O01 ,:~Xii,iuN LSNGTn: 102~ =IL- TYPE: LO ;,~ FiLE HESD=R $' £ ** ' '~,'E: -~SS i 002 =iLE i~.: '-" . -=2VICE NAME: -~,TE: ~5iil/2C ,::AX REC, O.~[~ LENGTh: 1,.,324 - [ iLE TYPE; _,~. MNEM CONTENTS 4PIN : 50-C29-20999 CN ': ARCO 4L$$KA iNC. WN ; ~.S. I&-~P UNITS FN : PRUDMUE mAY COUN : r~.SLC, FE STAT : ALASKA LOC : 155.G0 FORMAT -NTRY ~LOCKS TYPE -NTRY ?~ESCRiPTION DATUFi SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE CCL 68 4 'SS 68 4 GEJ$ 68 4 GR x¢: 4 ..~ 5KL ~8 4 SSS 6g SGM~ 68 ~ATO 6g R'iN 68 CURVE SAMPL: UNITS NAME CODE qiZE SAMPLE ~' :;: 1 ,3' I M L $ /: 5' 5---;'-- 4 I : '~", -FORHAT ** UNITS ,CPS CPS CPS CPS CPS Su ~NT~Y_~ nLCrKS~ ~ TYPE ENTRY 4 t DEPTHS DECREASE $ 6r'..O FRAXE SPAC'~NG~. 9 . ii[i FRA~<E S=AC-fiG UNiT~ 11 17, MAX_iMOH FRAiqES/RECORD ~'~ T ERFiNATOR. ~uu LEVEL SPy'S N~ CURV~ REoR SiZE S&MPLE UNITS CURV- CCC,=- ~Z S ~* ~-".mL[ UNITS CCL 68 4 1 DIM SS 68 4 1 CPS ~-~5 ~ 4 1 CoS ~R 68 ~ I AP1 ;5KL 68 4 1 CPS _ _ LS G2 M 0 N 5KS _ - C°S CPS cns CPS C~3 SGMA 68 4 't SU MSD 68 -~- 4 ~ATO 68 4 1 DIM RBOR 68 4 !iN 68 4 1 DiM RICE 68 & DATA 1 SU I DIM I DIM 'EPTH i0648,000 FT 3245,Si?C M imIIIlll JCL 0,O00 LS S49.~05 5S 8e9~.i3~ '$~iS ~3673.640 02 0.GgG GR 1i.763 :~L i29,987 ~x$ c89,93'J C~S SGMA ~.~)~ MSD J,U~O RA~O ~,9~5 <iN -i2.~37 RiCS 36.541 Gi 859.9-i4 384.961 2700i~.60u =.154 -EFTH i06GC,COO FT x2xO,B860 M . $'SL C.O©O L'S '1047.3C'i ~ 'i74~'i,olC lEiS 65102,250 02 i992,E57 GR q4,02C {KL ]7,441 BKS 129,134 ' CSS 12291,740 SGMA i7..52~ MSD 0·426 RATO i~.~=4~ RiN ~i,418 RiGS 2~,756 ' ~x2i.-i25 369.355 267422,300 i.793 5EDTH 10500,000 FT 3206,,4060 M i I i i ..... I ........... ." r- ',.., L O '" "" . ,.., ~0 LS S£1S 61569.970 02 ~L 26.547 BK~ $GMA i4.6i7 MSD '1217,226 SS 1694].220 01 7363.29~ 2797.6i4' GR 9,459' MON 350.'159 i30.669 CS~ i2496.0iC iSS 152651.000 0.i72 R~TO i3.840 RBOR 1.780 '' 20.217 Z.'=PTH 1,3400, 03.0 T )$;]Y;69.977C M """ L~,,, ',3. C-- 00 GEiS 00905.090 ~,L 20,965 S--gM ~ i5.38o RiN i i. i 20 ........ -,<~..: ( _._ CCL u,O00 LS 1557,55-~ SS 26767'~'370 G1 '6045,984 GEiS 88962,88-3 62 .J135,716- ~- GR 30,143 MON 385,396 5KL 7i .1S0 5KS 162~668 CSS i662~. 5iC · iSS 333~90. 530 SGMA 26.4i6 MSD 0.854 R~TO 16.157 RBOR 1 .47~ lin 7.706 RiCE 1S.2~5 :7.,_,-~i~ 'i0200.bGO Ff '~'i08.';060- M -CL O.O00 L$ i906.i4~ SS ' 19735.650 61 84ii.x28 G~is 87637.6°0 62 2254.379 GR 65.975 HON 36C..724 ~L i15,515 B~S 2i6.035 CSS i8368.840 I~S 29C0i5.900 SGM~ 20.470 M$O 0.282 RATO i5.254 RBOR 1'.456 ~2N 7.4i0 RiCS -i5.788 "=FT~ 13100 C¢0 .: · u , , ~u7o.4066 M ~CL O COO LS 9S5 ~65 S~I~ $'36~4_ ,7=0~ G2 201,114 8KL ' ~i, ~TN ? C~? RICE ?~ '01 SS 205¢r... 27C 01 2~11..~ . 403 GR 51 .297 MON ~2;.517 u~~ ~S 1 35E4.61 2 I SS 2757~..,n00 aaTO 2C.985 RBO~ 1.594 "~O FT 5Cu5 ,C DEPTH I0056,_.~ ,-ri []- ~00 LS ~3C.297 Sa 19i67.71'C 01 E012.7;6 ........ ~, ~ 5KL .~2,380 BKS 149,985 CSS 12372.16~-, ISS SGM& 35,801 MSD 0,389 RATO 22,6. RBOR RIN 7,745 RICS 22.521 27863d. 300 I .579 STARTING DEPTH =10545.000 FT :NDiNG D;PTH 10056.500 FT 3245,5170 M 30o5,2270 M FiLE TRAILER =iL= NAME: P~,SS SERVICE vERSiON # : i ]ATE; ~5/11/ qAXiMUM LENG'T¼: 1024 :iLE TYPE: L'O .~EXT FILE NANE; , ** =IL~ ?S~D?~ ~ ~ *~ =IL'E NAME: PASS 2.003 SERVICE NAME. 7 VEKSiON ~ : I ~=iil/ZC DATE; .~_, ','i,~X RECORD LENGTd~ ~.L TYPE: ~ -'~REViCUS 'FILE 1 C24 ~YTES *'~ iNFORMAT!GN RECORDS ¸ '- F C S L ENTRY BLOCKS TyPF-. ENTRY CE$CRiPTiO;~ 4 i g E-~T¼S 2-ECREAS~ $ 6C.G FR ~,FE 'SPACING 9 : .lin F?i'~F:E SPACING UkiTS ii 13 MAXIMUM FR~.MES/RECORb O l E RMI NATOR 0 · 5nn ~ ~ ~ ~ N~ ~v LEVEL ~: ~ u t- C A T U !,',, SP=CIFiS~,TiCN ~,:<VE ""- ff~4ME CODE SiZE SAMPLE LNITS CCC. CE SIZE SAF.'P LE UNITS CCL 66 4 I ~Ig r- CPS" ~ 65 4 1 'GEq3 65 4 I CPS ~KL 65 4 I CPS CSs 68 4 I APl LS 51 G2 f~CN iSS ' 65 4 I CPS ~v 4 t' CPS 68 4 I CPS ~ 4 1 CPS 66 4 1 CPS d3 4 i CPS RATO ' 68 4 . DiM RBOR 68 -~"' 4 R!N 68 4 1 ,DiM RICS ,58 4 ** FORMAT ** 1 o I M fl:>. ENTRY BLOCKS i'YP6 ENfKY' mmm-- mm--mm 8 OO.U 9 ,1iN 11 u -0.5O0 mmmm mmmm mmmm m lmm mmm ~-RAI~P bPACZN~ UR.LiS MAXIMUM FRAMES/F, ECORD . LF- vEL ,~P AC i NL~ 3ATUi~ SP;CiFTCATiON BLOCKS CURVE REPR N .~P, E CODE Szz- SAHPL; ijmZTS CURVE REPR i.,; A Fi E CODE ~iZE S~,M;LE UNITS ~C,L SS SEIS ='Kc. ~SS SGMA RATO R iN 68 4 1 68 4 1 CPS 68 4 I CPS 66 w : I AFl 68 4 1 CPS 68 4 I AP1 68 4 1 gU 68 4 1 68 .: DEPT~ i0643. LS 68 4 i CPS Gl 68 4 1 CPS 02 68 4 I CPS MON 68 4 1 CPS InKS 6-3 4 1 CPS TSS 68 4 1 CPS MSg 5 3 4 1 SU RSOR 68 4 1 DiM CCL O.CGO 6~1S 5x434~ . 360 BKL i79.¢81 SGMA 4i.602 ~iN i2.E52 ElM LS ~. 229.977 SS ~7569.246 ~-.-G-1_ 9~9~c04 -- ....... · .: <f:~ .... ~ . _.. HSD 1.244 RATO '29;~('4347' RBOR 2.156 R I C S 37.1 09 '%::(':J 1060O CCC =T ~-23,3 836C M G~iS 564i JKL 4 3 G:M A I G.GO0 LS 905.171 SS 14n~0,~ .590 01 5475.266 4.4i0 GE i832.77~ GR i~,969 MON 336.689 9.72Z ~ 'l'~O.Co'l u~b 10o-i,.226 ~ 23440-i.300 6.727 MSD 8.4'2 RATO 16.3g5 RBOR 1.833 i.02i RiCS Z2.C8~ DEPTh 10500.000 FT 3)00.406C M CCL u.COO L5 i259.770 SS i7071.01C Gl 7Z75.906 GElS 59941.550 GZ 2626.49& GR 1i .037 MON 370.310 5KL 43.584 BKS i5i.2i~ CSS i23i9.92~ TS$ ZS2697.930 SGM~ i4.20i MSD C.334 RATO i3.566 RBOR I .820 RIN 10. ~77. RICS .~0 .,~11 D=PTH 10400.C'..3 FT 3169.9270 M SCL O.COO LS 9:36.65~ GElS 53125.770 G1 2i.53.927 ~KL 52 4~ _,..,1 _,*KS 1 44 · 71 --~ ~iN :i 1. iSl RiCS Z0.569 SS 16251.353 01 ~206.891 SR 1'4.i07 KON 361.544 ..... ~ '~- 23~21~ ~OC C~ 11..%..~ .;¢ ~ ~. RATO ]6.iC~ RSOR 1.7~6 3EPTH ~0300.CCO FT 3139. ,-60 M ..... . SCL 962.550 LS 1~93.481 SS 27698.19'J 01 C-ElS 86759.190 02 1420.469 GR 31 .287 MON -KL 106.032 BK-S 195.992 CSS 16957.940 ZSS 3 G~-', A 24.000 'NSD 0.556 R~T0 13.3E6 R50R qlN 7.163 RICS 17.601 6623.738 401.027 298483.600 1.460 _.. =E'TH 10280 COO FT ~138 9660 H -CL O.CCO LS ' 207i.660 '~iS 896i7.560 G$ 232'i.662 5KL i63.855 6KS ~45.C54 rSS 3GM& 20.122 MSD C.559 RATO R~N 7.C97 RICS 15.548 53.250 MON i~646.780 iSS 14.54~ R~OR 2,577.303 z~5 i 44 289~i6.800 1.474 2E?TH 10100.003 FT 3.375.4S60 M * "" L.,, 0 . COO LS 971.. '""' C 3_. SS -:2-13 91112.190 Gl 235.690 GR 3KL 109.9'~5 BKS 2.~6,815 CSS SOMA 38.163 NSD 3.819' RATO -lin 6 ~96 RICS " . .,, 204~l.gge G1 52. 987 MON 13716~G33 iSS 21 ,r .-~I RBOR _?e61.52~~ ~ 343.110 275216.900 1.642 , : : -CCL O.CCO LS 786.115 SS GEIS 72375.5 02 231.5-~7 ' GR ~KL 101.~ BKS 197..674 CSS SGMA 3 6.1 RiN 7.4 G DE~TH 17645.270 61 40.9~5 ..... 11468.02C iSS 2664.612 '<61' "' .~ .:44 i'~ ¢-~ c66o~.503 i .5?.0 10' 35 56 ' MSD 0.748 RATO ' 22.g-47 RBOR SERVICE N~ME. VERSION GATE; iqAXi~UN LENGTH; ~iLE TYFE; LC · NEXT FiLE NAME.. 1 024 ................ ~- ~iLE HE~DER FIL:. NAM=.; PASS SERVICE NAME: 4 VERSi~Nu ~ ; DATE: 55iiii20 M~X RECORD LENGTh'- mILE TYPE'; LO ~-R- iuuS FTLE~ N~;<E: 1024 5YTES · ,k,~ iNFOR~4Z, TION RECORDS t. IN .... ,-, ~CNTENTS !Tr' Ul", APiN :.,,_---n-C2C-20~'97. CN ; AP. CO ALASKA ,-, ,,, : .~. 14- -NC. FN ; 'P:~UDHOE BAY COUN : N 'St '"~ 'LOC, : I ** FORMAT =NT~Y 9LOCKS i ¥1-"-,_ ENI~¥ UtSCRiviJ. UN o 8C,0 ~RA~: SPACING 0 TERmiNATOR -0,500 LzV~L SP$CiNG /;~Tur~ SP-CZPiCA~iON 5EOCK~ -URVE REPR ~,~AME CODE 'CL 68 . SS 68 SEJS 68 -R 68 =KL 68 '-SS 68 SG~A 6' -~N 68 CURV$ RmmR~ ~z~E S~MPL~ UNITS NAM: ~COE SiZE 4 1 ~$M LS 66 4 t 4 i ~S ~i 68 4 1 4' I CPS GE 65 4 4 I ~Pl MON 68' 4 ~ 1 CPS 5KS 68 '4 ~ :i AP~ iSS 68 4 4 1 SU MSD 68 4 4 1 uZM RBOR 6& 4 4 i DiM ~iCS 68 4 SAMPLE UNITS C.~S CPS - CP'S C~S C'~S CPm SU i DiM D i'M ENTRY TYPE ENTRY 6 6-'". O 9 ' . lin ii -G.580 FRAME SPACING UNITS .... ~AXiMUM FRAMES/RECORD .. ~ ERM iNATOR L~VEL SPACING 3ATUM SPECi~ iCATiON 5LOCKS -URVE REFR NAME CODE Ii~ .- ,,UL 68 SS 68 GElS 68 GR 68 5KL 68 CSS 68 SGHA 68 RATO 68 R I'N 6'8 SiZ CURVE SAMPLE CNiTS NAME i ~iM tS 1 CPS 61 ' i CPS "GZ 1 APl MON I CPS BKS' t AP1 ISS I SU ~qsD 1 DiM RBOR I DIM RICS R£~R CODE SiZE SAMPLE ll~! IlIlI lllIII 66 ~ 68 4 68 4 ' 1' 68 '4 c~ 4 I 68 4 68 4 '1 68 4 1 ~.$ 4 I UNITS Cr-.S CPS CPS CPS CPS SU SIM :.-i_ . ** DATA ** SE~TH 10~'5 nCO r . .~3C ~,~ ImIIIIiIIllmIlililiIilIliIiii! COL O.SCO LS SS 7~69.25~ Gl SKL 14.9.985 BKS 379.962 CSS SGMA 40.574, MSD 2.296 RATO RIN 12.011 R!CS 36.889 6539.3'''-~ ISS 243075.800 25.5 RBOR 2.138 DEPTH 10600,CC0 FT 3230.8.860 M ............................ I I CCL O.CO0 LS IC4£.527 SS GEiS 630.40.6i0 G2 ZC07'. 36,, GR 5KL 46.953 BKS i60.3c, 8 CSS SGMA i 6.8_.-.6 MSD 0.297 RATO RiN ii.i65 RiCS 2i.33~ 16-51 3. 09'",, Gl 59/.I . 6ei. 24.3~.5 MUN 372.i90 ii,646.940 iSS 252797.900 15'.916 RE, OR 1.788 DE~TH 'i0500.C00 FT 3200.4060 M CCL O.CO0 LS 14i0.383 SS GElS 65435.630 G2 3C00.385 GR ='KL 7-7. . ' '" ~ '" .~ . 404 ~-.~K~ 15,_.- (¢ ess SGMA 14.6~i MS,S 0.509 RATO RiN 10. ?g7 R'r C",. ~ 1"',-. u.., ,,"' p- 195i8.590 G1 7940.143 13.632 MON 350.023 ]3664.880 ZSS 2724]3.300 13.866 REOR 1.849 DEPTH 134u~ Cu,... FT 316c '~70 ~' CCL 0 "'00 ~. . ~,, - . .u ' ~ 1089 644 ~ i6-.s67.350 61 6698. 215 GE1S 5°8¥ "'C MON 366 6P o ~6. ~' ~ G~ 2433 6~C GR 1 ~KL~- 2~.~8 ~,,S 143.xnl'~ r35~ 119~7.~C~~ ~SS 240. ~. 70.600 ' 3GMA 15.516 MSD 0.14¢ R~TO 15.6~ RBOR 1.747 : RIN 10.~6~-~ RZCS 20.i69 3EPTH 103CO.CCO CT 3139.446C :- GEIS $4702.190 : ~ 3KL 61 .C32 S GM,:,. 17.582 : RiN 6.794 ~'-,-,.~ 10200.C~0,- ',, FT !cc . · %Ei$ ~3706.000 ~KL 135.578 ~GMA R ZN G2I~::~;-~ 373 S. 53 O G R 24 .%'3-39I:: M 0 N 38 Z. S 95 ~;~%:~%d'- %-~; ~:-;~t ~7:- :: 3108.9660 M ]47¢5~,_92' C'~?¢:''~?~1~~ S 56. 4 477 ......... 2'E2'2"7 ' 3 B-KS 252.654 CSS 1 93~ 8 ;'5-90 IS5 3060~4.330 22. 313 MSO ....... : ................. 0..380 ........ RAT-O ........... 1 5.842 ...... RBOR 1 .442 6.952 RICS 15.~Z8 ?-2 3"'"F'TIi 101CO.CCC FT 3078.4,..,60 ~ iIlll I IIiilll ilil III lliiIlli I CCL 0.000 L:::, iCig. Ori G--13 93991 .SlO G1 Z¢$.644 GR ~,KL 158.437 .SKS 269.i57 CSS SGFi.¢,, 37. 735 MSD O. 57=,, RATO -~ l i'~i 6. 943 RiCS 1 9 . 9i 6 22034.6~0 G-1 3i07.~-y 77.102 MON 353.172 14559.54C i~S 2~9~62.SC0 21.292 RBOR 1.575 i :i DEPTH 1,33..?,3.500 FT 3064.3130 M ~,~L O.SO0 L~- =3;'.519 ,~3 ~- ,o 767'39.500 G£ 302.638 GR . ~KL ~.~.433, 5KS 19~. S~'~ CSS ~GMA 35.403 MSD 0.434 R~T$ .:~3 ~IC$ 22.]71 ~,75· OTC Gl ~0~3. 2~=5 43.566 MON 361 .964 ,5.44C ~S'~ ~76"~3~ =.~ .400 23.109 RBOR 1.574 ':., , -~RT NG 3'-'"Ti',,-- =1 u6 ~ r . ,-'OO'" 7T ENDING DEPTH -10053.500 ~T 3244.,~"-'"30 ~'~., 3C64.31 .SO 14 FILE TR~iLER *~ S'ERVI~E NA,ME: V~RS~ON # : 1 DATE: 851111 M4XIMUM LENGTH: I 024. =IL.=_ TYPE: LO FiL; NAME: AV~RAG.O05 V:k~iON ~ : 1 UAl:: 35/ii/2t HAX R;CORD LENGTh; FiLt 'iYFE: LO 1024 BYT,-S .-:'. ~R~ViOUS FiL~ NAR;: ~ iNFORi~.ATZCN RECORDS MNEM CONTENTS A~N : 50-C2~-2699~ ~N : O.S. 14-32 UNITS FN : PRUDnOE BAY COON : N.SLOP: STAT : ALASKA ~CC : i~0. ."CO 60.0 .1iN D.~ TUM SPECIF !CAT~ON 3LOCKS ,SuAvE R~R NAME CODE SGMi 66 ~ATi 68 RiCi 68 GR2 68 KIN2 68 S G M 3 68 G~3 65 ~Z~3 6~ ~AAV 68 ~AV 6~ CuAV: KzP~ 31Z:~ SAMPLE UNITS NAMr~ ~CDE SIZE 3AMPL 4 1 GEl 65 ~ 1 4 1 R~Ni 6~ 4 1 4 1 SGMZ 68 4 i ~ i ~z R:~T2 68 4 4 1 RiC2 66' 4 1 4 1 AP1 RiN3 68 4 1 4 1 SGAV 68 4 I 4 1 R!AV 68 4 1 UNIT3 ENTRY ELOCKS $ 9 11 m~mm mmmmm mmmmmmmmmmmm 1 ~=PTH$ DE~R~AS=~ 6C.0 F~E SP~C~NG .1ZN =R~NE S~ACZNG UN~TS 12 ~XZ~UH -RAH~S/RECORD . . R ,.~ ¥ ~ ~. ,~::~: ::?::::-~-::_~:.:/~ n v~C~-'C~:~:-R-C ~¥:--:~:~-~: ~, ~'0 u --:: - Z I. 756 -:36337~ M :?~-:6333i:39~::~;;6..8783339: .:: R l T~2: 16.32i RZAV 11.195 RCAV 21;806 _ _ . O. C 0 O :;;::0 .-~OC---. S G A v C. O O 0 11 16.595 IS.G25 17.345 _ · . :. D: :::'TH, 10,;00-' . C '"' '",.., v FT 3139 .4 '-, "'". o ~ M S ~ .,'.~ I 26.4'~8, G~1 3"":,.,. I--3= R~'TI,-.- 16 .1~7.. RiCi 18.2R5~, SGMZ _P6. 333 GR2 52,-. 151 ~I;~2 7.202 .~IC2 18.171 S G!-~3 25.377 GR3 --5~ .~n4~ P, IN3 7.154 F, IC3 17.831 ~..'_~v 16 i,-:,? ii.~V ~.354 -,w I~ 11-~ r';EPTH 10200 rr-.n FT 'z108 ¢66C M SGH1 20.470 DR1 6~.975 RAT1 RIC1 I 5.788 SGM2 20.38/, DR2 RIN2 7.110 RIC2 15.680 S$M3 I~ ~54 R!N1 7 41 57.024 RAT2 14.453 20.16g R2T3 14.449 ....... mmmmmmmmmm mmmmmmmmmmmmmmmmmmmmmmmmmmmm ~ ~ ~-. ?' ;: SERV'ZC: KAHE: -'? F_,S/il / MAX£NuM L-~i',iGT~: ,'-iLE TYFE: LC NEXT FTLE NAPE: !~ TAPE TRAILER TAPE NAM:: S RviC~ NAHE: DATa: ...... ],,- ORiGiN OF DATA: FSY~ 'TAP- CONTTNoATZOm ~ ' Ol ~'.,-' . --_ Nc, ," , NEXT R EL NA~E: ,COMMENTS: DRESSER ATLAS 'REEL HEADER - I TAPE HEADER - 1 : FZLE nEADE~ - S .iNffORKATiON - 5 FORMAT - I0 DATA - 467 ' TASLE DU"Pi.. 5 L=S CUSTOH=P, TA~E --- CREATE£ -EY SDS PROGRAM R 2.0 TOTAL R-¢O~D$: I 501 * ALASKA COMPUTING CENTER . . ............................ . ....... SCHLUMBERGER . COMPANY NA1vIE : ARCO ALASKA INC. WELL NAME : D.S. 14-32 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBF~ : 500292099900 REFERENCE NO : 98360 RECEIVED JUL ? 4 1998 Alaska Oil & Gas Cons. Commission Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE · 98/07/16 ORIGIN : FLIC REEL NAME : 98360 CONTINUATION # : PREVIOUS REEL : COFk4F2TT : ARCO ALASKA INC, D.S. 14-32, PRUDHOE BAY, 50-029-20999-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/16 ORIGIN .. FLIC TAPE NA~E : 983 60 CONTINUATION # : 1 PREVIOUS TAPE : COF~IENT : ARCO ALASKA INC, D.S. 14-32, PRUDHOE BAY, 50-029-20999-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 14-32 API NUMBER: 500292099900 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 16-JUL-98 JOB ~ER: 98360 LOGGING ENGINEER: J SPENCER OPERATOR WITNESS: G SARBER SURFACE LOCATION SECTION: 4 TOWNSHIP: 1 ON RANGE: 14E FNL: FSL: 40 FEL: 2600 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 69. O0 DERRICK FLOOR: 68. O0 GROUND LEVEL: 39. O0 WELL CASING RECORD 1ST STRING 2NDSTRING 3RDSTRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (F~ WEIGHT (LB/FT) 9.675 10088.0 47.00 7.000 10802.0 29.00 5.500 9694.0 17.00 4.500 9792.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (f4~ASORE29 DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUFIBER : PASS NUMBER: DATE LOGGED: 25-AUG-83 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10493 0 10485 5 10480 5 10469 0 10464 5 10461 0 10460 5 10456.0 10449 5 10438 5 10434 0 10430 0 10429 5 10422 5 10422 0 10417 0 10413 0 10408 0 10405 0 10399 5 10393.0 10387.0 10381.0 10379.0 10378.5 10376.0 10375.5 10371.0 10370.0 10361.0 10360.0 10356.5 10355.0 10354.0 10350.5 10349.0 10347.5 10345.0 10336.5 10336.0 10331.0 10328.5 10324.5 10324.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.5 88887.5 10465.0 10461.0 10449.5 10439.0 10431.5 10422.5 10413.5 10382.0 10380.0 10376.0 10371.0 10362.0 10356.0 10354.0 10350.5 10348.0 10337.0 10329.5 10325.5 10492.5 10485.5 10481.5 10469.0 10465.0 10461.0 10456.5 10435.0 10431.5 10422.5 10418.5 10409.0 10405.5 10399.5 10393.0 10386.0 10380.0 10376.0 10370.5 10362.0 10357.5 10350.0 10348.0 10337.0 10328.0 10325.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 10318.0 10318.5 10315.5 10316.5 10315.0 10316.5 10306.0 10307.0 10303 . 5 10304.5 10302.0 10303.0 10299.0 10299.0 10298.0 10299.0 10295.0 10296.0 10288.5 10289.5 10287.0 10288.0 10286.5 10287.5 10285.0 10285.5 10282.0 10283.0 10280.0 10280.5 10277.0 10278.0 10278.0 10275.0 10276.0 10273.0 10272.0 10266.0 10265.0 10264.5 10265.0 10260.0 10261.0 10259.5 10261.0 10258.0 10259.0 10256.5 10258.0 10253 . 0 10254.0 10249 . 5 10250.5 10249.0 10250.5 10242.5 10244.0 10230.0 10231.0 10229.5 10231.0 10227.0 10228.5 10226.5 10227.0 10225.5 10227.0 10223.5 10224.5 10223 . 0 10224.5 10219.0 10219.5 10218.0 10220.0 10215.5 10217.0 10214.5 10217.5 10212.0 10213.5 10209.0 10210.0 10208.5 10210.0 10202.0 10204.0 100.0 102.0 101.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO'S DS 14-32 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GA~4A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAB~A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: **** FILE HEADER **** FILE NAJ~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUf4~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 1 DEPTH INCREMeNT: 0.5000 FILE SUFk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10517.5 10200.0 TDTP 10535.5 10199.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS AU3M~ER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 5 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 .............................. ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1102768 O0 000 O0 0 1 1 1 4 SIGMTDT~ CU 1102768 O0 000 O0 0 1 1 1 4 TPHI TDTP PU-S 1102768 O0 000 O0 0 1 1 1 4 SBHF TDTP CU 1102768 O0 000 O0 0 1 1 1 4 SBHN TDTP CU 1102768 O0 000 O0 0 1 1 1 4 SIGC TDTP CU 1102768 O0 000 O0 0 1 1 1 4 SIBH TDTP CU 1102768 O0 000 O0 0 1 1 1 4 TRAT TDTP 1102768 O0 000 O0 0 1 1 1 4 SDSI TDTP CU 1102768 O0 000 O0 0 1 1 1 4 BACK TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 FBAC TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 TCAN TDTp CPS 1102768 O0 000 O0 0 1 1 1 4 TCAF TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 TCND TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 TCFD TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 TSCN TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 TSCF TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 INND TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 INFD TDTP CPS 1102768 O0 000 O0 0 1 1 1 4 GRCH TDTP GAPI 1102768 O0 000 O0 0 1 1 1 4 TENS TDTP LB 1102768 O0 000 O0 0 1 1 1 4 CCL TDTP V 1102768 O0 000 O0 0 1 1 1 4 GR BCS GAPI 1102768 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 * * DA TA * * DEPT. 10550.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBH~.TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: TENS. TDTP -999.250 CCL.TDTP -999.250 GR.BCS 21.609 DEPT. 10170.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBH~V. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL.TDTP -999.250 GR.BCS 291.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1FOI~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCRE~IENT: 0.5000 FILE SU~UL~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10518.0 10398.0 TDTP 10537.5 10395.5 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP ............................ 88888.0 88889.0 88889.5 10530.5 10532.0 10514.5 10516.5 10501.5 10501.5 10497.0 10498.0 10494.0 10495.5 10491.0 10493.0 10487.5 10489.0 10484.5 10485.5 10483.5 10484.0 10480.5 10480.5 10475.5 10477.0 10469.0 10468.5 10467.5 10469.0 10463.0 10465.0 10464.5 10460.0 10461.0 10459.5 10461.0 10453.5 10455.0 10451.5 10454.0 10449.5 10450.5 10440.0 10440.5 10436.0 10435.0 10429.5 10431.5 10428.5 10431.5 10425.5 10426.5 10423.5 10423.0 10418.0 10418.5 10412.0 10413.5 10411.5 10411.5 10408.0 10409.0 10406.5 10406.0 10403.5 10403.0 10403.0 10404.0 10401.5 10400.0 100.0 101.0 98.5 $ RE,lARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 8 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 NUFI~ NTJMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102768 O0 000 O0 0 2 1 1 4 SIGMTDTP CU 1102768 O0 000 O0 0 2 1 1 4 TPHI TDTP PU-S 1102768 O0 000 O0 0 2 1 1 4 SBHF TDTP CU 1102768 O0 000 O0 0 2 1 1 4 SBt{NTDTP CU 1102768 O0 000 O0 0 2 1 1 4 SIGC TDTP CU 1102768 O0 000 O0 0 2 1 1 4 SIBH TDTP CU 1102768 O0 000 O0 0 2 1 1 4 TRAT TDTP 1102768 O0 000 O0 0 2 1 1 4 SDSI TDTP CU 1102768 O0 000 O0 0 2 1 1 4 BACK TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 FBAC TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 TCANTDTP CPS 1102768 O0 000 O0 0 2 1 1 4 TCAF TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 TCND TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 TCFD TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 TSCN TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 TSCF TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 INND TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 INFD TDTP CPS 1102768 O0 000 O0 0 2 1 1 4 GRCH TDTP GAPI 1102768 O0 000 O0 0 2 1 1 4 TENS TDTP LB 1102768 O0 000 O0 0 2 1 1 4 CCL TDTP V 1102768 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: ** DATA ** DEPT. 10537.500 SIGM. TDTP 13.995 TPHI. TDTP SBPiN. TDTP 35.880 SIGC. TDTP 2.187 SIBH. TDTP SDSI.TDTP 0.340 BACK. TDTP 51.117 FBAC. TDTP TCAF. TDTP 22982.242 TCND. TDTP 28030.516 TCFD. TDTP TSCF. TDTP 4110.616 INND. TDTP 2372.026 INFD. TDTP TENS.TDTP 1475.000 CCL. TDTP 0.000 DEPT. SBPIN. TDTP SDSI.TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 10395 500 42 983 0 233 28549 117 5183 575 1405 000 SIGM. TDTP 11.703 TPHI.TDTP SIGC. TDTP 1.458 SIBH. TDTP BACK. TDTP 66.574 FBAC. TDTP TCND. TDTP 28415.012 TCFD. TDTP INND. TDTP 2243.021 INFD. TDTP CCL. TDTP 0.000 22.851 SBHF. TDTP 35.880 TRAT. TDTP 24.061 TCAN. TDTP 9819.303 TSCN. TDTP 424.032 GRCH. TDTP 14.575 SBHF. TDTP 43. 407 TRAT. TDTP 14. 730 TCAN. TDTP 11734. 354 TSCN. TDTP 427. 182 GRCH. TDTP 33.326 1.732 52496.422 9389.539 -999.250 37.036 1.484 54038.203 9811.549 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 3 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 10516.5 TDTP 10535.5 STOP DEPTH .......... 10456.5 10455.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 10 $ CURVE SHIFT DATA - PASS TO PASS (I4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER: 1 BASELINE DEPTH .............. 88888.0 88887.5 88887.5 10516.5 10516.0 10516.0 10513.5 10512.0 10512.5 10512.5 10509.5 10508.5 10508.5 10509.5 10502.5 10501.5 10501.5 10495.5 10496.0 10495.5 10492.5 10494.0 10492.0 10493.0 10488.0 10489.0 10489.0 10485.0 10484.5 10484.5 10485.5 10480.0 10481.0 10481.0 10469.0 10468.5 10468.0 10469.0 10464.0 10464.5 10463.5 10465.0 10460.0 10461.0 10458.5 10461.0 100.0 102.5 101.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. REM~%RKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 11 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFI~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 SBI{NTDTP CU 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1102768 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10535.500 SIGM. TDTP 13 750 TPHI. TDTP 25.277 SBHF. TDTP 31.354 SBH~.TDTP 38.235 SIGC. TDTP 2 198 SIBH. TDTP 38.235 TRAT. TDTP 1.815 SDSI. TDTP 0.342 BACK. TDTP 164 052 FBAC. TDTP 57.399 TCAN. TDTP 45524.617 TCAF. TDTP 18874.688 TCND. TDTP 26248 309 TCFD. TDTP 8907.121 TSCN. TDTP 8449.293 TSCF. TDTP 3503.111 INND. TDTP 2156 393 INFD. TDTP 393.830 GRCH. TDTP -999.250 TENS. TDTP 1490.000 CCL.TDTP 0 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PA GE: 12 DEPT. 10455. 000 SIGM. TDTP SBHN. TDTP 41. 481 SIGC. TDTP SDSI. TDTP O. 250 BACK. TDTP TCAF. TDTP 30457. 578 TCND. TDTP TSCF. TDTP 5666. 248 INND. TDTP TENS. TDTP 1525. 000 CCL. TDTP 11 1 162 30427 2392 0 280 TPHI.TDTP 13.958 SBHF. TDTP 31.261 760 SIBH. TDTP 41.481 TRAT. TDTP 1.480 857 FBAC. TDTP 32.352 TCAN. TDTP 57208.203 211 TCFD. TDTP 12528.697 TSCN. TDTP 10642.865 439 INFD. TDTP 430.184 GRCH. TDTP -999.250 000 ** END OF DATA ** **** FILE TRAILER **** FILE NABIE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREM~rJFr 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, TDTP THIS FILE CONTAINS THE ARITHM~TIC AVERAGE OF BASE PASSES 1 , 2, &3 . THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 53 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 NUM~ NUIW~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUi~ SAMP EL~ CODE (HEX) DEPT FT 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 SBHIVPNAV CU 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TCNDPNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 INNDPNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 INFDPNAV CPS 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1102768 O0 000 O0 0 4 1 1 4 68 0000000000 ....................................................................................... LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 14 ** DATA ** DEPT. 10535.500 SIGM. PNAV 13.707 TPHI.PNAV SBPiN. PNAV 38.903 SIGC. PNAV 2.145 SIBH. PNAV SDSI.PNAV 0.340 BACK. TDTP 124.122 FBAC. TDTP TCAF. PNAV 20279.504 TCND.PNAV 26829.238 TCFD.PNAV TSCF. PNAV 3687.858 INND.PNAV 2214.297 INFD.PNAV DEPT. 10199.500 SIGM. PNAV -999.250 TPHI.PNAV SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV SDSI.PNAV -999.250 BACK. TDTP 149.711 FBAC. TDTP TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV 23. 38. 45. 9238. 404. -999. -999. 30. -999. -999. 994 903 928 738 990 250 250 399 250 250 SBHF. PNA V TRA T. PNA V TCAN. PNA V TSCN. PNAV GRCH. TDTP SBHF. PNAV TRAT. PNAV TCAN. PNAV TSCN. PNAV GRCH. TDTP 28.387 1. 775 47633. 641 8665. 580 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 1 DEPTH INCREFIENT: 0.5000 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 10560.5 10195.5 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 15 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): 08-MAR-98 CP 44.2 351 09-MAR-98 10548.0 10548.0 10198.0 10536.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS 971 TDT-P SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10802.0 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) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): TIED INTO SWS TDT-P LOG DATED 21-AUGUST-1993 LOGGED ON SANDSTONE MATRIX. HIGH GD24M~A RAY COUNTS ON LOGS 19 AND 20 ARE DUE TO NEUTRON SATURATION. LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 16 TAGGED TD AT 10548 FT MD. PUMPED 240 BBLS CRUDE BEFORE LOGGING. CONTINUED TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SURFACE EQUIPlWiENT PROBLEMS PREVENTED ACQUIRING 3 FULL PASSES THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELE~I CODE (HEX) DEPT FT 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) TCNDPSl CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TCFDPS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 INNDPS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1102768 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10550.000 SIGM. PS1 11.886 TPHI.PS1 22.968 SBHF.PS1 36.523 SBHN. PS1 32.706 SIGC. PS1 3.809 SIBH. PS1 32.706 TRAT.PS1 1.794 SDSI.PS1 0.370 BACK. PSi 137.173 FBAC. PS1 45.784 TCAN. PS1 48293.883 TCAF.PS1 20197.742 TCND.PS1 25466.535 TCFD. PS1 8858.418 TSCN. PS1 8735.680 TSCF.PS1 3653.486 INND.PS1 2076.067 INFD. PS1 337.966 TENS.PSi 1470.000 GR.PS1 130.000 CCL.PS1 0.000 DEPT. 10195.500 SIGM. PS1 13.849 TPHI.PS1 17.591 SBHF.PS1 35.087 SBHN. PS1 46.884 SIGC. PS1 1.969 SIBH. PS1 50.568 TRAT. PS1 1.506 SDSI.PS1 0.307 BACK. PSi 145.581 FBAC. PS1 31.546 TCAN. PS1 39203.734 TCAF. PS1 19738.547 TCND.PS1 25692.066 TCFD.PS1 9585.049 TSCN. PS1 7394.110 TSCF. PS1 3722.834 INND.PS1 2196.399 INFD. PS1 381.394 TENS. PSi 1415.000 GR.PS1 46.875 CCL.PS1 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ~ER: 2 DEPTH INCREM~IVT: 0.5000 FILE SU~m~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 10562 . 5 10385.5 TDTP LOG HEADER DATA 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ 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) : 08~MAR-98 CP 44.2 351 09-MAR-98 10548.0 10548.0 10198.0 10536.0 1800.0 TOOL NUMBER CGRS 971 TDT-P SET 21 10802.0 CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 19 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS TDT-P LOG DATED 21-AUGUST-1993 LOGGED ON SANDSTONE MATRIX. HIGH GAI~IMA RAY COUNTS ON LOGS 19 AND 20 ARE DUE TO NEUTRON SATURATION. TAGGED TD AT 10548 FT PUMPED 240 BBLS CRUDE BEFORE LOGGING. CONTINUED TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SURFACE EQUIPF~ENT PROBLEMS PREq;F2FrED ACQUIRING 3 FULL PASSES THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 20 TYPE REPR CODE VALUE .............................. 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 ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1102768 O0 000 O0 0 6 1 1 4 SIGM PS2 Cfi 1102768 O0 000 O0 0 6 1 1 4 TPHI PS2 PU 1102768 O0 000 O0 0 6 1 1 4 SBHF PS2 CU 1102768 O0 000 O0 0 6 1 1 4 SBPiNPS2 CU 1102768 O0 000 O0 0 6 1 1 4 SIGC PS2 CU 1102768 O0 000 O0 0 6 1 1 4 SIBH PS2 CU 1102768 O0 000 O0 0 6 1 1 4 TRAT PS2 1102768 O0 000 O0 0 6 1 1 4 SDSI PS2 CU 1102768 O0 000 O0 0 6 1 1 4 BACK PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 FBAC PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TCANPS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TCAF PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TCND PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TCFD PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TSCN PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TSCF PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 INND PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 INFD PS2 CPS 1102768 O0 000 O0 0 6 1 1 4 TENS PS2 LB 1102768 O0 000 O0 0 6 1 1 4 GR PS2 GAPI 1102768 O0 000 O0 0 6 1 1 4 CCL PS2 V 1102768 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 10550.000 SIGM. PS2 17.842 TPHI.PS2 SBH~.PS2 38.961 SIGC.PS2 0.000 SIBH. PS2 SDSI.PS2 0.621 BACK. PS2 51.580 FBAC. PS2 TCAF. PS2 10692.709 TCND.PS2 19591.293 TCFD.PS2 TSCF. PS2 1969.829 INND. PS2 1636.258 INFD. PS2 GR.PS2 29.922 CCL.PS2 0.000 DEPT. 10385.500 SIGM. PS2 5.787 TPHI.PS2 SBHN. PS2 37.996 SIGC.PS2 4.538 SIBH. PS2 SDSI.PS2 0.638 BACK. PS2 7.361 FBAC. PS2 TCAF. PS2 0.000 TCND.PS2 -999.250 TCFD. PS2 TSCF. PS2 0.000 INND.PS2 -0.250 INFD.PS2 60.442 SBHF. PS2 37.413 38.961 TRAT. PS2 2.614 31.145 TCAN. PS2 37529.688 4815.759 TSCN. PS2 6913.782 216.255 TENS.PS2 1485.000 0.000 SBHF. PS2 25.079 37.996 TRAT. PS2 0.000 2.629 TCAN. PS2 0.000 -999.250 TSCN. PS2 0.000 -0.089 TENS.PS2 1395.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 21 GR.PS2 25.344 CCL.PS2 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAI~IE : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAIViE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~FIARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10561.0 10451.5 TDTP LOG HEADER DATA 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE 08-MAR-98 CP 44.2 351 09-MAR-98 10548.0 10548.0 10198.0 10536.0 1800.0 TOOL NUFIBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 22 GR GAFflVA RAY TDTP THERMAL DECAY $ CGRS 971 TDT-P SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10802.0 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) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REFIARKS: TIED INTO SWS TDT-P LOG DATED 21-AUGUST-1993 LOGGED ON SANDSTONE MATRIX. HIGH GAMMA RAY COUNTS ON LOGS 19 AND 20 ARE DUE TO NEUTRON SATURATION. TAGGED TD AT 10548 FT MI). PUMPED 240 BBLS CRUDE BEFORE LOGGING. CONTINUED TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SURFACE EQUIPFIENT PROBLEMS PREVENTED ACQUIRING 3 FULL PASSES THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE APIAPI API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~4 CODE (HEX) O0 000 O0 0 7 1 1 4 68 0000000000 DEPT FT 1102768 SIGM PS3 CU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1102768 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1998 14:29 PAGE: 24 * * DATA * * DEPT. 10550.000 SIGM. PS3 SBHN. PS3 36.717 SIGC. PS3 SDSI.PS3 0.399 BACK. PS3 TCAF. PS3 19782.543 TCND.PS3 TSCF. PS3 3659.805 INND.PS3 GR.PS3 295.500 CCL.PS3 DEPT. 10451.500 SIGM. PS3 SBHN. PS3 36.916 SIGC. PS3 SDSI.PS3 0.379 BACK. PS3 TCAF. PS3 24436.121 TCND.PS3 TSCF. PS3 4547.628 INND.PS3 GR.PS3 60.625 CCL.PS3 14.056 TPHI.PS3 2.529 SIBH. PS3 186.280 FBAC.PS3 27217.703 TCFD.PS3 2102.737 INFD.PS3 0.000 13.353 TPHI.PS3 2.232 SIBH. PS3 163.369 FBAC. PS3 28459.527 TCFD.PS3 2128.468 INFD.PS3 0.000 25.712 SBHF. PS3 36.717 TRAT. PS3 96.161 TCAN. PS3 9257.770 TSCN. PS3 369.572 TENS.PS3 17.043 SBHF. PS3 36.916 TRAT. PS3 35.685 TCAN. PS3 11086.586 TSCN. PS3 422.403 TENS.PS3 30. 429 1. 819 47679. 805 8820. 848 1480. 000 24.740 1.552 49950.383 9295.900 1500.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 98/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 98/07/16 ORIGIN · FLIC TAPE NAME : 98360 CONTINUATION # : 1 PREVIOUS TAPE : CO~_JFT : ARCO ALASKA INC, D.S. 14-32, PRUDHOE BAY, 50-029-20999-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/16 ORIGIN : FLIC REEL NA~E : 98360 CONTINUATION # : PREVIOUS REEL : COf4~m%~f : ARCO ALASKA INC, D.S. 14-32, PRUDHOE BAY, 50-029-20999-00 t~IOiTAL LO00]~O COI~PUT£R PROCESSED ANALYSIS Company ~RCO ~L~SK~ IHC, Well DS ~4-32 CH,' C N.:, Field PRUDHOE BAY DA'I"E OF' JOB; 1 0-24-85 C:ount. s~ NORTH SLOPE St '~ .~ ...~ ALASKA Countr?2 USA CLIENT FORMAT DATA TAPE LOG I NFORMA T I ON S T AND AR D FORMAT ( L, I, S, ) L ~ I,lamm: DS; i 4-.. ~.. CH,YC:NS I ~ TAPE RECORDS Da'i:,~;~; 8 NAV, , 1 T i me:: F'.~,g,.-.-: ~ I . , HEADER RECORD Smr. vicm narnm: &G5FOt Pr..~s',..'ious r.~ml: Date: 85/ii,"08 Comment~: Origin: 3050il Continuation ~.: Oi ~ * * T A P E H E A D E'R * .* * * Ser'.vice: name: ~GSFO't Datm: 8571 I,"08 Commmnt. s; Origin: 30501 Continuation ~: Oi HEADER RECORDS Film tppm: LO Vcrsi on ~: Previous ¢ilm: Datm: M N E M CN WN FN COUN STAT CTRY SECT TOWN RANG Ei<8 EDF EGL PD LMF DMF RUN LCC SON LUN FL L. UL ENGI Wi TN PD DL TLI ~LI TC~ TLA~ ~HT MRT bit MSS MVIS RM RMF MFST MFSS RMC MCST MCSS INFORMATI ON RECORDS C: 0 N T E N 'T' S ARCO ALASKA INC, DS i 4-~2 CH,"C,NS PRUDHOE BAY NORTH SL. OPE AL. ASKA USA 04 i4 69 O 00 , 68 000 39 00'0 MS .... KB KB 30 , 72 0~/5 i ~0 . NORTH SLOPE HORTH SLOPE HUPP SENNETT DATE OF JOB i 0-24- flllIIilllIIlillllIllIilIllll IXIlIIiIl;llIIIIIlIIIlIIIIIlI IIilIIIIIlIIIIIlIIIiIlIIIiIlIIIIIl! IIIlIIiIllIIIillIlIiIIlIllIIIlIIII 10740.00'0 ............. 10635.0 00 ............... 9836,800 ................ iO6S4,00O ......................................... O.OOO ............... 0,000 ............... 0,000 ............... 0,000 ............... CRUDE iii 006 ............................................... O,OOO ................................................. 0,000 .................................................. O,OOO .................................................. U,UUU .................................................. 0.000 .................................................. UNIT TYPE CATG SIZE C 0 D E 0 0 4.0 65 O 0 40 65 O 0 40 65 O 0 2 O 65 0 O 20 6:.''=, 0 0 20 65 O O 2 65 0 0 3 65 0 0 ~ ~.:~ F T 0 ~ 4 68 F T 0 ~ 4 6 8 F T 0 .5"~ 4 68 0 S 2 65 0 0 2 79 0 O 2 79 0 0 I 0 65 O 0 i O 65 O O -v O 6 = 0 0 20 65 0 0 20 65 0 0 2 0 65 F T 0 3 4 68 FT 0 ~ 4 FT 0 3 4 68 FT 0 S 4 68 HR 0 2 4 H R 0 4 4 68 D E G F 0 '1 4 ,S :B DEGF O i 4 68 0 ~'-' ':'~ 0 65 0 2 20 65 CF' O 2 4 68 0 H bi M O 2 4 68 0 H M M 0 2 4 68 p b ~ ~ 0 2 4 68 0 2 i 2 65 0 H M M 0 2 4 68 D E G F 0 ~'-' 4 68 0 '2 i 2 E, 5 Page COMMENT RECORD · $ Thi~: LIS tape was writte, n b,.,., G~rhart Indu~trie_~ Wireline Service~.. :~ :~:~ All curve and tool mne. monic~ used arm those which most clo~:lp match ~ :~m Gmmrhart curve and tool mnemonics, ~m :'~: :~: :~ :~ :~ · ;'k :~: :~ :~ :~ :4': :~: · :~c :~ :~ ~ :8 · :~ :~ :~ · :~': · :~ :~ :a ~': H~ :~ :'~ H~ :~c :'B :~: :~ :~ :'t~ ;~ :'~: :'~: :'~: >~-: :~: :'~: · :~ :~: :~ :~': :+: :4': :+: ~: :~ >~: :~ :~ :~ :'~ :~ :~ :~c ~ :~: :.~ :~ :~ :~ :,~ :'1~ :~ :~ :~ :'1~ :~ :~ :'k :'~ :~:~ :~ :~ :~ :~ :~:~ :~ :'I~ :*J': :~ :~ :¢c :~ :.l.: ~c :~ :tc :*~ ~ :~ ~ ~: m :.N ~::~: ~ H': :~ :~ ~:~ ~ :~: :¢c :.lc :~ :~ :~ :~ :~: :~ :4,: :~c :~ :~ ~ :~: :~ :~ :~ :.~: :+: :~ :.B :,~ :~:~: :~< :~ :~ :.~: ~:~ :.~: :~: :~:~ :.~: :~ :~ :~: :+: :~ :~ :~ :~ GEARHART TO SCHLUNSERGER MI',tEM SERVICE UNIT MNEM SERVICE UNIT DEF'TH FEET DEPT FT NCNL I"IE R C~ E CPS NCNL MERGE CP'~~ FC:NL MERGE C:PS FCNI. MERGE CPS NPHS COMF'UTED SSPU NPHI COMPUT PU GR MERGE GAPI GR MERGE GAPI RAT COMPUTED RAT COMPUT CCL MERGE MV CCL MERGE MV AVG COMF'UTED AVG COMPUT DATA EN TRY FORMA T oPEC 1 F I CA T~-~E SI~E uuD. E 0 1 66 TIONS, ~** ENYRY BL. OCK LEGEND **** TYPE BESCP,,IPTiON 0 Tmcmin._~tor ( no mor. e entr-ies ) DATA FORMAT :SERVICE SERVICE API API Mi'.IEM iD ORDER ~ UNIT LOG TYPE DEPT 30501 i FT 0 0 NCNL MERGE S050i I CPS 0 78 FC:Ni_ M E F..'G E ~0.50i ~ CPS 0 78 NPHi COMPUT 3050ii PU 0 I2:2 GR blERGE S050~ I GAPi 0 54 RAT COMPUT 3050i I 0 0 CCL MERGE ~050i i MV 0 i 50 AVC~ COMPU'i" 305,0i i 0 0 AP1 AP1 FILE CLASS MOD :il: 0 0 0 30 0 0 3i 0 0 2 0 0 i 0 O 0 0 0 i 0 0 0 O 0 !~~ PEC I F I L. AT IONS PRC ~ S!Zb LVL ..IIPL. RC 4 0 1 G8 4 0 i 68 4 0 i 68 4 0 i G8 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 PROC:ESS INDICATOR'~-- 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 O00000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page DEPT H C N L F' C N L DA TA R E C 0 R D~, NPHi GR RAT CCL AVG 10407,500 0, 000 O, 000 3.'3.7.30 0 000 9'g,'= , -9. 2..,0 O, 000 i 0~07,500 6! 3, 1 O0 549,300 24,100 ~.3,400 1.116 .300 25.4~0 10207', 500 6':' F, 600 6L~7, 000 21 ,680 51 ,800 1 .084. ,4.7:0 17, .7:t 0 Ma:,.'.imu~ l~ngth: 102.4 TRA I L. ER RECORD"*~ name Vet. sion ~: File. tppe: LO Next Dat. e: * EOF :+:*:¢ Maximum 1,~ngt. h: 1024 HEADER RECORD Film tpp.e: LO Pcmvious .F'ii~:: 'i 0 MNEM CN WN FN COUN S 'l~ A T CTRY SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN t_CC SON LUN .FL LUL Ei',I G i WITN DD DL TLI 8LI TCS TLAB BHT MRT MT MSS MVIS RM RMF MFST MFSS RMC MCST MCSS 1 N F 0 R M A T I 0 N R E C 0 R D S C 0 H '1' E N T S UNIT TYPE CATG .:o I,.~. ~ E ARCO ALASKA INC, DS i 4--S2 CH/CNS PRUDHOE BAY NORTH SLOPE ALASKA USA iON, , , i4E, . , 69. 000 68 0'00 39 0 O0 MS KB . , , t<8 , , , i 7~08/'5i 60 NORTH SLOPE NORTH SLOPE HUPP SENNETT iO 74 O. 000 i 06S5, 000 ............. 98~6.0 O0 .............. i 06~. 000 ............... O,OOO ................... O,OOO ................... O, 000 ................... 0,000 ................... DATE OF jOB: i0-24-85 ....... Ill~ I~IiIlIlIlII III#III CRUDE ........... :: .......: O.OOO ................................................... 0.000 ................................................... 0.000 ................................................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: O.OOO ................................................... r 0 [.', E 0 0 40 65 0 0 40 65 0 0 40 ".~ 0 0 ;.20 65 0 0 2 0 65 0 0 '2 0 65 0 0 '2 65 0 0 .* '" 0 0 .3 65 F T 0 3 4 6 8 FT 0 3 4 68 FT O 3 4 68 0 3 2 "~- 0 0 2 ," 0 0 2 79 0 0 't 0 65 0 0 i0 65 0 0 20 65 0 0 20 65 0 0 2 0 65 0 0 20 65 FT 0 3 4 68 F T 0 3 4 68 F T 0 S 4 68 HR 0 '2 4. 68 H R 0 4 4 68 D E O F 0 i 4 68 DEGF 0 i 4 68 0 2 20 E, 5 0 '2 2 0 65 C: P 0 2 4 68 OHbiM 0 2 4 68 0 H bi M O 2 4 68 [:,EG.F O 2 4 68 0 2 i 2 65 0 H M M 0 2 4 6 DEGF O 2 4 68 0 2 i2 65 ii COMMENT RECORDS Thi.'~ LIS tape wa~ writ.tern b~., Gmarha~"t Industries Wirezlin~ All curve and tool mnemonics: used ar.m those which most Gmamhar. t curve and tool mnemonics, GEARHART TO SCHLUMMERGER MN EI'I SERV I CE UN I T MNEM DEPTH FEET DEPT RATi ~; OI,~F l.., T EIT;~ RAT CCI,. l MERGE MV [~ ~L. NCNL i MERGE CPS NCNL NPHS'i C OI'IPU TED SSPU NPH I FCHL 1 MERGE CPS FCNL GR 1 MERGE GAPI GR oERVIL. E UNIT FT COMPUT MERGE MV MERGE CPS COMPUT PU MERGE CPS MERGE GAPI DATA :~.* ~ ENTRY' BLOCI<S ENTRY FORMAT oPECIFICA T Y P E S I :.-~ E C 0 D E 0 ! 66 *~.~ ENTRY BI_OC:K LEGEND TYPE DE~,..RIPT ION 0 Ter. minator. ( no mor'~: mn't.r'ims ) SERVICE SERVICE APl AP1 APl APl FILE tINEbl ID ORDER ~ LINiT LOG TYPE CLASS MOD ~ DEPT 3050i I FT 0 0 0 0 0 RAT CONPUT .30501 I ...... 0 0 0 0 i CCi_ MERGE 30501 1 MV 0 i 50 i 0 i NCNL MERGE 3050ii CPS 0 78 30 0 i NPHI .,COMPUT S050i i :PU 0 i22 2,.2 0 i FCNL MERGE .'305 01 i CPS 0 ?8 ~i 0 i GR biERGE 3050i i tTAPi 0 54 i 0 i SPEC' I. F 1 CA TI 0 N'--'..-, F'RC SiZE LVL" ..~ M P L R C 4 0 1 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i (:~ 4 0 i 68 PROCESS ii',l[.~ i CATORS O00OO0 000000 000000 000000 OOO000 "000000 000000 000000 O00OO0 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT RAT CCL NCNL NP H I FCNI_ 104.08 000 """, , - =.~ ~ 250 O, 000 O, 000 1 690 O, 000 0.000 10S08,'000 1 o20'2 ,350 586.300 25.33 0 5i~- ~,. '400 34,900 i0208,000 1 ,0S9 ,430 614, I O0 2~.340 578.200 Fi lm nature: &GSFOi , 002 Ma:.,.'. i mum lmngt, f'~; ~824 TRA I LER RE:CORD"'". ~ Fiim type: LO ',,.'ersi on #: i ,S Fii~ nature.'. &GSF01 , 00~ Maximum length: 1024 HEADER RECORD'" Film typm: LO Pr. mvi ous f'i Da'bm M N E I'1 CN WN FN COUN STAT CTRV .SECT TOWN RANG E I< B EDF EGL PD LHF DHF RUN LOC SON LUN FL LUL ENGi W I'f'N DD bi.. TLI BLI TCS TLAB BHT MRT lit MSS MViS RM RMF HFST HFSS RMC MCST f4CSS 1 NFORMAT I ON RECORDS CONTENTS UN I T TYPE ARCO ALASKA DS PR NO At,. US 04 iO i4 69 68 39 KB KB 'I, ~0 72 08,¢5I 60 NORTH SLOPE NORTH SLOPE HUPP SENNE'¥'T i 0740. O00 ....... i 0635..000 ....... 9836.0 O0 ~ 0634., OOO O. 00 O ........... 0,000 ........... 0,000 ........... 0,000 ........... CRUDE DATE OF JOB i 0-24..-85 FT ........ FT ........ FT , , FT , , DEQF , DEGF CP OF.IMM OHMM DEGF 0 H M M DEGF S I Z E IS O,D E 18 COMMENT RECORD *,~ Thim..-.. LIS tmpe~ was writtmn by Gearhart Industries Wirmlinm Smrvicms, *~ All curve end tool ~nm~onic~ u~md ar.m those which ~ost closml~ ~;~atch ** Gmat'hart curve and tool mnmmonics. GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM ' SERVICE UNIT P .a g DEPTH FEET DEPT FT CCL2 MERGE MY CCL MERGE MV NCHL2 MERGE CPS NCNL MERGE CPS NPHS2 COMPUTED SSPU NPHI COMPUT PU FCNL2 MERGE CPS FCNL MERGE CPS RAT2 COMPUTED RAT COMPUT GR2 MERGE GAPI GR MERGE GAPI . , DATA FORM~,~T ~.PEC I F I ~]AT I ENTRY ~:** ENTRY BLOCK LEGEND {~: * :+: :+: :~ :+: :'{': :+: :~ :{~' :+: :'{': :~ ~': :'~ -'+: :+: :4': :+: :'1': :~: ~' ~: TYPE DESCRIPTION 0 Tmrminat~or < no mor. e entries ) TYPE SIZE CODE 0 1 66 2O DATA F 0 R M A T SERVICE SERVICE MNEPI iD ORDER ~ AP1 AP1 AP1 APl FILE UIqlT LOG TYPE CLASS MOD ~ DEPT .3050 i CCL MERGE .3 0501 NCNL MERGE ~050i i NPHi COMPUT S05011 FCNL, MERGE S050il RAT COMPUI' ~050i GR MERGE ~0501 F T 0 .0 0 0 0 MY 0 i 5 O i 0 ':2 CPS 0 "" ,, ~ .'4.. 0 0 .~"' .P U 0 i "'. ~2 2 0 2 :CPS 0 "'-" ._ r ~ ~ i 0 ..... 0 0 0 0 2 G A P i 0 54 i 0 2 · :, P E,C 1 F 1 E. AT 1 ON"~ PRO f~ SIZE LVL SMPL RC 4 0 1 68 4 O i 68 4 O i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 F,R 0 CE,",=. ~o iNDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00000:0 000000 000000 000000 000000 000000 00000,0 000000 2i F:, E F' T CCL 1'.t C: N L DA NPH t TA RECORDS FbNL RAT ~0=,- .~?,000 I04~.,' 000 't0397,000 10297,000 1 0197. 000 O. 000 .?50 ,560 ,400 . 'BO'O O, 000 4 ,:, ..s, ':' 00 ~68.700 641,300 ? 3'i , 600 P6,040 t 9 , 960 2:4,61 0 ':22,490 I8,576 0,000 448.4,00 S22,500 599.600 ,' ,s...~, 900 999, ,997 i , 1,40 i, 057 0, 000 18,300 21, ?00 3.3.600 54,200 Haximum length: 1024 TRA I LER RECORd)"~o Version ~: Film t~pe: LO Ne,'<t. ¢ilm: EOF ~'~. ** File name: &GSF01, 004 Haximum length: 1024 ~HEADER RECORDS Version File type: L.O Previous ¢ile: Date: P a C-J 24 M N E H CN WN FN COUN STAT CTRY SECT TOWN R A N G EKB EDF EGL PD LHF DHF RUN LOC SOH LUH FL L. UL ENGI W i TN DD DL TLI 8LI TCS TLA8 BHT HRT HT HSS MVIS RH RHF MFST HFSS RHC HCST HCSS CONTENTS ARCO ALASKA INC, DS 1 4-542 CH/CNS PRUDHOE BAY DATE OF NORTH SLOPE ALASKA USA 04. 1 ON, , , 14E,,, 69,0 O0 68, .00,0 39,000 MS .... 30 .... SO5011 720~/51G0 NORTH SLOPE NORTH SL. OPE HIJPP SENHETT i 0740.000 , i 0~35, O00 i OG~, 000 . O, .000 ..... 0. :00 0 ..... 0.000 ..... 0, 00'0 ..... CRUDE U 0 , 0 000 . 0 000 0 000 0 000 ,i, . I NFORMAT I ON RECORDS UN I T JOB i 0-2.4-85, i i · .I I IIllllllllillIIIIllllillll IIIIIIIIIIIIIIIIllllllllll IIIIlIIilllilIIIIIIIIIl$11 lllllllllllllllllllllllIII TYPE CATG L. UL. E 0 0 4, 0 6 5 0 0 4 0 65 0 0 4.0 65 0 0 2 0 es 5 0 0 20 0 0 2 0 6 5 0 0 2 ~5 0 0 ~'~ 65 0 O 3 FT 0 3 4. 68 FT 0 ~ 4 68 FT 0 .3; 4 6'8 0 .3 2 6,5 O 3 2 65 O .'U 2 6 5 O 0 2 79 0 0 2 ,-. 0 0 '10 65 0 0 lO 65 0 0 '20 65 0 0 Z ti ~ .j 0 0 2 0 65 0 0 20 65 FT O 3 4 68 FT 0 3 4 68 FT 0 3 4 6 8 FT 0 ~ 4 68 HR 0 2 4 68 H R 0 4 4 6 8 DEGF 0 1 4 68 DEGF' 0 i 4 68 O 2 20 65 0 2 '20 E, CF' 0 2 4 68 0 H bi i"i O 2 4 E, 8 0 H H H 0 '2 4 6 8 DEGF 0 2 4. 68 0 2 1 2 6 5 0 H M M 0 '2 4 6 8 u b u i.-. 0 '2 4 6 8 O '2 12 65 F' .~g 25 'COMMENT RECORD mm This LIS tape was writ,ten by Gearhart Industries Wirmlinm ~ Ail curve and tool ~nm~onics u~md arm tho=~ which :+:m Gmmr-ha~-t cur'vm rand tool mnemonics, GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT CCL~ MERGE MV CCL MERGE MV NCNL3 MERGE CPS NCHL MERGE CPS NPHS~ COMPUTED SSPU NPHI COMPUT PU FCNL3 MERGE CPS FCNL MERGE CPS RAT~ COMPUTED RAT COMPUT GR3 MERGE GAPI GR MERGE GAPI ENTRY ~.** ENTRY BLOCK LEGEND TYPE DESCRIPTION '0 Terminator ( no mol.".~_ ~ntri~s ) F,ORMA T Y P E T SPEC I F 1 CA SI~E~ CODE 0 1 66 TIONS . :;_'7 DATA FORMAT 'SERVICE SERVICE AP1 APl APl APl FILE Mi'-.IFM it:.', OR[:,ER ~- UNIT LOG TYPE CLASS MOD ~ DEPT 3 L:DOi i FT 0 0 0 O 0 CCI. MERGE 30501 i MV 0 i 50 NCNL MERGE 30501 i CPS 0 NPHI COMPUT .7 05'01i :PU O 122 2 O FCNL MERGE '.~ ' ~'' u.J 0 t i C P S 0 7 RAT COMPUT 30501 I 0 0 0 O t'_;R blERGE 3050 i I GAP i 0 54 i 0 SPECIFICATION PRC SIZE LVL SMPL. RC 4 0 I 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 PROCESS iN[.',iC:ATORS 000000 00000'0 000000 000000 O00OO0 000000 000000 000000 000800 000000 00000'0 000000 000000 000000 000000 000000 000000 000000 000000 00000.0 000000 P.agm -) DEPT CCL NCNL DA NPH I TA RECORD FCNL RAT ~R P a g ~ 29 I0599,000 0 000 O. 000 26. i90 0,000 -999 250 0 000 0499.000 460 485.200 085 481.000 i 052 16 600 0399. '000 280 360,900 25.290 316,900 24 700 0299,000 10199.000 4 420 65 0 636,800 966,500 20,550 14.988 622.900 1 021 ,600 1 056 93'8 54 5O 600 6 O0 099 , :000 46 0 557,200 24,780 494.600 125 53 400 Maximum lmngth: t024 TRA 1 LER. RECOF?.D'~.., Film tppm: LO Nmxt ¢ilc-.:: 3 0 Maximum t~ngth: 't024 H E A DEE R i.,~ECORDS Da'bm: Film typm: LC) Prmvious .Pi 3i H N E H CN WN FN COUN STAT CTRY SECT TOWN RANG EK8 EDF EGI.. PD LMF DHF RUN LCC SON LUN FL LUL ENGi WI TI',i DD DL. TLi DLI TCS TLAB BH'f' HRT biT hiSS MVIS RH Ri'iF blFST MFSS RHC HCST HCSS 1 NFORMAT I ON RECORDS CONTENTS .-.-'. I., H INC, ARCO ALA"' "" DS i 4-32 CH/CNS PRUDHOE BAY NORTH SLOPE A L A.S K A USA 84. iON ........ . 14E 69, OOO 68 OOO ..-', 9 O00 t,::8 i< B ,:-'2 08/5i 60 , HORTH SLOPE NORTH SLOPE HLIPP SENNETT i 0740, OOO ....... i 06'35. '00 O . 90:36. 000. i 0634. 000 , O, 000 ..... 0,000 ..... 0.000 O, 000 ..... CRUDE DATE OF JOB i 0'-24-85 · 6'666; .............. IIIlI IIlIl I 0 000 .............. 0 OOO .............. 0 000 .................................... ~ Il:Ill lllIIlIIIIIIIIIlIltIIIIllllIll u 666 .............................. 0000 .................................... i illlliiII iitliIiiliIliIiiIiIiiIIiliiiIt UI.,t I 1' TYPE CATG S I CODE 0 0 4 0 r-=,.., ~ 0 0 4. 0 615 0 0 40 GE; 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2: 65 0 0 .]4 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 bo"'" F T O 3 4 68 0 3 '2 65 O 3 '2 65 0 .3 2 65 0 0 c, "~ q 0 0 2. 79 0 0 10 65 O 0 iO 65 O 0 20 65 0 0 '~ O ' ': 0 0 2 0 65 0 0 20 "~ FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 Fl" 0 ~ 4 68 H R 0 2 '4 6 HR 0 4. 4 68 DEGF 0 1 4 68 DEGF 0 I 4 68 0 2 2 0 65 0 2 20 65 CP 0 2 4 68 OHMM 0 2 4 68 OHMH 0 2 4 68 DEGF 0 2 4 68 0 2 I2 65 0 H H hi 0 '2 4 68 DEGF 0 2 4 68 0 '2 12 65 P .E~ E] e · 3 '2 COMMEHT RECORDS ;~-'~ Thi~-. L.I$ tapm was writtmn by Gearhart Industrims Wir¢iinm Smrvicms. :~:~ m,~ All curvm and tool mnmmonics u~md arm thosm which mo~t clo~ml.~ match .'.~-~ ,.;...m Gmarhart cul~vm and tool mnmmonics, mm GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM DEPTH FEET DEPT CCL. 4 MERGE MV CCL NCNL4 MERGE CPS NCNL NPHS4 COI~IPUTED SSPU NPHI FCNi_4 ~ MERGE CPS FCHL RAT4 COMPUTED RAT GR4 MERGE ISAP I GR SERVICE UNIT FT MERGE MV MERGE CPS COMPUT PU MERGE CPS COMPUT MERGE GAPI DATA ~ · * E N T R Y B L 0 C K S ** * · ENTRY *** ENTRY BLO,..K LEGEND :+: :'i': :+:. :~ :~ .'~ :~: ~ :~: :~ :'!': :'~ :~ :+:. :'~. :'[': :t'. :~ :'k :'i': :~ * TYPE ) -o-. [ E..~U' R ] PT 101'4 0 Tmrminator ( no mor-m mntr. ie.$ ) F ORMA T Y P E . PECIFICATIONS ~.E CODE 0 i 6 6 P a g e. DATA FORMAT SERVICE SERVICE MNEM ID ORDER ~ AP1 AP1 AP1 APl FILE .UNIT LOG TYPE CLASS blOD ~ DEPT 3 05 01 i CCL MERGE .~ 050 i i NCNi_ MERGE ~050i l · NPHI COMPUT .SO501 ! FCNL biERGE ~050i i RAT COMPUT ~050ii OR hiE;RGE Z~ 05 0 i i FT .0 O 0 0 0 MV 0 150 i 0 4 'CPS 0 78 ~0 0 4 PU 0 122 2 0 ,4 .CPS 0 78 ~l 0 4 .... 0 0 0 0 4 GAPI 0 54 1 0 4 1 F I CAT I ON PRC: ~ SIZE LVL SMF'L RC PROCESS Ii',l[:, i r:ATORS 4 0 i 68 4 0 I 68 4 0 1 68 4 0 i 68 4 0 i 68 4 O i 68 4 0 i 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ~5 DEPT CC:L NCNL OATA NP H I RECORDc' FCNL RAT Page 0686.. :000 0 000 0,000 .-6,5~0 0 000 -999 250 0 000 i0586,.000 370 396.i00 2.3,640 364 900 1 400 10486.000 250 458,400 i6.400 489 i 00 i Oli 20 300 i0386.000 i0286.000 4!0 405. 400 685,700 23 21 240 810 .372 640 300 100 1 067 1 lOi 2i 36 900 40'0 i 0186,0 O0 420 659, .300 24 02 0 586 000 994 52 700 0086, ,000 350 540,500 26 350 472 100 1 133 47 700 9986.000 47 0 619.700 24 260 566 700 112 48 200 9886,000 450 601 .600 24 130 532 800 1 '121 38 800 File name;: TRA 1 LER RECORD'~ Ser. vi,'--'e name.: Film t.vpm: LO Version .Pile: P a g e: :'.~ EOF -**m *----SCHbU~BERGER .... * ********************** [.,IS TAPE VERIFICATION LISTIMG ,. I, VP n!n.H02 VERIFIC~TI[I~.? LISTING P/~G.~ 1 D~T~ :~:3/081]1 OD I,~I~,' ~EE[, ~'~a.~:E :13533~ CONT!~;j.~.TION ~ :0 PREV!O~$ PEEL : COZ ~' K~'~r S :LIBRARY SEPViC;; N A,~ E :EDIT DAT~ :~3/08/3t O,q I ('." ! ?:' :0000 TAP~7 h~,~ :8507 CO~9'rlr,;U;~TIO~.~ ~ :01 Rr O~,S TAPE : ** Wll.,~.; HEADER ** FILF. f,' A P, E :EDIT .001 SBRVIC~ N~ME DATP : M.&XI~qU~ LENGTH : 1024 ~ILE TYPE : P~EVIDUS PILE : ** IN,PO!,'?.~,~TION R. ECOg!DS ** PRI, IDN~: BAY TOWf¥: I ON SECT: 4 COiJ b': M. SI, OPE S~AT: ALASKa CTRY: USA uNi'r TYP_, CArE $IZt,, CODE: 000 000 016 065 O0:O 000 0(.)9 065 000 000 01.2 06~ 0oo 000 ooa 66¢ 0o0 00o 00/~ 055 000 000 002 06S o 00 000 0 08 065 000 000 ~06 06~ 000 00 O o 04 36 5 DvP O]O.Fi02 VW. PIF[CA:I'JON LISTING D~;~' 2 , ALASKA COVPUTTN~ CE,~TFR CON~P~HY = AILAS~TIC RICHFIELD C[3~PAMY ~I~:T:D = PRUDHOD RAY COU(':'FT : NORT~ 5LOPE BOROUGH ~ATE LDCGED: C,qST~,~C~ = 9.R25" ~ ~OOgR' - BTT SIZE : 8.5" . , l ....... !D .... TYPt] ~ " - r'IGNOSULFON~'q~E DE~"-ITY : 11.2 I,B/G RM = 1.1bO VI( ~S1T~' = 39,0 $ R~W = 0.910 '" ' = 3.470 DH = 10.5 RMC T .... FL~.tID [,['~88 = 6.8 C"~ RM a BMT = O a~g VP 0,10.NO2 VF, RIFIC~T%O,~ LISTING 66 73 65 66 CT~'!CA f ION IC.i~ $~VI, C~ U~IT :~Pl :APl APl API FILE 014 ,~'I 'v, 7 0 0 G~PT US/P G~PI GtC3 G/C3 CPS CPS .... o o o 0 0 0 0 7 !2 4~ 0 0 7 1 0 0 0 7 31. 32 0 0 60 52 32 0 0 60 31 32 0 0 42 68 2 0 0 42 44 0 0 0 42 35 1 0 0 42 34 92 O 0 42 34 93 0 0 42 2fl 3 0 0 42 42 I 0 0 a2 0 0 0 0 42 31 32 q 0 ~2 31 ?2 0 0 G~PI GAPI SIZE 4 0 4 0 1 a 0 I 4 0 4 O 4 0 4 0 1 4 O 1 4 0 4 o 1 4 0 4 0 4 0 o 0 ! 1~, rl'T iPBT 1091g. O000 SWLIJ -999.2500 GR 36.8652 OqHO 1261.0000 C,~I.,,I lOgO0.O000 SFI,U -42.0000 Gi~ 30.5508 ORHO 1261.0000 CAI,I 63.906~ GP -999,250n -999.2500 UT 0.0215 RHOB 8,5000 -9~9.2500 5.7969 IUN 36.468a PT 0.0215 RHOB -999.2500 -999.2500 IL, D -999,2500 GR 2,4453 NCNL 3.1328 ~:'~A 5.1172 ILO 80.3!.25 2.4453 3. 132q -g99.2500 -999.2500 3R74.0000 3.070~ 4.5000 a9,562~ 3874,000fl 3,0703 LV'P OIO.HOi) VERIFTC~T.[OH LISTIN~ PAG~ 4 DEP? MPHI G~ DMmT NPHI GR DEPT SP NPf{I .. SP FCMI,, DEPT NPHI F C N L DEPT' SP G~ DE?T NPHI PT FCNL GR G~ 10700.0000 SFL, U -46.~500 29.3457 1101.O000 1~8.8750 GR 10~00 0000 SFLU 85:3125 22.8516 9DHO 16&l.O000 C~LT 29.093S 10500.00(30 S~LU -91.75~0 20.0195 ~2~0.0000 CaLl 17.75(i)0 10400 O00O SF'LU -92~3~25 GR 29.3945 DRHO ~323.0000 C,~t,I 15.1953 GR 3.6875 IL~ 51.0625 DT -0.0044 RHO6 7.933& MRAT -999.2500 6 324.2 1~16~5o DT 0.0327 8. 8437 -q99.2500 i2 2500 P~46~8 DT 0.0195 R~O~ 8.2187 -999.2500 23,9531 IL~ 16.5781 DT -o.oo4a 8.2422 NRAT -909.2500 3750 ISM -~.0029 RHOB '999,2500 14.~437 IL~ 57,.25:00 'DT , 0049 RHOB .5'g3~ N~:~T -999,2~00 I0.0000 ILM 9'5000DT -0 0068 : · lOlO0 00()0 SFLt~ 2,5449 ILM -,,.1:1,:973 aR 7i:,1250: DT 49 8535 12P, H C) 0,0031 RHO~ 3~5[0600: C~LI: 15.4531 NR~T 70 4,375 .R 71. 1250 10000,0000 -999. 2500 5.3 8574 ~3: 2500 40.4063 2.4453 IbP 89.0~25 2,3477 2,4609 R~RA 5.8711 [bD 77.5625 GR 2.6660 I~CI,~L 2.7246 RNRA 9.?@13 IbP 79.1875 2.4?58 DaCML, 2.2422 RWRA 19.1875 IL, U 78.1.875 GR 2.3~57 2.0527 13.2656 ILD 93.6~75 GR 2.2559 NC~L 2.7070 R~RI 17.5000 ILO 82.6:075 GR 2.5509 tqC~,)L 2.5801 R~tR~ 0,843~ ILD 9.812, GR RRRt 2 · .1367 .[LD 108' 12:50 Ga 2,0?95 4.:160:2 R~RA 2.1914 ~3.1975 '3532.0"~03 2.4609 S.613~ 115.5~75 2~64.0000 2.6qla 9.1v97 31.2969 4020,0000 2.4t~9 22,2655 19.0a69 472~.0000 2.:lOqa 17.6875 t9.9375 3570.0000 2.5979 21.9~ 2 ....000 55.~563 99.~000 492~.0()00 2.0959 4.0:I, 95 - 9 99.25 0 0 -c~99. 2500 14;~ 1. 3.7 9900. 0000 SFLL' -999 -999. 2500 GR -999 40.3809 ORHG -0 632. 5000 C~LI 8 40.2J ~7 GR 3~ ,2500 IbM .2500 DT .6362 RNOB ,5156 .7656 9800.0000 5?LU -999 -999.2500 G~ -999 54.5410 DRMO -0 ]79.5000 C~LI 8 56.4375 dR 54 .2500 .2500 .6597 .5~59 .0000 9700.0000 SFt, U -999 -9Qq.7500 GR -999 -999.2500 DPHO -999 -999.2500 CALl -999 -999.2500 GP 59 .2500 IbM .2500 bT .2500 PHOP .2500 N~AT .4375 -999. 2500 f)~HO -999. 2500 CALl -~9 -999. 2500 GR 53 .2500 lf.,~! ,2500 DT 2500 RHC3B [2500 NRAT .7813 9500. 0000 SFLU -999.2500 GR -.~9~:2500 C~bI -9a9. 2500 II.,N' -999.2500 DT -99~9,2500 RgOB -99¥.2500 NRAT 63.2913 .~400.0000 999.250O 997,2500 DRHO '-999. 2500 CALl -999. ~5oo 999. 2500 999-2500 :DT ~.09g. 2500 ~HOB 88,875O ~'!..¢,2500 CAf.:i '.999, -999.2500 GR 137. 7500 9200.0000 S?.~LU -999.2500 ~99. 2500 :'9.9:9.2BO0 L .... ~q99.2500 t"))~ H 0 -qq9'250n ~g. ~500 CAL:I -999.2~00 NRAT -999.~500 GR 88.4375 9100.0000 SFbf.l -999.2500 ILM -999. 2500 GR : : '999.2500 DT 999, ~50 (') tJRHO -999. 2500 RHOP.. ~9~9. 2500 CAbI::: -999,2~06 N'RA'r -099.~500 (;R 68.1. R75 -999.2509 -999.2500 G9 2.31~4 ~iCNL 3.3301 R>:RA -999.2500 -999.2500 G~ 2.1621 4.1211 -999.250r! -999.2500 GR -999.2500 -999.2500 -99q.~500 ill', -999.2500 dR -999.~500 NCNI, -999.2500 RNR~ -999.2500 -999.2500 Ga -999.250o NCN!., -999.2500 -9~9.2500 TL, D -9 922;500 -999,2:~0, -999,.2500 ~999,2500 IbD :999.:2500 -999,2500 '999.2500 ' :":'"'~' -999,25 6 G~ -999.2500 -q99.2500 3.1~55 -qq9. 2509 99=.2~0n 1493.0000 3.9335 -999.2500 -999.2500 -999.2509 -999.2500 -999.2500 999.250~ -999.25OO -Q99,2500 a 9 Q. '25 0 n -999.2SC)O 25 00 .2500 2500 2500 ~agq,25,, n, O .0.0o 999' ' .25 O0 -999.2:500 Lvp 019.H02 ¥~IFIC~T!ON T.,ISTIN~ ~.GF: 6 9000.0000 SFbU -999.2500 GR -999.2q00 DRHO -999.2500 CALI -999.2500 GR -999.2500 IL~ -999,2500 DT -999.2500 R~;O}~ -999.2500 NRA? ~3.0000 5900,0000 SFL, U -909.2500 GR -999.2500 DRHO -q99.2500 C~DI -999.2500 G~ -999,2500 -9~9.2500 DT -999.2500 RHOB -9q9.2500 9~.1~50 5800,0000 SFLU -999.2500 GR -999,~500 DRHO -999.2500 CaLT -999.2500 GR -999 2500 ILM -999'2F00. -999.2500 57,1875 ~700.0000 SFLU -999.~500 -999.~500 -999.95~0 CALI -o99.~5~0 GR -999.2500 II,,~ -999.2500 DT :099,2500 ~HO¢ ~99.~500 NR~T 88.000(:} 8600.0000 SF'LU -999.2500 -999.2500 DRHg -999.2500 -999.2500 -999.2500 II, Mi -999. 2500 DT moa. 2500 75.9375 ~ 500. O 000 S ..~'.L U -(~99,2500 O~ 999.2500 ALI -999.2500 GR -999,2500 ILM '909. 2500 DT · ,9q9,~500 RHOB '~9~,2:500 hlRAT 97.6250 ~400. 0000 SKLU . a99. 2500 GR -99~. 2500 -9a9. 2500 -999,2..:~00 GR -9o9,2500 Il N - 9 99..2500 RHO~5 '9'99i~5'0:0' N~AT ]300,0000 999. 2500 -QQ9.2500 -999.2500 -999. 2500 I1, N '9~:9'2500 :DT 6~.:2:~00 NRaT 47.0625 5200 0000 SF:..,C: -999 2500 -999,2500 GP -999,2o00 : D -999. 2500 P~,~e 999,2500 PHOB -999 25(,0 CALI 999-2500 NRAT -099. 2500 GR 55.0(>00 -999.2500 -99g,2500 -999.2500 -999.2500 -999.2500 IL, P -999,250n GR -999.2500 -999.2500 -999.2500 -999.2500 GR -999.2500 NCNi, -9~9,2500 -999.2500 -999.2500 -999.2500 -999,2500 IuD -999.2500 GR -999.2500 NCNL -999.2500 R~Ph -999, : IDb ' 999 G R : 9,250o -999. 2500 -999,2500 -999.250r) -999:.2:500 -999.2500 -99° -q':-)9.2500 - 9 ~ 9.25 -999. 2500 -g99.250~ -9P9.2500 -999.2500 -9~9.250,:) -999.2500 -99q.2500 -999.2509 -999.2500 -gqw.250r~ -999.250n -999.2500 -999.2500 -999.2500 -999.250n -99q', 2.~0o -999,2. 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' NCNL -999.2500 RNRA -99~,2500 ILE' Z999, N .,, 999.,~500 Cf'i[* 5 O0 RNR K -999.2500 IbD 99.2500 -999,2~00 -999.2, O0 -999.2500 -099.2500 .uuo 2~0,~ -999. :2500 -999.2500 -999.2,500 -949. 2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -~99.2500 -999.2500 -999.250o -999.2500 -a99.25oo -999.2~oo -q99 2~oo .2500 -~9,2500-~{~, 250o .9 ~9:2500 -q"~' 2500 .2500 LVP O!r).H02 VE~,~F'IC~aTIPN LTST~NC R~C. iF:: ? D~iPT ?200 . 0000 SFI, U SP -999.2500 GR NPHJ -g99.2500 DRH[) .FC?.~[, -999. ~500 C~LI G~ -99g. 2500 GR -999.2500 -9o9.~500 DT -999.2500 RHO8 -999°2500 NRA. 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