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183-133
RECEIVED STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM!WELL�MP ETION OR RECOMPLETION REPOOAND LOG DE9 2017 la. Well Status: Oil ElGas ❑ SPLUG 0 Other 0 Abandoned 25.105 20AACded 0AOG 25 2lb.Well C 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 Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 12/02/2017 • 183-133 • 317-508 • 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 9/22/1983 50-029-21010-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 10/28/1983 PBU 14-34 Surface: 5084'FSL,1243'FEL,Sec.09,10N,R14E,UM • 9 Ref Elevations KB 69 • 17. Field/Pool(s): Top of Productive Interval: 5000'FSL,4975'FWL,Sec.10,T1ON,R14E,UM GL 39.05 BF 41.91 PRUDHOE BAY,PRUDHOE OIL • Total Depth: 4849'FSL,5245'FWL,Sec.10,T1ON,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 11228'/8650' • 1 ADL 028312 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 675203 • y- 5940145 • Zone - ASP 4 . 11925'/9248' • 77-043 TPI: x- 681421 y- 5940208 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 681695 y- 5940063 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No II 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 DIL/BHC/GR,LDT/CNL/GR,CBL,Gyroscopic Survey 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' 112' 31' 112' 30" 1937#Poleset 13-3/8" 72# L-80 30' 2602' 30' 2568' 17-1/2" 2000 sx Fondu,400 sx PF'0' 9-5/8" 47# L-80 27' 11159' 27' 8593' 12-1/4" 500 sx'C',300 sx PF'0' 7" 29# L-80 10849' 11925' 8338' 9248' 8-1/2" 415 sx Class'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 10903' 10761'/8267' 0tok3 08^/0P 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No D. 1 . (2 ij 1- Per 20 AAC 25.283(i)(2)attach electronic and printed information C DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11273' Set Posiset Plug 11265' -5 Gal Cement 11228' Set 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 Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate .001 Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only V77-- 6/12-0 oselif 0' REDMS J. - 8 `: r`` -7.1L ia 28. CORE DATA • Conventional Core(s) Yes ❑ No a • • Sidewall Cores Yes 0 No ' 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 0 No El • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 11313' 8721' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 11313' 8721' Base of Sadlerochit-Kavik 11800' 9138' Formation at total depth: Kavik 11800' 9138' 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: Ciolkosz,Ryan R Authorized Title: I tion and D o roller Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: Date: '9/20 Ill Contact Phone: +1 907 564 5977 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 la. 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 lb.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 14-34 ACTIVITYDATE SUMMARY T/I/O= 2156/2154/71 (LRS Unit 42 -Assist Slickline: Load and Test) Pumped 427 bbls of crude down IA to load. Pumped 209 bbls of crude down TBG to load pre MIT's. MIT-IA***PASSED*** @ 2679 psi Max applied pressure 2750 psi Target pressure 2500 psi. Pumped 9.1 bbls of crude down IA to achieve test pressure. 1st 15 min IA lost 54 psi, 2nd 15 min IA lost 8 psi. For a total loss of 62 psi in a 30 min test. bled back 8.1 bbls. Freeze Protect Flowline w/ 3 bbls of 60/40 Meth followed by 79 bbls crude and pressure up per DSO MIT-OA***PASSED*** © 1105 psi Max applied 1200 psi Target pressure 1050 psi Pumped 15.28 bbls down OA to achieve test pressure. 1st 15 min lost 65 OA psi. 2nd 15 min lost 30 OApsi, for a total loss of 95 psi.in 30 min test. Hang tags &AFE sign, Notify DSO. . Well shut in upon departure. SV,SSV,WV,AL=closed MV=open IA,OA=OTG. 9/25/2017 FWHP's146/363/138 (Drlg screening) SET BK-DGLV AT ST#5 (4,262' MD). LRS LOADED IA W/427 BBLS OF CRUDE. SET BK-DGLV AT ST#4 (6,641' MD). LRS LOADED TUBING W/209 BBLS OF CRUDE. LRS PERFORMED SUCCESSFUL MIT-IA TO 2500 PSI. PULL EMPTY 4-1/2"WHIDDON CATCHER FROM 10,879' SLM / 10,884' MD. 9/25/2017 ***LRS IN CONTROL OF WELL ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** T/I/O = 2450/100/70. Temp = SI. TBG FL (eline request). AL SI © CV, ALP = 1800 psi. TBG FL= 8600' (1157'Above Sta #02 DMY, 131 bbls). 10/9/2017 SSV, WV, SV= C. MV= 0. IA, OA= OTG. 23:30. ***WELL SHUT-IN ON ARRIVAL*** (SLB ELINE CONVEYED GYRO SURVEY) INITIAL T/I/O = 2400/100/50 PSI TOOL ZERO AT SWAB = 11.46'. RIH WITH PEH-EF(1-3/16" FN)/GYRO TOOLS. BEGIN LOGGING GYRO FROM SURFACE TO 11500'AT 100 FPM. PERFORM STOPS AT GYRO REP'S REQUEST. 10/10/2017 ***JOB CONTINUED 11-OCT-2017*** T/I/O= 2499/107/64. Assist E-Line (gyro survey) Pumped 5 bbls of 60/40 Meoh, 290 bbls of 1% KCL, and 38 bbls of crude into the TBG. Eline in control of well per LRS departure. 10/10/2017 FWHP's=Vac,500,330 IA,OA=OTG SURVEY) CONTINUE LOGGING GYRO AT 100 FPM FROM SURFACE TO 11500' MAKE STOPS AT GYRO REP'S REQUEST. TOOLS TAG HIGH AT 11434'; WORKED UP AND DOWN UNTIL TOOLS CAME FREE. LOG OUT OF HOLE FROM 11350' TO SURFACE MAKING STOPS AT GYRO REP'S REQUEST. WELL S/I ON DEPARTURE. FINAL T/I/O = 0/0/0 ***JOB COMPLETE 11-OCT-17*** 10/11/2017 T/I/0=2400/0/26 Temp=Sl Assist Eline w/ Load and Kill (DRLG SCREEN (MAINT)) Pumped 2 bbls 60/40 meth, 290 bbls 1% KCL, 2 bbls 60/40 meth and 38 bbls crude down Tbg for Load and Kill. Eline in control of well per LRS departure. IA,OA=OTG FWHP's=- 11/8/2017 20/-6/40 e • Daily Report of Well Operations 14-34 ***JOB STARTED 8-NOV-2017***(SLB ELINE CONVEYED GYRO) MIRU. WELL SI ON ARRIVAL. INITIAL T/I/O = 2400/0/0. LRS PUMPS 290 BBLS OF 1% KCL FOR L&K; 38 BBLS CRUDE FOR FP. LOG GYRO FROM SURFACE TO 11350'. LOG GYRO OOH. PERFORM STOPS AT GYRO SPECIALIST'S REQUEST WHILE LOGGING. REZRO ON SWAB = 2.42'. 11/8/2017 ***JOB COMPLETE 8-NOV-2017*** T/I/O = 2455/Vac/30. Temp = SI. TBG & IA FL's. (E-line Request). ALP = 0 psi & SI @ IA casing valve. TBG FL @ 7002',(between sta#4 &sta#3, 107 bbl). IA FL @ 560', (30 bbl). 11/18/2017 ***WELL S/I ON ARRIVAL** (SLB ELINE CIS WELLTEC MILL) INITIAL T/I/O = 2300/0/20 PJSM, MIRU. R/U LRS & L&K THE WELL W/290 BBLS 1% KCL AND 38 BBLS DIESEL FREEZE PROTECT. 11/23/2017 ***JOB CONTINUED ON 24-NOV-2017*** T/I/O = 2444/Vac/24 (LRS Unit 42 Assist E-Line - L&K) Pumped 5 bbls 60/40 meth down TBG, followed by 290 bbls 1%KCL, 38 bbls DSL down TBG for FP. FP tags on WV FWHP = Vac/Vac/70 11/23/2017 'E-line on well upon departure*** ***JOB CONTINUED FROM 23-NOVEMBER-2017*** (SLB LINE CIS; WELLTEC MILL, POSISET, DUMP BAIL CEMENT) RUN 1: RIH W/ HEAD (FN 1-3/8")/SWIVEL/WRD/CCL/WELLTEC TRACTOR (FN 1- 3/8")/MILL(MAX OD). OAL= 37'. OAW = 580LBS. MAX OD = 3.805" MILL OUT 4.5" HES XN NIP AT 10884' WITH 3.805"WELLTEC MILL. DRY DRIFT AND CONFIRMED TAIL PIPE DID NOT SPIN OFF. AFTER MEASUREMENT OF MILL: 3.804" RUN 2: RIH W/ HEAD (FN 1-3/8")/CCL/PLUG BACK TOOL/POSISET PLUG, PLUG NUMBER H405501. OAL= 34', OAW = 110 LBS, MAX OD = 2.125". LOG CORRELATED TO SLB CLT LOG DATED -1-JAN-1986. SET POSISET MID ELEMENT AT 11275', CCL TO MID ELEMENT = 22.6', CCL STOP DEPTH = 11252.4'. TOP OF PLUG = 11,273'. RUN 3: RIH W/ HEAD (FN 1-3/8")/CCL/DUMP BAILER ASSEMBLY. OAL= 42', OAW = 210 LBS, MAX OD = 2.125'. DUMP 2.8' OF CEMENT ON TOP OF POSISET PLUG. CEMENT PLUG 11275' TO 11/24/2017 11272.2'. TOTAL CUMULATIVE CEMENT = 2.8'. • Daily Report of Well Operations 14-34 ***JOB CONTINUED FROM 24-NOVEMBER-2017*** (SLB DUMP BAIL CEMENT; SET WHIPSTOCK) RUN 4: RIH W/ HEAD (FN 1-3/8")/CCL/DUMP BAILER ASSEMBLY. OAL = 42', OAW = 210 LBS, MAX OD = 2.125'. DUMP 2.8' OF CEMENT ONTOP OF POSISET PLUG. CEMENT PLUG 11275'TO 11269.4'. TOTAL CUMULATIVE CEMENT = 5.6'. RUN 5: RIH W/ HEAD (FN-1 3/8")/CCL/DUMP BAILER ASSEMBLY. OAL = 42', OAW = 210 LBS, MAX OD = 2.125'. DUMP 2.8' OF CEMENT ONTOP OF POSISET PLUG. CEMENT PLUG 11275' TO 11269.4'. TOTAL CUMULATIVE CEMENT = 8.3'. TOC 11,265'. RUN 6: RIH W/ HEAD/ERS/SWIVEL/2 x CENTRALIZER/WPP TOOLS (MOTOR/TELEMETRY/GAMMA/SHOOTING TOOL)/BAKER WHIPSTOCK. OAL = 51', OAW = 700 LB, MAX OD = 3.625". SET TOWS AT 11228', CCL TO TOW = 14.1', CCL STOP DEPTH = 11213.9', CCL STOP DEPTH = 11213.9', WHIPSTOCK ORIENTATION = 31 DEG ROHS. LOG CORRELATED TO SLB CET LOG DATED 01-JAN-1986. TIED INTO GAMMA AND CCL OVER INTERVAL 11191' - 112134'. RDMO. NOTIFY PAD OP ON DEPARTURE AND HAND OVER RAP. FINAL T/I/O = 11/25/2017 VAC/0/50 T/I/O=0/0/0 Set 5" Gray"K" BPV#606 through tree. Removed upper tree, installed Temp. 11/26/2017 CDR tree#5, with platform. FWP's BPV/0/0 see log for details. T/I/O = BPV/Vac/40. Temp = SI. Bleed WHPs (pre rig). No flowline, well house or scaffold. OA FL near surface. Bled OAP from 40 psi to 0 psi in 30 mins (gas). Monitored for 30 mins, OAP increased to 0+ psi. Final WHPs = BPVNac/0+. 11/27/2017 SV, WV, WV= C. MV = O. IA, OA= OTG. 09:30 T/I/I/O = 0/0/10 Temp = S/I (LRS Unit 46 - MIT-T) ***MIT-T PASSED*** MIT-T Passed @ 2577 psi, Target pressure 2500, Max applied pressure 2750. First 15 min. TBG loss 98 psi . Second 15 min. TBG loss 37 psi, for a total loss of 135 psi. Pumped a total of 4 bbls of 60/40 down TBG followed by 12 bbls of DSL to reach test pressure. Bled TBG down to 500 psi per FB WSL. 11/28/2017 FWHP: 500/0/12 WV SV SSV = C, MV= 0, IA/OA= OTG T/I/O=BPV/0/0 Pulled 5" Gray"K" BPV#606 through tree. Ensured passing MIT. Removed 11/28/2017 tree cap bonnet, installed blind with jewelry. PT'd to specs. FWP,s 0/0/0 see log for details. T/I/O = SVNAC/10. Temp = SI. Bleed OAP to 0 psi (pre rig). Wellhouse, flowline, SSV, scaffold removed. OA FL near surface. Bled OAP to BT from 10 psi to 0 psi in <1 min. Held open bleed for 1 hr. Monitored for 30 min. OAP increased 0+. Final WHPs = 11/28/2017 SVNAC/0+. T/I/O = 280NAC/0+. Temp = SI. WHPs to 0 psi (pre rig). Wellhouse, flowline, SSV, scaffold removed. OA FL near surface. Bled TP to BT from 280 psi to 0 psi in <10 min, returned — 1.5 bbls. Held open bleed for 1 hr. Monitored for 30 min. WHPs unchanged. Final WHPs = ONAC/0+. 11/29/2017 MV= C. IA, OA= OT. 23:59 • ! North America-ALASKA-BP Page 1 IS- Operation Summary Report Common Well Name:14-34 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/30/2017 End Date:12/4/2017 X3-018T8-C:(1,363,166.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:CDR-2 Spud Date/Time:9/22/1983 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. 1BPUOC USA00000831 Active datum:KB©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code , NPT Total Depth Phase Description of Operations (hr) (usft) 11/30/2017 00:00 - 06:00 6.00 BOPSUR P PRE BOPE STACK RECONFIGURATION -BEGIN OPS TO PREPARE STACK FOR RECONFIGURATION -PJSM, LO/TO ACCUMULATOR SYSTEM. WSL WALKED THROUGH WITH DRILLER OBSERVING NABORS LO/TO AUDIT. AUDIT CAME OUT 100% -REMOVE AND REPLACE ANNULAR ELEMENT. -REMOVE DEPLOYMENT LINE SPOOL. CAP .R3/BL3 I-PERFORM FIRST STAGE OF RAM RECONFIGURE -SIMOPS:RIG DOWN CHECK LISTS 06:00 - 15:30 9.50 BOPSUR P PRE CONTINUE WORKING ON BOPE STACK RECONFIGURATION. BLIND/SHEAR RAMS NOT COMPATIBLE WITH AUTO LOCK DOUBLE RAMS -NOTIFY TOWN AND ADJUST RECONFIGURATION PLAN ACCORDINGLY. -REMOVE LINES AND INSTALL TREE CAP,LTT TREE CAP,OK. 15:30 - 23:00 7.50 BOPSUR P PRE I TRUCK ON LOCATION TO PULL PIT MODULE }AND RE SPOT. -PRE JOB WITH PEAK AND RIG CREW WITH REGARD TO PULLING PIT MODULE OFF. -SET MAIN SUB AND MODULE DOWN. CONTINUE WITH RAM RECONFIGURATIONS 23:00 - 00:00 , 1.00 RIGD P PRE INSTALL JEEPS, PJSM WITH PEAK SECURITY ARRIVAL. BEGIN RIG MOVE TO DS14-34 12/1/2017 00:00 - 04:00 4.00 DEMOB P PRE MOVE RIG FROM H-PAD TO DS14 ARRIVE ON LOCATION. RELEASE SECURITY. REMOVE JEEPS. 04:00 - 06:00 2.00 DEMOB P PRE CONDUCT PJSM FOR PULLING OVER WELL WITH PEAK AND NABORS CREW. -DISCUSS USE OF STOP BLOCK,STOP COMMAND AND SPOTTER POSITIONS. -DISCUSS 2 FT RULE,STOP THE JOB AUTHORITY AND MITIGATIONS FOR COLD WEATHER OPS. -DRILL SITE OPERATOR NOTIFIED,WAIVED WITNESSING PULLING OVER THE WELL. -NABORS TOOL PUSHER AND WSL WITNESSED AND VERIFIED ALL PRESSURE BLED OFF ANNULI. -SPOT SUB OVER WELLAND SPOT PIT MODULE.RIG ACCEPTED @ 06:00 HRS, 12/1/2017. 06:00 - 21:00 15.00 DEMOB P PRE WORK ON RIG UP CHECKLIST. -NIPPLE UP BOPE,TORQUE UP ALL CONNECTIONS. -LTT ON SWAB VALVE/MASTER VALVE,3500 PSI,GOOD. -RIG UP LINES IN CELLAR -TEST GAS ALARMS,PREP EQUIPMENT FOR BOPE TESTING. Printed 12/11/2017 3:52:16PM *All depths reported in Drillers Depths* • North America-ALASKA BP 2407 Operation Summary Report Common Well Name:14-34 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/30/2017 End Date:12/4/2017 X3-018T8-C:(1,363,166.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:CDR-2 Spud Date/Time:9/22/1983 12:00.00AM Rig Release: Rig Contractor NABORS ALASKA DRILLING INC. BPUOI USA00000831 Active datum:KB @69.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 DEMOB P PRE CLEAN AND CLEAR CELLAR AND RIG FLOOR -PERFORM WALK THROUGH PRIOR TO FLUID PACK -PERFORM FLUID PACK AND SHELL TEST. SMALL LEAK ON HAMMER UNION. -TROUBLE SHOOT SLOW LEAK DOWN. GET GREASE CREW COMING FOR CONTINGENCY 12/2/2017 00:00 - 00:30 0.50 DEMOB P PRE FINISH FLUID PACK 00:30 - 06.30 6.00 BOPSUR P PRE TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -TEST ANNULAR AND VARIABLES WITH 2-3/8" j AND 3.5""TEST JOINTS -ALL RAMS TESTED ON RAM LOCKS -ALL TESTS CHARTED -TEST WITNESS WAIVED BY AOGCC REP ADAM EARL 12/01/2017 07:14 -7-1/16"ANNULAR,BLIND/SHEAR RAMS, 2-3/8"PIPE/SLIP,MUD CROSS,2-3/8"X 3-1/2" VARIABLE,2-3/8"PIPE/SLIP I-PERFORM ACCUMULATOR DRAWDOWN TEST. 06:30 - 11:00 4.50 BOPSUR P PRE RECONFIGURE LUBRICATOR EXTENSIONS FOR DRILLING OPS -TEST#9 AND#10 VALVES ON CHOKE, (REVERSE FLOW) -TIGHTEN BOLTS ON TREE WITH INJECTOR ON. -PRESSURE TEST FLOATS/ 11 00 - 11:15 0.25 BOPSUR P PRE H2S RIG EVACUATION DRILL,H2S RELEASE IN CELLAR. -RIG EVACUATED TO THE MUSTER AREAAND HEAD COUNT,LESS THAN 5 MINUTES. -GOOD AAR WITH DISCUSSION AROUND WIND DIRECTION AND ALWAYS VENTILATE ON WAY OUT. -DISCUSSED SOP WITH REGARD TO LOW LEVEL ALARM. -EACH HAND ACCOUNTED FOR. 11:15 - 12:00 0.75 STWHIP P WEXIT LINE UP AND OPEN MASTER VALVE TOA CLOSED SWAB. -CHECK FOR PRESSURE ON THE WELL,(0 PSI)ON THE WELL. -PREP TO FILL COIL 12:00 - 14:00 2.00 STWHIP P WEXIT PJSM.FILL COIL WITH(10)BBLS MEOH AND SLICK KCL. -OPEN SWAB AND FLOW CHECK TO TIGER TANK,(10 MIN),WELL BORE IS STATIC. -BLOW DOWN LINES. 14:00 - 15:00 1.00 STWHIP P WEXIT PJSM.MAKE UP WINDOW MILLING BHA. -WINDOW MILL 3.80"GO(TIGHT),3.79"NO GO. -STRING REAMER 3.80"GO,3.79"NO GO. - INJECTOR MADE UP @ 15:00 HRS. Printed 12/11/2017 3:52:16PM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 3 M • Operation Summary Report Common Well Name:14-34 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/30/2017 End Date:12/4/2017 X3-018T8-C:(1,363,166.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:CDR-2 Spud Date/Time:9/22/1983 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000831 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 15:00 - 21:30 6.50 STWHIP P 11,233.00 WEXIT RIH WITH WINDOW MILLING BHA#1 ATTEMPT TO LOG A MEANINGFUL TIE IN. NO CHARACTER OVER LOG INTERVAL DISCUSS WITH ODE AND GEO TEAM. DRY TAG WHIPSTOCK PINCH POINT TAG AT 11242'-5.33'=11236.67' UNCORRECTED. -8.5'CORRECTION TO 11228' CIRCULATE WELLBORE FLUIDS TO TIGER TANK. MAINTAIN CIRCULATION TO TIGER TANK UNTIL RETURNS CLEANED UP. SWAP HOLE OVER TO 8.6 PPG MILLING FLUID. ONCE DRILLING MUD AROUND. PURGE 1 LUBRICATOR TO TIGER TANK. PERFORM 10 MINUTE STATIC FLOW CHECK. WELL DEAD. • pi 21:30 - 00:00 2.50 STWHIP P 11,235.20 WEXIT MILL 3.80"WINDOW IN 7"LINER PER BAKER REP FROM 11233.2'MD TO 11235.2' H34k -RATE:2.60 BPM IN,2.60 BPM OUT -MUD WEIGHT:8.67 PPG IN,8.62 PPG OUT -DWOB:0.7-3.5 KLBS •-CIRC PRESSURE:2429 PSI 12/3/2017 00:00 - 01:00 1.00 STWHIP P 11,236.20 WEXIT MILL 3.80"WINDOW IN 7"LINER PER BAKER REP FROM 11335.2'MD -RATE:2.59 BPM IN,2.59 BPM OUT -MUD WEIGHT:8.64 PPG IN,8.61 PPG OUT -DWOB:3.5KLBS -CIRC PRESSURE:2485 PSI 01:00 - 07:00 6.00 STWHIP P 11,239.50 WEXIT MILL 3.80"WINDOW IN 7"LINER PER BAKER REP FROM 11336.6'MD -RATE:2.59 BPM IN,2.59 BPM OUT -MUD WEIGHT:8.64 PPG IN,8.61 PPG OUT -DWOB:2.0 KLBS -CIRC PRESSURE:2465 PSI WOB FELL OFF.MILL TO 11,242.5' 07:00 - 08:30 1.50 STWHIP P 11,252.50 WEXIT MILL 10'OF RATHOLE TO 11,252.5' -CONFIRM WITH GEO,EXITED AND IN SHUBLIK. 08:30 - 11:45 3.25 STWHIP P 11,252.50 WEXIT DRESS WINDOW. -MAKE SEVERAL PASSES UP AND DOWN THRU WINDOW @ 11,233'-11,242.5' -UP WT 53.5K,DOWN WT 22K.DRY DRIFT WINDOW,SMOOTH. -PAINT FLAG ON BOTTOM @ 11,252.5',FLOW CHECK WELL,(10 MIN),WELL BORE STABLE. 11:45 - 14:30 2.75 STWHIP P 11,252.50 WEXIT POOH W/WINDOW MILLING ASSEMBLY. -FLOW CHECK AT SURFACE,WELL BORE STABLE,8.6 PPG MUD IN AND OUT. -TAG UP AND POP OFF INJECTOR @ 14:30 HRS. 14:30 - 15:30 1.00 STWHIP P 11,252.50 WEXIT PJSM.LAY DOWN WINDOW MILLING BHA. -WINDOW MILL 3.80"GO,3.79"NO GO. -STRING MILL 3.80"GO,3.79"NO GO. -MAKE UP DRILLING ASSEMBLY,2.80 BEND MOTOR AND HUGHES BIT W/P-104 CUTTERS. -MAKE UP INJECTOR @ 15:30 HRS.TEST QTS @ 3500 PSI,OK. Printed 12/11/2017 3:52:16PM 'All depths reported in Drillers Depths* TIME= 5X7 FMC 1203 •WHLt4=AD=, GRAY GI3�13 • 1 4_34 NOTES: 4-112"CHROME TBG. 'ACTUATOR= BAKER-C OKB ELEV= 69' I I a.-E/.; 69' BF.H.EV= 41.91' KOP= 2100' , , 2199' H 4-112-HES X NP,D=3.813" Max Angle= 56°@710_0' Datlan MD= 1148' Datum ND=- 8800'SS ? GAS LFT MANDRILS ST MD TVD DEV TY FE VLV LATCH PORT DATE - 13-3/8"CSG,72#,L-80 BTC,ID=12.347" I 2600' © 6 3103 3004 34 KBG-2 MAY BK 0 07/06103 5 4262 3786 53 KBG-2 DMY BK 0 09/25/17 4 6641 5311 51 KBG-2 DMY BK 0 09/25/17 Minimum ID = 3.804" @ 10884' 3 8262 6365 46 KBG-2 DM' BK 0 07/03/03 4-1/2" HES XN NIPPLE MILLED 2 9757 7472 40 KBG-2 DMY BK 0 07/03/03 1 10666 8191 36 KBG-2 DMY BK 0 07/03/03 ' ' 10734' —4-1/2"HES X NP,I7=3.813" Z X 10766' H9-5/8'x4-1/2"BKR S-3 NKR,D=3.875" TOP OF 7"LNRJ-1 10849' ' 10864' H4-1/2"FES X NP,D=3.813" M ' 10884' H4-1/2"HES XN NP MLLED TO 3.804"(11/24/17) 4-1/2"TBG,12.6#,13-CR,.0152 bpf,ID=3.958" H 10896' • 10897' —{4-1/2"WLEG,D=3.958" 9-5/8"CSG,47#,L-80 BTC,D=8.681" - 11168' 0 11228'ELMD —4-112"X 7"BKR DELTA WS w IRA TAG(11/25/17) PERFORATION SUMMARY REF LOG: BRCS ON 10/27183 ~11266' TOP OF CMT(11125117) ANGLE AT TOP PERE: 33°@ 11460' MAW& —maimm"' 11273' H2-1/8"POSISET PLUG(11/24/17) Note_Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz Opn/Sqz 3-1/8" 4 11408-11418 S 05/24/94 3-1/8" 4 11422-11452 S 05/24/94 3-1/8" 4 11460-11480 0 07/14/95 4 11523-11533 0 02/07/95 4 11537-11547 0 06/01/94 4 11550-11560 0 06/01/94 4 11560-11564 0 06/01/94 4 11574-11580 0 06/01/94 11625'CTMD —FISH-PDS CENTRALIZER ARM(08/29/11) 11580-11594 0 07/14/95 i PUSHED TO PBTD(02/29/16) 11619-11629 S 05/24/94 11630-11650 S 05/24/94 11626'CTMD —FETIDPOST SOZ(06/01194) 11650-11660 S 05/24/94 3-1/8" 4 11680-11686 S 05/24/94 PBTD H 11886` 44•*4' 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" H 11926' al4a•�•�4a•�4�4 DATE REV BY COM ENTS DATE REV BY COkL 4TS PRUDHOE BAY INT 10/31/83 ORIGINAL COMPLETION 10/30/17 JN/J&D UPDATED REF,BF&TOP OF 7"LNR WEI: 14-34 07104/03 DAVRLP RWO 11/28/17 MS/JMD TALL XN NP/SET PLUG,CMT&WS PERMT No: 1831330 02/24/16 SWC1JMD GLV GO(02/23/16) API Nb: 50-029-21010-00 03/16/16 SJW/JMD PUSH FISH DH(02/29/16) SEC 9,T14N,R14E 195'FAL&1243'FEL 09/21/16 JMD UPDATED PERF SUMMARY 09/19/17 CW/JMD ADDED OKB&BFE BP Exploration(Alaska) wPti o j V T; • 4 THE STATE• Alaska Oil and Gas Of/\ L sKA Conservation Commission 1� 333 West Seventh Avenue _ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 loa7117 R Main: 907.279.1433 ALASp. Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna Egbejimba Engineering Team Leader t BP Exploration (Alaska), Inc. W�� � 1\1 . 0 2.8I P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-34 Permit to Drill Number: 183-133 Sundry Number: 317-508 Dear Mr. Egbejimba: 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, (gar: Hollis S. French Chair DATED this2- day of November, 2017. • RBDMS L� NOV - 2 2012 • • 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 3. in the upper left corner of Form 10-403 is checked. If the "Abandon" or ,/ j "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 LASKA OIL AND GAS CONSERVATION COMM! APPLICATION FOR SUNDRY APPROV IIIII 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill IA' 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. 183-133- Address: P.O.Box 196612 Anchorage, Exploratory 0 Development Il- 3. 9 AK 6. API Number: 50-029-21010-00-00 - 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Num E C E I V E D What Regulation or Conservation Order governs well spacing in this pool? G Will planned perforations require a spacing exception? Yes 0 No 0 - PBU 14-34 , OCTc 7 9. Property Designation(Lease Number): 10. Field/Pools: D6 l O r ADL 028312 ` PRUDHOE BAY.PRUDHOE OIL � � 11. PRESENT WELL CONDITION SUMMARY C Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11925 4 9251 11625 8987 2502 11625 11625 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 31-112 31 -112 1490 470 Surface 2572 13-3/8" 30-2602 30-2568 4930 2670 Intermediate 11132 9-5/8" 27-11159 27-8595 6870 4760 Production Liner 1076 7" 10849-11925 8340-9251 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11460-11594 8846-8960 4-1/2"12.6# 13Cr80 25-10903 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 10761/8269 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Il Exploratory 0 Stratigraphic 0 Development B ' Service 0 14.Estimated Date for Commencing Operations: November 15,2017 15. Well Status after proposed work: / Oik /''l t,�/INJ 0 WDSPL 0 Suspended �, 7i,1-7 16.Verbal Approval: Date: GAS 0 l.- WAG 0 GSTOR 0 SPLUG 0 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: Ciolkosz,Ryan R be deviated from without prior written approval. Contact Email: Ryan.Ciolkoszc bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 5977 Authorized Title: Engineering Team Leader-CTD&RWO Authorized Signature: (► Avow — Date: 1 012 V ia-S I�. c COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: (31 1 - 5 01? Plug Integrity 0 BOP Test I" Mechanical Integrity Test 0 Location Clearance 0 Other: 43r t-e-,5 7,- f a 3 bQOp b-t 4nr)v/arp r--v'r-� 1--1--i- h-- to 2-5,0j251_5 , Post Initial Injection MIT Req'd? Yes❑ No. Efj �`r�n4, pl v pJ q g� 7`11-a pri2 it Spacing Exception Req iredYes❑ No Subseq nt Form Required: /(% " 4 APPROVED BYTHE t r 11.Approved by: COMMISSIONER COMMISSION Date: vii- /'//li? l't AI\ „' ORIGINAL RBDVS 'v- ROV - Z 21117 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • To: Alaska Oil & Gas Conservation Commission q From: Ryan Ciolkosz CTD Engineer T.; Date: October 25, 2017 Re: 14-34 Sundry Approval Sundry approval is requested to plug the 14-34 wellbore as part of the drilling and completion of the proposed 14-34A CTD sidetrack. 14-34 was original drilled in 1983 and RWO install new tubing in 2003. The well has confirmed integrity. Plan would be to drill a CST slant well to replace 14-34 which is currently a marginally competitive producer due to very high gas rates. High gas production is from either the uppermost open perforation or leaking liner/squeezed perforations in Z4B or upper Z4A and may be enhanced by a fault/fracture crossing the well. A CST well targeting a potential Z3 column or Z3/2C immaturely swept waterfllood in the vicinity of the parent well, will eliminate the leaking liner concerns of the parent and will mitigate the risk of faults/fractures by providing adequate standoff. Proposed plan: Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on or around Decemeber 1st, 2017. CDR 2 will mill a 3.80"window in the 7" liner and drill an Ivishak well to 12152 ' MD. The lateral will be completed with a 3-1/4' x 2-7/8" 13Cr-80 liner which will be cemented and perforated. This Sundry covers plugging the existing 14-34 perforations via the 14-34A liner cement job or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)) and via Posi-set plug 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. CO�Ct1c, The ,�rb�eci +.reel plc duces „v;r6 a (;QA of y 1a' �CF/sr.J 44 o f'er Cvfi d� N60% 74. , et q ver4, e (201( 15 ti 2f �cF7wo, ��, 'M ,,[ //so /�Q r4 well does ACT rece;"` in✓ct �� 7.-41, qua Cls `io5vw� r �/ ie Cec4 ar a W4 1 S'ti'� ;n !ece4t6y did well �' �� ( err S q/ltdw fv/� r /pip/ray-tot recover, am dl's poctai of roeI,9407 i1 Ov • • Start Date November 15th, 2017 1. E Mill XN Nipple, Set Posi-Set, Dump Bail cement, Set 4-1/2"x7" Whipstock 2. F A/EL: Load TBG. Wait 3 days and Test Posi-Set 3. V Pre CTD Tree Work. Rig Work: 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,502 psi. - 2. Mill 3.80"window plus 10' of rathole. Swap the well to 8.6 ppg drilling fluid. • 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD. 5. Run 3-1/4" x 2-7/8" 13CR-80 liner. 6. Pump primary cement bringing TOC to TOL, 21.2 bbls of 15.3 ppg liner cmt planned* 7. Freeze protect well, RDMO Post Rig: 1. V: Tree work. Pull TWC if needed. 2. F: Liner lap test(positive pressure test) 3. C: RPM log (rush process), perforate -50' MD 4. S: Set live GLVs, set LTP (if necessary) *Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka TREE= 5X7 RwY GEN 3 120E 1 4-34 W13LFEAD= GRAY Illitl-t I Y NOTES: 4-1/2"CHROME TBG. ACTUATOR= BAKERC NT1AL KB.ELEV 64.23' I I BF.REV= 45.4 KOP= 2100 Mix Angle= 56"6-7100' I 2199' --14-1/2"HES X NIP,t)=3.813" 1 Datum MD= 11487' -- Datura ND= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" --I 2600' 1 ST MD TVD DEV TY FE ` VLV LATCH PORT DATE 6 3103 3004 34 KBG-2 DMY BK 0 07/06/03 5 4262 3786 53 KBG-2 DOME BK 16 02/23/16 4 6641 5311 51 KBG-2 SO BK 20 02/23/16 Minimum ID =3,725" § 10884' 3 8262 6365 46 KBG-2 DMY BK 0 07/03/03 4-112" HES XN NIPPLE 2 9757 7472 40 KBG-2 DMY BK 0 07/03/03 --- — 1 10666 8191 36 KBG-2 DMY BK 0 07/03/03 • 10734' H4-1/2"I-ES X NP,E)=.3.813" 110' 10755' —19-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" Lip OF 7"LNR — 10854' ili 10864' —4-1/2"FES X NP,D=3.813" • 10884' —4-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12,8#,13-CR .0152 bpf,D=3.958" — 10896' 1089T —4-1/2"WLEG,D=3.958" 9.5/8"CSG,47#,L-80,ID=8.681" —I 11158' PERFORATION SUMMARY REF LOG: BRCS ON 10/27/83 ANGLE AT TOP PERF: 33"@ 11460' Note:Refer to Roducton 08 for historical perf data SIZE SPF I INTERVAL Opn/Sqz Opn/Sqz 3-1/8" 4 11408 11418 S 05/24/94 3-1/8" 4 11422-11452 S 05/24/94 3-1/8" 4 11460-11480 0 07/14/95 4 11523-11533 0 02/07/95 4 11537-11547 0 06/01/94 4 11550-11560 O 06/01/94 4 11560-11564 O 06/01/94 11625'CTMD —FISH•-PDS CENTRALIZER ARM(08/29/11) 4 11574-11580 0 06/01/94 ; PUSHED TO F'BTD(02/29!16) 11580 11594 0 07/14/95 11626'CTMD --I PBTD POST SQZ(06/01/94) 11619-11629 S 05/24/94 11630-11650 S 05124/94 11650-11660 S 05/24/94 3-18" 4 11680-11686 S 05/24/94 PBTDj—H 11885' ♦.���� ..4444 T.LNR 29#,L-80 BTC,.0371 bpf,ID=6.184" -1 11925' kVA DA I E REV BY COMMENTS I DATE REV BY GOMfuENTS PRUDHOE BAY UNfT 10/31/83 ORIGINAL COMPLETION 02/24/16 SWCJJMD GLV GO(02/23/16) WELL: 14-34 07/04/03 DAV/TLP RWO _ 03/16/16 SJW/JMD PUSH FISH OH(02/29/16) FERMI No:'1831330 07/06/03 DTRtKK GLV GO09/21/16 JMD UPDA IUD PEIRF SUMMARY API No: 50-029-21010-00 04/02/10 CJN+SV GLV GO(03/30/10) SEC 9,T1ON,R14E 195'FM.&1243'FEL 09/19/11 SWCI PJC FISH-CENTRALIZER(8/29/11) _ 09/11/13 DI/JMD TREE C/O(08/18/13) BP Exploration(Alaska) •X7 NEW-FAD= 5 GRAY IGEN 3 14-34A SAFETY NOTES: 4-1/2"CHROME TBG. ACTUATOR= BAKER C OKB ELEV= 69' I I REF ELEV= BF ELEV= 41.91' KOP= 2106- I 2199' -14-1/2"HES X NP,D=3.813' kW Angle= 56°@ 7100' Datum WD= 11487' Datum ND= 8800'SS GAS LFT MANDRELS ST MD ND DEV TY PE VLV LATCH PORT DATE 110 13-3/8"CSG,72#,L-80,D=12.347" 2600' 6 3103 3004 34 KBG-2 DMY BK 0 07/06103 5 4262 3786 53 KBG-2 DMY BK 0 09/25/17 4 6641 5311 51 KBG-2 DMY BK 0 09/25/17 Minimum ID =3.725" @ 10884' 3 8262 6365 46 KBG-2 DMY BK 0 07/03/03 4-1/2" HES XN NIPPLE 2 9757 7472 40 KBG-2 DMY BK 0 07/03/03 1 10666 8191 36 KBG-2 DMY BK 0 07/03/03 10734' -14-1/2"HES X NP,D=3.813" ►—, Ea10755' -19-5/8"X 4-1/2"BKR S-3 PKR D=3.875' ow r1�1� 10853' - 3.70"BKR DEFT.OY PA34T SLV,D=3.00" 111 f." 111. 11♦/ 1 10853' -3-112"XMP,D=2.813" TOP OF 7"LNR - 10854' ►�.1 1,1,1,! )911 119 1(,1 '11', 10863' -13-1/2"X 3-3116"XO,OD=2.786" 14.4 114�,, 10864' 41/2"HES X NP,D=3.813" 1414 1*4/ 1" I' 10884' — 4-1/2"HES XN NP, MLLED OUT TO 3.80"D 41/2"TBG, 12.6#,13-CR, 0152. bpf,D=3.958" H 10896' 1(11 ►114 _ *1 1.O. 1 10897' -14-1/2"WLEG,D=3.958" 9-5/8"CSG,47#,L-80,ID=8.681" H 11158' 114 1 ►11 111 ►1111 111 ►1111 111 ►1111 111 ►1111 111 ►1111 111 ►1111 4-1/2"X 7`BKR DELTA WS - 1122€t' N.*I 41 N I NAciik,lik; FBTD -1 12120' 3-1/4"LNR,6.6#,13CR-85 TCA,0079 bpf,D=2.850" -1 12152' 11625'CTMD -PBTD POST SQZ(06/01/94) PBTO -{ 11886' II.*** 1111111111111 11625'CTMD -FISH-PDS CENTRALIZER ARM(08/29/11) (7"LNR.29#,L-80 BTC,.0371 bpf,D=6.184' 11926' /1e1a1e141,1/1 PUSHED TO P8T0(02/29/16) DATE F2EV BY COMMENTS DATE REV BY COIVIVENTS PRUDHOE BAY INT 10/31/83 ORIGINAL COMPLETION 02/24/16 SWUM)GLV GO(02/23/16) WELL. 14-34 07/04/03 DAV/TLP RWO 03/16/16 SJW/JM) RJSH FISH DH(02/29/16) PERMIT Pb."1831330 07/06/03 DTR/KK GLV C/O 09/21/16 ND UPDATED PERF SIIM IARY API No: 50-029-21010-00 04/02/10 CJN/SV GLV C/O(03/30/10) 09/19/17 CVV/JMD AXED OKB&BFE SEC 9,T1ON,R14E, 195'F NL&1243'FH_ 09/19/11 SWC/PJC FISH-CENTRALIZER(8/29/11) 09/27/17 MGS/JND GLV GO(09/25/17) 09/11/13' DIYJND TREE 00(08/18/13) BP Exploration(Alaska) Well Blank •DR2-AC BOP Schematic irate Quick Test Sub to Otis I -1.1 ft — — — — — - Top of 7"Otis 0.O ft i :'1 ,„, ;. -4 CDR2 Rig's Drip Pan Distances from top of riser n Excluding quick-test sub Top of Annular =MU= Innl \ 7-1/16"5k Flange X 7"Otis Box : Hydril 7 1/16" Top Annular Element 0.7 ft f Annular Mkt Bottom Annular 2.0 ft ► nt oEl'a• Blind/Shear CL Blind/Shears I 3.3 ft ► 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft 85 B6 """ "" :7 B8 Deployment Line( I :: ` °r 7 Mud l.. EIS -M 5k Mud • • . • '•• -� _ �` crus f Ill „, Ill 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft ► 2-318"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft ►i' B1 I B2 B3 I B4 Kill Line "r c �IAI • • ♦ ,pr0114:41:14111 t.p ' Ill III Blind/Shear CL Blind/Shears 10.0 ft ► 2-3/8"Pipe/Slips ',i CL 2-3/8"Combi's 10.7 ft -.... • CL of Top Swab 13.3 ft ��� 1—Swab 2 Test Pump Hose 4/Swab 1 CL of Bottom Swab 14.8 ft w�� TI it T2 CL Flow Tee 16.2 ft _ � -_ t♦ - - BOP2 CL of SSV 17.5ft I; - i Master2 } - Fusable CL of Master Valve 19.0 ft BOP1 Rik1 Master 1 LDS 20.5 ft -- o.,_ _ I .IA , l', II II n u n Gound Level [110A :I1 , II II II II n ge Project Well History File 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. k (~' ~- ~ 3'~ Well History File Identifier 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: " ' .el Logs of various kinds NOTES: [] 'Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation ._~ x 30 = .,~J0_ . . c~I = TOTALPA(~ES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: 'O~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES '~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~/YES NO IIIIIIIIIIIIIIIIII Stage 2 8Y2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A"I-rENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 ,~ ~ ~r ~~ .` e.~s "~..4 by ?~ ^ ,~,_, CSC ~. '~ (QJ9 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, r~, .._ ~ :~~G~t, ..~~i~r t..°~w. . 1~3-~33 1 ~ - 3 ~f- 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 h na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292037803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA i4-04A 1961640 500292032001 Sealed Conductor NA NA 14-o5A 1920010 5002920327oi Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA to-08A 2022100 500292033001 Sealed Conductor NA NA 14-09B 1820340 500292053402 Sealed Conductor NA NA i4-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 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-i6A 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 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA t4-34 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 14-40A 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 1020 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 K/[(',JIL STATE OF ALASKA ALAS AND GAS CONSERVATION C ~v, MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Pedorate [] Variance [] Othe~ [] Alter Casing I~ Repair Well [] Plug Perforations [] Stimulate [] Time Extension [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well [] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 183-133 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21010-00-00 7. KB Elevation (ft): KBE = 69' 9. Well Name and Number: PBU 14-34 8. Property Designation: 10. Field / Pool(s): ADL 028312 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11925 feet true vertical 9251 feet Plugs (measured) Effective depth: measured 11885 feet Junk (measured) true vertical 9215 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 81' 81' 1530 520 Surface 2600' 13-3/8" 2600' 2567' 4930 2670 Intermediate 11158' 9-5/8" 11158' 8594' 6870 4760 Production Liner 1071' 7" 10854' - 11925' 8344' - 9251' 8160 7020 Perforation Depth MD (ft): 112523'- 11580' Perforation Depth TVD (ft): 8899'- 8948' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 10897' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer; 10755' 4-1/2" HES 'X' Nipple 2199' 12. Stimulation or cement squeeze summary: ~'~ '~. .... ":~. "...' ~. Intervals treated (measured): ,~ i ~ ~' ~ (',?~ ? fl) Id ~ Treatment description including volumes used and final pressure: i~:~,, !: '.: ,, 13. Representative Daily Avera~le Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubin,q pressure Prior to well operation: 1,528 37,403 686 876 Subsequent to operation: 1,044 22,943 1,157 783 ~ 4. Attachments: 15. Well Class after proposed work: ' [] Copies of Logs and Surveys run [] Exploratory [] Development [] Service [] Daily Report of Well Operations 16. Well Status after proposed work: [] Oil [] Gas [] WAG [] GINJ [] WlNJ [] WDSPL 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743I N/A Printed Name Terrie Hubble Title Technical Assistant ~0~,~ ~ Phone (~,0~1~,~ Prepared By Name/Number: Signature 564-4,6:~8, ~, , Date ...,,... Terrie Hubble, 564-4628 Form 10-404 Revised,~:~;~N~JF~j.) AUG ~., 0 2003 ~ BFL Well: 14-34 RWO Accept: 06/25/03 Field: Prudhoe Bay Unit Spud: N/A APl: 50-029-21010-00 Release: 07/03/03 Permit: 183-133 Rig: Nabors 4ES Date PRE-RIG WORK 05/09/03 BAKER 3-3/8" IBP SET WITH TOP AT 10807'. MID OF ELEMENT AT 10814'. COLLAPSE TAGGED AT 10837'. 06/04~03 DRIFT W/4.49 CENT W/BAKER EQ SLEEVE BELOW DRIFT. SAT DOWN & EQUALIZE IBP @ 10794' SLM. PULL IBP @ 10792' SLM. START FISHING RUBBER IBP ELEMENTS. 06107103 FISH ONE 6" IBP ELEMENT, ONE 6" ELEMENT PULLED OUT W/IBP, ONE 1" WIDE ELEMENT STILL IN HOLE. DUMP 50# OF SLUGGITS ON TOP OF PLUG BODY @ 10,825'SLM. ATTEMPTING TO PULL STA 11. 06/08/03 PULL DGLV FROM STA #8 @ 10,292'SLM. OPEN POCKET. PULL CATCHER FROM 10,804 SLM. 06/18/03 CHEMICAL CUT THE 5.5" TUBING IN THE FIRST FULL JOINT ABOVE THE GLM AT 10780'. 1ST RUN: 16', 2 STRAND STRING SHOT. 10735' - 10751'. TAGGED AT 10834'. 2ND RUN: 4 7/16" CHEMICAL CUTTER. CUT TUBING AT 10746'. 06/21/03 PUMP 50 BBLS HOT DIESEL DOWN FLOWLINE TO FLUSH OUT BP EXPLORATION Page I of 5 Operations Summa Report Legal Well Name: 14-34 Common Well Name: 14-34 Spud Date: 9/22/1983 Event Name: WORKOVER Start: 6/26/2003 End: 7/3/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/3/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations , , 6~25~2003 08:00 - 09:30 1.50 MOB P PRE Scope down & lower derrick. 09:30 - 10:30 1.00 MOB P PRE R/D equip & prepare to move. 10:30 - 13:00 2.50 MOB :P PRE Begin move from DS 11 to Ds 14. ( 10 mile move) 13:00 - 17:00 4.00 MOB P PRE Had flat tire on sub module. Change tire. 17:00 - 19:30 2.50 MOB P PRE Con't to move from DS 11 to DS 14. Spot in sub module over well # 34. 19:30 - 21:00 1.50 RIGU P PRE Raise & scope up derrick. 21:00 - 22:00 1.00 RIGU P PRE Berm & Spot in pipe shed & pit modules. R/U electric lines. 22:00 - 23:30 1.50 RIGU P PRE R/U lines to tree & spot in tiger tank. Finish rigging up lines. Accepted rig @ 2200 Hrs. 23:30 - 00:00 0.50 WHSUR'P DECOMP M/U lubricator & pull BPV. 6/26/2003 00:00 - 00:30 0.50 WHSUR P DECOMP Finish pulling BPV & L/D lubricator. 00:30 - 01:00 0.50 WHSUR P DECOMP Pressure test lines for well kill to 3500 psi, tested good. 01:00 - 02:00 1.00 WHSUR P DECOMP Finish taking on 8.5 ppg heated seawater. Hold pre-spud & PJSM. SITP = 300 psi, I/A = 660 psi, O/A = 150 psi. 02:00 - 07:00 5.00 KILL P DECOMP Kill well. Pump in @ 6 BPM 350 psi. Had fluid returns after pumping 29 Bbls. Recovered diesel. Well cleaned up after 388 Bbls. Getting back clean heated water. ( hole in tbg?) Con't to circulate for a total of 890 Bbls. Monitor well. Well stable, tubing & annulus on slight vacuum. O/A 400 psi. 07:00 - 09:00 2.00 WHSUB P DECOMP Set BPV w/two way check & N/D tree. 09:00 - 13:00 4.00 BOPSUIq P DECOMP N/U 13 5/8" x 5M BOPE. C/O pipe rams, install 3 1/2" x 6" variable pipe rams. 13:00 - 19:30 6.50 BOPSUIq P DECOMP Conduct full test on BOPE. Test witnessed by AOGCC state rep Lou Grimaldi. Tested all equip except pipe rams. LP 250#, HP 3500#. AOGCC gave waiver on pipe rams until completion is pulled. (could not test due to Grey Gen III hanger w/BPV & dart) Installed 3 1/8" annulus valve. Recharged N2 bottles on Koomey. 19:30 - 20:30 1.00 WHSUR P DECOMP Pull dart in in BP¥. P/U 5 1/2 Landing Jt & function tested pipe rams. Perform Koomey test. 20:30 - 21:00 0.50 WHSUR P DECOMP M/U lubricator & pull BPV. L/D luricator. 21:00 - 00:00 3.00 PULL P DECOMP Clear & clean rig floor. M/U double spear assy. stab onto 5 1/2" tbg & pull on completion. No stretch in pipe, hanger "frozen". Work pipe up to 240 K. Install heat blanket on tbg spool & apply steam to spool. Work pipe would not pull free. Unlatch spear & L/D. 6/27/2003 00:00 - 00:30 0.50 PULL P DECOMP M/U jar & spear assy. RIH & jar. Hit jars 5 times @ 1401<; & hanger came free. S/D steam, hanger pick up w/198k. Land hanger & P/U to insure it will come free w/o jarring. 00:30 - 01:30 1.00 PULL P DECOMP L/D jarring assy. P/U spear & spear tubing. Pull hanger to floor. 01:30 - 02:30 1.00 PULL P DECOMP Remove control lines & clamps. L/D hanger & spear assy. Pump 20 bbls down annulus, hole not filling. R/U Camco spooler. Hold PJSM. 02:30 - 06:00 3.50 PULL P DECOMP POOH & L/D 5 1/2" completion, double displacing hole. Well stable. Recovered all control line bands & clamps. ~06:00 - 15:30 9.50 PULL P DECOMP Continue to POOH w/5 1/2" completion string, double displacing hole & pumping 10 bbls hi vis seawater every 2000' of tubing pulled. Shoot fluid level, level @ 1120'. 251 its laid down total plus cut off joint 21.32'. Chemical cut looks good .... OD of cut = 5.56". 15:30 - 18:00 2.50 PULL P DECOMP Pump 50 bbls seawater & 10 bbls viscosified seawater down hole. Well stable. PJSM. P/U & set test plug, test pipe rams @ Printed: 7/8/2003 1:09:56 PM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: 14-34 Common Well Name: 14-34 Spud Date: 9/22/1983 Event Name: WORKOVER Start: 6/26/2003 End: 7/3/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/3/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 6~27~2003 15:30 - 18:00 2.50 PULL P DECOMP 250 / 3500 psi. L/D test plug. Set wear bushing. 18:00 - 20:30 2.50 PULL P DECOMP Load & tally fishing tools & 9 Dcs. P/U BHA #1 & RIH. O/S, bumper sub,oil jars, 9 DCs & Accelerator. 20:30 - 00:00 3.50 PULL P DECOMP P/U 3 1/2" DP & RIH. ~6/28/2003 00:00 - 04:00 4.00 FISH P DECOMP Con't to P/U 3 1/2" DP & RIH hole. P/U total of 326 Jts. 04:00 - 05:30 1.50 FISH P DECOMP P/U kelly, RIH Circulate & tag up on fish @ 10760'. Attempt to work down over tbg stub. Could not engage overshot. Attempt several times & also rotate. No luck. P/U 193K, S/O 115K, Rot 145K. PP 375 psi, 65 SPM. 05:30 - 06:00 0.50 FISH P DECOMP POOH w/BHA #1. 06:00- 06:30 0.50 FISH P DECOMP Service rig 06:30 - 11:00 4.50 FISH P DECOMP Continue to POOH w/DP & Fishing BH^. :11:00 - 13:00 2.00 FISH P DECOMP PJSM. Stand back collars. Recovered cut joint, 14' pup, GLM, 14' pup, 6' pup, Baker PBR, & 4 1/2" Buttress collar. Left in hole: 5' Buttress pup w/pin end looking up & Baker FHL Packer & tailpipe. 13:00 - 13:30 0.50 FISH P DECOMP Shoot fluid level. Fluid level static @ 1260'. Repeat to confirm. 13:30 - 14:30 1.00 FISH P DECOMP M/U BHA to fish 4 1/2" Buttress tbg pup & Baker packer. 14:30-18:30 4.00 FISH P DECOMP RIHw/FishingBHA&31/2"DP. 110stands 18:30 - 21:00 2.50 FISH P DECOMP P/U kelly, start pumping @ 73 SPM, 400 psi. & RIH. Tag up on top of fish @ 10812'. Engauge fish w/overshot. DP pressured up. ( tail pipe plugged very slow leak off.) S/D pump. Work pipe &jar to 240K. P/U 187K, S/O 123K. Packer came loose sfter 40 min jarring. Packer dragging up to 30K over at times. Set back & blow down kelly. Fill hole w/116 Bbls. Taking 3 BPM to keep hole full. Monitor well. Fluid level falling. 21:00 - 23:00 2.00 FISH P !DECOMP POOH 15 stands, first 5 stands came dry. fill w/2X displacement. After 15 stands fill hole w/116 Bbls. Monitor well. 23:00 - 00:00 1.00 FISH P ;DECOMP Con't to POOH w/2X displacement. Pipe wet. Have 10K additional weight. 6/29/2003 00:00 - 06:00 6.00 FISH P DECOMP Con't to POOH w/packer. Pulling wet initially & finally drained out. 06:00 - 08:00 2.00 FISH P DECOMP Continue out of hole, stand back collars. Fish, (Baker Packer), hanging up at wellhead. 08:00 - 10:00 2.00 FISH N DPRB :DECOMP Back out lock down screws on wear bushing. Packer stil hanging up. Pull up to 50K over, stuck hard. Hit two licks on jars @ 40K over, no movement. Make up (1) stand 6" drill collars & pop loose going down. Pick up & work up to 75K over, setting off jars with no significant movement. Measurements indicate stuck point below wear bushing, either in lower wellhead or top of 9 5/8" casing. Work pipe to break free going down, OK. Opt to hang off pipe & inspect problem area. 10:00 - 11:30 1.50 FISH N DPRB DECOMP M/U collars & Baker cite sub on top of DP. RIH w/fish to 4000' on 3 1/2" DP. 11:30 - 12:30 1.00 FISH N DPRB DECOMP M/U Halliburton 9 5~8" RTTS / Storm Valve & set @ 55' (+ -). Pressure test @ 1000 psi, OK. 12:30 - 14:00 1.50 FISH N DPRB DECOMP Inspect situation. Appears pin end on pup jt below 9 5/8" hanger is lipped out. 8.5" drift thunks out on lip. Consulted town engineer. Opt to run string mill & clean it up. 14:00 - 15:00 1.00 FISH N DPRB DECOMP PJSM. N/U BOPE. 15:00 - 16:00 1.00 FISH N DPRB DECOMP Set test plug, body test on BOPE to 250 / 3500 psi, OK. Pull Printed: 7/8/2003 1:09:56 PM BP EXPLORATION Page 3 of 5 Operations Summa Report Legal Well Name: 14-34 Common Well Name: 14-34 Spud Date: 9/22/1983 Event Name: WORKOVER Start: 6~26~2003 End: 7/3/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/3/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of OperatiOns 6~29~2003 15:00 - 16:00 1.00 FISH N DPRB DECOMP test plug 16:00 - 18:00 2.00 FISH N DPRB DECOMP M/U baker 8.51" OD string mill. Dry tag 23' in from top of rotary table. Bring on pump @ 3 bpm / 50 psi. Rotate @ 80 -100 RPM. RIH to 23' & mill / dress lipped out area of 9 5/8" casing pup. Dress to 30'. Ream (3) passes. Drift OK w/pump & rotary table off. L/D string mill. 18:00 - 18:30 0.50 FISH. N DPRB DECOMP P/U storm packer retreiving tool, RIH & Equalize packer. Release packer w/87K. Well on vacuum. 18:30 - 19:00 0.50 FISH N DPRB DECOMP Pump 5 BPm @ 300 psi. & load hole w/117 Bbls of seawater. 19:00 - 19:30 0.50 FISH N DPRB DECOMP POOH & LID storm packer. 19:30 - 22:'00 2.50 FISH N DPRB DECOMP POOH & stand back 40 stands of drill pipe & 3 stands of DCs. Packer (fish) still hanging up in tbg spool. 22:00 - 00:00 2.00 FISH N DPRB DECOMP Work pipe & jar on packer to 75K. Packer stuck in tbg spool. P/U additional DC. Con't to jar on stuck packer. 6/30/2003 00:00 - 00:30 0.50 FISH N DPRB DECOMP Con't to work pipe & jar on packer, packer finally came free. 00:30 - 02:00 1.50 FISH N DPRB DECOMP POOH LID Fishing tools & packer & tail pipe assy. Recovered pup jt, packer, 2 Jts tbg, nipple, pup & shear sub. Packer did not have any rubbers. Slips did not appear to retract completely causing packer to hang up in spool. 02:00 - 02:30 0.50 FISH P DECOMP Clear & clean rig floor. 02:30 - 03:30 1.00 CLEAN P DECOMP I p/u BHA # 3, Bit, Scraper, 2 Junk Baskets, Bumper Sub, Jars, 6 DCs. RIH. 03:30 - 05:00 1.50 CLEAN P DECOMP Cut & slip 84' of drilling line. Check Breaks. 05:00-09:00 4.00 CLEAN P DECOMP RIH w/ BHA #3 on 31/2" DP to 9000'. Up wt195K, Downwt 115K. 09:00 - 10:00 1.001 CLEAN P DECOMP PJSM. M/U Halliburton RTTS & RIH, set @ 55' (+ -). LID DP. Pressure test RTTS to 1000 psi, OK. 10:00 - 13:00 3.00 WHSUR P DECOMP PJSM. Pull 9 5/8" mandrel pack off. Replace w/new pack off & pressure test same to 4000 psi / 30 minutes, witnessed, OK. 13:00 - 14:00 1.00 CLEAN , P DECOMP PJSM. RIH w/(2) jts DP. Release RTTS & LID same. 14:00-15:00 1.00 CLEAN P DECOMP RIH w/ 31/2" DP to10, 770'. Pick up kelly. 215Kupwt, 119K down, 131K rotating weights. 15:00 - 17:30 2.50 CLEAN P DECOMP Bring on pump @ 5 bpm / 1100 psi. Rotate slowly & scrape on down to 10,808', no hangups. Pump 129 bbls & get returns. Continue pumping & mix & pure 50 bbls Hi Vis sweep. Chase around while working from 10,740'- 10,808'. Total pumped 506 bbls. Stand back kelly. 17:30 - 22:30 5.00 CLEAN P DECOMP POOH w/bit & scraper assy. 22:30 - 23:30 1.00 CLEAN P DECOMP Stand back DCs. L/D BHA #3. Bit, scraper, 2 junk baskets, bumper sub & jars. Emptied junk baskets. No missing rubbers. 23:30 - 00:00 0.50 CLEAN P DECOMP Pull & L/D wear bushing. 7/1/2003 00:00 - 01:00 1.00 CLEAN P DECOMP M / U 8.51" String Mill on Kelly. RIH and Dressed Off 9-5/8" Casing from Below Tubing Spool Through Top of Casing Pup to 33' in Depth. POOH, Broke Out and L / D Mill, Stood Back Kelly. 01:00-02:00 1.00 EVAL P DECOMP MIU9-518"RTTS, 9 x 6-114" DC and l Stand of 3-112" DP. RIH to 375', Set RTTS at 375'. 02:00 - 03:00 1.00 EVAL P DECOMP Filled the Hole. Tested Lines to 3,500 psi, OK. Pressure Tested 9 5~8" Casing to 3,500 psi f/30 rain, OK. Monitored 9 5/8" x 13 3~8" Annulus, 0 psi. Released RTTS Packer. 03:00 - 08:00 5.00 EVAL P DECOMP RIH w/9-5~8" R'Frs Packer on 3 112" DP to 10,803'. 08:00 - 09:00 1.00 EVAL P DECOMP Held PJSM. Set RTTS at 10,803'. Filled the Hole. Tested Lines to 3,500 psi. OK. Printed: 7/8/2003 1:09:56 PM BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: 14-34 Common Well Name: 14-34 Spud Date: 9/22/1983 Event Name: WORKOVER Start: 6/26/2003 End: 7/3/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/3/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From-To Hours Task Code NPT Phase Description of Operations 71112003 09:00 - 10:00 1.00 EVAL P DECOMP Closed Pipe Rams, Pressure Tested 9 5~8" Casing from 10,803' to Surface to 3,500 psi f/30 Minutes on Chart, OK. Monitored 9-5/8" x 13-3/8" Annulus, No Pressure or Indication of Communication. Bled Off Pressure, Opened Pipe Rams. 10:00- 10:30 0.50 EVAL P DECOMP Released RTTS Packer. 10:30 - 16:30 6.00 EVAL P DECOMP Held PJSM. POOH and L / D 3 1/2" DP. Hole Fill 2 x Displacement. 16:30 - 17:00 0.50 EVAL P DECOMP Held PJSM. Slipped Drilling Line. 17:00 - 18:00 1.00 EVAL P DECOMP Broke Out and L / D 9 x 6-1/4" DC. 18:00 - 18:30 0.50 EVAL P DECOMP Broke Out and L / D 9-5~8" RTTS Packer. 18:30 - 19:30 1.00 RUNCOr~!:) COMP R / D 3-1/2" DP Handling Equipment. Cleared and Cleaned Rig Floor. 19:30 - 21:00 1.50 RUNCOI~ .COMP R / U 4-1/2" Tubing Handling and Running Equipment. 21:00 - 21:30 0.50 RUNCOI~ 'COMP M / U 4-1/2" Tail Pipe: WLEG Assembly - XN Nipple Assembly w/RHC-M Sleeve in XN Nipple - X Nipple Assembly - 2 Jts 4-1/2" 12.6# 13Cr Vam ACE Tbg - 9-5/8" x 4-1/2" S-3 Packer Assembly - Upper X Nipple Assembly. Torque Turned Connections, M / U Torque 3,620 ft / lbs. BakerLocked All Connections Below Packer. 21:30 - 00:00 2.50 RUNCOI~ COMP M / U and RIH w/4-1/2" 12.6# 13Cr80 Vam ACE Tubing. Torque Turned All Connections, M / U Torque 3,620 ft ! lbs. Pumped 10 bbls Down Hole Every Hour While RIH. 7/2/2003 00:00 - 11:30 11.50 RUNCOI~ COMP M/U and RIH w/253 Jts 4-1/2" 12.6# 13CrVam ACE Tubing, 6 GLM Assemblies, X Nipple Safety Valve, Upper X Nipple Assembly, Packer Assembly, Lower X Nipple Assembly, XN Nipple Assembly w/RHC-M Sleeve and WLEG Assembly. Torque Turned All Connections, Average M / U Torque 3,620 ft /lbs. String Weight Up 127,000#, String Weight Down 87,000#. Pumped 10 bbls Down Hole Every Hour While RIH. 11:30 - 12:00 0.50 RUNCOI~ COMP M / U Tubing Hanger, XO and Landing Joint. M / U Circulating Head and Line. 12:00 - 13:00 1.00 RUNCOI~ COMP , RIH and Landed Tubing Hanger. RILDS. Completion Equipment Set At The Following Depths: Item Length Depth WLEG Assembly 11.15' 10,896.88' XN Nipple Assembly 11.27' 10,874.46' X Nipple Assembly 20.65' 10,853.81' 2 Jts 4-1/2" 12.6# 13Cr Vain Ace Tbg 84.03' 10,769.78' 9-5/8" x 4-1/2" S-3 Packer Assembly 24.48' 10,745.30' X Nipple Assembly 20.77' 10,724.53' 1 Jt 4-1/2" 12.6# 13Cr Vain Ace Tbg 42.01' 10,682.52' #1 GLMAssembly 26.52' 10,656.00' 21 Jts 4-1/2" 12.6# 13Cr Vain Ace Tbg 880.24' 9,775.76' #2 GLM Assembly 28.52' 9,747.24' 35 Jts 4-1/2" 12.6# 13Cr Vain Ace Tbg 1,468.16' 8,279.08' #3 GLM Assembly 26.54' 8,252.54' 38 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 1,594.88' 6,657.66' ~4 GLMAssembly 26.57' 6,631.09' 56 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 2,352.65' 4,278.44' #5 GLMAssembly 27.06' 4,251.38' 27 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 1,132.07' 3,119.31' #6 GLM Assembly w/Shr Valve 26.67' 3,092.64' 21 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 882.38' 2,210.26' Printed: 7/8/2003 1:09:56 PM BP EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: 14-34 Common Well Name: 14-34 Spud Date: 9/22/1983 Event Name: WORKOVER Start: 6/26/2003 End: 7/3/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7~3~2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 71212003 12:00 - 13:00 1.00 RUNCO~ P .COMP X Nipple Assembly 20.80' 2,189.46' 52 Jts 4-1/2" 12.6~ 13Cr Vam Ace Tbg 2,164.90' 24.56' 4-1/2" 12.6# 13Cr Vam Ace Pup Jt 2.35' 22.21' Tubing Hanger 3.38' 18.83' 13:00 - 17:00 4.00 RUNCOk I~ COMP Held PJSM. R / U Seawater Truck to Pump. Took on Corrosion Inhibitor. Tested Lines to 3,500 psi, OK. Reverse Circulated 160 bbls of 140 deg Seawater Followed by 550 bbls of 140 deg Seawater w/Corrosion Inhibitor Down 9-5~8" x 7" x 4-1/2" IA. Took Returns Up Tubing. Pump Rate 3 bpm, 150 psi. 17:00 - 18:00 1.00 RUNCOr~P COMP Held PJSM. Dropped Ball/Rod Assembly, Allowed Time for Ball to Seat in RHC Sleeve in XN Nipple at 10,884'. 18:00 - 19:30 1.50 RUNCOI~!3 COMP Pressured Up on Tubing To 2,500 psi To Set Packer, Continued To Pressure Up on Tubing To 3,500 psi. Tested Tubing f/30 Minutes, OK. Bled Tubing Pressure Down to 1,500 ~si and Shut In. Tested 9-5~8" x 7" x 4-1/2" Annulus to 3,000 ~si f/30 Minutes, OK. Quickly Bled Down Tubing Pressure and Observed DCK Valve Shear. 19:30 - 20:00 0.50 RUNCOI~ COMP Bled Down All Pressures. Pumped Down Both Annulus and Tubing to Ensure DCK Valve Fully Sheared, Good Communication Through Both IA and Tubing. 20:00 - 20:30 0.50 RUNCOI~ COMP Blew Down and R / D Lines. Broke Out and L / D Landing Joint and XO. 20:30 - 21:00 0.50 RUNCOI~ COMP Set BPV and Test Dart, Tested to 1,000 psi, OK. 21:00 - 22:30 1.50 BOPSUF.P COMP Held PJSM. N / D BOPE. 22:30 - 00:00 1.50 WHSUR 3 COMP Held PJSM. N / U Adapter Flange and Production Tree. 7/3/2003 00:00 - 01:30 1.50~ WHSUR 3 COMP Tested Hanger, Neck Seal and Void to 5,000 psi, OK. Tested Tree to 5,000 psi, OK. 01:30 - 02:00 0.50 WHSUR 3 COMP Held PJSM. R / U DSM Lubricator, Pulled BPV, R / D DSM. ;02:00 - 03:30 1.50 WHSUR P COMP Held PJSM. R / U Little Red Hot Oil, Pressure Tested Lines to 3,000 psi, OK. Pumped 140 bbls of Diesel Freeze Protect Down Annulus. Pump Rate 3 bpm, 2,350 psi. 03:30 - 05:00 1.50 WHSUR P COMP R / D Little Red. Opened Tree Valves and U-Tubed Diesel Freeze Protect. 05:00 - 05:30 0.50 WHSUR P COMP !R / D Lines, Set BPV. Installed Blind Flange on Tree. 05:30 - 06:00 0.50 WHSUR P COMP Secured Well. Release Rig at 0600 hrs, 07 / 03 / 2003. Printed: 7/8/2003 1:09:56 PM GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-FN: Sherrie NO. 9606 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/1/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 7-3A '¢~ ~ ('Q~ CNT. G 950711 I 1 D.S. 14-34 '~ ~ \ ~"~ PROD PROFILE 950714 1 1 D.S. 16-13 "<~1 r')._"~ INFLATABLE BRIDGE PLUG 950713 I I , .. D.S. 17-7 ~f' ~' (^ (,~ PROD PROFILE ....... 95071 4 1 1 ~.s. ~-~ ~ ~ ~.? :..oo~.o.~ ~0~ ~ ~ .... ...... , , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. : A°Chor~°e' C°ro~/,~/bn STATE OF ALASKA ALASK'-"..31L AND GAS CONSERVATION C-MMISSION REPORT OF SUNDRY WELL OI-',-:FIATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM 5. Type of Well Development Exploratory Strafigraphic Service 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number/approval number 83-133 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11925 feet 9250 feet Plugs(measured) PBTD Tagged @ 11584' MD (2/5/95) Effective depth: measured 11584 feet true vertical 8951 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1937 # Poleset 81' 81' Surface 2531' 13-3/8" 2000 sx Fondu & 400 sx PFO 2600' 2566' Production 11089' 9-5/8" 500 sx C & 300 sx PFO 11158' 8594' Liner 1071' 7" 415 sx Cl G 11925' 9250' Perforation depth: measured 11523-11533'; 11537-11547'; 11550-11580' true vertical 8899-8907'; 8911-8919'; 8922-8949' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10782' MD; 4-1/2", 12.6#, L-80, PCT @ 10864' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2181' MD; Baker FHL packer @ 10782' MD 13. Stimulation or cement squeeze summary I'lc l V LI.~ 14. Intervals treated(measured) See Attached MAR - 7 ~995 Treatment description including volumes used and final pressure j~[~t$[~, rJii & Gas Cons. Commission Representative Daily Averaqe Production or Iniection Data ~[i~i~. - Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 241 2161 1251 - 271 1374 9872 1791 333 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 ~~~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 r,r,- k'7 ItAII:) SUBMIT IN DUPLICATE 14-34 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/5/95: RIH & tagged PBTD at 11584' MD. 2/7/95: MIRU & PT equipment. Reperforated: 11523- 11533' MD (Z4/3) Ref, Log: BHCS 10/27/83. Used a 3-3/8" carrier & shot 4 spf at 60 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. RIH w/perforating gun & shot 10' of reperforations as follows: Returned the well to production & obtained a valid welltest. ECEIVED & Gas Cons. Co~issjo~ Anchor::,,, GeoQuest 500 w. International Airport Road ATTN- Sherrie 2 J 1995 NO. 9264 Company: 2/22/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 ~J~¢~r~e Field' Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Mylar Disk · '" 79-75- 7G.7o "D.S. 1-25 PATCH SE'I-RNG RECORD 020495 1 1 D.S. 1-22A DUAL BURST TDT-P 020395 I 1 D.S. 11-11. PERF RECORD 020395 I 1 D.S. 9-38 INJEC PROFILE 020495 I 1 D.S. 9-45 DUAL BURSTTDT-P 020595 1 1 D.S. 9-45 RST 020495 I 1 D.S. 9-51 PROD PROFILE 020595 I 1 D.S. 16-4A RST 020295i I 1 D.S. 18-14 ITUBING CuT'rER RECORD 020595 I 1 D.S. 5-26 PROD PROFILE 020695 1 1 D.S. 5-28 PROD PROFILE 020695 I 1 D.S. 6-10 DUAL BURSTTDT-P 020795 I 1 D.S. 9-8 PERF RECORD 020695 1 1 D.S. 11-16 PERF RECORD 020395 1 1 D.S. 14-34 PERF RECORD 020795 1 1 ,,'. SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: STATE OF ALASKA ..,~. ALASK;"-'~ILAND GAS CONSERVATION ( /IMISSION REPOR'i OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate X Other X 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 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number/approval number 83-133 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11925 feet 9250 feet Plugs(measured) PBTD Tagged @ 11580' MD (7/7/94) Effective depth: measured 11580 feet true vertical 8949 feet Junk(measured) Casing Length Size Cemented Conductor 81' 20" 1937 # Poleset Sudace 2531' 13-3/8" 2000 sx Fondu & 400 sx PF O Production 11089' 9-5/8" 500 sx C & 300 sx O Liner 1071' 7" 415 sx CIG Measured depth True vedicaldepth 81' 81' 2600' 2566' 11158' 8594' 11925' 9250' RECEIVED Perforation depth: measured 11537-11547'; 11550-11580' AUG I 5 1994 true vertical 8911-8919'; 8922-8949' Alaska 0il & Gas Cons. C0mrnjs~i0n AnchoraCe Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10782' MD; 4-1/2", 12.6#, L-80, PCT TAIL @ 10864' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2181' MD; Baker FHL packer @ 10782' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) ,See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 847 10047 Subsequent to operation 342 ? 984 2132 1959 Tubing Pressure 1385 250 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 Title Engineering Supervisor Form 10-404 Rev 06/15/88 11 R7/1 ~) ~.~.' 1(7 . IWP SUBMIT IN DUPLICATE 14-34 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GSO & ACID STIMULATION 5/12/94: RIH & tagged PBTD at 11763' MD. 5/24/94: MIRU CTU & PT equipment to 4100 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT & pumped cement to squeeze off the perforation intervals located at: 11523' - 11533' MD (Z4/3) 11537' - 11547' MD (Z3) 11550' - 11564' MD (Z3) 11574' - 11594' MD (Z3) 11630' - 11660' MD (Z2) Ref. Log: BHCS 10~27/83. Pumped 43 bbls of Latex Acid Resistive Cement & attained 3500 psi max squeeze pressure, & held for 1 hour. Placed a total of 8 bbls of cement behind pipe. Contaminated cement & jetted contaminated cement from wellbore down to 11605' MD. POOH w/CT. Rigged down. 5/27/94: RIH & tagged PBTD at 11612' MD. 6/1/94: Reperforated: 11537' - 11547' MD (Z3) 11550' - 11564' MD (Z3) 11574' - 11580' MD (Z3) Ref. Log: BHCS 10/27/83. Added Perforations: 11564' - 11574' MD (Z3) Ref. Log: BHCS 10~27/83. 7/7/94: RIH & tagged bottom fill at 11580' MD. 7/17/94: MIRU & PT equipment. Loaded the wellbore w/1% NH4CI Water, then RIH w/CT mounted Inflatable Packer to inflate & set at 11500' MD. Pumped Stimulation fluids through the open perforation intervals (listed above) located below the packer. Pumped: a) 50 bbls 50% Diesel / 50% Xylene @ 2.6 bpm, followed by b) 50 bbls 12% HCI w/10% Xylene @ 2.3 bpm, followed by c) 25 bbls 9% HCI - 1% HF @ 2.5 bpm, followed by d) 100 bbls 1% NH4CI Water @ 2.6 bpm, followed by e) 10 bbls 1% NH4CI Water spacer, followed by f) 41 bbls 50% Diesel/50% Xylene @ 2.3 bpm, followed by g) 57 bbls 12% HCI w/10% Xylene @ 2.5 bpm, followed by RECEIVED 1 5 1994 AIr~ska 0il & Gas Cons. Commission Anchora~je h) 29 bbls 9% HCI - 1% HF @ 2.5 bpm, followed by i) 145 bbls 1% NH4CI w/5% Musol Water Overflush @ 2.6 bpm, followed by j) Shutdown. Released & POOH w/Packer. Rigged down. Returned the well to production w/lift gas & obtained a valid welltest. Note: - Oil rate decreased by 505 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 755 BOPD, resulting in a net oil benefit of 250 BOPD. Drill Site: 14 Well: 34 K-VALVE DESIGN Wed Jun 22 17:47:54 1994 DOME SET PRESSURE: 170 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 230 PSIG K-VALVE CLASS (A,B,C): A COMMENTS' · Likely have to choke back well during normal operation. Also, rates may go up after k-valve installed. This may cause a redesign to be necessary. CC: ENGINEERING FILE / COORDINATOR~/~IB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) FS3 DS Supervisors PRB 13 (COVER ONLY) WELL TEST DATA GOR GLR LIQ Drill Site: 14 Well: 34 CK LGR FTP OIL %WTR 86 3520 250 129 80.6 1087 5491 666 86 3498 209' 0 99.9 0 5960 612 50 2289 492 0 99.9 0 3457 1108 86 3000 202 100 50.0 5000 17500 200 51 60 49 85 83 83 81 0 1385 0 1274 1016 70.7 12062 3531 3470 0 1535 525 73.9 12468 3250 2014 0 999 1324 72.0 13673 3815 4745 0 994 1311 71.9 14111 3965 4666 0 992 1195 71.3 13445 3847 4176 0 953 1014 74.9 10586 2653 4045 Rydell Reints, ATO 15 (WITHOUT ATTACHMENTS ) S. ~ATE'''OF ALAS~ (COVER ONLY) '~? / .. ,A '~ .% ~'a',.., -'./~ P~ P I SEP~TO~/~ DATE SEL ~ P~S 665 0.23 88 196 06/20/94 Y 0 0.00 68 201 06/19/94 0 0.00 89 206 06/17/94 445 0.00 0 0 06/06/94 847 71.5 11861 3372 2979 2538 0.00 140 863 05/14/94 0 0.00 144 819 04/26/94 0 0.00 131 882 04/03/94 0 0.00 152 912 03/25/94 0 0.00 153 896 03/21/94 0 0.00 151 900 03/14/94 0 0.00 155 904 02/27/94 ESC=EXIT; Fl=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2181 FTP @ CLOSE (PSIG): 230 PRESS ADJUSTMENT: 22 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI WPS C= ..60130e-4 N= 1.000000 ~NEW C= ..92379e-2 ENTERED N= 1.000000 Drill Site: 14 Well: 34 Wed Jun 22 17:28:33 1994 SENSITIVITY TABLE P.I. 0.23 0.23 0.23 0.23 %WTR 81.0 81.0 81.0 81.0 GOR 1087 1087 1087 1087 LGR. 3500 0 1500 2500 FTP 1 530 999 274 1024 1009 FTP 2 230 ~b~ 748 708 704 100 605 (588)/ 579 590 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; Drill Site: 14 Well: 34 Wed Jun 22 17:29:13 1994 K-VALVE DESIGN SSSV DEPTH (MEAS): 2181 FTP @ CLOSE (PSIG): 230 PRESS ADJUSTMENT: 22 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR GLR 86 3520 250 129 80.6 1087 5491 CONDITIONS AT CLOSURE: 86 3520 230 129 80.6 1087 5469 WELL TEST @CLOSE TEMPERATURE @ SSSV: 118 118 PRESSURE @ SSSV: 297 274 LIQ 666 SEP COML PWF PI TEMP PRES DATE SEL 665 0.23 88 0 06/20/94 Y 669 630 0.23 88 0 DOME SET PRESSURE: 170 PRIOR DESIGNS: DATE: 04/19/93 SET PRESSURE: 620 11/17/92 620 05/21/92 710 FTP @ CLOSURE: 150 TEMP: PIPROF 775 PIPROF 900 PIPROF ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..60130e-4 N= 1.000000 NEW C= ..92379e-2 ENTERED N= 1.000000 ARCO Alaska, Inc. Date: June 14, 1994 P.O. Box 100360 '-'"3chorage, AK 99S10,~~ Transmittal#: 94045 '~ ~' Subject: From/Location: Telephone: To/Location- q~ ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Well Number 1-10A I/L~ ! 2-33 I 3-18A i 3-27 "~" ~ I 6-3 ~ f 6-10 .5.~ i 6-16 5.~ ! 6-22A ~,'-~- ! 7-4A 'IV ! 7-6 '~,_"~ ! 7-7A q2 LoP- -CS-{ ':/-'~. i 4-07ST zq, i 4-19 c~.~_llq~ ! 4-46 I(~-(~ ! 5-3A , i Log Date i Tool Type ! ! 06-02-94 i/' USIT 05-22-941 f CNL i 05-19-94 I.~ CCL 05-24-94 i/BAKER IBP REC 05-26-94 1 / PERF REC _ ~ 06-04-94 I/ INJ PROFILE RECEIVED A!~.skr_, OJJ UN 2 0 ~994 & Gas Cons. Commission rage i 05-25-94 l~ USIT i 06-04-94 i-Production Profile i 06-02-94 i~ CCL 06-03-94 1,'"' PERF REC 05-22-94 Y'Patch Settin(j Rec 06-05-94 ~Tul~, lng Puncher 05-22-94 1 .,/' CNL 05-21-94 ~ CNL i 05-21-94 ivProduction Profile i i 05-20-94 ! / Pref Rec J i 05-21-g4 !" CNL f ! 05-24-94 !/' CCL i Run, 1 5" 1 5" 1 5" 511 1 1 5" 15" 1, 1"5" 1,5" 14-3 j06-03-94 I~ PERFREC 14-12 !05-28-94 l/' GRLOG 14-12 I05-28-94 i"Production Profile 14-20 !06-01-94 i~-'/ PERFREC 14-34 f06-01-94 !/ PERF REC 16-13 i05-24-94 !" Baker IBP Rec 06-05-94 1~' Leak Detection 511 1~ 5II 1~ 5II Contractor 1.1"5" SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH 1, 5" SCH 1, 5" SCH SCH 511 ! 5II If 5II i 1, 5" 1, 1"5" ! 05-21-94 iv" Prod Profile i 05-26-g4 iv/- Perf Rec i 05-25-94 i," Bridge Plug i 05-20-94 ~:~mduction Profile 9-50 i 05-20-94 l,'Production Profile~ 11-291 J 05-31-94 t/' CNL f 1 5" 11-291-{05-30-94 ! ~- USIT ( 1 5" 11-291 I 05-31-94 ! ,-" TDT-.¢ I 1, 5" 11-291 ~ 05-30-94 I/ CBT i 1 5" 11-35 1 05-31-94 t ~' USIT J 1 5" 11-35 i 05-31-94 i'"', CBT [ 1 5" 11-36 ! 05-23-94 ! / CBT J 1 5" 1 5" 1 5" 1 5" 1 5" I 5" I 5" 17-12 I 17-19 i 1, 1"2"5" 18-1 i 18-1i 05-26-94 I / PERF REC i 1, 5" 06-04-94 k' Pack Off Gas Lift ! 1, 5" 06-04-94 t/Tubing Puncher i 1, 5" SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH, ~ SCH SCH SCH SCH SCH SCH SCH SCH ARCO Alaska, Inc. I$ a Subsidiary of At/anl]cRIchfleldCompany ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location: P.O. Box 100360, .-~",m, horage, AK Mar 15,' 1994 Transmittal #: 94029 John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 9951°,d~ ~' i WeiI t Log Date Tool Type I Run, Contractor Number (M-D-Y) Scale IR i 01-02 i 2-26-94 Prod/Spin/Tempi_,~ 1, 5" Schlumber [(~ i 01-03I 2-19-94 ProdJ, CBS/Temp~'~ 1, 5" Schlumber ~, ! 01-09 ~ 3-01-94 Tubing Cutter fN> 1, 5" Schlumber ~'~ I 01-11 I 2-27-94 Prod Prof/Spin ! 1, 5" Schlumber, ?--~t ! 01-18 t 2-23-94 Leak Detection ! 1, 1"&5" Schlumber, ~7..--?..b'~I 01-25 I 3-06-94 CNL I 1, 5" Schlumber ~z~-.- L~ j./03-20A ~ 2-17-94 Perf ! 1, 5" Schlumber ~03-20A f 3-03-94 DuaIBurst ~'~' 1, 5" Schlumber ~ ~D"-c ~ 03-32 2-26-94 Leak/PressFFemp 1, 2" Schlumber I.~ l. 03-34A 2-24-94 Prod/Press/Temp 1 , 2"&5" Schlumber .H?.. i 04-01 2-19-94 Prod 1, 5" Schlumber ;30~* i 04-24 2-22-94 Prod ! 1, 5" Schlumber I'~{ ! 04-40 2-22-94 Perf ! 1, 5" Schlumber ~a,"4- i 04-46 2-16-94 Rope Per[ t 1, 5" Schlumber t~ k04'47 2-18-94 v Perf i 1, 5" Schlumber ~ 04-47 '2-15-94 '" CBT-GR ! 1, 5" Schlumber i X,04-47 2-15-94 v CET-GR 1, 5" Schlumber ~0 05-06 2-11-94 Perf 1, 5" Schlumber ~7.. 05-14A 7-11-93 USIT/Cem&Corr (~u3,r'~l, 5" Schlumber cl~- 05-15A 05-15A cC~ GND/GR-t-~~_ 1, 5" Schlumber lt'~ ~ 05-26 3-02-94 Dual Burst 'l'c~' 1, 5" Schlumber ~,?.. [/06-15 2-21-94 Prod 1, 5" Schlumber t\ 06-15 2-22-94 Comp Neutron 1, 5" Schlumber 5'7' 06-22A 3-01-94 Perf 1, 5" Schlumber Iio 07-08 3-02-94 Prod/~ ~ 1, 5" Schlumber Iq~ 07-23 3-07-94 Leak/Spin/Tem~ 1, 5" Schlumber lzf=l 09-34 2-21-94 Tubing Cutter ~ 1, 5" Schlumber ~ 11-02 2-10-94 Inj Pmf/S¢~' ,~l'~, 5" Schlumber ~;) /'11-04 2-20-94 Tubing Cutter r~ 1, 5" Schlumber ~11-04 2-17-94 Tubing {)~tvt~H ~.v.J, 5" Schlumber t-'Jr~ 11-7ST 3-06-94 Inj Pmf/Spin ~l/'~.- 1, 5" Schlumber 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber ~ lOST /Spin/~,C..hb ~ ---I.~ "~111- 3-08-94 Comp/l~fl~table 1, 5" Schlumber 6ST . I Z~co-- ~cl '/4'11-17 .2-20-94 Leak 1, 5" Schlumber ~..11-17 3-08-94 Prod t 1, 5" Schlumber tt% 11-23 8-09-91 TMD I 1, 5" Halliburton ?J~ /11-24A 3-05-94 Perf/GR/CCL I 1, 5" $chlumber ~! 1-24A 2-22-94 Comp/Per[ i 1, 5" Schlumber ;.~co ARCO Alaska, In~. I~ a 8ubMdl~? o! AllanllcRIciffbldComlanY 12-01 j 3-06-94 t Prod i 1, 1"&5" Schlumber 13-10 I 2-24-94t Perf ! 1, 5" Schlumber I 14-2BI 1-16-94i CNL/GR { 1, 2"&5" Schlumber 14-2BI 1-16-94 Sub-Sea ! 1, 1"&2" Schlumber 14-2B i 1-16-94 BI-I~ Acoustiloc.:j l~P.. 1, 2"&5"Schlumber 14-2B i 1-16-94 Dual Laterio~GRl,~ 1, 5" Schlumber 14-2B i 1-19-94 Secj Bond/GR(cC~, 1, 5" Schlumber 14-2B 1-23-94 PFC/GR/CCL ! 1, 5" Schlumber .14-2B 1-23-94 i PFC/Collar I 1, 5" Schlumber 14-24 2-19-94t Lea~,, ! 1, 5" Schlumber 14-28 3-05-94 Leak I 1, 1"&5" Schlumber 14-34 2-15-94 Prod/Press/Tempi 1, 2"&5" Schlumber 16-08 3-07-94 Prod Prof/Spin I 1, 2"&5" Schlumber 17-21 2-24-94 Perf 1, 2"&5" Schlumber PWDW 2-09-94 Water 1, 5" Schlumber ~02-01 Inj/FBS/Templ~- ( Well 4-24 the correct APl # is 50-029-21508-00 Number of Records: E. DeGrey DiStribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ~",!!i~t~'il ~)f"A'laSka ~ Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: . ~//.~ ~/_.~ Date: RECEIVED ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-30-93 REFERENCE: ARCO 1-20~~' ]~(p 4-11-93 --- 1-16 4-13-93 -- aT_. 4-9-93 4-10-93 -- 3-10 4-z-93 --4-Z9 4-8-93 Inthtable mp Setting Run 1, 5" Sch Dual Burst TDTP (Borax) Run 1, 5" Sch Production Run 1, 5" Sch Static Press/Temp Run 1, 5" Sch Perf Record Run 1, 5" Sch Tubing Cutter l~m 1, 5" Atlas Production Run 1, 2'&i~' Sch Static Pressure/Temp Run 1, 5" Sch Perf Record l~m 1, 5" Sch SBL/C~/CCL Run 1, 5" Atlas PFC/CCL (packer Setting) Run 1, 5" Atlas Dual Burst TDTP/Temp (Borax) Run 1, 5" Sch Production Run 1, 5" Sch Dual Burst TDTP (Borax) Run 1, 5" Sch Dual Burst TDTP (Borax) Run 1, 5" Sch Production Run 1, 5" Sch ~m./GR/CCL Run 1, 5" Atlas s~/~c(~ R~n 1, 5" Atlas _sm-/C,a/CC~ mm 1, 5" m~as Please sign and return ~ attached copy a~ receipt of data. ,ECEIVE, . Have A Nice Day! . Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL RE£EIVED MAY 0 6 199~ APPROVED Trans# 9305~-~-'- .... # P~~ PB ~~ ~ R&D ~ BPX g STATE OF ~~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINAL.q 1.7-"/~-!7 2-20-93 3-18-93 2-xx- -2-',a 2-xa-oa a.1--~--78 1-8-93 x-2a-oa ~- ~ ~12 9-19-92 ~ ~ ~5-6 2-13-03 .-a-a~-~3 - 2-15-93 ~~ ~16 3-9-03 2-.-082'2°'°3 11-1~ a-lo-9a 13~~_i~2-14-92 ~_~ 13~3/ ..... 12-14-92 --14-5A 3-19-93 ~14-28 3-2-93 ~-- ~ ~4-28 3-8-92 * ~4~$~t~2-~0-.~ ~-~ ~16-25 -2-26-93 16-26-~- ~2-28-93 ~--~ --16-28 2-28-93 ** 16-29A-~-~-1-93 ~- ~ --17-15 11-16-92 /17-16 1-12-93 Sonya Wallace ATO-1529 Leak Detect Run 1. 5" Perf Record Run 1. 5" Prod Profile Run 1. 5" Prod Profile Run 1.5" PITS Run 1, 5" Prod Profile Run 1, 5" Perf Record Run 1, 5" ~ l~ofilo Run 1, 5" Peri' Record Run 1, 5" Prod Profile Run 1, 5" Collar Log Run 1, 5" Leak Detection Run 1, 2~&5" Prod Profile Run 1, 5" TMD Run 1, 5" Peri' Record Run 1.5" Peri .Record Run 1, 5" ~ Profile Run 1. 5" Peri Record Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Perf Record Run 1. 5" Prod Profile Run 1, 5" Prod Profile Run 1. 5" Prod Profile Run 1. 5" Iai Profile Run 1.5" Temperature Log Run 1. 5" Prod Profile Run 1.5" GR/Collar Run 1, 5" GR/Collar Run 1. 5" Prod Profile Run 1. 5" Tracerscan Run 1.5" Traceracan Log Run 1. 5" PITS Run 1. 5" Baker ~ IBP/Collar Run 1, 5" Baker IBP/Collar Run 1, 5" TMD Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1. 5" Perf Record Run 1. 5" Perf Record Run 1. 5" Ca~lco HLS Camco Camco Camco Camco HLS Camco Camco HL~ Camco Camco HL.q HLS HLS Camco HLS Camco Camco HIS Camco Camco Camco Camco Camco Camco Camco Camco Camco HIS HIS Camco Camco Camco Camco Camco Camco Camco HIS HIS APPROVED_~_ Trans# 93049 CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON MOBIL # PHILIXP~ #BPX # STATE OF ALASKA The correct APl# for 14-34 is 50-029-21010-00. The coorect well name for this lo~ is 16-29A. Drill Site: 14 Well: 34 ~3 -/33 K-VALVE DESIGN Sat Nov 14 13:55:43 1992 DOME SET PRESSURE: 620 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 775 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: CC- Due to problems dumping, the FTP @ closure has been lowered to 775 psi. This is below the CL pressure. To test, put well into LP and stage choke open until the k-valve dumps. (P%~ $~7 ~%% ~{%~ ~~ ~ ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: MMM RECEIVED NOV t 9 1992 &laska Oil & Gas Cons. Commission Anchorage Drill Site: 14 Well: 34 Sat Nov 14 13:46:05 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2181 FTP @ CLOSE (PSIG): 775 PRESS ADJUSTMENT: 274 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 82 0 1035 1728 64.1 6932 2486 4818 2246 3.56 156 0 11/13/92 Y CONDITIONS AT CLOSURE: 82 0 775 2056 64.1 6932 2486 5733 1895 3.56 156 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 175 177 PRESSURE @ SSSV: 1268 993 DOME SET PRESSURE: 620 PRIOR DESIGNS: DATE: 05/21/92 SET PRESSURE: 710 FTP @ CLOSURE: 900 09/07/91 485 750 01/0 /81 0 750 TEMP: PIPROF P I PROF NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..66605e-3 N= 1.016683 NEW C= ..68718e-3 ENTERED N= 1.016683 Drill Site: 14 Well: 34 SENSITIVITY TABLE Sat Nov 14 13:51:53 1992 P.I. 3.56 3.56 3.56 3.56 %WTR 64.0 64.0 75.0 75.0 GOR 6950 8000 6950 8000 LGR 0 0 0 0 FTP 1 1035 1268 1261 1299 1285 FTP 2 775 993 993 1009 1001 FTP 3 0 0 0 0 0 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fi=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; Drill Site: IA Well: 3~ ~$-133 K-VALVE DESIGN Mon Nov 09 00:A5:09 1992 DOME SET PRESSURE: 700 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 900 PSIG K-VALVE CLASS (A,B,C): A WELL HAS BEEN DUMPING AT 1000-1050 FTP. WELL CONDITIO~ HAVE CHAN~ SLIC4~fLY. PLEASE HAVE K-VALVE BENCH TESTED. WELL IS PINCHED BACK TO AVOID K-VALVE DUMPS. FrCOORD/ENG. WELL FILE (W/ATT) J. C. SMART/M. G. SHOEMAKE (W/O ATT) J. E. FAUSE"I-r/c. W. SHUMWAY (COVER) PRB24 PRB 2O PRB 13 T. L. RUT (W/O ATT) ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: R. T. BURNO RECEIVED NOV 1 7 1992 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASK,-~---''''' AND GAS CONSERVATION C~-"MISSION 0 1~ I 6 I N REPORTuF SUNDRY WELL OP,*-RATIONS 1. Operations performed: Operation shutdown Plugging ~ Perforate ~ Pull tubing ~ Alter casing ~ Repair well OIJ'mr 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X Expk~ra~/ Stratigraphic 4. Location of well at surface 196' FNL, 1243' FEL Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM RE( EIVED N 0V - 6 1992 Alaska 0il & (~as 00ns, G0rnmisst0~ Anchorage 6. Datum of elevation(DF or KB) 69' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number/approval number 83-133 10. APl numbe.~b 50 - 029-~!1010 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11925 feet Plugs(measured) 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1937# Poleset 81' 81' Sudace 2531' 13-3/8" 2000 sx Fondu & 400 sx PF'O' 2600' 2566' Production 11089' 9-5/8" 500 sx C & 300 sx '0' 11158' 8594' Liner 1071' 7" 415 sx Cl 'G' 11925' 9250' Perforation depth: measured 11523-11533', 11537-11547', 11550-11564', 11574-11594', 11630-11660' true vertical 8899-8907', 8911-8919', 8922-8934', 8943-8961', 8992-9018' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @10782'MD; 4-1/2",12.6#, L-80, PCT tail @ 10864'MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2181'MD; Baker FHL packer @ 10782'MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1921 16097 3000 1299 Subsequent to operation 2375 ~ 19469 3351 1295 Tubing Pressure 1031 1046 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 ~ ~' ~ Title Senior Area Engineer Form 10-404 Rev 06/15/88 f/ Date ///~//~ ~-- SUBMIT IN DUPLICATE SUMMARY OF WELL OPERATIONS ARCO Alaska, Inc. perforated DS 14-34 over a selected interval in Zone 3 of the Prudhoe Bay Unit on 4/18/92 (11550'-11564'MD Ref Log: BHCS 10/27/83). Produced fluids were in the wellbore at the time of perforating. A short summary of the work is given below. - Began perforating operation on 4/18/92. - RU perforating unit and pressure tested equipment to 3500 psi. - RIH w/gun #1, tied-in, and shot #1' 11550'-11564'MD @ 4 spf - POOH. All shots fired. - Secured well. RD. TLR 9/29/92 R ( EIVED Nov - 6 1992 Alaska Oil & Gas Cons. CorrlmissJo~ Anchorage ARCO ,~ls.~ka, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-18-92 REFERENCE: ARCO CASED HOLE FINALS ?? 14-18 4-29 ~4 18-3 6-4-92 Peri' Record R~n 1j, 5" 5-8-92 Peri Record R~n 1, 5" 5-29-92 Peri Record Run 1, 5" 6-12-92 Peri Record R~ 1, 5" 7-2-92 Peri Record Run 1, 5" 6-9-92 Peri Record Run 1, 5" 6-9-92 Peri Record R~n 1, 5" 4-18-92 Peri Record R~n 1, 5" 7-3-92 Peri Record R~n 1, 5" --,,...l.. R'E C E IV E D Sonya Wallace T 0 5 199l APPROVED ATO-1529 0C ~s~ 9220~-- Alaska 0il & Gas Cons. Commission Anchorage # CENTRAL FILF~ # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ~io~9e W~i~h last ~eSi~h %ess ~n 75% Of design. c~en~ ~0~e is 200+ psi ~ - .......... 2';£-i- - - Wt~it f_O~ message t~ ~iear RECEIVED MAY 1 1 1992. Alaska 0il & Bas Cons. Commission Anchorage Drill Site: 14 Well: 34 K-VALVE DESigN Wed Mar I8 I7:47:35 I992 DOME S~I' PRESSURE: 610 PSIG @ 60 DEG F FT~ @ C~OSE ('PSZ~)': 7'50 PSZ~' K-VALVE CLASS' (A,S',C)': A COMMENTS: Update K-Valve design. Test by producing into LP production cc: c. ~. F~ / W.D. COO~aa~ J.C. SMART / M.G. iHOENAKE J.E. FAUSETT / C.W. S~AY FR~ 24 FR~ 2O PI%~ 13 m.t. SACAK S~A~ OF DESIGNED Printing contents of current screen - wait for message to clear RECEIVED APR O 1 1992 Alaska 011 & Gas Cons. Commi~sion Anchorage Drill Site: 14 Well: 34 Wed Mar 18 17:39:41 I992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2181 FTP @ CI, OSE (PSIG): 750 PRESS ADJUSTMENT: 332 TEMP CORRELATION: PIPROF NOTE: LINEAR CURR USES SEP TEMP, FI FROF USES BH TEMP AND WELL FI CONDITIONS OF WELL TEST: CK LG~R FTP OIL %WTR ~UR G~ LIQ FWF 75 0. I0g0 1943 59.2 8580 3498 4764 2182 3.36 154 CONDITIONS AT CLOSURE: 75 0 750 2446 59.2 8580 3498 5999 1829 3.36 154 WELL TEST @CLOSE TEMPEI~TUI~ @ SSSV: 17'4 177 SEP COML DATE o o31o319 610 T]~: PIPROF NA NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SEN$ITIVITY TABLE; F6=CHECKLIST; FI0=ACCEPT; SFS=RESTURE WELL TEST; CFg=CYCLE DATA; Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 34 Wed Mar I8 17:43:03 1992 SENSITIVITY TABLE P.I. 3.36 3.36 3.36 3.36 %WTR 59.2 59.2 65.0 65.0 C~R 8580 ', 9500 8580 9500 LGR 0 0 0 0 FTP 1 I090 1309 I308 1314 131I FTP2 750 976 982 971 974 FTC3 500 760 772 745 755 ~'l'~:R VALUES FUR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT ~A$ KATE, AND FLfIWING TUBIN~ PRESSURE I, 2, or 3. PRESSURES AT THE SSSVWILL BE CALCULATED FOR EACH GROUP OF ITEMS ESC=EXIT; FI--HELP; F2--WELL TESTS; F3=DESIGN; F4=DISTRISUTION LIST; F6=CHECKLIST; FI0--ACCEPT; Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 34 K-VALVE DESIGN Sun Aug 11 14:11:45 1991 DOME SET PRESSURE: 485 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 750 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: New K-Valve well. First design. CC: C.P. FARMER / W.D. COOPE~-a' K.M. KENNEDY / L.D. LASH J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 M.O. JOHNSON ATO 1552 STATE OF ALASKA (COVER) DESIGNED BY: Matt Maguire Printing contents of current screen - wait for message to clear -~e: 14 Well: 34 Sun A~ K-VALVE DESIGN DOME SET PRESSURE: 485 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 750 PSIG K-VALVE CLASS (A,B,C): A New K-Valve well. First design. FARMER / W.D. COOPER-~ KENNEDY / L.D. LASH FAUSETT / C.W. SHUMWAY .~EERING WELL FILE PRB 24 PRB 20 PRB 13 M.O. JOHNSON STATE OF ALA~ DESIGNED BY: uontents.of current screen - wait for message to c[ AL~-..~-~-A OIL AND GAS CO b -RVATIO~ ,,MMISSION REPO . OF SUNDRY WELL L,. ERATIONS 1. Operations performed: Operation shutdown -- .---. Plugging ---. Perforate X · Pull tubing ---. Alter casing -.- Repair weft -~. Othe~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510~360 4. Location of well at surface 196' FNL, 1243' FEL Sec, 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM Type of Well Explorat~7 Stm~r~phic 6. Datum of elevation(DF or KB) 69' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 g. Permit number/approval number 83-133 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11925 feet Plugs(measured) true vertical 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Conductor 81' 20" 1937# Poleset Sudace 2531' 13-3/8" 2000 sx Fondu & 400 sx PF'0' Production 11089' 9-5/8" 500 sx C & 300 sx '0' Liner 1071' 7" 415 sx Cl 'G' Measureddepth True vedlcaldepth 81' 81' 2600' 2566' 11158' 8594' 11925' 9250' Perforation depth: measured 11523-11533', 11537-11547', 11574-11594', 11630-11660' true vertical 8899-8907', 8911-8919', 8943-8961', 8992-9018' Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80, PCT @10782'MD; 4-1/2",12.6~, L-80, PCT tail @ 10864'MD Packers and SSSV (type and measured deplh) Camco BaI-O SSSV @ 2181'MD; Baker FHL packer @ 10782'MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation 14. RECEIVED JAN 1991 Reoresentative Da[~ Average Production or Injection 'O'~t-.~ ..... Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1630 12423 688 -- 1353 2048 13619 814 --- 1372 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. Sic~ned Form 10-404 Rev 06/15/88 Senior Area Engineer Date ///'/~,,/~, ~ SUBMIT IN DUPLICATE DS 14-34 SADLEROCHIT ZONE 3 ADD PERF PROCEDURE REPORT OF WELL OPERATIONS PROCEDURE: WORK PERFORMED ON 10/10/90 1. RIG UP E/L AND TEST LUBRICATOR 2. RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS . PERFORATE ZONE 3 INTERVAL 11574'-11594' MD (BHCS 10/27/83) TO ATTAIN 4 SPF WITH RUNS AS REQUIRED. POOH. 4. RD AND RELEASE E/L. 5. RETURN WELL TO PRODUCTION STATUS RECEIVED JAN ~ 1991 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ~.-~, ~ ~' '~'~ I ~ AL/''''''' )IL AND GAS CONSERVATI(. ~ '"~MISSION REPOn i OF SUNDRY WELL O i RATIONS 1 .' Operations performed: Operation shutdown Pull tubing Alter casing Plugging Perforate X. Repair well Olher 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FNL, 1243' FEL Sec, 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM 12. Present well condition summary 5. Type of Well Development Exploratory Strafigraphic 6. Datum of elevation(DF or KB) 69' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number/approval number 83-133 10, APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured~ ~/~t~l~ ~'''0 Total depth: measured 11925 feet true vertical 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Casing Length Size Conductor 81' 20" Su dace 2531' 13-3/8" Production 11089' 9-5/8" Liner 1071' 7" Junk(measured) Cemented ,~1~1~.~.__ .0~. J~~red depth True vertical depth 1937# Poleset 81' 81' 2000 sx Fondu & 400 sx PF'0' 500 sx C & 300 sx '0' 2600' 2566' 11158' 8594' 415 sx Cl 'G' 11925' 9250' Perforation depth: measured 11523-11533', 11537-11547', 11574-11594', 11630-11660' true vertical 8899-8907', 8911-8919', 8943-8961', 8992-9018' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @10782'MD; 4-1/2",12.6~, L-80, PCT tail @ 10864'MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2181'MD; Baker FHL packer @ 10782'MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1630 12423 688 2048 13619 814 Tubing Pressure 1353 1372 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 Form 10-404 Rev 06/15/88 Title Senior Area Engineer Date SUBMIT IN DUPLICATE feet DS 14-34 SADLEROCHIT ZONE 3 ADD PERF PROCEDURE REPORT OF WELL OPERATIONS PROCEDURE' WORK PERFORMED ON 10/10/90 I . . . RIG UP E/L AND TEST LUBRICATOR RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS PERFORATE ZONE 3 INTERVAL 11574'-11594' MD (BHCS 10/27/83) TO ATTAIN 4 SPF WITH RUNS AS REQUIRED. POOH, 4. RD AND RELEASE ElL. 5. RETURN WELL TO PRODUCTION STATUS RECEIVED NOV 2 1 1990 ,O j! ~ Gas Cons. G~.m~lg~ ARCO ALASKA, F'.O. BOX ANCHORAGE, ALASKA 995i 0 DATE' i0-t9-90 REFERENCE' ARCO CASED HOLE FINALS t -5 9-9-90 PERF' 2-4 8-t6-90 F'ERF RECORD 3-25 t O-~ i-90 COLLAR/PERF 5-5 9-4-90 F'ERF RECORD 9-44 ~ ~-t 0-90 COLLAR .. ~ ~-22 9-7-90 PERF J 2-8B J 0-7-90 COLLAR/F'ERF ~4-34 ~0-~0-90 F'ERF RECORD ~ 5-6 ~ 0-4-9~ CCL i 5-6 J 0-4 2-90 VER'i'ILOG ~5-~ ~0-i¢,-9~ PERF RECORD i 8-i 4 t ¢,-4-90 COLLAR/F'ERF i8-i4 i0-4-90 F'RODUCTION F'ACKER RUN t , 5' F:UN ~, 5' RUN t , 5' RUN t , 5' RUN i, 5' RUN t, 5' RUN t, _,~' RUN t , 5' RUN i, 5' RUN i , 5 ~ RUN i, 5' RUN J, 5' RUN i, 5' F'LEA3~E 3'IGN AND RETURN THE ATTACHED HAVE A N.i '~'AL. LY HOFF~CI,'ER ~-. ~.,.- I .. TO-- i 529 COPY AS RECEIPT OF DATA A F' F'~ ~ V E.[_.~ ~ TRAN~,~ HL$ HL$ Al'LA3~ I-ILS ATLAS HL3,' A'FLAS' $CH ATLAS' ATLAS 5'CH ATLA3' A'FLA$ DISTRIBUTION ~ CENTRAL FILE£ ~,- CHEVRON D & M ~ EXTENSION EXPLORATION · .-'"' EXXON HARAI'HON - MOB :[ L .- RECEIVED · .- F'H :[ LL I F' 'Z F'B WELL F'IL .E(~T 2 ~ 1990 R & D ~- B R X Alaska Oil & Gas Cons. Commission · $ $ T ATE 0 F A L A '~'""K'"~ch°rage I'EXACO THE AF'I~: FOR ,3-25 I3' 5,:-}-029-2t02i O~ THE CORRECTED WELL NUMBER FOR THIS L CORRECT AS 2-8. '¥HE AF'I~ 13' STATE OF ALASKA .---. ~';~ ~ '~ ~''' ~ '~'' ALASK,~-~'-'''_ AND GAS CONSERVATION Cf vllSSION APPLICA, ION FOR SUNDRY APPROVALS 1. Type ef Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing Re-enter suspended well Time extension Stimulate Vadance Perforate 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 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM Other X 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number 83-133 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11925 feet Plugs(measured) 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1937# Poleset 81' 81' Surface 2531' 13-3/8" 2000 sx Fondu & 400 sx PF'0' 2600' 2566' Production 11089' 9-5/8" 500 sx C & 300 sx '0' 11158' 8594' Liner 1071' 7" 415 sx CI 'G' 11925' 9250' Perforation depth: measured 11523-11533'; 11537-11547'; 11630-11660' true vertical 8899-8907'; 8911-8919'; 8992-9018' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 10782' MD; 4-1/2", 12.6#, L-80, PCTtail @ 10864' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2181' MD; Baker FHL packer @ 10782' MD 13. Attachments Description summary of proposal ~ Detailed operations program BOP sketch x 14. Estimated date for commencing operation I September 1990 16. If proposal was verbally approved Oil x Gas Name of al)prover Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 15. Status of well classification as: Suspended Signed Title Date FOR E:OMMI~ION H~I= ONLY Conditions of approval: Notify Commission so representative may witness I Approva, No. Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAl. SIGNED BY i nMM!r' I" qR~ITH ~..v, 11 · ............ SUBMIT IN TRIPLICATE 474 RFK c._' J_ C~n]her. ATO-1478 SH Well 14-34 Foamable Surfactant Gas Shut-off Treatment Preliminary Procedure Objective: Place foamable surfactant into leaking Zone 4 squeeze perfs above existing Zone 2 and Zone 3 producing perforations to lower the well's GOR. 1. Set a coiled tubing or wireline bridge plug between perforations and leaking squeeze perforations. . Pump a small slug of (depending on injectivity of the well) of .5% surfactant solution (100-200 bbls) using coiled tubing or surface pump truck. Depending on injectivity, pump behind the liquid slug pre-foamed surfactant of varying quality using up to approximately 3 MMSCF/D of nitrogen gas. 3. Pull bridge plug and put well back on production. 4. Monitor well's gas production with well tests and production profiles. Other well information: Current status: SI due to high GOR. Expected static bottomhole pressure: 3670 psi at 8800' SS Expected fluid in wellbore at reperforation: seawater. 6 5 4 3 2 COIL£D TtJBIN~ UNIT BOP EOU 1 PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR IrLANO£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAJAS 5. ~X)0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX J HIRE'LINE BOP EOUIPMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WlRELINE RAUS (VARIABLE SIZE) .1. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF STATE OF ALASKA ALASK, '_ AND GAS CONSERVATION C ~IISSION REPORT SUNDRY WELL OPrRATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM 5. Type of Well Development Exploratory Strat~graphic Service 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number/approval number 83-133/9-1020 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11925 feet Plugs(measured) true vertical 9250 feet Effective depth: measured 11885 feet ~ true vertical 9215 feet Junk(measured) I Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1937# Poleset 81' 81' Surface 2531' 13-3/8" 2000 sx Fondu & 400 sx PF '0' 2600' 2566' Production 11089' 9-5/8" 500 sx C & 300 sx '0' 11158' 8594' Liner 1071' 7" 415 sx CI 'G' 11925' 9250' Perforation depth: measured 11523-11533'; 11537-11547'; 11630-11660' true vertical 8899-8907'; 8911-8919'; 8991-9017' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10782' MD; 4-1/2", 12.6~, L-80, PCT tail @ 10864' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2181' MD; Baker FHL packer @ 10782' MD I~ rrrl~rr~ 13. Stimulation or cement squeeze summary J~ r,, c [~ i V C ~ 14. Intervals treated(measured) See attached AUG 0 8 ]990 Treatment description including volumes used and final pressure -~a~_ .0jJ & Gas Coils. Representative Daily Average Production or In!ection Data ' : ~l~l{;~101'ag~t Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl 1320 13524 278 2834 11417 618 Casing Pressure Tubing Pressure -- 2057 1182 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 Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE zt4q RF:I4 ~.n' .I ~nlh~.r ATC)-147R RH DS 14-34 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 12/6/89 : MIRU CTU & Stimulation Equipment. PT equipment to 4500 psi. RIH w/CT & pumped 270 bbls of Crude into wellbore. Washed perforations at: 11630 - 11660' MD Ref. Log: BHCS 10/27/83. Pumped the following treatment: 27 bbls 12% HCI w/10% Xylene, followed by, 50 bbls 12-3% HCI-HF, followed by 49 bbls 12% HC1. Flushed w/8 bbls Diesel. POOH. Rigged down. 12/9/89 : A CTU Squeeze was performed as follows : MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/573 bbls of seawater. Pumped 32 bbls of cement, squeezing perforations at: 11630 - 11660' MD Ref. Log: BHCS 10/27/83. Placed 7 bbls of cement behind pipe at 2200 psi maximum squeeze pressure. Contaminated cement and jetted out contaminated cement from wellbore. RD. 12/18/89 : Conducted welltest that indicated the squeeze broke down. 4/8/90 - 4/9/90 : A CTU Acid Wash and a Cement Resqueeze were performed as follows: MIRU & RIH w/CT. Loaded wellbore w/seawater. Washed squeezed perforations at: 11630 - 11660' MD Ref. Log: BHCS 10/27/83. Pumped the following treatment: 47 bbls 12% HCI w/10% Xylene, followed by, 60 bbls 12-3% HCI-HF, followed by 24 bbls 6% HCI, followed by 24 bbls 2% NH4C1. Mixed cement. Pumped 30 bbls of 'G' & 20 bbls of expansive cement, to resqueeze perforations at: 11630 - 11660' MD Ref. Log: BHCS 10/27/83. Placed 5 bbls of cement behind pipe at 3000 psi maximum squeeze pressure. Contaminated w/Biozan & cleaned out contaminated cement from WB. RD. 4/14/90 : Reperforated: 11630 - 11660' MD Ref. Log: BHCS 10/27/83. Added perforations: 11523 - 11533'MD 11537 - 11547'MD Ref. LOg: BHCS 10/27/83. Returned well to production and obtained a valid welltest. ' ARCO ALAS'KA., 1'NC.. F', 0, BOX -i ,'.--_',¢.--:,'56,:;, ANCHOR. AGE, AL.A£'KA DATE · '7 -..-5 ,.'::, - 9 £~ 995i;3 u/i 4.~s Cons ,-," '~nc,'~orage' ~'°mmi~sion F;:!EFEF.'.ENCE- ARCO CA£'ED HOLE F'ii'-.!AL!: 3---:5i 7-i 6-..-9,:-'~ F'i._UiD F.'.E,~:I:"-'-:"f'iV!TY ":-" ~ %.". -"t "~ ,:~ .~,::. ,"-i8-9;3 FLUID RE:::-:.[S'i-iVIl-'f "~ '- i '7- 2 '~ -'::-'":~ F'ERF Rii:CORD 9.-- i '"...-:' 7-- i F.~---9;.::, F'F'F:F RFSL':ORD 9 .- 4 i 7 .... i 5". .... 9'.D C: B 'f' ? --4 i 7-i 5-96, CIE";-"' 9-4i ?-!5-9,:D C-R IN CAZING i 4 - ~ 7-"---',-'-;----":;'"'-; F'FF;..'F RE~'"~i.~:'D , i ,~.-~ : '.,- ---- -- i -. i ~-2A-, '7 - '---' r; .-. 9 ;:",._ ._. .. COLLAP/r:'-~:',.q:I=,, : ~.,., i2'-i(is 7 .... i ,' 9,:'-} F'L~ T ....... -.' '"'-' U.,.n R~::_'?i:.?T'rVI ~ 'r' i-,a .... :7.-: 4 '7, - .~, '5, "- ':;', ;:;._. F:_ 14 R E ~ I S T .,_.'r: ,, i T Y · ~ 8 -- "z ,-', -' i -':':'- -- '::;: "";; ... , - ..... , ,' - . , ,, F-' LI I I D R E .'".," i ~-: T i "-';/i T Y ! ':';'- i ,i 7-i 9-96' COLLAR/F'Ei'?F i15-i ¥ '7--i 9--':?¢ COLLAR/PERF F' L i-'.:.A $ E SIGN Rii:CEiVED BY HAVE A NiCE AND RETURN THE A'FTACHED DAY ! K c R COPY A~..~ RECI:"IF'T OF' DR'FA~ T R A N S :.": ,ii.' (..' S' C H $ C i-.i ,::.'..] H ,~i: (::: i..i ,!-;.' C ?:,' C .,'::',,"Fi_A.? A f'LAZ S' C H $ C H £CF! ATi_AS' ATLAS D IS'TRIBU"FION · ,-~'CENTRAL FILES .,-~' PFIILLIF'S.: "",~ CHFVRON F'B WELL F']:L_E~/ D & ~'4 ~:;' * D it. L':' ~...' T f." ?.. i ¢ -,,. :..A, t,~..--'[ON. EXPLORATION -,. BPX HARATHON TEXACO · ~,~ MOBIL 'f'H':,: COF.'.RECTEi.'., AI::'i:$ FOR i4-34 ]:Z 5,:-)-,::)29-'2i,::.:,iF;,, ARCO ALASKA, INC. F'.O. BOX i0~S60 ANCHORAGE, ALASKA -995i0 DATE' 4-24-90 REFERENCE' ARCO CASED HOLE FINALS 5-4 4-t 5-90 COLLAR/F'ERF RUN t, 5' 7-i 0 4-9-90 CCL/F'ERF RUN t S-26 4-t 2-90 COt_LAR/F'ERF RUN t4-t5 4-tt-90 COLLAR/PERF RUN t, 5' i4-t7 4-t5-90 COLLAR RUN t 4-:34 4-i 4-96, COLI_AR/PERF RUN WGI-7 4-8-90 GR/CCL RUN WGI-7 4-8-~(-}, CBT RUN t, .,~' WGI-7 4-8-90 CET RUN PLEASE SIGN AND RETURN 'THE ATTACHED COF'Y A£ RECEIPT OF DATA. RECEIVED BY __'____~ HAVE A NICE DAY! SALLY HOF'FECKER ~ ~'~~F'F'R, ~.. OVED ~ ATLA~' ATLAS A'FL.A,',... ATLAS ATLAS ^ .~ ~,TI_A~ SCH 2'CI-.I DISTRIBUTION. CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO ARCO Alaska, Inc. Prudhoe Bay ~ =lineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 6, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-34, Permit No. 83-133 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/REK/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 14-34)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany AR3E~--6132-C .. 1. T'~/pe of Request: STATE OF ALASKA ALASK,~' ~'"',. AND GAS CONSERVATION C( AISSION n p APPLICA, ,ON FOR SUNDRY A[-, ROVA[.S l§lh/Al. Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Change approved program Pull tubing Variance Perforate Stimulate Other X -- 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number 83-133 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11925 feet Plugs(measured) 9250 feet Effective depth: measured true vertical Casing Length Conductor 81' Sudace 2531' Production 11089' Liner 1071' Perforation depth: 11885 feet 9215 feet Junk(measured) Size Cemented 20" 1937# Poleset 13-3/8" 2000 sx Fondu & 400 sx PF'0' 9-5/8" 500 sx C & 300 sx '0' 7" 415 sx CI 'G' measured 11630-11660' true vertical 8992-9018' Measured depth True vertical depth 81' 81' 2600' 2566' 11158' 8594' RI IV .D ,.,o,",., ,,,' 1989 Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10782' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10864' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2181' MD; Baker FHL packer @ 10782' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation November 1989 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby,~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~~. ~~~ Title 15. Status of well classification as: Gas Suspended Operations Engineering Manager Date FOR COMMISSION H~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- ORIGINAL SIGNED BY LOJ~NIE C. SMITH JApproval No. '~'" / p, ett~ ~ ~ Co,~ Date SUBMIT IN TRIPLICATE Well 14-34 Coiled Tubing Unit Cement Squeeze Project AFE #APl l07 Subcomponent AFE #KSl176 Preliminary Procedure Objective: Perform a CTU cement squeeze to eliminate excess gas production from leaking squeeze perforations. 1. Surge the well with a 2000 psi surge disk. Test well. 2. Perform a full strength mud acid perforation wash. Perform a fill cleanout if necessary. Flow the well to produce out the acid. Test well. 3. RIH with CT. Pack the well with filtered seawater. 4. Pump 31 bbls of cement followed by 2 bbls of fresh water and 35 bbls of bentonite mud. Squeeze off the following perforations: Zone Present Interval Shot Density 4 11408-11418 4 11422-11452 4 11460-11480 2 11630-11660 CTU Squeezed, Leaking CTU Squeezed, Leaking CTU Squeezed, Leaking 4 SPF 5. Immediately jet or reverse out the diluted cement. 6. Reperforate the following intervals one week later: Zon~ Present Interval Shot Density 3 11523-11533 FSD 3 11537-11547 FSD 2 11630-11660 FSD 7. Bring the well back on production. Other well information: Current status: Shut-in due to high GOR Expected static bottomhole pressure: 3670 psi at 8800' SS Expected fluid in wellbore at reperforation: seawater. RECEIVED Anchorago 6 5 4 2 COILED TUBINg UNI? BOP E0U l P~E U7 t. 50C)0 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI4 1/16" STUFFING BOX 2 NIRELINE BOP EOUIPMEN7 _ 1. 5000 PSI ?" WELLHEAD CONN£CIOR fLANGE 2. 5000 PSI WlRELIN[ RAMS (VARIABLE SIZ£) · 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC~ F'.O. BOX iOOS60 ANCHORAGE, ALASKA 995 i O DATE' -9-t8-89 REFERENCE' ARCO CASED HOLE FINALS t-? 8-2S-89 F'RODUCTION PROFILE 2-4 9-2-89 LEAK DETECTION SURVEY 2-i9 8-24-89 PITS S-t6 8-25-89 INJECTION PROFILE 4-5 8-30-89 STATIC TEMF' SLJRVEY 4-i9 8-29-89 STATIC '¥EMP SURVEY 4-i9 8-S~-89 TEMP FM 6-t4 9-i~-89 COLLAR 7-i~ 8-Si-89 LEAK DETECTION SURVEY i°-°t~ ~ 8-S0-89 TEMP SURVEY iS-22 8-Si-89 INJECTION F'ROFILE t4-20 8-S~-89 PRODUCTION PROFILE i4-24 8-Si-89 PRODUCTION PROFILE t4-34 8-S~-89 PRODUCTION PROFILE i6-4 8-i3-89 LEAK DETECTION i7--7 5-i9-89 LEAK DETECTION i?-ii 5-t9-89 LEAK DETECTION RUN i, 5' RUN i, 2' RUN t, i"&5" RUN i.. 5' RUN i, RUN i, '2'&5' RUN i, RUN t, RUN t , ':2"&5" RUN t, 5 RUN i, 5' RUN t, RUN t, RUN ~, 5" RUN ~, RUN~ i 3, RUNS ~-3, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ CAMCO CAMCO CAMCO CAMCO CAMCO C A M C 0 C A M C 0 A FL. AS CAMCO HR$ CAMCO CAMCO CAMCO CAMCO CAMCO OTIS OTIS RECEIVED BY HAVE A NICE DAY! SALLY HOF'FECKER AT0-i529 CENTRAL FILE~ CHEYRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL F'ILES R & D BPX STATE OF ALA.S'KA TEXACO ARCO Alaska, Inc. Prudhoe Bay ,_ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-34, Approval No.9-561 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 14-34) W1-3 Rf C I¥I I) JUL 2 8 t989 .Alaska Oil & Gas Cons. C0mrnissl0n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKi"-~"'L AND GAS CONSERVATION C '~'"'MISSION REPORT SUNDRY WELL OP .RATIONS 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 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, 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 14-34 9. Permit number/approval number 83-133/9-561 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11925 feet Plugs(measured) 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1937# Poleset 81' 81' Surface 2531' 13-3/8" 2000 sx Fondu & 400 sx PF 'O' 2600' 2566' Production 11089' 9-5/8" 500 sx C & 300 sx 'O' 11158' 8594' Liner 1071' 7" 415 sx R E C ~IV ~ P 11925' 9250' Perforation depth: measured 11630-11660' ~[~{_ 2 ~ ~0o~'~ ¢,,J~.sk8 0ii & Gas Cons. Commission true vertical 8992-9018' Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10782' MD; 4-1/2", 12.6~, L-80, PCT tail @ 10864' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2181' MD; Baker FHL packer @ 10782' 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 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 934 3441 503 -- 215 3064 23781 524 -- 1269 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 -'~~,~_~-'~ ,~,,_ ~-~..J'-~.,~u~- Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Drill Site 14-34 Description of Work Performed TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: July 14, 1989 1. Obtained a valid well test. . . EDTA Perforation Perforation Breakdown Treatment To Stimulate Zone 2 11630-11660' MD (Ref. DIL 10/27/83) MIRU wireline unit. Tagged bottom at 11831' MD. Changed out the orifice from station #1 with an Otis RP circulating valve set at 2500 psig differential. Loaded the 5-1/2 x 9-5/8" annulus with dead crude/diesel to surface. Pressure tested annulus to 2500 psi to ensure no communication exists. Loaded 5000 gals of filtered fresh water (150 °F minimum) for blending the Na2EDTA. Added the following ingredients for mixing the Na2EDTA. 30-36 Ibs/bbl of Na2EDTA (approximately 4000 lbs) 2 gals/1000 gals of F75N, NE-18 or Losurf 300 (surfactant) 1 gal/1000 gals of A186, CI-9 or MSA (organic inhibitor) 4. Loaded 500 gals of xylene, 80 bbls of slick diesel and 270 bbls of dead crude. . MIRU pump trucks and transports. Ensured that' 2000 psi is placed on the 5-1/2 x 9-5/8" annulus. 6. Rolled all acid compartments on location before pumping fluids downhole. 7. Pumped the following fluids down the 5-1/2" tubing: A. 2 8 bbls Slick diesel to establish treating rate and pressure B. 340 gals Xylene C. 4700 gals Na2EDTA w/additives and 250 ball sealers, 1.1 SG and 0.625" diameter D. 4 7 bbls Slick Diesel E. 2 7 3 bbls Dead Crude 8. Immediately following treatment, monitored pressures for 15 minutes. . Sheared the RP valve in the top station by placing 2800 psi differential pressure. Unloaded the well. 1 0. After all stimulation fluids have been recovered, obtained a valid well test. ARCO Alaska, Inc. Prudhoe Bay _,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 18, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-34 Approval No. 8-273 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/CMH/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 14-34) W1-3 REC .'!VED JUL 2 41989 41aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK,~""tL AND GAS CONSERVATION CC-'~MISSION REPORT ,JF SUNDRY WELL OP _RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 20, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-34 9. Permit number/approval number 83-133/8-273 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11925 feet Plugs(measured) 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 81' 20" 1937# Poleset 81' Sudace 2600' 13-3/8" 2000 sx Fondu & 400 sx PF 'O' 2600' Production 11089' 9-5/8" 500 sx 'C' & 300 sx PF 'O' 11158' Liner 1071' 7" 415 sx 'G' 11925' True vertical depth 81' 2566' 8594' 9250' Perforation depth: measured 11630-11660' true vertical 8991-9017' RECEIVED Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 plastic-coated tubing @ 10782' MD Alaska Oil & Gas Cons. C0mrnis,< Anchorage Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2181' MD; Baker FHL packer @ 10782' 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 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2171 16909 390 -- 1107 567 311 Tubing Pressure 1932 245 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x..z_ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~'J//~~)~ Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 100 C. M. Hightower, 263-4713 SUBMIT IN DUPLICATE DS 14-34 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 5123188: M1RU CTU & Stimulation Equipment. PT Equipment to 4000 psi. RIH w/CT and washed perforations at: 11460 - 11480' MD Ref, Log: BHCS 10/27/83. 11630 - 11660' MD Pumped the following treatment: 48 bbls 12% HC1 w/Xylene, followed by, 48 bbls 12-3% HC1-HF, followed by 47 bbls 12% HCI w/Musol. Displaced w/Crude. POH. Rigged down. 5/27188: MIRU CTU & Stimulation Equipment. PT Equipment to 4100 psi. RIH w/CT and washed top set of perforations at: 11460 - 11480' MD Ref. Log: BHCS 10/27/83 Pumped the following treatment: 47.5 bbls 12% HCI w/25% Xylene, followed by, 47 bbls 12-3% HCI-HF, followed by, 47 bbls 12% HCI, followed by, Displaced w/Meth-Water. POH. Rigged down. 5129188: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 32 bbls cement, squeezing perforations: 11460 - 11480' MD Ref. Log: BHCS 10/27/83. 11630 - 11660' MD Contaminated cement with 93 bbls contaminant. 5/30/85: Cleaned out contaminated cement from WB. 6/18/88: Rcpcrforatcd: 11630 - 11660' MD Ref. Log: BHC5 10127/83. Returned well to production and obtained valid production test. ARCO Alaska, Inc. Prudhoe Bay ._ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-34, Permit No. 83-133 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/TPA/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 14-34)W1 -3 JUN 2 7 Gas Cons, CommlsS~Ott Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlar~ticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/~--"IL AND GAS CONSERVATION C "--"MiSSiON APPLICA I'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X_~ Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, 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 -14-34 9. Permit number 83-133 10. APl number 50 - 029-21010 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11925 feet Plugs(measured) 9250 feet Effective depth: measured 11885 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1937# Poleset 81' 81' Surface 2531' 13-3/8" 2000 sx Fondu & 400 sx PF 'O' 2600' 2566' Production 11089' 9-5/8" 500 sx C & 300 sx 'O' 11158' 8594' Liner 1071' 7" 415 sx 11925' 9250' RECEIVED Perforation depth: measured 11630-11660' ~JUN 2 7 1z989 true vertical 8992-9018' Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 10782' MD; 4-1/2", 12.6#, L-80, PCTtail @ 10864' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2181' MD; Baker FHL packer @ 10782' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation July 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby,41ertify that the foreg~ correct to the best of my knowledge. Signed ~/~ ~~~ Title Operations Engineering Manager FOR COMMISSION H~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' Oil x Gas Suspended Date i A..rov , Co~Date Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 13R2 T_ P_ AIl~.n_ 2RR-4R.':i7 SUBMIT IN TRIPLICATE Drill Site 14-34 EDTA Perforation Breakdown Treatment ARCO Alaska, Inc. proposes that a perforation breakdown treatment using EDTA be performed on Well 14-34. The treatment will be performed as follows: I. Obtain a valid well test. . MIRU wireline unit. Make a tag run to ensure that fill is not covering the perfs. Change out the orifice from station #1 with an Otis RP circulating valve set at 2800 psig differential. Load the 5-1/2 x 9-5/8" annulus with dead crude/diesel to surface. Pressure test annulus to 2500 psi to ensure no communication exists. . Load 5000 gals of filtered fresh water (150 °F minimum) for blending the Na2EDTA. Add to the following ingredients for mixing the Na2EDTA. 30-36 Ibs/bbl of Na2EDTA (approximately 4000 lbs) 2 gals/1000 gals of F75N, NE-18 or Losurf 300 (surfactant) I gal/1000 gals of A186, Cl-9 or MSA (organic inhibitor) 4. Load 500 gals of xylene, 80 bbls of slick diesel and 270 bbls of dead crude. 5. MIRU pump trucks and transports. Ensure that 2500 psi is placed on the 5-1/2 x 9-5/8" annulus. 6. Roll all acid compartments on location before pumping fluids downhole. 7. Pump the following fluids down the 5-1/2" tubing: A. 3 0 bbls Slick diesel to establish treating rate and pressure B. 500 gals Xylene C. 5000 gals Na2EDTA w/additives and 250 ball sealers, 1.1 SG and 0.875" diameter D. 5 0 bbls Slick Diesel E. 2 7 0 bbls Dead Crude 8. Immediately following treatment, monitor pressures for 15 minutes. 9. Shear the RP valve in the top station by placing 2800 psi differential pressure. Unload the well. 10. After all stimulation fluids have been recovered, obtain a valid well test. 6 5 4 3 2 COILED TUBIN~ UNIT BOP EOM ! PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYD~UL~ SLIPS 4. 5000 PSI 4 t/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 Anct~orage H]RELINE BOP EOUIPMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) .1. 5000 PSI 4 1/6" L UBRICA'fOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-*OFF D~ql'F - A-,?i -RR K'FFFF:F:'NF'.F--' . AF:F:FI F:~,~F"I) HFil F F TNAI 7-?fi A-iR-fiR £F)I I AI:L' - k'llN ~ . "~" ATI ¢'~ t4-.~4 A-tR-RR C.(ll I AI--.,'/F'FF.'FflF:~.~'¥TflN I;.'IIN ~ "~,' ATI A~'.-.. F'I F-'.A,,?F XTF. N ANT) R'FTI. IR'N TFIF~ ~TTAP. FIFD I:RF:'Y ¢,5: R'FP. FTF'T rIF D~TA. ~' -IT I'-:F T V Fi T'~ .P,Y HAV.F.-. (~ N.TC'.F' D~Y' F'FTE;GY ~4FNNFTT .~"F O- ~ 529 D T.~'TK' T RI ITT r:'.' F-.:N T F.' A 1 .. F'[ I..F,? ~ .F".¥TFNX'TON FYF'I F!F:ATTFiN ,, F-¥¥r,N ~r .. t..~ Pi~F:ATHflN~- .~,'. N I.-.)).--:: T !. · ~'ARco Alaska, Inc. Prudhoe Bay l=.gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 13, 1988 C. V. "Chat" Chatterton~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-34 Permit No. 258 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/CMH/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 14-34)W1-3 WELLS2/120 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . AR3B--6132-C STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COMM,,.SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ] Re-enter suspended well '- Alter camng ['; T~me extension Change approved program Plugging "q Stimulate ~ Pull tubing Amend order .r Perforate ,.v.' Other 2 Name of Operator 5. Datum elevation (DF or KB) ARC~ Alaska, Inc. 69' RKB feet 3 Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 196' FNL, 1243' FEL, Sec, 9, T10N, R14E, UM 7. Well number DS 14-34 At top of productive ~nterval 60' FNL, 301' FEL, Sec. At effective depth At total depth 209' FNL, 30' FEL, Sec. 10, , T10N, R14E, UM 8. Permit number 258 9. APl number 50-- 029-21010 10. Pool 10, T10N, R14E, UM Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 81 ' Surface 2600' Intermediate . Production 11158 ' Liner 1071' 11925 feet feet 9250 11885 9215 Size 20" 13-3/8" 9-5/8" 7" Perforation depth: measured 11630-11660' true vertical feet feet Plugs (measured) Junk (measured) Cemented 1937" Poleset 2400 Sx Measured depth 800 Sx 415 Sx 81' 2600' True Vertical depth 81' 2566' 8992-9018' Tubing(size, grade and measured depth) 5½", 17#, L-80 plastic-coated tubing Packers and SSSV(type and measured depth) Camco Bal-0 SSSV @ 2181'; Baker FHL Packer @ 10782' 11158' 10854-11925' 8594' 8343-9250' RL:C IVEO Alaska Oil & Gas Cons. Commissior~ Anchorage 12.Attachments Description summary of proposal ? Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May 1988 14. If proposal was verbally approved Name of approver Date approved 15. I herebymcertify that,the f_oregp~ng is true and correct to the best of my knowledge // Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness E} Plug.integrity E] BOP Test ID Location clearance ,Approved Copy ' "Returned ~ ORIGINAL SIGNED BY ~ .-/~ ._~ ¢~ LONNIE C. SMITH Commissioner Form 10-403 Rev 124-85 WELLS2/120 C. M. Hightower, 263-4713 the commission Date DS 14-34 CTU SQUEEZE INTENDED PROCEDURE · me Be RU WLU and make gauge run to PBTD at ±11885 MD. RU CTU and perform HC1/mud acid/xylene wash of perforations 11408-11686' BHCS (overall). Note: Current perforated interval: 11630-60' BHCS, others previously squeezed, but some leaking. Return well to production for a minimum period of 24 hours. Using CTU, squeeze cement the perforations 11408-11686' BHCS (overall) with Class G cement. Contaminate the cement in the wellbore and WOC. . Jet wellbore clean to PBTD of 11885' MD. POH, leaving wellbore filled with seawater with diesel cap. CTU. · 7. Reperforate the following interval: 11630-60' BHCS 4 SPF 8. Return well to production. Well Information (Ref. BHCS 10/27/83) Est. BHP @ 8800' SS: 3750 psi Current perforations: 11630-60' (BHCS 10/27/83) Proposed perforations: 11630-60' (BHCS 10/27/83) Fluid in wellbore at time of perforating: seawater with diesel cap Recent test (3/13/88): 1296 BOPD, 9979 GOR, 4% water, 1561FTP Rig down RECEIVED APR 1 4 1988 Oil & G~s Cons. OomrnTs~io;'~ Anchorage c~m3/435 '-",,rca Alaska Inc. - Pruclhoe "Flelcl API~: ~10104~ Well Type: ProOucer Spucl Date: 9-22-&3 Completion Date: 10-31-83 Original RKB: 69' Hanger Type: Gray Top of $acllerochlt: 11314' Maximum Hole Angle: 56~ Annulus Flulcl: Diesel/NaCl-9.6e Reference Log: All Depths are RKB MD to Top of Equlprnent, Jewelry 1 I 2181 2 10763' 3 10777' 4 10782' 5 10851' 6 1086~' 7 10864' 7 10908' 11 8 9 10 11 New I~! Workover I=! Hanger: 24' Angle Through Sacl. ' 32~ BHCS 10-27-83 ~ laI-O IgV Nipple: ID - 4.S62' Baker PBR A~sembty Crossover: 5 1/2' x 4 1/2' Baker FHL Packer: 9 5/8'x 4 1/2' Camco DB MpI:~: ID - 3.813' Baker Shearout Sub Tul~ng tc~l 4 1/2' ELM ruling tall: 4-10-85 Mlnlmurn ID: ~o DB Nlppte: ID - 3.813' Cmlng ~nd Tubing 13 3/8' 72dt L-80 0 2600' 9 5/8" 47~ L-80 0 11158' 7' 29~ L-80 10854' 11925' 5 1/2' 17~ L-80 0 10782~ 4 1/2' 12.6~ L-80 10782' 10864' 2954" 1 CA-MMIG CA Dummy 5808' 2 CA-MMIG CA Dummy 7831' 3 CA-MMIG CA Dummy ~ 4 CA-MMIG CA Dummy 9136' 5 CA-MMIG CA Dummy 9740' 6 CA-MMIG CA Dummy 9816" 7 CA-MMIG CA Dummy 10264" 8 CA-MMIG CA Dummy 10341' 9 CA-MMIG CA Dummy 10668' 10 CA-MMIG CA Dummy 10735" 11 CA-MMIG CA Eq-Dum RK RK RK RK RK RK RK RK RK RK RKED Casing Casing Uner Tubing Tubing tall ~:~; :~ ~.~ Cons. A~-~chorage 12 PBTD = 11885' TD= 1192E 10 12 I~erval Zone FI' SPF Date 11408-11418 4 10 0 3-23-84 11422-11452 4 30 0 3-23-84 11460-11480 4 20 0 3-23-84 11619-11629 2 10 0 9-17-86 11630-11660 2 ,.30 4 10-6-86 11680-11686 2 6 0 7-24-85 Datum 8700' SS = 11286' MD 8800' SS = 11404' MD CTU SQZ: 7-25.-85 Reperf: 7-27-85 CTU SQZ: 9-25-8~ CTU SQZ: 7-25-85 Reperf: 7-27-85 CTU SQZ: 7-25-85 Reperf: 7-27-85 CTU SQZ: 9-25-86 Sclueeze perfs CTU SQZ: 9-25-86 Squeeze perfs CTU SQZ: 7-25-85 Revision Date: 2-19-87 Reason: Reperf after CTU Squeeze Previous Revision: 9-86 2 1. 5000 PS1 ?" W[LLHr. AD CONH£C10R t'LAHG£ 2. 5000 PSt WIRELIN£ RAU$ (VARL,~L.£ $t2'£) 3. 5000 P,~I4 1/6" LUBRICAI'OR 4. 5000 PS1 4 1/'6" FLOW TUB[ PACK-OFF* RE£E[¥ED Aiasks Oil & Gas Cons, 6ornr~issi.c,'.~ Anchorage H]RELINE BCI~ EOUIPMENT 5 4 2 1. e~C)C)O PSt ';" WI:LLPIr.,d~) COflNI;C*IOP, ri.A, ~'. SO00 PSt 4 4. SC)C)O PSI 4 1/0" SI"C~ RAMS, S. SO00 PSi 4 1/IS" sIurrK BC)x .COiL.gO ' ' ' A . . ARCO ALaska, -in:~. F'. O. Box Anchorage, ALaska DATE' Apri L 2~, ~98'? REFERENCE' ARCO Cased HoLe Final 4-i5 4-i-87 7-24 4-6-87 9-S 4-S-87 f 4-34 4-5-87 .. Inj. Profile Survey Run ~, 5" Leak Detection Log Run ~, 2' IzLowmeter/Temp. Survey Run t, 2" Ftowmeter/Flujd DensJty/'Femp Run ~, 5' & 5" C a fll E 0 £; a m c o Ca fll C 0 Ca fl~c o F'[ease sign and Received By HAVE A NICE DAY! Rosanne Peek A1'0-t 529 return the atta_c~e.~d co~ as re~'~p~ TRAN$ .~87229 Approved DISTRIBUTION of data. Cen'.ra[ Fi Les ~ Chevron D & M Extension Explora'~ion E'x xon Ma r a t h on Mob i L · :.'. .... ,::) CZ- ..i ,.:.. .... '"""' :; i '" 'i' .... F-':,':'-, ! -.? ......,y ...... :..:.:, L Oil & Gas (;..:qs. cu,ml'lissioll !:-:.: e c e i ',.:' ,:a ct E:':...' ........................................................ -/:mchofage H i:':', ;~.,"'::' .... i::', i'-,I. ]1 "":...,..~::' i":, i::'~ Y ~. i:-".[ .,'.::..' _'.i: a !'l i'i .'.'-:-." F:' (.~' ,.'.:-:' !< i".':'~'T' r!-.-i...:.':: ..... .,-: ::: '"" ':" '" ;"'; '""' :,$ E, ":' E:: ~. ::r.-:', ,,.,..,...: ::. ,. ..~ i:"-i j::-' F" i" 0 '-'./'"' .-4 ............................................................................... ;";) ]; :!i.' 'T i:;,: ]: i~': U 'f' ]; ('i H ii::, t' o 'f" ,::1 a 't' a. ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 2, 1986 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-34 Permit No. 258 Dear Mr. Chatterton: Attached is the "Subsequent" Sundry Notice detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/CMH/jp Attachment cc: Standard Alaska Production Company Pi(DS 14-34)W5-4 WELLS/16 ARCO Alaska, Inc. is a Subsidiary of At~anticRichfieldCompany STATE OF ALASKA ALAS.,,, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, :[nc. 3,,,Ad ~e s S,, r. u. ~ox 100360, Anchorage, AK 99510 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, TION, R14E, UM At top of productive interval 60' FNL, 301' FEL, Sec. 10, , TiON, R14E, UM At effective depth ~tpt~e, pt~0' FEL, Sec. 10, T10N, R14E, UM Plugging [] Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) 69' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 14-34 8. Approval number 258 9. APl number 50-- 029-21010 10. Pool Prudhoe Bay Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 11925 feet 9250 feet Plugs (measured) Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 11885 feet true vertical feet 9215 Length Size 81' 20" 2600' 13-3/8" 11158' 9-5/8" 1071' 7" measured 11630-11660' true vertical 8990,8-9016,9' Junk (measured) Cemented Measured depth True Vertical depth 1937" Poleset 81' 81' 2400 Sx 2600' 2566' 800 Sx 415 Sx 11158' 10854-11925' ~bing(size, grade and measured depth) 5½", 17#, L-80 plastic-coated tubing C Pack~s~n~ SSSV(tyDe and measured depth) amco ~a±-u SSSV ~2181'; Baker FHL Packer @ 10782' 12. Stimulation or cement squeeze summary 8594' 8343-9250' Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1315 12153 0 0 2281 2193 961 45 0 577 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 I- ~' ¢ WELLS/i6 C. M. Hightower, ATO-1516, 263-4713 Date //~"//~ [ Submit in Duplicate DS 14-34 SUMMARY OF CTU WORKOVER GAS SHUTOFF 9/22/86 9/27~86 The perforations 11408-18', 11422-52', 11460-80' and 11619-29' BHCS were ac:rd washed with 35 bbls 15% HC1 and 50 bbls mud acid. The above perforations were squeeze-cemented with 170 sx Class G cement with approximately 10 sx being placed behind pipe. 9/28/86 The well was cleaned out to 11885' PM PBTD. 10/6/86 It was perforated in the interval 11630-60' BHCS 4 spf. 10/19/86 The well was returned to production and tested 2193 STBD, 2% water, 438 GOR with 577 psi FTP on 38° choke on 10/19/86. CMH2/67 ARCO A£aska, Inc~ F'~O~ Box Anchorage, Alaska 99~ DATE' October ~4 ,~986 REFERENCE: ARCO Cm~:ed Hol. e Final. · ->~74~t~:'~0-6-86 Col. tar/Perf. Log Run ~6-~9 9-S0-86 Co[tar/Perf. Log Run ~-4, ~8-9 9-~7-86 GR & Cottar Log Run ~ear Gear Gear F'l.ease _¢ign and re~urn the att'ached copy as receip~ of da~a. Received By__ HAVE A NICE DAY! Rosanne F'eek ATO-t 529 TRAN$ $8664~ DISTRIBUTION Central. Fi les Chevron D &M Extension ExpLoration Exxon Marathon Mobil. F'hillip~. F'B Well F'i les R & D Soh i o Texaco Alaska 011 & Gas Cons, Commission Anchorage ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 16, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 14-34 Permit No. 83-133 Dear Mr. Chatterton: Enclosed is the "Intention" Sundry Notice detailing work proposed on the above mentioned well. Very truly yours, D. F. Scheve DFS/CMH/plt cc: Standard Alaska Production Company Pi(DS 14-34)W1-3 CMH/12 ARCO A~aska, Inc, is a Subsidiary o! AHanticRicb;ieldCompan¥ STATE OF ALASKA ALASKA ,,IL AND GAS CONSERVATION COMM, .~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request' Abandon [~ Suspend [ ~ Operation Shutdown ['J Re-enter auspended well [, Alter casing [. Time extension { i Change approvecl program [ I Plugging [} Stimulate [3 Pull tubing [ } Amend order [ ] Perforate [ i Olher Jr' 2. Name of Operator ARCO Alaska, Inc. 3. Address PO Box 100360, Anchorage, AK 99510 Location of well at surface 196'FNL, 1243'FEL, Sec. 9, T10N, R14E, UM - 5. Datum elevation (DF or KB) 69' RYJ~ 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-34 At top of productive interval 60'FNL, 30I'FEL, Sec. At effective depth At total depth 209'FNL, 30'FEL, Sec. 10, T10N, R14E, UM 10, T10N, R14E, UM 8. Permit number 83-133 9. APl number 50-029-21010 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11925 feet Plugs (measured) 9250 feet 11885 feet Junk (measured) 9215 feet Casing Length Structural Conductor 81 Surface 2600 Intermediate Production 11158 Liner 1071 Perforation depth: measured 11408-11418' Size Cemented Measured depth True Vertical depth 20" 1937# Poleset 81' 81' 13 3/8" 2400 SX 2600' 2566' 9 5/8" 800 SX 11158' 8594' 7" 415 SX 10854'-'11925'' 8343'-9250' ; 11422-11452'; 11460-11480' 8802-8810'; 8814-8839'; 8846-8862' Tubing (size, grade and measured depth) 5½", 17#, L-80, Plastic Coated Tubing Packers and SSSV (type and measured depth) CAMCO Bal-O SSSV @ 2181'; Baker FHL Packer @ 10782' 12.Attachments Description summary of proposal J~ Detailed operations 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~certify that t_,he foregoing is-true and correct to the best of my knowledge Signed X~'~ ,4~~ Title operations ]~-~?ineering Manager Date Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval [] Plug integrity [] B~;~l~d ~lTocation clearanceI No. c:~-' Returned ~. S~I~ by order of Commissioner the commission Date ~'nrm 113-4133 Rev 12-1-85 C. M. Hightower ATO 1516, Ext. 4713 Submit in triplicate DS~14-34 Prudhoe Bay Field CTU Cement Squeeze Intended Procedure AFE No. 697788 · · · t Be · · RU WLU and make gauge run to PBTD @ 11885'MD. RU ELU and perforate the interval 11619-29' BHCS 4 SPF for precautionary squeeze. Flow and clean. Rig up coiled tubing unit (CTU) and perform HCl/mud acid wash of perforations 11408-629'BHCS. Squeeze cement perforations 11408-629'BHCS with 23 bbl Class "G" cement using CTU. Contaminate cement in wellbore and WOC. Jet wellbore clear to 11885'MD. POH & rig CTU down. Perforate the following interval: 11619-60' BHCS 10-27-83 8. Bring well in and test. Return well to production. CMH/12 6 ,5 4 2 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANG£ 2. 5000 PSI 4 1/16" PIP[ RAIDS 3. 5000 PSI 4 1/6" HYT)RAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX COILED TUBING UNIT BOP EOUIPHENT ARCO Alaska, inc-/~.. Post Office '~.100360 Anchorage. ,.,..,ska 99510 Telephone 907 276 1215 ~. Date:: October 21, 1985 Reference: ARCO CH Finals 2-10~' CET Log 6-30-85 3-2J CET 3-11-85 '~6-10 ~CET 3-6-85 7-2-' CET 3-8-85 - 9-16 ~ Gamma Ray 4-27-85 ll-12"CBL 12-13-$4' 13-4 ~CCL/Perf 5-8-85 13-25~EPL 4-13-85 13-98'CNL- 8-14-85 14-2z CET 6-29-85 14-4' CET 6-29'85 ~'14-7j CCL 4-5-85 ~ x3 14-34~CET 3'-~0-85 :'~' ' "'~ 15-12'CET 3-9-85 ·; '"'~'~17'1 i~CET ':~ 3-23-85 -' ~ 17-13~ET ' 3~-85 -. -- ~-17-14~ET ' 3-3-85 . Run 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch if 5" Sch 15 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1: 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch (Recomputed) (Epithermal-Recomputed) (Thermal-Recomputed~. of da~'.) ~ Please sign as receipt~ ~/~~_~u'~-~]r(~~I/'''- Received by' _ 41~ska Oil &'.Gas ·Cons Pam Lamber t z4nchorag,,' Omrn/ss/ort .. ATO 1429C Chevro~ -~ DAM -- Expl. Services Ex~. Exploration Exxon MarathOn Mobil Phillips -~. PB Well Files-. R&D Sohi~ T~xaco -- Trans 365 AI~CO Alaska. Inc. ,I · SuDs,O:ary O! Atilltt~cl;lichfielf~Com~)at'~¥ ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 D_ate: September 5, 1985 Reference: ARCO CH Finals 3-28 Perf Record 8-2-85 Run 1 5" Welex 3-30 Perf Record 8-8-85 1 5" Welex 14-34 Perf Record 7-27-85 1 5" Welex 15-10 Dual Spaced Neutron 8-10-85 Run 1 5" Welex Pam Lambert ATO 14 29C Alask~ Oil ~ b=,~ C,t,;~S. $O~,l~iSsiori Anch..','-r a.~ Trans 308 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R&D Sohio --State" of' Alaska. Texaco · . ARC(] Alas'ka, Inc F'.O. Box Anchorage, ALa.ska 995i 0 DATE° March REFERENCE · i 4, t 985 ARCO Cased HoLe Finals° 3-4-85 .-_"~-7-85 .~--- 4 8.5 · '~_ ~ 5,_ o:: 8- i ~-84 8- i ~-84 S-7-8S 2-8--8S CPL/I'DT-M w/Its'Ting PLS CPL./TDT-M w/I_ i_s'i' CPL/TDT-M w/[i.s'Ting Tempe'~a T ute Log Temperature Log CCL/Perf Record CET/Ca[ i per Log CPL/TDT-NB w/lis'T PL.S F [e~.s~ ~ign and re~urn ~he at tac:hed c:opy as ;-ecei Received By .... HAVE A NICE KelLy McFar L[and ATO-. i 4"~9F,. TRANS, ~044 of da'La, DISTRIBUTION Chevron D & M Exploration £ervices Extension Exploration Ex xon Hara~hon Hob i [ MobiL[ E & F:' Phi L[ I. i p,s' F'rudhoe Bay Well. Fi Les' R & D $ohio Sta~e of ALaska Texaco ARCO A La.'...:ka, Inc. P.O. Box i0C')S60 Anchorage., ALaska 99~:i 0 _> . r;8~ DATE March 14, t-.,, _.- R I!-" I:-- E F;,' E: N C: E: ' AF;:CO Magne'l: i c Tapes w/I. i s--I: ings' / 6-4~/' I 1-22-84 TDT L i.~ :.":70100 Run 4 .'.';'ch * . .... - _ ") ,')_ o ,~ ..... '-" - '-- ,~ '. ' ~:'701 r:) 4 '-:; r' ,,__D'~'' o-4 11 ..... -- ID1 !,~,:,~ c-'~ _ ,, /ff,~,/ Rut, _.h '.~': t2--t0 ,t---.~0-8,-~ ., An,,~,wer .a-rOk")¥7 etli'l :5 .?ch ~(' ; ................ f ,.~ ..z,:~ .... i :i-:- 2 S - 84 T D T A n .s 1,.3--5 11-23-84 . 'f'[~T [_is' ~:'70tC-)2 F;'.un S £,'ch ,.--¥Co_,S .... _ . .~{4~34 t t -24-84 TDT Aris'wet ~: ;,;:)t (:).: I:;~u.l-~ '-) ~..c.h '×' ---D-:-5'-~'--t- ?-t~--' ~,- ~7-:'~2::-,9°5 .............. 01--I--~?(_-')(-)92 ............ RiJn -'t . _ "-Y~ .... t7-12/ ) -, .... i,-~-,_,_, F:'re-..Edi'f -~:7£:,092 F;,'un t 3'ch *' i 7--i .... ~--t 2--°~' ~-:...-_ ,_,¢ Wave fo'rm:~ :~7(-)092 *_:: o I"~ i o ~F'F' [ e a s' e .s i q n a ;'; cl '~" e 't' u r ,- ,-- L.\_ , · ; .-;'; l'.', ~' _ ........................................... HAVE A NICE DAY! .--~f'i. ' . · , KeL L-/ HcFar Land ATO- ~ 429F -- i copy prey i ous- Ly s'e;-,t I:)y £c1", I. Ltflil:)ei"gei" . D 15"[' R I BUT I ON (Q~Iy_QH) C-h err on I) & i'.t Exp [ora't-ion ~,e'r'vices Extension Exploration Ex xon Mara 'thon Hobi L E & F:' F'hi LLip~ Prudhoe Bay WeLl. R & D $ohio State of ALaska Fi Les' ARCO Alaska, Inc Post Office ~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 31., 1984 Mr. Harold Hedlund State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- DS 14-34 Completion Report Dear Harold, The DS 14-34 Completion Report, dated 01/19/84, incorrectly lists the ADL number as 28311. The correct lease desgination for this well is ADL 28312. Please make this change to your files. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU2/L52 XC' Well File K. McFarland, ATO 1429 P. T. Willman, ATO 1069 NOV 0 A~aska 0il & (~as Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, In,.. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Pressure Data D.S. 1-4 ~-- 3-15-84 PBU/CDBR D.S. 1-25J'- 5-25-84 PBU/CDBR D.S. 1-26.f-- 5-30-84 PBU/CDBR D.S. 3-19-~ 5-25-84 PBU/CDBR D.S. 3-22/ 6-29-84 PBU D.S. 3-23~- 5-24/25-84 CDBR D.S. 6-17~' 6-16-84 Static Survey D.S. 7-7A ~--' 6-15-84 Static Survey D.S. 7-13'~ 6-14-84 Static Survey D.S. 7-14,j 6-14-84 Static Survey D.S. 7-16~-~ 6-30-84 PBU D.S. 7-16/ 7-2-84 PBU/CDBR D.S. 9-8~ 6-20-84 Static Survey D.S. 9-18J 6-20-84 Static Survey .l ~ 6-21-84 Static Survey D.S. 12-16~ 5-19-84 CDBR D.S. 12-17f 5-20-84 CDBR D.S. 13-33--~ 6-22-84 PBU/CDBR D.S. 14-8~? 6-28-84 Static Survey D.S. 14-23'4---5-16-84 CDBR D.S. 14-24~ 5-17-84 CDBR D.S. 14-25 5-18-84 CDBR D.S. 14-32~ 5-20-84 CDBR D.S. 14-33~ 4-29/30-84 CDBR D.S. 14-34 ~ 5-19-84 CDBR Otis Camco GO Camco Camco GO GO GO GO GO GO GO Camco Camco Camco Camco Camco _- //Please sign and return the ~ data. attached copy as receipt of Kelly McFarland ~ATO-1429F TranS. ~290 DISTRIBUTION dhevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob' ~ 6.:~s-~.. Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, In.._ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Cased Hole Finals D.S. 3-6~'~ 6-10-84 Diff Temp D.S. 3-19---- 5-25/26-84 Spinner Survey D.S. 3-22- 6-29-84 Spinner Survey D.S. 6-10f 7-4-84 Temp Log D.S. 7-3-- 7-6-84 Temp Survey D.S. 7-18~ 7-4/5-84 Spinner D.S. 7-24' 4-19-84 Spinner D.S. 9-18-- 6-21-84 Diff Temp D.S. 12-15f--4-13-84 Spinner D.S. 12-18- 4-14/16-84 Spinner D.S. 13-1/~'~ 6-17-84 Diff Temp D.S. 13-10/'6-22-84 Temp Log D.S. 13-12-~ 6-18-84 Diff Temp D.S. 13-13~'-5-31-84 CFS/Spinner D.S. 13-16J~J4-12-84 Diff Temp ~.S. 13-27"~"~6-2-84 CFS/Spinner D.S. 13-28'-~- 6-3-84 CFS/Spinner D.S. 13-28~~ 6-3-84 Temp Survey D.S. ~3-28--~ 7-8-84 Temp Log D.S. -13-33~ 6-22-84 Diff Temp D.S. 13-33-' 6-23-84 Spinner Log D.S. 14-3~/ 6-30-84 Diff Temp D.S. 14-21- 7-7-84 Caliper Log D.S. 14-24/ 3-25-84 Caliper Log D.S. 14-34-~' 5-19-84 Spinner Log D.S. 17-10/ 6-17-84 Diff Temp ~~~l,ease sign and return the attached copy as data. Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Go Run 1 5" Camco Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 4 5" Camco Run 1 5" Camco Run 1 5" Camco receipt of Kelly McFarland ATO-1429F · Trans. 9301 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil ' ' Mobil E & P A!a.~kn Oil & C~,~s Ce~s. Commission A~chor,,~q~ Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska 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 -~' -j 5-20-84 Static 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 ~- 5-27-84 Common Data Base Report D.S. ~14-23/~ 5-16-84 PBU D.S. 14-24_f 5-17-84 PBU D.S. 14-25 ~5-17-84 PBU D.S. 14-32Y~"5-20-84 PBU D.S. 14-34 ~'- 5-19-84 PBU GO GO DA Otis Camco GO Camco GO GO Camco 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 ~'SCaCe of Alaska 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 ,~D.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/TDTvM 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 ~hevron D & M Drilling 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 Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference · ARCO Magnetic Tapes D ~ ~' '~" 4 °'-' o,,. ~- D.S. 14-34~' 4-30-84 ~D.S. 9-23~ 3-4-84 - D.S. 12 ig 4-22-8;~ ..--D.S. 12-18 J 4-22-84 .~-'D ~ S. 12-23 J 6-7-84 ~i-D ~ S. 4-4~ TDT Answer I~69201 w/listing TDT Lis #69200 w/listing OH #69242 w/listing TDT Lis #69193 w/listing OH #281794 w/listing 6-11-84~ CH/CNS #281792 w/listing Run 1 Sch Run 1 Sch Run 2 Sch GO GO Please sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Kelly McFarland ATO-1429F Trans. # 230 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio -State of Alaska ARCO Alaska, Inc. Post Office~--'P~-360 Anchorage, .<a 99510 Telephone 907 277 5637 April 13, 1984 Reference- ARCO Pressure Data D.S. 6-9J 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 '~3-21-84 D.S. 14-8 f 3-23-84 D.S. 14-27~ 4-2-84 D.S. 14-32,~ 4-2-84 D.S. 14-34 f 3-25-84 D.S, 15-4j 3-15-84 3-15-84 D.S. 15-13 f 3-11-84 3-11-84 Static Static Horner Plots w/listing Static Static Static Static Static Static 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 McFar la~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 ~ -, ~-~. ~,*~/ /. T~ Carolyn Smi /~'// ' ~-.~]': Z '~ -'-' j'~' S oh io ..... . ...,.~?,~i~s!c~ State of Alaska .~,,:~-~;~,~ '7. ,~ ~ ~ "" ARCO Alaska, Inc. Prudhoe Bay ~-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 16, 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 14-5 DS 14-23 DS 14-24 DS 14-25 DS 14- 3-4~ Permit No. 78-64 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Permit No. ~3-133 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/la Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 14-5,23,24,25,34)W4-3 RECEIVED APR 2 0 ]984 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska. Inc. Is a Subsidiary of AflantlcRIchfleldCompany ~-'" STATE OF ALASKA ALASK,~ ~.qL AND GAS CONSERVATION ~, .... AMISSION WELL COMPL,;TION OR RECOMPLETION REPORT AND LO Classification of Service Well 1. Status of Well OIt,X~ GAS [] SUSPENDED [] ABANDONED [] SERV{CE [] 2. Name of Operator 7. Permit Number ~ ALaska, Z~c. 83-133 . 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-21010 4. Location of well at surface 9. Unit or Lease Name 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, L~ (Surface) ~ ~ Bay _Unit - At Top Producing Interval 10. Well Number 14-34 - 60' FNL, 301' FEL, Sec. 10, T10N, R14E, UM (Top Prod) ~1. Field and Po°l At Total Depth 209' Fb~Lb, 30' FJ~, Sec. 10, ~ZON, :[~L4E, f. iv[ (~])). ... ~ :~]ay Field 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. ~ ~ oil 69' ~J ADL 28311 i2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 09/22/83 10/28/83. 1Z/23/83I N/A feet MSL I' 20. Deptl~ where SSSV set I 21. Thickness of Permafrost i 7. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey INipple @ 2181feet MDI 19007 11925'I~D, 9250' Tt~D l1885'I~),9215'TVD yE~([] NO [] . , . 22. Type Electric or Other Logs Run D!L/IK{C/GR, LU~/~/GR, CBL, Oyrosoopic Survey ~3. CASING, LINER AND CEMENTING RECORD ., SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE 'TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . .. , 20:: ~3i.5~ H-40 Surz. 81' 30" Instld w/1937# Poleset 13~3/8'' 72.0~ :bLS0 Surf. 2,600' 17%" Q-t-¢ucl w/2000 sxs Fondu + 400 sxs ~' "0" 9-5/8" 47o0~ L-80 Surf. 11,158' 12z~'' Of~] w/500 sxs "C" Qt~ 300 sxs PF "0" 7" 29# 1-80 10,854' 11,925' 8~" O;-,td w/415 sx~ "G" uut ~4. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING R.ECORD . interval, size and number) SIZE E~EPTH SET (MD) PACKER SET. (MD) 11408-11418' MD 4 spf f:~" '11,864' 10,783' .. 11422-11452' MD 4 spf 11460-11480' MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8803-8863' ~ DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED ' N/~ . . _ - 27. PRODUCTION TEST , . Date First Production Method of Operation (Flowing, gas lift,'etc.) Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGA'S'oILRATIO Date of Test 4/12/84 5.1 TEST pERIoD ~ 868 1998 0 45I 2300 FIDTM Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATEI~-BBL 'OIL GRAVITy-APl (corr) Press. 1688 N/A 2;4:HOUR RATE I1~ ~}87 9z~2 0 27 _ , ,. 28. CORE DATA . . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED APR 2 0 ]984 Alaska Oil & Gas Cons. Commission Anchorage . Form 10-407 Rev. 7~1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 29. NAME Top Sadl~ochit Base Sadlerod~t GEOLOGIC MARKERs MEAS. DEPTH 11313 ' 11765' 11800' TRUE VERT. DEPTH 8723 ' 9110 ' 9141' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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". Fnrm I ARCO Alaska, Inc. Prudhoe Bay ~-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 4, 1984 Mr._ C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 13-27 DS 13-28 DS 13-29 DS 14-34 Permit No. 83-67 Permit No. 83-60 Permit No. 83-43 Permit No. 83-133 Attached are "Subsequent" Sundry Notices for work performed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/la Attachments cc: Sohio Alaska Petroleum Co. File PI(DS13-27,28,29 & 14-34)Wl-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA .:*.. ALASKA, 'IL AND GAS CONSERVATIONC AMISSION 'SUNDRY I OTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LL :~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM Production locations are awaiting approved gyro. 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 12. I 6. Lease Designation and Serial No. ADL 283~ 7. Permit No. 83-133 8. APl Number 50- 029-21010 9. Unit or Lease Name Pr~dhoe Bay Un i t-. 10. Well Number 14-34 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) 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.) (Submit in Duplicate) X~ Altering Casing [] [] Abandonment [] [] Other [] 13. proposed work, for Abandonment see 20 AAC 25.105-170). Began perforation operation 3/22/84. equipment. RIH with gun # 1, shot 10/30/83), flowed well, SI well, POH, 11432-11452' MD 4., spf (20', Ref: CBL Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any RU perforation unit, pressure test 11460-11480' MD, 4 spf (20', Ref: CBL all shots fired. RIH with gun #2, shot 10/30/83), flowed well, SI well, POH, all spf, shots fired. RIH with gun #3, shot 11408-11418' MD and 11422-11432' MD, 4 (10', Ref: CBL 10/30/83), flowed well, SI well, POH; upper 10' of gun did not fire (11422-11432' MD). RIH with gun #4, shot 11422-11432' MD, 4 spf, 10' (Ref: CBL 10/30/83), flowed well, SI well, POH, all shots fired. RD and secured well. Signed14' I hereby/p~rtify//,~~~~~_ that__the foregoing is true and correct to the beStTitleOf mYRegionalknowledge. Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA~ ,_ AND GAS CONSERVATION C('~"MISSION MONTHLY REPORI DRILLING AND WORKOVER OPERATIONS _ 1~ Drilling well~ ....... ~E----- ~- ~orko--~er ~ ~ -- ~- 7. Permit No. 2. Name of operator 83 - 133 ARCO Alaska, Inc, 3. Address P. 0. 4. Location of Well atsurface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 69' RKB ADL 28311 8. APl Number Box 100360, Anchorage, AK 99510 50- 029-21010 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 14-34 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool For the Month of. October ,19 83 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2230 hfs, 09/22/83. Drld 17-1/2" hole to 2625'. Ran, cmted & tested.~'~ 13-3/8" csg w/FS @ 2600'. Drld 12-1/4" hole to 3414'. Stuck pipe. Plug back to 3100'. Sidetrack hole ~ 2759'. Drld 12-1/4" hole to 9891'. Plug back hole to 2600' . Drld~ 12-1/4" hole to 11,196'. Ran, cmted & tested 9-5/8" csg. Drld 8-1/2" hole to (11,925'~;? OH logs. Arctic pack 13-3/8" x 9-5/8" annulus. Ran, cmted & tested 7" csg. Ran CBL 5-1/2" compl assy. Secured well & RR ~ 2400 hrs, 10/31/83. 3. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 81'. Instld w/1937# Poleset. 13-:3/8" 72#/ft, L-80, BTC csg w/FS @ 2600'; Cmtd w/2000 sxs Fondu + 400 sxs PF "C". 9-5/8", 47#/ft, L-80 BTC csg w/FS @ 11,158'. Cmted w/500 sxs "C" cmt + 300 sxs PF "C". 7", 29#/ft, L-80, BTC csg f/10,854' - 11,925'. Cmted w/415 sxs "G" cmt. SEE DRILLING HISTORY -14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHC/GR f/11,791' - 11,157' LDT/CNL/GR f/11,793' - 11,157' CBL f/11,875' - 10,750' 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. SIGNED TITLE Area Dr~ I ~. ,.' ng Eng'.' neet DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~404 D R N / M R 59 Submit in duplicate DS 14-34 DRILLING HISTORY NU 20" hydril and diverter system. Spudded well @ 2230 hrs, 09/22/83. Drld 17-1/2" hole to 2625' (Surface Kickoff). Ran 65 jts 13-3/8" 72#/ft, w/FS @ 2600' Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" hydrii and diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Drld FC + cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 3414'. Stuck pipe. Unable to recover fish. Fish consists of bit #4, NB Stab, Monel, XO, Teleco DC, MS Sub, Monel, Stab, 2 Monels, RWP, SDC, Stab, 3-SDC. RIH w/OEDP to 3100'. Plug back hole w/500 sxs Coldset II cmt. Sidetrack hole starting @ 2759'. Drld 12-1/4" hole to 9891'. Survey instrument found to be malfunctioning. Plug back hole to 2600'. Sidetrack hole @ 2790', drld 12-1/4" hole to 11,196'. Ran 273 jts 9-5/8" 47#, w/FS @ 11,158'. 'Cmtd 9-5/8" csg w/500 sxs "G" cmt Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & new form. Tstd form to 12.5 ppg EMW - ok. Held 12.1 ppg. Drld 8-1/2" hole to 11,925' (10/28/83). Ran DIL/BHC/GR f/11,791' - 11,157'. Run LDT/CNL/GR f/11,793' - 11,157'. Arctic packed 9-5/8" x 13-3/8" annulus w/300 sxs PF "C" + 133 bbl AP. Ran 28 jts 7" 29#/ft, f/10,850' - 11,925'. Cmtd 7" liner w/415 sxs "G" cmt. Drld cmt to 11,885'. PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Run CBL f/11,875' - 10,750'. Ran 5-1/2" completion assy w/tail @ 11,864' & pkr @ 10,783' + SSSV @ 2181'. Tstd tbg hanger & packoff to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 2400 hrs, 10/31/83. DRN/DH41: tw ARCO Alaska, Inc. Post Office/'~'-~ 360 Anchorage .ska 99510 Telephone 907 277 5637 February 2, 1984 --- Reference: Arco Cased Hole Finals D.S. 3-24 ~/-'~10-16-83 ACBL/VDL/Sig/GR D S 4-15"/ 1-7-84 CFS D.S. 4-16/ 10-1-83 D.$. 6-6--/' 1-13-84 D.S. 7-14 11-6-83 D.S. 13-32 /1-4-84 ACBL/VDL/Sig/GR CPL/TDT-M w/listing CH CNL w/Hodges & Lehman Avg. GR ~.~ 1-4/5-84 Diff Temp ~ 1-4-84 CFS D.S. 14-34~/ 10-30-83 ACBL/VDL/Sig/GR , t/?lease sign and return the attached copy as receipt of data. Run 1 5" DA Run 1 5" GO Run 1 5" DA 5" Sch Run 10 5" GO Run 1 5" GO Run 1 5" GO R~n 1 5" GO Run 1 5" DA Kelly McFar land ATO-1429F Trans. # 044 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay Caroline Smith Sohio ARCO Alaska, Inc. Post Office B-' ' 360 Anchorage, ~:a 99510 Telephone 907 277 5637 February 2, 1984 Reference' Arco Open Hole Finals DoS. 14-34 10-27-83 CPL/Cyber look 10-27-83 BHCS 10-27-83 DIL/SFL 10-27-83 LDT/CNL/GR (Raw) 10-27-83 LDT/CNL/GR (Poro) 10-27-83 GR through 9 5/8" casing Run 1 5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" ~~l~Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 043 DISTRIBUTION Chevro~ D &M Dallas Drilling Exxon Getty Marathon Mobi 1 North Geology Phillips Prudhoe Bay Caroline S Sohio State of Alaska ALASK,. ...L AND GAS CONSERVATION L_ '~MISSIO WELL COMPLETION OR RECOMPLETION REPORT AND LOG F--, (.,, 1. Status of Well Classification of Service Well OIL]~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-133 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21010 4. Location of well at surface ! i ~'CAT!~?~$! 9. Unit or Lease Name 196' FNL, 1243' FEL, Sec.9, T10N, R14E, UM I V~[~'~Fi;'~ i Prudhoe Bay Unit At Top Producing Interval, ,~!~'ur'~.-¢J ----i 10. Well Number 60' FNL, 301' FEL, Sec.10, T10N, R14E, UM ''i5."~'~'~' ....ii 14-34 At Total DePth '" 11. Field and Pool 209' FNL, 30' FEL, Sec.10, T10N, R14E, UM Prudhoe Bay Field 5. Elevation69, RKBin feet (indicate KB, DF, etc.)II 6.ADL_[~8,3~i.~.~.~,.~ ]~Lease Designation and Serial~./~-Ne ~7, ~E~'~P,~ - - Prudhoe Bay 0i 1 Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/22/83 10/28/83 11/23/83J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11925'MD,9250'TVD 11,885'MD, 9215'TVD' YES IX1 NO []'lNipple ~ 2181 feet MDJ 1900' (Approx} 22. Type Electric or Other Logs Run DIL/BHC/GR, LDT/CNL/GR, CBL, Gyroscopic Survey 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/1937# Poleset 13-3/8" 72.0# L-80 Surf 2600' 17-1/2" Crntd w/2000 $x$ Fondu + 4D0 sxs PF "C" 9-5/8" 47.0# L-80 Surf 11,158' 12-1/4" Cmtd w/500 sxs "C" cmt + 300 sxs PF "C" 7" 29# L-80 10,854' 11,925' 8-1/2" Cmtd w/415 ~xs "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" 11,864' 10,783 ' 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.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ 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 : Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC03 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS Top Sadlerochit O/W Contact Base Sadlerochit MEAS. DEPTH 11,313' 11,765' NOT RI TRUE VERT. DEPTH 8722' 9109' iACHED 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONE 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the fzo~egoing is true and correct to the best of my knowledge Signed F ~~~.~~li/ TitleArea Drillir'g 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- 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". Ea l/htman / ipstock l A PETROLANE REPORT' of SUB-SURF,4CE DIRECTION.4 L SURVEY ARCO ALASKA, INC.. COMPANY D. S. 14, Well Number: 34 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION CDC JO8 NUMBER A-0983-022 SURVEY BY A Chapman(Conrtolled Drilling Consultants) TYPE OF SURVEY DATE TELECO/Dir-ectional ~.~ ~~V~L) Si " . 26-Oct-83 OFFICE Alaska AR'C:(:) Al ..A:i3t.'::A ? l NC,, ]::~S 1.'q., ~E:::LL. NO: :::.,4.1. 'I"F!.:LE'.C':C~/EISS ( t'":DC: ) I::'I::;:UDHOli::: B/~Y ? NORTH :i:::L. OF':'E:-, AL(~SI'.'::A "f'E:L. ECO., ,0-2:'..~.5:'31 I'"lE:,, :::":II',IC'~L.E '.:',HOT., :27"tO-:!.'C~Zl..':.~1:3 I'1:!.':.,? DF:TL.L.-EF:,:: A ~::I-IAF'MAN ~"': O Iq 7 F:,; OL L.. E: [) [)R l L- I... ]: N ~".i C O !',1'.::; U L T A N T S k/liii:l':;~"l" :[ C:(.:~L '.}.i;Ei"_':T :[ fin fi:(-~L.C:I..IL(.~TI~I ][ N PLANE I'lF F'ROF'C!'.=;RL,' " . ,__: .... . '~ .. -. I ,- · DIRI:L. IIUN. N. 8~' DELi, )~ ~I~N. RECORD OF SL!RVEY RP, D]:LIS OF' E:LIRVR"I'I_IRE I¥1ETHOI"~ ARC' I":l AI....ASI:::A~ 'il r, IC. r)S 14, WEI..L. NO: 24 TELEL-r'i/I'ISS (CDC) PRUDH(]Ei ]3AY,, NORTH :E:L. OPE., ALASKA C:OMF'UTAT I ON T I ME DATE 13: 4:=;: 51 26-0CT-8:3 F::' A G E N 0. ,.1 o HEA :i;I,..IRFD [)R I F::'T DR I F"I" CFfl...IRF:;E VERT I CALVERT IcAL "~' ¢" - L ... .:,UE.:.EA R E C T A N 6 IJ L., A R C L t-.t S U R E r. lOC4L. E(ii DI!!i]::'"I'H AIxlCiI_E DIREC"rION LE:NCi]'H DEF'I'H F:;Ef':TION 1"VII C 0 0 R b I N A "1' E S DISTANC:E DIRECI'ION '..3EVEI:;~I"F'",. I:::' IE E T D M D M F'E E 'l' F' [= E "r F E E "1" F E E T F E E'r F'E E T D FI I) G / 100 F:' 0. c) 0 0 0 C). 0.00 0.0C) -:69. O0 O. O0 0. O0 O. OC) 0 0 0.0() 13:31. () 0 0 0 1:3:3 ;L. 1:331. O0 O. ()() 1262. O0 C). 00 0.00 0.00 0 0 0., 00 :14.24. 2 () '.S 51 0 E ';~:3. 1423.98 1.25 1354.98 1.02 S 1.26 E 1.62 S 51 0 E 2.15 :1.547. :3 6 S 70 0 E 12:3. 1546,E:6 5.96 1477.E:~, 3.70 S 6,,00 E ....... 7,0~, S 58 19 E 1.1:2 1670, :3 54 N 7:3 0 E 12:3. 166'P,,6:3 ~3.:33 1600.63 3.90 S 13.:38 E ~:3.9:3 S 7:3 46 E 1,,?'1 :[7'ii)2,. 5 24 N 68 0 E :1,'i;)15., ./..:, 0 N 74 0 EE :;:!:()::i:',5. .1.()0 N '78 () E 2159., 1 ::":; 2.'::4 N 80 0 E 2:315. 1'7 :=,:0 N 8:2 C) E ,:...'. -. 1 7,==. 22 :34.28' ':' 1 ,-.44.61 E;O. '="-' ~ '-' · -,.:, 1 ;/6o. 42 ....'-0o4. 75.:26 '""-' '-'~" 116.37 '"":¢"' z.~.:,....,. 16 0,,60 S 22.70 E 3. :38 N :34.24 E 7.42 N 50.44 E 12.21 N 75. 12 E 18.71 ~1 116. 16 E :24'7(). :2:3:30 N 80 Q E :;;it 5:3.1. 2 ./.':, 6 N 78 0 E ' ' ";;' 1 ...... :~."', ,'~!'% "' ' '.~i;I...IRV E Y :E; CINAL a- -. a; ... I ¢.", F'CI.I_OW T NC~ ARE DIRIF.:CT I, ~!Nlep.~,,:.,-! I.]T.:~_ . .,,_ .. oF,~ r~.!." D. ,,E.., TI~,i~,,...F.P'" · ' --i .......... -5 "' ""'-' 6:2 ,.. =~- ..0 N '2"/.q.c~ ':::o :'::o N 7 .... 0 E 2()'P. ,,.,,6¢-,,:,. ':-:"':.¢1.80 .'.:."61'Fy.62 ..,._,. 2'F'24. :27 () N 89 0 E 1F":4. 2849. '.:;,~1 :37'.P. 35 2780.91 67.49 N i~i',O :1. 7.::i::() 15 N 89 0 E 9:3. 29:31 · 53 423.90 2862.53 68.27 N 291.17 E :2:7 8 .~l,-, 42:3. 12 E 22.71 :=; 88 30 E 34.41 N 84 22 E 5(11).98 N'81:38 E '76.11 N :=:o 46 E 117.65 N 8() 51 E 171.21 N :=:0 54 E 197.48 N :B() 3'? E · -'9 ':'~ 7'? 6 z. ~ d ....... N 1 [i.:. :38Z1-.54 N 7'? 54 E 428.59 N E:O 50 E 1.2/ (). 6 9 :3, :=:6 '.':~, 76 2.65 :3.90 4.. 4:B .='='. ii: 1 4..11 :2:, 4.9 :=:11(). 34 0 r,I 88 0 E :3'::!:()1 ,,::.:.:/=, :F.:() N 89 <') E :':i: :=: 5 :'::: . 40 45 N 8'2' 0 E :3Zl.qS. 4,4 0 N 84 O E :35:3'7,, 44, o N ::32 0 E 93. 3010. 28 473. :34 2':/,..41.28 91. :"::;084. 59 525.85 3015.59 152. :3203.31 620.68 31 ;34.31 92. 3271.27 6E:2.54 3202.27 · '72. 3:336.32 747.19 3267.32 .6S7.56 N 472.55 E 70.94 N 525.,04 E 74,25 N 619.84 E 79, 1 1 N. 681.64 E :--¢7.04 N 746. '..30 E ~t77.64 N 81:38 E 529,,E:1 N 82 18 E 624.27 N 83 10 E ~..8(:~. 22 N 83 2:3 E 751.26 N :=:3:21 E 4.07 2.. :=' },, 7:. 9:L 4.16 2,/=. ,/:. ,ql()/=,. 52 0 N 81 0 E 569. 3709.4.5 !172.43 :36.40.45. 15Q.48 N 117Q,,72 E 1180..];5 N ,-5:2 41 E :l. 6:;:i'.'i;*. 50 45 N 81 0 E · 52:1:3. 4035.91 1576.71 3966.91 214.40 N 1574.27 E 1588.80 N 82 15 E '.:5152. :50 4.5 N 79 0 E 52:2:. 4366.81 1976.36 4297.81 284.72 N 1973.10 E 1'.-}93.54 N :Bt 47 El 5,/::,7'?. 49 45 Iq :5:1 0 E 52'7. 4703.7':-? 2376. 17 4-634.7~2 355.08 N 2372.10 E. 2398..':]3 N 81 29 E ,':.:.7;'.i':;i!:7. 49:3('~ N 80 0 E 54:i:i:. 5058~79 2788~71 4989.79 423.98 N 278:3.85 E 2815.95 N F.:I 20 E 1 · 0/". (). 24 O. :30 .(:)...=,,.., O. 15 /'.75q !=;1 I'= rq' :::::'::: ("1 E ,.:!:'P'i:~'.-.-~., 52 '.:.:c~ N r-':'70 E '7'()'.;~'2. 56, 0 S ':7./0 0 E .... ~.--'1 N 81 az. · 52: 7. .... '::; 3'P 4 '"':,,=?'-' 31 ? 0 '7':., ._.~.:,"'.~'-',., '~ . 88 .48:3, '? 7. Iq :":; 1:3 .... 5 2..4 E.. '"'-"-' ;:...:0 '-"-' E :.:i'. 4. 5 ?]'-" / -s:-:.:,c: 9 '.;.;~ 3 "' ...... :,.,ts., 1.2: ._. ..... 54.77, !'.:: .500,7.6 N :3:377,2.0 E .3~14, 1:3 N :B1:34 E '~'c:::, 560(). 46 :3458· 3:3 ~'-' ..... '. , .. o.:,...~! 4.6 502 '7"t. N .:,4.-.z, 6:3 E :3489, 04 N 81 4:3 E O. 55 1. :3:=: ._l ['IS ]. Zl., WEI...I._ FII'.}: :ii .~l "I'EI_.Ef']I:I/lIS:=: ( I'] I'.)C ) l::'l::~l.l]'ll. IFII'l.)li~'. [~j : ~l~ Y l, l,.l(]RTH :."i;J..l. lii'.JJ:'lJ[~.i': C: 0 H F' Lll' A T I 0 N T' I MIiF DAI'E 1:3: 4 :_=:: 5:~ 1 2. 6-. 0 C'F --::J: 3 F:'(:~F.![E: N(] ,,, :2' ,, T'RUE I,IEA:::Ii..IR[i:"['i ]]ll::;~]'ll::'"r I]RIF]" COI..IF~t=;F:: VFRI'ICAI_. VF'R'I'II::AL SL!BSE:A R E C -I" A N 13 U L.. A R C: I... 0 DEF::"T'H AIqGL. E D I REF:'T' I FiN LEIqCi'II"H DEF'TH SEf':T ! 01',1 TVD C: 0 f'l R D I N Pi l' E :3 D !'.3TANf]E D I I:;~EF:T .T ON :=;EVI:ER I 'l' F:'E'E'f' D M II H FEET FEET FEE]" FI'ET FEET FEET 7:2:8:3. ' ...., ...' :30 :=: '20 0 E '7 :.=::3 .1.q.'? 1'.'.:3 '.=: ::_::9 0 E 7:F.:7!5,, 4,,S :3()S 90 0 Ii.:: :!:!:():3(). 4.6 :]!:0 '.'.:!; 89 0 [ii: :":i',585. 4.,.'1. 45 :!:;; :;'i:S:.' 0 E 9 ():ii: ./::..4. 1 () '.=i; 8/,:. 0 E ',:.:' /.,-., (:! 0 . 40 0 S 85 0 E 10155. :]!::F: :=:0 S E-'(') 0 E 10.q. 5:3. .:'::630 '.E; 7.5 0 E 1S.'6. 5714 · 95 :3617.41 564.5.95 9:3, 577:3,. 6:3 :=:689.54 5704 ,, 63 4'i.:'4. 6 :[ 04. 'FI5 4055l :iii: l 6035. '~5 155. 621 I, 64 4168.22 6142.64 · '.55'.5. 65S; S:¢. '77 4564.7:3 6530, 7'7 514 7 .=,._, 2' 70 F~":, '"4 v 7 ... ,.:,,~. 70 ':;':':;'=' - '=" 7 7 ~ 8 48 ......... 7 7,_, 7 . 4,8 '~'~'-' · ..,...,,:, 4. :=: 9 . 5][i) 2· 74 N 361 I. 68 E 3646. 50 N 82 5 Ii!'] 502.1! N :--::683. 81 E 3717.87 N 82 14 E 498.91 N 4050.15 E 40:=:0.76 N 82 5'.':'~ E 497.9:Z: N 4162.58 E 4192.2'5 N 8:3 11 [":: 491.():[ N 4559,,20 I"= 4585.57' N 8:3 51 E 1. '79 :3..5'?.) 0.58 0.47 ('~. ) 0.85 (),. 6:]i: 29::1 :-7..:er.R3 88 ..,,7 =, 1 4.6 7954 :~:~ :364. '-'"' . ........ ................ .'=,,:::1 N 5757 .., .T F' 5769 07 N ':::/- :22 E:' 1 :22 f:: I I',IAL CI_CI::!;IJRE = D I RIEC:'f I ON; D I ST AIq(":E: ; , : i ^RCQ iALASKA,, !,HCa4' ' ? i, ': DS 1' ;' NElL TEL~I~OO F^STHhN Wp~[P, 8TOCK:. {NC. i : : , , , , , , .................... i ....... ; , ,., ii:' , , , , , , P :l{~oo~ ,' ' i,,,:,op f ' { ' '1 .. ~L.OSURE. !5T69. .2 ''1 ARCO ALASKA, INC, DS 14, WELL NO: 34 SIE;MA-GYRO .JOB NO: A1183RO403-'..NZ PRUDHOE BAY, NORTH SLOPE, ALASKA · SIGMA-GYRO, 0-11885 MD, ¢-;t..IRVEYOR: dAHN/CORAM, DATE RUN: 23-NOV-83 SI6MA 300 NO: 74/_-., PROBE NO: 0/:.4 FORESIGHT: N ."F-.~ 12 W SURVEY TAKEN FROM WELLHEAD VERT I CAL -=.E..T ION C:ALC:LIL. ATE[~ IN PLANE OF:: PROPO'.=;AL' DIRECTION: N 89 DEO I'F~ MIN. E RECORD ElF SI.JRVEY RA'DIUS OF CURVATUI~E METHOD ARE:Fi ALASKA, IN.C.:. Fi:.:.: 14, WELL NO: :34 SIGMA-GYRO PRUDHCIE BAY, Iq.ORTH SLOPE, ALASKA ,JOB NO: A118:3RC)40:3-NZ C .0 M P U T A T I 0 N T I MI!:' DATE 1:2:: ':'._, Pi....' 22 (") ...... '.~ -, IA N- :::: :7 F'AGE Nr3. ;1 TRUE MEASURED FIRIFT DRIFT C:OLIRSE VERTICAL VERTICAL SUBSEA R E E: T A N DEPTH ANGL. E DIRECTION LENGI"H DEPTH SEC'TION ]'VD C 0 0 R D I N A T E '.S DIf.:!;TANC:E DIRECTION F;EVERI'I' FEE'T D M D M FEET FEET FEET FEET FEET FEET Ii M Ill3/100F: 0. (') 0 0 0 O. 0.00 O. 00 .-69.00 0.00 100. O. 10 ¢'.., =;._ .':";¢) .... E 10A. 100 .00 (") . (") 1 ._,':' 1 .00. 0 .1 .':";.... S 200. 0 20 S 4 31 E 100. 200.00 0.05 1:2:1,00 0.58 8 300. 0 10 S 1'7 48 W 100. 300.00 -0.01 231,00 1.01 S 400. 0 21 S 38 5'7 W 100. 400.00 -0.23 33:1.00 1.42 S 500. 0 26 '..:.; 52 13 W 1£)0. 4.9'B.9'F~ -0.75 430.9'.::~ I .92 S 600. 0 31 S 52 49 W 100. 5t-.?'.~.'.~9 -1.4:3 530.99 2.44 S 700. 0 25 S 18 18 W 100. 699.99 -1.'.--/1 630.F~'.:.~ 3.10 S 800. 0 2 8 50 6 W 100. 7'?'?.'79 -2. 1:3 730,'F~'.-.-~ :3.42 S ?00. 0 1:2: S 22 44 E 100. 8~.~9.'.~'F~ -2.19 830.99 3.63 S . '- .'M ¢' 2.0 40 W L 73 0 7.4 W 1.40 W 2.81 $ 29 51 W 0.08 1.87 W 3.62 S .31 8 W 0.:'::0 2.09 W 4.01 S :31 26 W 0. :3 2.14- W 4.22 S 30:33 W 0.22 1000. 1100. 12£)(3. 1300. 1400. 0 14 N 77 6 E 0 .9 S 3 10 E 0 :'--:2 S 2g '-'f · .:, .) $ 0 2:2 c. '",~, 42 · _, .:,,:, E I 43 :S /.-:3 4.6 E 100. 99.9. '~8 100. 1099..~8 100. 1199. '78 100. 129'F~. 100. 139..~. 76 ' -1,85 '930, ~8 :3.81 .S -1'60 ' 10~0,.98 4.00 S -1.44 11:30. 'PS 4.58 $ -0.91 1230.98 5.37 .S 0.61 1330.96 6,60 ::; ' 1.81 W 4.21 S 25 2:3 W 0.3() 1 MA W 4 .-,c~ .... ,' ..... 21 16 W 0. :2:1 1.38 W 4.7:s: S 16 49 W 0.4(11) 0.85 W 5 .. 44 S 8:5'? W C). 0'.-? 0 /-.9 E 6.64 '.S 5 '=;% E 1 '-":::' m -- . .--... mm .1::...,.i 1500. 1600. 1700. 1800. 1900. 2 22...° 70 4 E :3 28 N 84 20 E 4 27 N 70 17 E 5 19 N 68 38 E 5 50 N 73 15 E 2000. 7 5:3 N 76:32 E 2100. 11 48 N 78 8 E 2200. 14 0 N 79 5'P E ~'-':3C). 0 , 16 4 7 N 81,'._,'-"=' E 24('). (').. 2:('). 48 N :31 -. '? o ~"' E 100. 1499.89 100. 1599.76 100. 1699.52 100. 1799.16 100. 1898.68 100. 1997.95 100. 2096.44 100. 2193.91 100. 2290.31 100. 2384.95 3.87 1430.89 8.88 15:30.76 15.62 1630.52 2:3.64 1730.16 32.88 182~.68 44.53 1928.95 61.34 2027.44 83.32 2124.~1 109.58 2221.31 141.50 2315.75 8 (]0 c. 8.6:3 :S 7.12 S 4.13 S 0.'P5 S 2.18 N 5.95 N 10.19 N 14.48 N 19.27 N 3.97 E 8. '?t~ E 15.71 E 2:3.69 E 32.89 E 44.51E 61.28 E 83.21E 10~.41E 141.28 E 8. '.-.?:3 S 26 2:3 E 12.46 S 46 10 E 17.25 S 65 2::3 E 24. F)!5 :.:; 8 0 7 E 32.?1 '.--; :38 21 E 44.56 N 87 12 E 61.56 N 84 27 E 83.83 N 83 1 E 110.37 N :-_-:2 28 E 142.58 N :-::2 14 E 0.6::: 1./-.::3 1.3'7 (:). 8'? 0 2. 17 '-' 85 2.23 2.82 4.00 2500. 24 42 N 77 5::_: E 2600. 2:3 50 N 74 37 E 2700. 30 28 N 7.5 4 E 2800. 28 41 N 82 45 E 2900. 26 47 N 88 7 E 100. 2477.15 100. 2566.41 100. 2653.31 100. 2740.26 100. 2828.76 179.6.3 2408.15 223.50 2497.41 271.41 2584.31 317.93 2671.26 366.36 2759.76 26.16 N 36.83 N 49.76 N 59.25 N 6.2.95 N 179.33 E 223.08 E 270. :34 E 319.25 E 365.63 E 181.23 N 81 42 E 226. 10 N 8(:) 38 E 275 37 N 79 ·-...~ E 324.70 N 79 2'.-.? E 371.01 N 80 14 E 4.14. 4. :39 1.66 4. 1 '::-~ · _.... 14 ARCO ALA:S:KA, INC. I~-' , :[.:, 14 WELL. NO 2:4 '.E:IC~MA-GYRO PRUDHOE BAY, NORTH :--:LOPE, ALA',E;KA J 0 B N 0: A 11 ,:,.:, R ..J 40.:,- N Z C 0 Ivl P U T A T I 0 N T I ME DATE 13: '-' =' ',-.'":' 09-,J A N-:33 .:!._1 · .,_ TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C: L 0 S U R E DOGLEG DIF_F'TI~ ANGLE DIRECTION LENGTH DEPTH SECTION TVD C n 0 R D I N A T E S DISTANCE DIRECTION F.;EVERI"I" FEET D Fl D M FEET FEET FEET FEET FEET FEET D bl DG/100F :3000. 29 32 N :37 55 E 3100. 3:3 55 N 87 59 E 3200. :36 56 N 87 34 E :3:300,, :39 46 N 87 3 E :3400. 42 42 N 85 41 E .?::~¢JCJ 45 ~"-' N 82 ....... :,,:, 14 E 3600. 48 5c) N 81 22 E 3700. 51 21 N :::1 13 E: 3800.' 52 2 N 81 18 E :390(), 51 4.6 N 81 42 El 4000. 52 8 N 81 51 E 4100. 5'2 26, N 81 57 E: 4200. 52 18 N 81 41 E 4300. 52 43 N 81 28 E 4400. 51 16 N 81 5 E 4500. 50 1/:, N 81 29 E 46c)0. 50 29 N 81 14 E 4700. 50 33 N 81 8 I?_- 4800. 5c) 51 N 81 6 IE 4900. 50 41 N 81 8 E 5c) 00. 50 52 N :31 I E 5100. 50 47 N 80 53 E 5200. 50 31 N 80 46 E 5300. 49 17 N 81 16 E 5400. 49 6 N 81 42 E 1 c)0. 291/:.. '.';'2 100. 3 C)cJ 1. ~ ~ 10c). 3c) 83.42 100. .:,'"161. ':',.~, ..':: 10 c) 'R "~ ':'" . ...- ._, Z. 01 413.54 2847.92 466.11 27:32.95 524.05 3014.4:2: 586.07 30S/2.83 651.90 3168.01 64..58 N 412.80 E 66.45 N 465.2:5 E: 68.69 N 523.27 E 7.1..60 N 585.26 E 75.7-/ N 651.04 E 417.82 N 81 7 E 470.(J7 N 81 52 E 527.76 N 8:2:31 E 58'F~./:,2 N E::':: 2': E 655.4:3 N 83 22 E: 100. 33C)8.73 721.26 2:2:39.72: 100. 3:376.60 794.05 3:307.60 # 100 :_'-:440.74 ,.-.,7C). 01 :]-:371.74. 100. :3502.71 747.72 3433.71 100 ~'~ . ~:,._,64,40 10;:'~;..,.... 70..,~.-:,z~¢~;.. ,.. 40 · :,/_-,~6 C ' 78 03 1:39. ?7 N ' lO2 04 ::.~2 1 O0. "' '-' -J..;."J ! 103 '"~'~ - . ! -' 18 E 1111 N 46 E , .:,%..,..m! ,~ · ~ ' . . .. ."'.:J .-.,-) 100 2:/:,87.~'(') '1.1182,22 ..618,-'L 151'.'10 N 1180,50 E 1190',12: N 82 42 E "", ~, 'T.., . ,.") . .".~ .-, ."t,l~' l.c)O, o74o. 2/.:, 1260, 74 ._,67.. 2/-, 16.,:...:,6 N 1 :::9 '--' ':. . _ ,'-..,,::,...E 1 ...- 6 ..~ 32 N :E:2 :-':'? E 100, '-'~' ~.. 339, :3740,' 17:3.97 N N _ E . ,:,o0 :/ 11 1 37 11 . 17::37.2:9 E 1:348,66 8';' :::5 100 .:,,:, 70. 68 1417.40 3801 6 ::: 18._'5.91 N 141 ..5 ':'q . · '"e' . . ..-..,_ E 1427 44 N :.7.-:::.:, :':: .1. E 100. 39:33. ~/2 1494.10 3:864.92 100. 3'Y97.70 157c). 38 :3928.70 100. 40/:, 1.27 1646.80 3'?'F~2.27 100. 4124.59 1723.41 4.055.5'.-.-~ 100. 4187.83 1800.08 4118.82: 197.64 'N 1491.84 E 1504.88 N 82 27 E 209.21 N 156:3.00 E 1581.89 N 82 24 E 221.04 N 1644.28 E 1/:,59.07 N 82 21 E 2:32.97 N 1720.76 E 17:36.4/_-, N .82 17 IF_ 244.93 N 1797.29 E 1813.90 N 82 14 E 100. 4251.06 1876.75 4182.06 100. 4314.22 1953.45 4245.22 100. 4377.61 2029.94 4308.61 100. 4442.02 2105.64 4373.02 lc)0. 4507.36 2180.63 4438.36 256.93 N 187:3.82 E 1891.35 N 82 12 E 269.11 N 1950.38 E 1968.86 N 82 9 El 281.43 N 2026.73 E 2046. 17 N 82 6 E 293.2:7 N 2102. '29 E 2122.66 N 8'-.'2 :3 E: 304.56 N 2177. 15 E 2198.35 N 82 :2 E 4. --,c, ..~m ,..m :3.0:3 ":' 8L", d:.... :'::. 0 ./::, .-. · _ . · -, .';,c::~ 2.5:Z-: 0./:.:ii!: (). 41 0. :38 0. :31 0. :24 0.47 1.49 1.05 0.29 0. 11 0.30 ,7, ):::.: 0.2C) 0. 1:3 1. :30 0.38 :];500. 49 27 N 81 47 E 5600. 49 26 N 81 47 E 5700. 49 3 N 81 47 E 5800. 49 33 N 81 48 E !5900. 4? 29 N 81 29 E 100. 4572.60 2255.76 450:3.60 100. 4637.63 23:31.08 4568.63 100. 4702. ?0 2406. 18 462::3.90 100. 4768.10 2481.36 46:.~9. 10 1 Oc'J. ,.. .... :, ........ 4c'':''-' 01 -s, ~ .'-, /., 76, 4,7/.:,4 cJ 1 315.44 N 2252.16 E 2274.14 N 82 2 E 326.2'-7..". N 2327. ::"':~ E .,_-s, :A Pi O_ _.. 1 I N ,:,'-"-'.-' 1 E 337.10 N 2402.33 E 2425.87 N 82 i E 347.90 N 2477.:39 E 2501.7c) N 82 0 E 2:58.'F/4 N 255:2.6/_-, E 2._;77.77 N :=:2 0 E: 0.36 0.0 I 0.38 0.50 0.25 ARCO ALAI:;KA, INC. ][..:, 14. WELL NCm: 34 '.=,IGMA-GYRO PRUDHOE BAY, NORI'H SLOF'F, ALA.=,F..A ,_lOB NO: A 11,=,.=,R.)4L.=,-NZ C F/M P I..I 'T A"F I 0 N T I M E': D A'I' E 1 :=.'::.=,'-' :'._,: 2 :.2 09 -, ...I A Itl .-:!ii: ::ii: F:'AOE NO. TRUE MEA.:,LRED I:RIFT DRIFT COURSE VER'FICAL VERTICAl_ '.:;UBSEA R E C T A N G U L A R C: L 0 8 U R E DFu3LE:'Fi; DEPTH ANGLE D I REC:'r I ON LENGTH DEF'I'H SECT I ON I'VD' C 0 0 R g I N A T E S D ! .:, fAN....E D I REC'I' I ON '..:..;EVE-:F~ I "1" FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/10('~F:' 6000. 49 7 N 81 59 E /..:.100. 49 40 N 82 18 E 6200. 49 32 N 82 37 E 6:300 49 16 N ~ . ,=,.=, ._', E: 6400. 49 26 N 83 6 E 6500. 50 48 N 83 5 E 6600. 51 32 N 830 E 6700. 51 10 N 83 5 E 6800. 51 13 N 83 10 E 6900. 52 15 N 84 20 E 7000. 5:3 21 N 87 42 E 7100. 55 4::: S 89.53 E 7200. 55 11 S 89 31 E 7300. 51 31 N 89 52 E 7400. 4'7 50 N '89 39 E · :,/_".-.~.8:3. N 262'7 7~] E '=' /' .'q ':' 60 N :=:1 ._,'='-.'¢ IF- #. ~ _, ._ ._, · . :_::80.2.0 N 270'Z..:. . ':.~1. E 272'.=.~. F,'='._.~. N 82 c). E 2'..T¢ (). 1 ';' N 27'78.41 E 2 :=:(')::~ / '- ,=, ...- ..... =,,~ N "'"'-' 0 E · =,.-..-. 66N · ? .-. ,=,...,.=,. 76 E 2:'"'::=: 1 61 N :=::2 ':.i: 408.80 N 2929.1() E :2' 957.49 N 82 3 E 100. 5222.38 3010.06 515:3.38 · 100. 5285. ()8 3087.49 5216.08 100. ._;347.53 :3165. 14 5:;:'78.53 100. 5410.20 3242.60 5341.20 100. 5472.13 3320.74 5403.13 418.02 N 3005.29 E 3034,22 N 82 5 E 427· 46 N 3082·61 E 311:.2.1.1 N 82 6 E 436.'.:.¢1 N 316().15 E 3190.21 N 82 8 E 446.22 N 3237.50 E 3268.11 N 8'2 9 E 454..76 N 3:315.56 E :3346.60 N 82 11 E lOC)," .... ~ = '=: '-', ._ .,: 58 :3400 26 .546:3, ..,=,.'s,'-"4. 60 , .~,:,""-' N ..:,'-"::"~=,, 01 E '-'..:,4.""/.,= :,, 07 N 8:;;':' :t '7 E 100. 5590.53 3481.74 5521.53 461',84 N 3476.4.8 E 3507.02 N :B:.2 26 100. 5647. 17 3564. 14 5578.17 461.42 N 3558· 89 E 3588./:,::: N 82:2:7 E 100. 5706.84 3644.35 5637.84 461.18 N 3639.11 E :3668.2.2 N :::2 47 E '100. 5771.53 3720.59 5702.53 461.49 N 3715.35 IF_ 3743.90 N 82 55 E 0. !5::': 0 ,, 59 O. 28 (). 42 0. 17 (-). "7 ":, 0.37 0.09 :L. :3:=: 2.9C) :'::. 14 0.70 3.69 ::.::. 69 7500. 46 31 N 89 34 E 7600. 46 54 N 89 39 E 7700. 46 45 N 89 48 E 7800. 46._.-'--{'" 'S 89 ~._.~'- E 7'=/o0. . . 46. 29 c.._, Rc'-Y_. 45 E 8000. 46 32 S 89 26 E 8100. 46 33 S 89 18 E 8200. 46 12 S 89 10 E 8300. 45 52 S 8::: 52 E 8400. 45 22 S 88 42 E 100. :'"'-"- 50 379:3 9::: .. 770 50 ._,,'..,.=, ;Y. . . - "'~' · 100. 5'7:~08.06 :3866.72 5:E::3'.-7~. 0/=. 100. 5976.48 3939 · 65 5907.48 100. 6045. 12 4012.37 5976. 12 100. 6113.93 4084.90 6044.93 100. 61:..:2.75 4157· 44 6113.75 100. 6251.52 4230· 02 6182.52 100. 6320.51 4302.39 6251.51 100. 6389.92 4374.34 /:.320 · 92 100. 6459.86 4445.77 6390.86 461.99 N 3788.69 E :3816.75 N 83 :2: E:' 462·47 N 3861·48 E 3889.0:3 N 8:3 10 E 462.82 N 39:_::4.41 E 3961,,54 N :::3 17 E 462.87 N 4007. 14 E 403:3.78 N 8::: 25 E 462./=,4 N 4079.67 E 4105.:::2 N ,'=:3 :.=.:2 E 462.1:3 N 4152.22 E 4177.86 N :3:2::=:9 E 46.1.33 N 4224.82 E 4.249.93 N 83:4.6 E ~ 60. :3 ::: N 4297 .2 O_ E 4:321 . '79 N :3:2: ._, ~'=.:.'-' E 459. 15 N 43&,?. 17 E 43'Fn=:.2:3 N 84 0 E 457.64 N 4440.63 E 44/_-,4. 15 N 84 7 E 1.. ::_::2 0.3'? 0. 18 C). :3.1. 0. '.:': ::.i: 0. 10 0.36 C). 40 O. 51 8° 23 E :::500. 44 57 S -"-' 8600. 44 32 S 88 3 E 8700. 43 53 S 87 56 E 8800. 4:3 17 S 87 1'? E 8900. 42 :::7 S 87 4 E 100. 6530.36 4516.65 6461.36, 100 · 6601 · :38 4586 · 98 65:32.38 100. 6673.06 4656.64 6604.06 100. 6745.49 4725· 48 6676.49 100. 6818.68 4793.50 6749.68 455 '-'= . F, N 14 E . ,:..-, N 4-511 ._ :3 E 452:4.50 84 4.53.67 N 45,'-_-:1.90 E 4604.20 N ::":4 21 E 451.24 N 4651.58 E 4673.42 N 84. 28 E 448.39 N 4.720.47 E 4741.72 N 84 :---:4 E 445.£)6 N 4788.54 E 480?. 17 N 84 41 E 0.47 0.49 0.66 C). '? 4 0.68 ARCO ALASKA, INC. ]:):E: 14, WELL..NO: :34 SIRMA-GYRO PRUDHOE ]BAY, NLRTH SLOPE, ALASKA JOB NO: A 11:::- ...... '::R¢')4(')'-':.- N Z C O M P I...I T A T I O N T I ME DATE 13: '-"-- ' ":' '-' .: ...... (")9 - IA N" .... ,c,. ,9.. . ,_ '--,:.'~.."~ P PiG E NO. 4 TRUE ,-'1 , , ,-1 ,,-' _ . MEA.:,_IRET~ DRIFT DRIFT COIJRSE VERTICAL VERTICAL .=,_IB.=,EA R E C T A N G I_1 L A R C L 0 S II R E I",]GLECi DEPTH ANGL. E DIRECTION I...EI',.IGTH DEPTH SECTIOIxl TVD C 0 0 R D I N A T E :.]; DIF;TANCE DIRECI'ION :.];EVERIT FEET II M D M FEET FEET FEET FEET FEET FEET D M JIF:i/10OF:' '.-.:'.'(')00.4.1 40 S 86 35 E 91c)0.. . 40 44 ..,c.-,=-,/c,,.., 6 E '::,'20,F). :3'F-' 4? S 85 41 E 'TI :':~ (-) (') .-,,- r..-_ ,:, ~ ...... =, .~ .., 1 '.E;,.,._ 1 :'2, E '?400. 40 1 S 84 58 E 100. 6892.82 486(). 46 682:3.82 1 C)0. 6968.05 4926. 14 6899.05 100. 7044.34 4'?~'.-.-¢ 0.57 6'275.34 100. 7121.11 5054.37 7052. 11 100. 71 '~7.78 5118.27 71 :;.)8.7:9 441.:3/.. N 4855.54 E 4875.56 N 84 48 E 4:37.16 N 4'=:¢21.28 E 4940.66 N 84 55 E 4:32.54 N 4'28.5.77 E 5004.5F) N :::5 :3 E 427.51 N 504'.T¢.63 E 5£)67.70 N 85 1() E: 422.07 N 511:3'.60 E 5130.'29 N 85 17 El .9500. 40 15 S 84 43 E '9600. 4£) 1:3 S 84 23 E '.::*'7 C) 0. ::=:9 5.9 'S 83 32 E 'P800. 3'.-:¢ 10 ~:; 82 50 E ~/?]00. 3'.:~ 11 '.=; 82 14 E 100. 7274 2'3 5 ~'"' "- . 1, ,=, ...-. 407205. 100. 7:350.55 =" / . · _,Z4 :,./.,6 72:-]: 1 55 100 7427 (')3 ~'" ' '"~' ....· _ .:, 1 t). 6,4 7.: .... :, (.~, 10 ¢3. 7'.~ (") 4. (')'?5:3 7:3 · H 7 7 4...~ ._, · 0 · .~i'=: '?"/'. 3/., 7512.60 10 0 7._ .: 1.6 0 ,. --,.:, 41/.,.27 N 5177. :.]:1 E 51'FY4.52 N 85 24. E 410 14 N .~":' 42.14. r'E ,-5.-,.~o _ ...... ,' ....... 1/-, hi :=:r-i :32 E: 4..).:,. :37 N .=-;..':":_ ('). 6.. '.'-..' 1 E 5.':: 21 . P; 2 N ,-, ~' ='.., ._':: 9. E :::9.=i :7-.:2 N ~"-' '- ....... ,.:, 6 .~/. 48 E 5_ '::._ :::_ 4 · 05 N ,..,':'._'=, 47 IS' :=:F:7 62 N ~q'~':":' 13 E ."szla=; ::.~4 N '-'"" 55 .......... ._. .... : ...... E (':). 21 0.6() C). '?4 ("). '="2' ,..I I,.i 10000. 38 50 S 81 18 E 1010(). 38 30 S 7..9 58 E 10200. :37 46 S 78 21 E 10300. 37 15 S 75 23 E 10400. 36 24 S 74 5 E 1C)O, 76~9 31 54..'98 55 75'20 31 ..7:,'-4 ~' /.,1 N P";4';,'4.43 E ._,.:,07==' 4.6 N :::::6 :3' E -- . I II I I · I 100 77:37 ~:B 55/., (I C) I.~'~ I~ ' ' '1 ' 766~. 2:,~ 4/., .~,~=/- 0'.=./ E ~/-.r:: 99 N 8/_", 12 E ....... .~68, N ._.oc ......... 100. 7816 0.~ F,/:,20 60, 7747 0:3 '-~ ~' '-"-' ........ · -,6 :E:5 N 5616 74 E . N E . . ..., 6 .'" ,z,. (3 7 ,'",""/., ~.":" ~. '} 100. .-~,O~o.~...,. o"?'-, 5/.,7.c.~' 7~7826.. 35 ~ 343 .02 N 5676 .04 E ._~/- ~'/',_,c,,=. . 44) N ""/',.,., :E::]: E 100. 7~75:38 5737 :..47 7.906 ~: ~"-'7 24 N ~ '"-"-' S74"~ · -7 ....... 87 E 2.":C~ N 86 44 E I I -- . -- .~ · I1 '.. -- --' %. · . 0.67 0. '.-:/0 1.2.5 1.87 1.16 10500. 35 51 S 72 48 E 10600. 35 58 S 71 50 E 10700. :35 41 S 70 43 E lC)S/C)(). :34 57 S 67 3?/ E 11000. 34 43 S 66 49 E 11100. 34 12 S 65 27 E 11200i :34 2?7/ S 63 57 E 1. 1:2:00...,':'._, ~-' 2 c-., 63 54- E 11400. :.]:2 48 S 62 46 E 100. 8056. 15 57'.-T/3.68 7987. 15 1 O0. 8137. 14 5842/. :36 806:.]:. 14 100. 8218.21 5'?.~04.57 814'F7.21 100. 82'.~:-.-/. 4:.]:5~75:~. 16 8230.48 100. 8381. 12 6012.70 8312. 12 100. 8463 · 2C) 6065. 12 83'.'.:/4.20 100. 8545.64 6116.60 8476.64 1 C) C). 86'.-'~' 8.20 6167. :33 8559.20 100. 8711. :33 6216...97 8642.33 100. 87?5.26 6265.25 8726.26 :310 44 N ~ 79 ¢) ~:'.:./ E ~'~7'::',,'::: 71 N ::: 6 ''=' / ................ :, :, E 2'.::'/2.63 N 5846.28 E 5853.60 N 87 8 E 27:2:. 84 N 5'.:.)01.72 E 5'F./C):::. 07 N 87 21 E 254· 14 N 5956.55 E 5'261. '.-.-¢7 N :=!:7 :':i::3E 2~-:':: 17 N /-,¢)10.':'~ E /-,¢)14 87 N :E:7 47 E 211.06 N 6063.03 E 6066.70 N :38 0 E 188· 17 N /_-.114.79 E 6117./=,':T¢ N :-]:::: 14 E 164·07 N 6165.81 E /:,167.'?'.~¢ N :E:8 2'2 E 13'.=.~./'.5 N 6215.75 E 6217.32 N :.]:8 43 E 115.26 N 6264.32 E 6265.38 N :.::::=: 57 E (). '.-:~:=.: 0.58 (). 71. (:). 5':,:.'i: 0.5:} C). ?2 0.8'.:.~ 1.44 C). 66 11500. 33 5 S 6,2 20 E 11/-._ ,F). F).. 2'.9 21 S 60 ..,._4="- E 11700,. 28 31 S 6,0 42 E 1 18 0 0. 2 8 4 5.:.'-' ._,:._-,'" 5 7 E 100. 887.9.18 6313.21. 8810.18 1 O0. 8'264.68 6358.51 88'.~5.68 100. .9052.1 ".-} 6400.47 88183. 1 ?.~ 100. '.~¢ 13'.~. 96 6441.62 'F,070,. '.~6 ?/0.20 N /_-,312. 5$¢ E 6313.'2:3 N 8? 11 E 65.56 N 6:358. 18 E 6:358.52 N 89 25 E 41.775 N 6400.42 E 6400.5/:, N 8'.:.~ 3'7 E ]7.86 N 6441.86 E 6441.89 N :::'.~¢ 50 E 0.37 :3.80 0.84 C). :=:/:. F'RCI._IECTED TO F'BTD ARE:O AL.A'.:.':~KA, I NC. DS 14, WEL. L NO: 34 SIGMA-GYRO F"'RIII"U-IOE BAY-, NFIRTH .c~LOF'E~ ALA.:.F..A JOB NO: A118:3RO403-NZ C 0 M F' U T A 1" I 0 N T I M E l"i A T E 13 ' ":'"~i · 9 9 ¢~':) -. ~A N-, ::: :':: PAGE NO, 5 ]"RUE MEA'.-':URED DRIFT DRIFT COUR:-::E VE. RTI_.AL VERTI'F':AL SUBE:EA R E C T A N O U L A R C L I'"1 '.:; I.I R E Df]F:;LEF:; DEF'TI'~ ANGLE DIRECTION LENGTH DEPTH .SEC]'ION I'VD 12:0 0 R D I N A T E :::: DISTANCE I.]IRECTION SFVERI"I .... FEET D M D M FEET FEET FEET FEET FEET FEET D M DG / 100F' F:'R(:h_IECTED 'f'O 'rD 7.5. ~1 6472. :'"!: 1 ?."~ 136.71 0.74 S 6472.78 F 6472.78 :--; 'il;'() (") E O. 00 F I N A I_ C L 0 :E; U R E - D I R E c"r I 0 N: D I .-5;T P · AN ...E. 0.00 ) ARCO ALASKA, INC. I]S 14, WELL NO: 34 SIGMA-GYRO dOB NO: Al183R0403-NZ F'RUDHOE BAY, NORTH SLOPE, ALASKA SIGMA-GYRO., 0-11885 MD, SURVEYOR: dAHN/C:ORAM, 1lATE RUN: 23-NOV-8:-_-: SIGMA 300 NO: 746, PROBE NO: 064 FJI~E.::,IGHT: N 9 12 W SURVEY TAKEN FROM WELl_HEAD RECORD OF' INTERF'OLATED "-' ! ' c.,t RVEY ARCO ALASKA, INC. [)S !4, WELl._ NO: 34 SIGMA-GYRO F'RUFJHOE BAY, NF~RTH SLL]F'E, AI_A'.3K~ ,, COMF'I..,ITAT l FJN F'A(3E IqCJ,, JOB NO-" A11R3RO40:3-NZ TI'ME DATE 1:3 -" :'iF7 ." 4:3 ()'~-,_IAN-8:'::: ' MARKER ......... CODE ............. NAME TRUE .SUBSEA MEASI_IRE1'~ VERTICAL MD-Z'FVI] VERTICAl_ R E C T A N O U L A R C L 0 S U R E VERTIE:AI_ DEPTH FIEF'TH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIREF:I"I(]Iq THICI.:::NES'.!:; FEET FEET FEET FEET FEET FEET II M TOF' SA(ii RIVER "FOP SHUBLIK I'OP SADLEROCHIT O/O CONTACI" TOP ZF~NE :3 T L-IP Z EruNE 2 HOT (] / bi C 0 Ixl'T A C T 1 I 19:.2. O0 8621.59 2570.4 :3552.5'.-.) 11224.00 8648.15 2575.9 8579.15 1131:3.00 8722.24 2570.8 865:9.24 11330.00 8736.51 2593.5 8667.51 I 1525.00 :.::'.~00.56, 2624.4 8831.56 116.1 ¢.~.. ~1~ 0 8981 .31 26. 37,7 ._.° ¢~.. 1 _c,. 31 11686.00 ~.~.:, ~. 94 ~ :,46. I :3970. 'F~4 117:~ .... ~ 00 9109.24 ~,/- ~.,~ ._,.~.R9F~4C}. . .. 24 165.88 N 6161.74 E 158. O'F.~ N /.-, :[ 77.80 E 136.36 N 6222.07 E 132.21 N 6':-':30.3:.:.: E 83.92 N 6,323.9'F/ E 6,0 ¢.~/-, N AR/-,/-, '-"-' E . ...... . .,::.~ 4.5. 1:_,' N 6,3'.T~4.52 E · ~m iF. mm mi ~., 17 N 6,427:37 E ,~ "" '~)7 :3:3 6 :i. ,-..,.::,.N 27 E 6179.82 N 8::: 32 E 622:3.56 N 88 45 E ./::,231.7:3 N ;E:8 47 E 6:324.55 N 8','.'-~ 14 E: 6~:66.51 N 6:9 2.:'7 E /-, :--~ 94../' ":' ::: 9 __. '",,:, N _. :36 E 6,427.42 N 89 46 E :} Suggested form to be inserted in each "Active'' well folder to d]eck for timely compliance with our regulations. .. · ' Operator, Well Nan~ and Number Reports and Materials to be received by: /~ ~ ~ -- -'_~~.~-~.~ · Date Required Date Received Remarks · - · Ccmpletion Report Yes . Well History .... Yes .:., /V'.t- P ~u~ ~,~ /k~_~'- Pl ...... 'OK Core s · Core Description ~/'*~/¢/~' Registered Survey Plat 't~ m, , · In¢l'i sari. on Surve7 ~ ..... / Directional Survey '7e5-'?1 1' ~ ¢-~ ¥ ~.~/~ ~ Drill Stun Test Reports ./~/4~ · ,. Proddctidn Test Reports ~ :' ~ /--. STATE OF ALASKA M -'NTHL-O Y ALASKA _ AND GAS CONSERVATION CC_ ,,vllSSION REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~]X REV [ S I ON Workover operation [] 2. Name of operator 7. Permit No. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well 196' FNL, 1243' FEL, Sec. 9, TION, R14E, UN at surface 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 6. Lease Designation and Serial No. ADL 28311 8. APl Number 029-21010 50-- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 14-34 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of October ,19 83 2. Depth Spudd 13-31 Sider 12-1/ OH lo 5-1/2 at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks " ed well (~ 2230 hrs, 09/22/83. Drld 17-1/2" hole to 2625'. Ran, cmted & tested 8" csg w/FS @ 2600'. Drld 12-1/4" hole to 3414'. Stuck pipe. Plug back to 3100'. rack hole @ 2759'. Drld 12-1/4" hole to 9891'. Plug back hole to 2600' . Drld 4" hole to 11,196'. Ran, cmted & tested 9-5/8" csg. Drld 8-1/2" hole to 11,925'. gs. Arctic pack 13-3/8" x 9-5/8" annulus. Ran, cited & tested 7" csg. Ran CBL. Ran "compl assy. Secured well & RR @ 2400 hrs, 10/31/83. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 81'. Instld w/1937# Poleset. 13-3/8" 72#/ft, L-80, BTC csg w/FS @ 2600'. Cmtd w/2000 sxs Fondu + 400 sxs PF "C". ~ 9-5/8", 47#/ft, L-80 BTC esg w/FS ~ 11,158'. Cited w/500 sxs "G" cmt + 300 sxs PF "C". 7", 29#/ft, L-80, BTC csg f/10,854' - 11,925'. Cmted w/415 sxs "G" cmt. SEE DRILLING HISTORY 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHC/GR f/11,791' - 11,157' LDT/CNL/GR f/11,793' - 11,157' CBL f/11,875' - 10,750' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17'~herebycertifythatthef~?g/~ingistrueandc~rrectt~thebest~fmykn~w~edge'~r-~L ~/~~_-- , SIGNED t ' ' ~ TITLE Ar~ rlr~ 1 1 ~ n~ Eg~ n~r DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR59 Submit in duplicate DS 14-34 DRILLING HISTORY NU 20" hydril and diverter system. Spudded well @ 2230 hr~, 09/22/83. Drld i7:1/2" hole to 2625' (Surface Kickoff). Ran 65 its 13-3/8" 72#/ft, w/FS @ 2600,. .Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" ..- hydril and diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. -NU BOPE & tested to 5000 psi - ok. Drld FC + cmt. Tstd csg to 1500 ~- .... : psi ~- ok. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12,1/4" hole to 3414' Stuck pipe. Unable to recover fish. Fish consists~..of bit #4, NB Stab~ Monel, XO, Teleco DC, MS Sub, Monel, Stab, 2 Monels RWP, SDC, Stab, 3-SDC. RIH w/OEDP to 3100'. Plug back hole w/500 sxs Co~dset II cmt. Sidetrack hole starting @ 2759". Drld 12-1/4!' hole to 9891'. Plug back hole to, 2600'. Drld 12-1/4" hole to ~,1,,196'. Ran 273 its 9-5/8" 47#, w/FS @ 11,158 . Cmtd 9-5/8" csg w/500 sxs" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Dr]d FS & new form. T-std form to 12.5 ppg EMW - ok. Held 12.1 ppg. Drld 8-1/2" hole to 11,925' (10/28/83). Ran DIL/BHC/GR f/11,791' - 11,157' Run LDT/CNL/GR f/11,793' - 11,157'. Arctic packed 9-5/8" x 13-3/8". annulus w/300 sxs PF "C" + 133 bbl AP. Ran 28 its 7" 29#/ft, f/10,850' - 11,925'. Cmtd 7" liner w/415-sxs "G" cmt. Drld cmt to 11,885'. PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1 Run CBL f/11,875' - 10,750'. Ran 5-1/2" completion assy w/tail @ 11 8~4' & pkr Ca 10,783' + SSSV @ 2181'. Tstd tbg hanger & packoff to 5000 ps~ ok. Displaced well to diesel. Dropped ball' & set pkr. Secured well & released rig @ 2400 hfs, '10/31/83. DRN/DH4 i- tw ARCO Alaska, Inc. Prudhoe Bay ,_ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 30, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 14-31 Permit No. 83-111 DS 14-34 Permit No. 83-133 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS / JCD / j lh Attachments cc: Sohio Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRichfleldCompany ~---, STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION C. ~IMISSION SUNDRY NOTICES AND REPORTS-ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-133 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21010 4. Location of Well 196' FNL,.1243' FEL, Sec. 9, T10N, R14E, UM Production locations are awaiting approved gyro. 6. Lease Designation and Serial No. ADL 28311 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-34 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 starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to a tank for cleanup. The perforated intervals will be given in the subsequent report. 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 Interval: 11408-11418' MD 11422-11452' MD 11460-11480' MD Ref: CBL 10/30/83 t4. I hereby 0~rtify that theJ~regoj,ng is true and correct to the best of my knowledge. Signed ~'/.~~~~ Title Re gio,a]. ~,Tl_gineer The space below for Commission use Conditions of Approval, if any: IIRI~,I~I~[ SIIlil£D Approved by. ~ [8~l~lE C. Sglflt COMMISSIONER Approved Copy Returnee / - By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, I~ Post ©ttic~ .... ~360 .~.';choraoe .... ~'k~ 99510 Te,ecno,~e~7 277 5~3T December 19, 1983 Reference: Arco Directional Data D.S. 3-25,~/ 12-6-83 D.S. 4-20'- 8-17-83 D.S. 14-27 w/ 12-12-83 D.S. 14-34~" 10-26-83 D.S. 14-35 ~ 11-2-83 Single Shot Magnetic Survey Single Shot/GO MWD Single Shot Single Shot/GO MWD EW Teleco EW EW EW sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 674 Chevron D & M Dallas Drilling Getty Marathon Mckil DISTRIBUTION North Geology · Phillips ~,/~'~//~'~ ,'., .... Prudhoe Bay .-~- c~-~ ~ ' ' .'": Sohio State of Alaska ARCO Alaska, Inc. Post Offic~'~'~ 360 A nchoragetlk, .~ka 995'10 Telephone 907 277 =_.637 December 8, 1983 Reference: Arco Magnetic Tapes w/listings D.S. 3-26 11-6-83 OH # 68730 Run 1 Sch RFT # 68730 Run 1 Sch D..S. 14-35 11-12-83 OH # 68770 Run 1 Sch RFT # 68770 Run 1 Sch D,S. 14-34 10-27-83 OH # 68714 Run 1 Sch Please sign and return the attached copy as receipt of data. .Kelly Mc. Farland ATO-I429F Trans. # 659 DISTRIBUTION Chevron D & M Dal!a~ Drilling ~x×cn Getty North C~oloyy Phillips Prudhoe Bay R & D Caroline Smi~:,--~ Sohio Marathon State of Alaska Mobil ALASKA _,_,L AND GAS CONSERVATION C( MISSION L/~ "'-~',~'. MONTHLY REPORT OF DRI LLI NG AND WORKOVER OPERATIONS.~~ 1Z Drilling welX~ ...... Workove-----r operatio~ D --~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-133 4. Location of Well 196' FNL, 1243' at surface 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21010 9. Unit or Lease Name FEL, Sec. 9, TION, R14E, UN Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 6. Lease Designation and Serial No. ADL 28311 10. Well No. 14-34 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of October , 1983 12. Depth Spudde 13-3/8 Sidetr 12-1/4 OH 1 og 5 - 1/2" at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks d well ~ 2230 hfs, 09/22/83. Drld 17-1/2" hole to 2625'. Ran, cmted & tested " csg w/FS @ 2600'. Drld 12-1/4" hole to 3414'. Stuck pipe. Plug back to 3100'. ack hole ~ 2759'. Drld 12-1/4" hole to 9891'. Plug back hole to 2600'.__[.a~,Dr[d "hole to 11,196'. Ran, cmted & tested 9-5/8" csg. Drld 8-1/2" hole s. Arctic pack 13-3/8" x 9-5/8" annulus. Ran, cmted & tested 7" csg. Ran CBL. Ran compl assy. Secured well & RR @ 2400 hfs, 10/31/83. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 81'. Instld w/1937# Po]eset. 13-3/8" 72#/ft, L-80, BTC csg w/FS ~ 2600'. Cmtd w/2000 sxs Fondu + 400 sxs PF "C". 9-5/8", 47#/ft, L-80 BTC csg w/F5 ~ 11,158'. Crated w/500 sxs "C" cmt + 300 sxs PF "C". 7", 29#/ft, L-80, BTC csg f/10,854' - 11,925'. Crated w/415 sxs "G" cmt. SEE DRILLING HISTORY 14. Coring resume and brief description NONE 15. Logs run and depth where run ~,. ~,.,~: ' DIL/BHC/GR f/11,791' - 11,157' LDT/CNL/GR f/11,793' - 11,157' CBL f/11,875' - 10,750' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE NOV :_. ,_~ i',~:~ Alaska, 0il & Gas Oo~s. Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~' ~' ~ TITLE Area Dr'~11~ ng Fn? n,~i , DATE /I--~--~'Z~ .o _ port on ,orm ,s ,or mo.t., m.. .,.. w,.. Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~404 D R N / M R 47 Submit in duplicate DS 14-34 DRILLING HISTORY NU 20" hydril and diverter system. Spudded well @ 2230 hrs, 09/22/83. Drld 17-1/2" hole to 2625' (Surface Kickoff). Ran 65 jts 13-3/8" 72#/ft, w/FS @ 2600' Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" hydrii and diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Drld FC + cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 3414'. Stuck pipe. Unable to recover fish. Fish consists of bit #4, NB Stab, Monel, XO, Teleco DC, MS Sub, Monel, Stab, 2 Monels, RWP, SDC, Stab, 3-SDC. RIH w/OEDP to 3100'. Plug back hole w/500 sxs Coldset II cmt. Sidetrack hole starting @2759'. Drld 12-1/4" hole to 9891'. Survey instrument found to be malfunctioning. Plug back hole to 2600'. Sidetrack hole @ 2790', drld 12-1/4" hole to 11,196'. Ran 273 jts 9-5/8" 47#, w/FS @ 11,158'. Cmtd 9-5/8" csg w/500 sxs "G" cmt Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & new form. Tstd form to 12.5 ppg EMW - ok. Held 12..1 ppg. Drld 8-1/2" hole to 11,925' (10/28/83). Ran DIL/BHC/GR f/11,791' - 11,157'. Run LDT/CNL/GR f/11,793' - 11,157'. Arctic packed 9-5/8" x 13-3/8" annulus w/300 sxs PF "C" + 133 bbl AP. Ran 28 jts 7" 29#/ft, f/10,850' - 11,925'. Cmtd 7" liner w/415 sxs "G" cmt. Drld cmt to 11,885'. PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Run CBL f/11,875' - 10,750' Ran 5-1/2" completion assy w/tail @ 11,864' & pkr @ 10,783' + SSSV @ 21~1' Tstd tbg hanger & packoff to 5000 psi - ok. Displaced well to diesel. D~opped ball & set pkr. Secured well & released rig @ 2400 hrs, 10/31/83. DRN/DH41' tw , , '-~'-' ~' ~'-'-- STATE OF ALASKA .~-. ALASKA Oi- AND GAS CONSERVATION CO~ ,IISSION MONTHLY RE:RORT OF gltlLLINO ANI WOItKOVE:I1 · Drilling wellx~ Workover operation [] 2. Name of operato~ 7. Permit No. ARCO Alaska, Inc. 83-133 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21010 9. Unit or Lease Name UM Prudhoe Bay Unit 4. Location of Well atsurface 196' FNL, 1243' FEL, Sec. 9, T10N~ R14E, 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 6. Lease Designation and Serial No. ADL 28:311 10. Well No. 14-34 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. September ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2230 hfs, 09/22/83. Drld 17-1/2" hole to 2625'. Ran, cmted 13-3/8" csg w/FS @ 2600'. Drld 12-1/2" hole to 3414', as of 09/30/83. SEE HISTORY & tested DRILLING 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40 weld conductor set ~ 81' 13-3/8", 72.0#/ft, L-80 BTC csg w/FS @ 2600'. SEE DRILLING HISTORY Instld w/1937# Poleset. Cmted w/2400 sxs Fondu + 400 sxs PF "C". 14. Coring resume and brief description NONE 15. Logs run and depth where run N/A 6. DST data, perforating data, shows of H2S, miscellaneous data NONE Aiaska. 0il & Gas 00~s. t;0mmissi0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ -~ ~ z,~ITLE DATE NgT~.-d~-e/~r_rt on this for~ required for each ca~'endar month, regardless of the status of operations, and must b'~ filed in duplicate with the Alaska Oil~and Gas Conservation'Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR40 Submit in duplicate DS 14-34 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well Ia 2230 hrs, 09/22/83. Drld 17-1/2" hole to 2625' (Surface Kickoff). Ran 65 jts 13-3/8 72#/ft, FS @ 2600'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" hydril & diverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOP£ & tstd to 5000 psi - ok. Drld FC & cmt. Tstd cs§ to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 3414'. Stuck pipe. Fishing as of 09/30/83. DRN/DH36' tw Alaska Oil & Gas Cons. Anchorage STATE OF ALASKA '-'"' ALASKA OIL AND GAS CONSERVATION COM~VllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER []X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-133 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21010 4. Location of Well Surface: 196' FSL, 1243' FEL, Sec. 9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-34 12. 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). The work described in our sundry notice dated 09/12/83 has not been done, nor is it scheduled to be done in the near future. Therefore, please cancel our request for permission to alter the 9-5/8" casing program. ECEIVED Alaska 0ii & Gas Cons, C0mmJssi0~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~' ~~ j/ Title Area Dri 11 i ng Engineer The space below for Commission use / Conditions of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 GRU4/SN34 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State of Alaska ALAS¥~A jkIL A~D GAS CO~S~RVATIO~ COMMISSION C ir~-~v~'? C~v'~~~~na DATE: Septem~r 27, 1983 lO: . ~.~,~, /' FILE NO: 10SA:D2 T~RU= Lonnie C. Smith /~?~ Commissioner TELEPHONE NO: FROM: Harold R... Eawkins . ~'~.~ Petroleum Inspector SUBJECT: Witness BOPE Test on ARCO Alaska, Inc., Well Ko. D.S. 14-34, Sec. 9, T10~,R14E, U.M. Permit No. 83-133. Su/%day, Septembe..r 25, 1983: I left ARCO's D.S. 3, subject of another report, to ARCO's D.S. 14 to witness a BOPE test. I witnessed the BOPE test for ARCO on D.S. 14-34. There were no failures. I filled out an A.O.G.C.C. report which is attached. In sum_mar}~, I witnessed the BOPE.' test on ARCO's Well ~;,o. 14-34 ' that Parker Drilling performed. The BOPE test was satisfactory'. Attach~.~nt 02-001ACRev. 10/79) O&~ ,~4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Well Operat°r,4,~ ~ ~-f/~.,~A /~7~--, Representative~_~/~V ~r~jv3-~/_~ Well /~- ? ~ Permit # ~3--/ 3 ~ Location: Sec /~ ~2 R/~/,)M ~3~Casing Set @ ~J J? ft. Drilling Contractor ~,~-,f?/..fJ~ Rig # /~ Representative. 7fCiC-/-~ ~,)/~-~/~ Location, General Well Sign General HOusekeeping. Reserve pit Rig ROPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pres sure ~ ~ ~¢ ps ig Pressure After Closure /~--~ psig 200 psig Above Precharge Attained: --- min Full Charge Pressure Attained: ~ mind'sec Controls: Master . Remote ~./~ Blinds switch coverd~/~ Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves / / Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure No. flange's fl 2 Adjustable Chokes Hydrauically operated choke Test Results: Failures ,~.~7. ~ Test Time. ~ Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. · days and Distribution 0rig. - AO&GCC cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc. Post Office bux 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 9, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-34 Dear Mr. Chatterton: Enclosed is a sundry notice for the subject well. We propose to alter the 9-5/8" casing program. Since we expect to start this work on September 16, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. Sincerely, ,. M. A. Major Area Drilling Engineer MAM/JG: tw GRU4/L43 Enclosures Gas Gon~, Gommis$ion Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-133 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21010 9. Unit or Lease Name Prudhoe Bay Unit OTHER F~X 4. Location of Well Surface: 196' FSL, 1243' FEL, Sec. 9, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 6. Lease Designation and Serial No. ADL 28311 10. Well Number 14-34 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [~X 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). ARCO Alaska, Inc., proposes ~ alter the casing program as follows: 9-5/8" 47# L-80 BTC 29' MD (29' TVD) to 3000' MD (2867' TVD) 9-5/8" 43.5# L-80 BTC 3000' MD (2867' TVD) to 5080' MD (4349' TVD) 2ozo/ ~/~/A ~-~'J 9-5/8" 47# L-80 BTC 5080' MD (4349' TVD) to 11125' MD (8625' TVD) ~¢~/~ There are no additional changes to the casing program. Estimated Start: September 1~, 1983. Alaska Oil & Gas Cons Commiss/or~ Anchorage 14. I hereby certify that~he foregoing is true and 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 ORIGINAL SIGNED BY LONHIE C. SI~ITlt Approved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 GRU4/SN22 September 2, 1983 Mr. Mark A. Major Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaskm 99510 Prudhoe Bay Unit DS 14-34 ARCO Alaska, Inc. Permit No. 83-133 Sur. Loc. 196'FNL, 1243'FEL, Sec. 9, T10N, R14E, UM. Btmhole Loc. 276'FNL, 331'FWL, Sec. 11, T10N, R14E, UM. Dear ~. 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 amd a mud log are not required. A continuous directional survey is ~equired as per 20 ~JkC 25.050(b)(5). If available, a tape containing the digitized log info~rmatio.n shall be submitted on all logs for copyin~ except experimental logs, velocity surveys and dipmet~r surveys. M~ny ~ive~s in Alaska and their drainage systems have been classifi~ as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the re~lations promulgated thereunder (Title 5, Alaska Administrative Code).. prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, L~apter 70> and by the Federal Water Pollution Control Act, as amended, Prior to commencing operations you may be contacted by a representative of the Department of Enviror~enta! Conservation. To aid .~ in scheduling field work, please notify thi. office 24 hours prior to c~encin~ installation of the blowout Mr, Mark A. Major Prudhoe Bay Unit DS 14-34 -2- September 2, 1983 ;. _ prevention equipme~nt so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing.equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Verx truly yours, Chairman of Alaska Oil and Gas Conservation Co~ission be~6..H/A Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environm~ntal Conservation w/o encl. ARCO Alaska, Inc. Post Office B,... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 23, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-34, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 14-34 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we expect to spud this well on September 19, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. M. A. Major Area Drilling Engineer MAM/JG4/L35:sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ~ ALASKA (J,L AND GAS CONSERVATION CO,.,MISSION PERMIT TO DRILL 2O AAC 25.OO5 DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] SERVICE [] STR~IGR~HIC DEVELOPMENT OIL [~]( SINGLE ZONE II(IX DEVELOPMENT GAS [] MULTIPLE ZONE [] ',~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 196' FNL, 1243' FEL, Sec. 9, T10N, R14E, UN At top of proposed producing interval 270' FNL, 140' FEL, Sec. 10, T10N, R14E, UN At total depth 276' FNL, 331' FWL, Sec. 11, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF etc.) 69' RKB 6. Lease designation and serial no. ADL 28311 9. Unit or lease name Prudhoe Bay Unit 10. Well number 14-34 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 5 mi. NE of Deadhorse miles 331' ~ TD fr/ADL 28312 feet 14-33well 118' (~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 11945' MD, 9205' TVD feet 2560 09/19/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3378 psig@__~ Surface KICKOFF POINT 1400 feet. MAXIMUM HOLEANGLE 45 oI (see 20 AAC 25.035 (c) (2) 4129 psig@ 9205 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole tO" 7-1/2" ~'2-1/4" 8-1/2" Casing 20" 13-3/8" 9-5/8" 7'! Weight 91.5# 72# 47# 29# 22. Describe proposed program: ;ASING AND LINER Grade Couplingl Length H-40 We1 ded I L-80 BTC J L-80 BTC 111096 ' / L-80 BTC / 1120' SETTING DEPTH MD TOP TVD 81' 30' I 30' 2752' 30' I 30' I 29' ~ 29' 10825' 18413' I MD BOTTOM TVD 111'1 111' 2782'12700' 11125'18625' I 11945 ' ! 9205 ' I QUANTITY OF CEMENT (include stage data) 1805# Polset 2000 sx Fondu+1000sx PF 500 sx G 1st stage 300 sx PF 1, 2nd stage 400 sx Class "G" cement ARCO Alaska, Inc., proposes to directionally drill this well to 11945'MD (9205'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 ~ested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety ~quipment 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 14-33 will be 118' away from DS 14-34 at the surface. It is also 195' away from DS 14-34 at 2278' TVD. There are no other wellbores anywhere down hole closer than 200' to DS 14-34. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~~ TITLEArea Drilling Engineer The space below for Commission use DATE CONDITIONS OF APPROVAL Samples required I~YES I~NO Permit number APPROVED BY Form 10401 Mud log required I~YES ~4~L© Approval date Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE September 2, 1983 by order of the Commission Submit in triplicate ANNULAR ] PREVENTER -' L...I SPOOL ~_~---~ BOP STACK DIAGRAM Accumulator Caoacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 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 charging off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and [200 psi remaining pressure. 13-5/8' BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing 1 iquid. Z. 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~l screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3; minutes, then test at the high pressure. 5. Increase presure to~O~i and hold for a minimm of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close topop se:~_~_set f pipe rams. Increase pressure to~[_~O and hold for at least 3 minutes. Bleed pres- sure to zero. Close valves directly upstream of chokes and, open chokes. Increase pressure to SO00 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rahs 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. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. [0. Bleed pressure to zero. Open bottom set of pipe rams. 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 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. [5. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform comolete BOPE test once a week and functionally operate 8OPE daily. Rev. 5/13/81 ~' C,: c L O' '. ; ~ ' SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC'. IO" HYD. OPR. BALL VALV1E ../.....,---WELL BORE (SEE DETAIL) IO" HYD. OPR. BALL ,, VALVE I ALL 90° TURNS ARE TEE" CUSHION I ., RESERVE PIT AREA NOTE · FLOWL INE DR ILL ING RISER 20" 20O0 PSI WP ANNULAR PREVENTOR ~{O" DIVERTER LINE Valves on diverter lines open automati cally when the annular preventer is closed. -- DR ILL lNG SPOOL IO" HYDRAULIC OPERATED BALL VALVES "DETAIL 202601020; \, 3?. /2.92..' IZ. 4~' I0 I0 ! I II I AtlanticRlchfleldCompany MAP L0oA'r'lOk~ 5 J I...o~J~ : /48° ~5' o5."/5'7" '"''-~.; ~"~ """L.'t "~, ~3' ~_ .' _ '', %.£(/% ~ . ...~ : ,~ _ _~ , .,,~. ; ,. r.,: :, t. ~: ~: ,. ................... ,- i V' F t'~ t. A'r' : -~ o' / 4: 3o. ~% '~' '~.'~~ ' ~..., ~o~. ,,~. ~' o~ ~ o~o" ..,. '. , ~ .'~ ~ (...~ .' ..,......' .. /~:~-uu & ~as Cu~i,:._. Cu~iuu~:;.;'os.i I I I ~ I I I~1 ~'"z '~'-' As¢ zoN~ ¢ %00000 10000 1000 PERCENT HATER DAILT GAS, HCF/DATXIO4 O0 50 O lOOO lO0 10 · :::::. :-~'~!'~:i':!: :.:.-i.::.!::: ..... ' .... ::::~ l i.~i: ::~.: :.:\' ~ii '-~ .... ? .... "-' I I .- ~'=;::,':;-; i;;..!. ; . ; ; ' , ; _ ~ '. ; · i ! i / 1..I... ~. :./.--, - - · ' ..: · : i-:. :. ; : : : -':::!!!i![~i -. !!:-. ":~ -- - i' 'i .-' ...... '"' ' :~ -r-'j"::i .--:~:] '-:':' =:": ':: :-:" r-::-.-:--; !'_i-: ii :~-:.': :--7 ;' =::-= I':: :'.:-: :' :.-r - ii!:. .................~l :=-7:~.:i::: "'! '= i:!] -'...:~' 7'~.=.-L''.-::-'' , ............... i~.'-: '" -- ,".:.::' 7-; .=" . ..................... I00 I CUMULATIVE GAS, MCFXIO8 1 lO00 lO0 lO !:- l:--.l::; :1::;: 1 1000 SO0 0 lOOO NO. OF PROD. HELLS 100 10 DA~,~--OIL OR HATER, BBLS/DATXIO4 1 lO00 100 I0 CUMULATIVE OIL OR HATER, BBLSXIO'7 CHECK LIST FOR NEW WELL pERMITS Company ·., Lease & Well NO,. ,!~' ~/~' ITEM 'APPROVE DATE _ _ (3) Admin ~ ~-30 -~O ~(~t-~u 11) le me 3. 4. 5. 6. 7. 8. 9~ 10. 11. YES NO Is well to be located in a defined pool., .......... Is well located proper distance from property line .. Is well located proper distance from other wells ... ' Is sufficient undedicated acreage available in this ~'].'1~::::::::i~ f~- Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-daY wait .......................... Does operator have a bond in force .., ............................... ~'~__.__ Is a conservation order needed .................................... ~. Is administrative approval needed ................................... REMARKS (4) Casg ~.~.~, (12 thru 20) (5) BO PE ~, ~_~, ~-~ (21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ..., ..... ~ Will cement tie in surface and intermediate or production strings ... ~_ __ Will cement cover all known productive horizons ..................... ~ Will surface casing protect fresh water zones ....................... ~ . ,, Will all casing give adequate safety in collapse, tension and burst.. ~.~ Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~-~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: 0 ~-~ 0 Geology: Engi~e~,er..ing: H~-~'~- LCS~ BE~/ WVA rev: 12/06/82 INI;rIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of The history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effod has been made to chronologically organize this category of information. TDT DATA LI~TING COMPANY : ATLANTIC RICHFIELD COMPANY WE[,~ : 14-34 CO~NT¥ : N, SLOPE STATE : ALASKA COUNTRY : USA ~EFERENCE: 000070105 CONPAN.Y, : .~?I',AN'i;TC RTCNFI£LD WELL : 1 .4-t~ PAGE: 1 )EP~W nA$SI PA.SS~ PASS] P.ASS4 PA$S5 PASS1 PA$S~ PASS3 PASS4 PASS5 PASS1 PA$$2 PASS] PASS4 PASS5 RVE. &VE, 11853 [1859 22.77 t1851 45.73 22 75 34.48 11850 14.88 92.15 15 2715..O5 11849 15,2R 14,82 16,15 J0,7~ I~ O~ J4,89 ~1848 ~8.7~ ~5.4~ J5,32 J7.3~ 12,49 ~7 9~ ~5.26 14.63 NEAR FAR GAP! GAP! GAP! GAP! GAP! CU CU 43 07 12,85 1.3 20 72 75 0 o 14.87 10,2 18.4 0 4 21.61 22.75 13.6~ lg.~ 18 ~ 306 6 29 9 0 J. 9,5g 19,7 18 4 306 6 !2,86 19.2 4 ]06 6 29 9 17 13.56 99 15 48 O5 89 6:2 26 14.75 686 11847 17.99 !7,47 , !6:2l 1 78 18 11846 ~8'10 19,27 16,94 17 11 15.55 13.72 15,38 ~:84 10 2 18 11845 !9.0~ 17.8~ t6.44 1.6.11 ~7 40 1.5.28 t4.10 15.63 1,4,00 15.38 11844 1.9.54 17.2I 16,60 15'78 17 27 !5.20 14.59 15,20 14,85 X1843 18,75 16,43 18,72 18,69 1.6 83 15.37 14.93 14,03 15,81 14.96 19 ~ 18 1184~ 17.38 lfi'35 !7,35 t. 9.4t 18 05 11841 1'?.6~ 16.93 17,49 1.7.04 16~79 15.03 14 96 15 10 15,36 15 O0 19 2 18 X1840 17.80 17 08 18,30 17 25 16 83 15.03 14 19 14 24 1],67 15 76 19 2 18 11839 !.9,86 !b 36 ~8,60 t1838 21.27 17 15 21,25 1.8.44 16 .1837 18.83 17 85 18,79 18,8~ 15 836 1.8,47 17 69 19 11 19,54 1 835 18.46 19 68 iB O~ ,.7.90 17 11834 1~..1, I~ 87 ,7 18 1.6.43 18 1183! 17,91 17 1~ 17 36 16.81 ~0 I1832 17,21 !.8 36 17 33 18.77 t1831. 17.21 17 t7 16,54 1.7,85 18 11830 17,36 1'7 35 16~50 17o85 11829 17,36 17 35 ~0.07 ~7,74 19 1.6 71 14'78 14 34 15 12 I4 15 80 15,06 14 68 14 85 15 17 15 84 14.63 14 74. J4 18 15 96 !4 72 15 44 15 46 lb 21 15 27 15 4a 15 46 15 27 14,75 17 29 19 56 19 2 18 40 20,6 19 21 19,6 19 63 19.1 18 I5 18.5 61 20 o 20 35 18 7 19,0 21 27 18 7 lg.~ 19 306 306 306 306 306 306 306 306 6 29 306 6 29 306 20 5 29 6 29 ~o 6 29 9 6 29 9 6 29 9 6 29 9 29 9 6 29 9 9 9 9 9 7 $ 0 ? 4 4 11828 11827 11826 ti:B"2B 18 11821 19 71 20 1182~ ~0,72 18 1182~ 19.21 19 72 18 118 .~. 61 18 11819 10,96 18 1t8 9 85 1181~ I~ 27 2O 11816 t8 05 20 li815 ~9 !. 814 ?1 11813 22 11812 ?0 1:1811 23 1180~ 18 11808 ?0 11807 19 11806 ~1 118O5 23 15 17.35 90,40 18.19 18 30 16 66 17 77 20'24 19,50 21 49 15 19 19 96 ~1~50 ~1.5~ ?1 49 ~5 8~ 18 9~. ~0,41 I7,~8 ~0 24 i7 O~ ~1.19 17.75 1.9 27 16 72 18,55 63 ~8,55 66 65 18,~8 10 19, 6 07 18.21 oo 15 03 16 63 16 08 17 60 17 lto40 18.30 ',7 69 '6 16.2q 19 96 15 . 18.00 21 99 ~6 32 16 18,07 22 32 16.22 16 19,47 22 52 16.85 17 19,91 20 04 !6 30 15 70 1.9 25 91,13 20.40 ~8 15 17 40 61 22 90 20,97 20,09 18 46 19 (>~ 16 88 22 24 21 33 1.8,83 21,44 18 b5 16 32 30 86 ~3 96 ~4,96 20,00 21 bO 21 6~ 21 25 19 19 27.32 27,83 18 46 22 47 1~ 20 16 77 19,7~ 27;0~ 16 30 15 24 17 05 18 05 1.9.47 19,60 15 33 16 04 16.79 ~8,0~ ~t,85 ? 19 41 20,33 22 93 1 . , ~.~ ,.47 17 q 19.65 ~3.43 ~5.33 18.13 17.b~ 17 46 15 54 16 07 17 50 1,~ 96 71 15.80 16 IR 17 30 !6,08 16 '6.1 17 65 15 ~ 15 78 17 44 J, 5 . 94:16 93 ~7 4! !6 58 16 58 15 41 14 23 15 55 ~5 95 ~5 68 ~6 25 16 77 17 85 19 46 1.7 86 18 · 43 I7 68 18 96 ~1 80 ~1,21 23 25 17 77 ~3,19 19 43 15 58 17.10 17 35 15 69 I6,90 16 96 16 75 !7,15 16 3~ 16 94 17;40 17 5~ 18 86 19.18 18 55 lq 4 ,g 20 27 15 7 19 55 I~ 0 19 57 14 4 17 · 86 15 71 16 8 24 6t. 17 ] 9~ 18 8 81 23 6 29 ~3 36i8 35 3 27 ~ 28 96 27.~ 35 · 75 50.0 50 7! 48 9 52 ~ 6~ 7 30 2S]4 31.1 36 6 27.6 33 60 42,1 50 54~ 35 58.0 7~i5 73,8 19 22 30';8 20,9 26,8 29;4 25,2 25 2 34;:1 27 31,6 25 3.0,9 3~ 37'6 42 46,0 359 44,0 40 I 38,9 6] 5 55,8 62,1 44,6 39,4 34,5 22 33 31 3! 3! 30 33 3! 24 2'7 31 ,24 2 2 $9 6~ 0 0 t8 0 19 0 i9 0 18 017 0 17 0 17 0 19 28 54 15 20 37 60 15 03 80 15 03 86 14 78 27 15 06 46 I5 56 11 I5 31 91 15 48 21 i5 52 21 15 2~ 6,00 1 7'69 6,79 i5,75 6,32 8. 6"22 2~ 6'85 05 ~'30 79 7,40 I8, 65 63 18 29 32 21 60 63 18 24 15 ~ 04 I6 44 27 16 47 69 17 68 C('tb, iPA~ ". ~Tir,AN][~]rc RT. CHFT~LD CDNPAN¥' ~ELb : 14-34 PAGE 2 o3 oASS4 PASS~ PASS] PASS2 PASS3 PASS4 PASS5 PASS1 PASS2 PAS,53 PASS4 PA,SS5 AV AVE, ~'D~R MEAR NEaR WK~R MMAR F~R FAR F.~R FAR FAR NEAR FAR FT C[~ Cf! CU CU CU CII CLI Ct~ Ctl CH GAPT GAPI GAPZ GAP~ GAP1 .CU CU 76.2 78 7 73.1 71 66.1 74 58.6 60 50 3 49 56 8 62 66 0 70 59 0 66 537 59 55 B 60 590 61 60 6 64 55 8 59 56 ! 54 * 6O 56, 54,~ 5455 53,5 59 53'9 59 52'9 56 52:! 61 57 62 59, 59 55 56 55 53 58 i 59 58 59 60 59 31 27 24 ~2530 ~ 7 33 ~3 8 2~ 3 24 27'2 25 ~ 29,7 39 4216 49 9 51;0 55 56,.8 59 ~ 63,6 40,0 46~3 3 2 3 3 1 9 o 2 6 3 80 52 68 66 62 58 59 59 66 69 66 54 60 64 60 60 5~ 59 63 50 6{) 2' 28 $0 210 57 20 30 74 57 30 ~2 86 35 6 23 36 67 76 37 86 89 35 73 92 ~ 76 29 ~ 65 67 9 54 ~ 3 95 i 54 73 ] 26 45 ~ 39 76 ~ 4539 95 ~6 95 40;29 42,95 46'32 46,20 42,23 40,89 42,92 39,:54 37;70 21'79 17'04 15,65 16~16 ~5,33 14,75 '14,27 1:5,.27 !6~44 $6,79 17-02 14'46 57 14.69 86 ~6,86 54 ~;44 04 ~7;40 30 I9.16 1:~ 22"52 67 20,85 Cf~,'~A~UY .' t~TLA~.!TTC R.T. CHF]ELD w~Lb : 1~,-34 PAGE 3 )EPT~ PASS1 PASS? PASS] PASS4 PASSB PASS1 PA$$2 PASSB PASS4 PASS5 PASS1 PASS2 PASS3 PASS4 PA555 AV£, AVB, FT Cf! C{! CU CU CiI C}! CU Cll Ct] C{! GAPI GAPI GAP] GRPI GAP! CU CU i1755 16,13 17.44 ]8,24 ~7.27 26.61 ~6.99 15,76 14 79 15.62 15.98 12.5 26.1 24 3 25 4 30 13 16 11754 17,47 17.66 ~7,3, ~6.29 19,2~ ~4 99 15,05 14 95 15.22 15.0~ 12.8 19.0 23 2 24 ! 27 47 14 i1753 ~9 04 !6 8R 18'49 16.27 18.85 15:88 16,25 ]~60~ 14,98 15'2~ 15,2 10,! 21 0 26 9 28 04 15 1175~ ~9:33 18:6] 19.40 !7.90 !9.50 ~6,3~ ~5.69 ~5 6q ~6.09 15.26 15.0 2~ 8 25 5 25 7 26 21'83 20 99 19.77 18 97 20 68 20.22 20 49 45'I 54'2 59,2 50.9 63 ~0.9~ 21 63 ~2,10 33 40'~ 45.5 54,4 50,8 ~1743 ~,90 ~5,44 ~.83 ~2,47 ~0 21 ~0'77 ~2 58 20 44 ~0,3] ~0 60 29~ 40 0 46,6 44.0 47 ~174~ ~3,60 ~3.0~ ~.00 ~3.50 20 58 20.55 20 47 19 69 19,4! ~0 24. 26.0 ~0~5 4~.] 11740 ~4.35 25,82 ] ~. 1 19 99,61 ~2 70 ~1,22 ~2 11 24'40 ~3,69 ~2 21 50.5 48 6 54 0 6]i~ 58 11739 31.07 31,32 33'61 34,17 73 63 24,29 27 33 ~9,04 31'24 27 19 56 7 55 4 63 6 66 67 173~ 41,45 37,07 34,73 35.17 30,16 ]0.86 31 18 ]2.92 30,69 30 68 58 ]. 61 4 64 8 67 ~ 66 6 25 9 2 .- !6.36 {7 41 18,25 ,.5,30 13 53 '4 54 13,06 13 14, 20. ~ ~ . 28 li731 18,29 18,66 ~.7 O0 24 50 5 O0 16.90 !6.41 16 1! 16'B6 !6 O0 11 1 19 9 2t 3 22 5 30 18.29 16 11730 !7.07 19.04 !8 15 25 38 6 86 ~4,85 15 74 ~6 44 17~07 16 6! 13 ] 1~ O 21:3 22 5 27 17,07 16, 15 1!72~ 10,50 15.71 18 15 I .i 80 20 33 1 70 I~ 30 16 44. 1.3~56 14 .48 12 2t,3 29 5 17 24 5O 1':'I727 2543 2'4 4 28 724 ~6'79 17,4) 1.7 21 1.6 80 ~7' b9 I5 24 ~4,25 15'29 13 71 12 . . i9' 31 16,79 15 11717 t7.~9 16.63 1.5 90 t7 19 16 44 14274 I4 53 14 63 ~.5,30 I4 55 11 9 16 ~ 2!,3 23 2 25 17,.29 14 .65 !6 11 17 40 t4 2215 48 1.4 38 13,68 t5 05 1! 5 17 1 18,1 2.99 :i4 11:5 0 19.9 11 . . 8 1 8 !400 15 56 15 75 '3 27 14 6] 0 6 ~ 0 3 ' !i71] 18.25 11712 ~8,58 ~9 38 16 40 4 8 '16 24 15 65 14 29 15,69 14 63 12,~ 17 ~ 17 :2i, 18.58 16 11709 i8.30 16'86 16,7~ !7 lO 19,99 15.24 13. 53 1~ 54 13.9i 15 38 10,3 !. I 1~u ! 18,30 15 11707 ~6'65 ~6'40 ~@.32 !6. 21. ~. 63 ~4.6$ ~ 77 ~ 23 i. 4,06 14 88 1 ~ 13 7 18 i ~ 16,65 ii 90 O; 07 '!' 71 o= 99 02 88 82 77 94 '/7 55 2 29 86 O6 39 61 85 51! 70 9'8 30 18 69 57 $0 '50 ,00 24 04 CO~iPAN¥ t aTT~ANTTC RTCNF.TE[~L) CONPAN~ W£Lb : 14-34 PAGE 4 JEPT~~ PASS! PASS? PASS3 PA$$4 PASS5 PASS1 PA$$2 PASS] PASS4 PASS5 PASS1 PA$$2 PASS3 PA854 PA$$5 AViA AVE ~R NEaR NEaR NEAR NEaR F~R FAR FAR F~R FAR NEAR FAR FT CII f!l CU fl.i CU Cl! Cl! C!.l CU CII GAP! GAPI GAP! GAPI GAP! CU CU ~1705 16.57 16:5 .1~ 17.6q 17,8~ 15 ~ 14 14 15 29 16,16 14 49 17 14 92 [1701 18.35 ~8 3~ J8 04 17,93 17 57 J6,08 16 5~ 15 50 16,7! 11700 J7,27 18 11 16 75 19.$5 1,7 58 16,02 15 29 14 73 15.74 15 28 11.4 [1699 ~8,33 18 8~ 16 93 ~9.25 16 57 J4,53 ~5 78 J4 74 ]4,49 14 58 [169~ ~8.6~ ~8,6~ 17 54 ~9,1! 16 75 ~5.00 15 03 J4 77 14.48 ~4 42 13.& 20 [1697 ~7.15 ~7.1) 17 08 19.10 !8 83 ~5.04 1.5 41 15 1~ 13,63 14 03 13,6 19 [1696 !0.25 17'8) ~7 85 20.57 ~9 4! 15.07 {5 66 15'17 14,49 14.49 12.6 ~7 [1695 ~5.83 1.7,40 16.00 19.~6 20 71 15'25 ~5 86 15.46 14,9) 15,14 16.1 19 [1694. ~.5.24 ~6.54 15.81 18.33 ~6 60 ~5.~ ~4 9Q 14.89 14.34 14.49 [169~ 15.5~ 17 38 15.17 1.5.50 ~6.74 14,90 14 3~ 13'91 13 06 lO.O 15 97 ~4,44 14 60 ~4 06 13 42 1).8 16 60 ~3,80 14 33 ~4 04 ~4 49 10.6 18 ,45 13 ,44 13 i1692 15.77 !7 02 16,47 17.60 17 11691. !4.54 !6 40 !6,93 16'88 16 11690 !4,70 16 33 ~7,11 14.49 ~.6 11680 15,46 1.7 38 1~.56 16.10 i7 i168~ 15,84 1.9,00 16,24 15,43 16 11687 ~5,4~ ~0,16 19.36 15,54 ~7 11685 ~7.,35 16;55 ~7,33 16~35 14 i:1684. 20.13 18,86 1.7,52 16;35 1.5 II683 19 50 17~72 16,25 17,43 18 i168~ ~.~ 90 t7.44 15.3B 16'?! i1681 16 30 16'00 17.91 19.20 17 :25 14 04 96 15 ,12 14 42 t, 5 5~'14 44 14 49 14 49 t3 57 14 27 11!1680 ~5,i9 16;2~ 18'79 17 46 ~7 83 X3 49 679 ~.7,47 17122 18~79 !7 77 17 83 i14 57 I4 11677 ~.6,82 17,88 16,79 ~6 74:15 26 13 97 ~.1676 1.7,91 18~25 ~6~77 16 24 15 35 14 70 14. 31675 18,9I 1.9.~1 16'47 16 24 17 07 ~5 36 !5. i1674 ~7,5~ 18,22 ~.6'93 16,43 t8 04 14 86 15. Ii'67~ ~8'0~ 36'90 !6255 17125 38 11672 16,27 16,15 ~.6,04 '1~7, 36 18 21 1.4 96 11671 16.43 ~5~46 ~9,35 17,58 1:9 19 11670 16,32 !.5;45 19"35 1.6,46 ~8 4 [1669 !7~61 15~90 ~.6,68 ~.7.18 16 7! 13,~7 13.05 1.3 [1668 ~8"61. I6~27. 15~73 ~5103 ~1667 1.7.21 ~.6.~3 ~6,50 14.92 I6 16 ~5,29 ~4 1!:1666 17.04 16.32 ~7.47 t4.47 18 85 15i17 15 ~1665 16.47 ~:5.79. ~.8~47 15'81 I8 15 ~.5'03 ]3 ~1664 ~.6,69 20.~5 !9~38 16~85 17"44 14':80 I4 X~663 ~.7,16 21'58 1~.99 16.16 ~6.33 t4W56' ~4 ~11662 i6;.96 23'32 18,~9 ~6,63 11660 79,2i. 23,37 !6'93 ~7'43 ~6.50 ~.4,67 16 ~1659 18.67 ~7.93 !7,49 75;32 ~7~08 1.4;38 ~5 11658 ~8'5~ ~5'67 ~S.54 ~5'60 ~5,66 ,2~ 15 ,85 14 ,48 1,4 64 ~4,94 15 .5X 14 07 13,94 15 78 77 15,1~: 15 67 08 13.:60 14~.73 SS 14,17 78 I4,!7 i4~88 16 58 14;25 16 79 ~4,96 15~07 15 28 34'6] ~4~79 14 23 14,.44 !3 83 56 ~4.35 13 83 38 ~4'38 14 14 88 33,56 ~,4 09 06 11'5 18 70 ,4 42 15.0 18 83 13 02. 15,2 1.8 07 13 .43 !1,2 11 13'14 13 49 12.7 15 11 13'94 1:5 02 16,2 17 17 4 21 lli 16 :0 14 20 06 14 78 13.27 96 1435 12.45 1.4 42 13 82 {.3~53 ~4 96 14 67' 14'78 1.4 3 77 79 4~ 74 84 6 II 18 3 12 16 85 13 2 15 29 O 36 27!3 32 20 3 24 18.0 22 15.5 17 16 16 19 20 17 18 7o 25 27 ,ti 23 7 2 20 .5 0 2 24 1 22 21 0 20 214 23 20 0 28 20 5 24 226 2O ~ 20 ,~ 2? 27 6 22 ~ 2~ 2! 19 4 25 I8 0 22 21'5 24..4 20'7 24.4 8 26,57 6 32, 5 3:{,4 3 32.5 9 3:{ 4 7 ? $ $ 29 37 37 29 3O 25 25 25 25 28 29 2~ 2~ 2~ 1 66 16 25 15 15 04 I] II o? 25 90 77 {4 44 54 13 8O 70 13 68 46 13 4~ 45 O1 06 1 ° 9? 4 24 4 O) 13 49 1457 13 97 ~470 15 36 14 86 36 O~ 15 80 4? ~5,03 68 ,196 14,,56 6 14,36 52 14'06 COMPANY : ~Tt, AMT!C RTCHFIELD COhPAN¥ PAGE 5 )EPTH PASS1 DA,.$,,. PASS3 PASS4 PASS5 PA$$1 PASS2 PA$,53 PASS4 PASS5 PASS1 PASS2 PAS~3 PASS4 PASS5 AV AV NEaR WEaR NE~R NEAR NEAR F~R FAR F~R FAR FiR NEaR FAR PT C{] CJI C{~ C!~ C{] C{{ C{} CU CU Cll GAPI GAPI GAPI GAPI GAPI CU CD [1649 17.1~ 16.93 !.7,24 15.53 !7 08 ~3.38 13 [1648 1.5.9g 16.04 !5.81 15.55 15 35 13.30 13 [164716.8315,1126'1516.65160713.8514 [164617'2414,9017.2414'931'7'2413,7813 [1645 !'1.24 !5'2417.2414,5516.3913.7813 [1644 !5,7~ 14'9917'7214.1316;1113"3514 1164310.2416,631.8,3616'8616,1124,8114 i164~ 17'19 ~7'02 27.90 16'69 16'07 14,46 1164~ !7.6e 16.02 1.6,3~ 17.44 26,08 !5'4~ ~5 11640 1'7,69 10,I0 ~6'55 {7~2! 16;50 15"4~ 11639 !.7.0~ 1,5,56 {7;13 ~6.07 17,57 ~4.03 ~4 X.1638 17'36 16,30 1.7;10 15,43 16,90 14,07 !4 ~1637 ~7,7~. 15,35 17o05 ~7~25 17,65 14.07 13 ~636 18.08 ~,5,95 1.6,50 ~7.SO 1618~ 14 1~635 1.5,76 25,95 16,50 ~7,74 ~6~15 141~1 ~4 li634 ~6'04 16.~ 1.5,14 t. 7,9~ 16.05 ~4,41. 1163~ 1,~'8~ 18,5~ ~5~75 17,15 15,90 ~4.2~ 14 ~163~ t7'6! 17,57 16~71 16 85 16~35 23.7~ ~4 11627 !640 16.,60 1'7;83 t8 85 1576 1.4 3314 116261.6:02 !6;4~ 1:7,3.317041,604 ~358 11625 t6,96 ~5,69 !8~571:.799 !.589141712 ~162415;~415;67168~ ~8691611, 140013 [165718.9615.6719.7416.161.7.2213.9014.28 [165617.5517,3517.4324.6815,9514.2~ 14.10 [1655 !.8.30 18,27 16'35 15.65 17o41 13,90 13,94 [1654 16.40 14,91 16,27 16,55 17,90 13,56 14,4~ [1653 16.59 1~.66 18.18 1.6.33 18.40 13,47 14.85 [165~ !5.24 15'99' 16,18 15'51 17 I3 13.66 14 76 14 O1 14 BO 13 650 !7,24 15.7~ 16,27 16,22 !~ 43 !3~83 13 38 1.2 99 13 '0~ 14 13 t3 51 I3;51 11 13 73 14.00 15 10 13 78 14,36 13 81 13 51. 1~,10 12 24 13 5! 14 '17 .67 3 9t. 1,4 O~ 4 15 14 10 6~ 15 17 14 17 I4 88 13 53 ~3 14 21 66 25 53 14 24. 15 60.14 24 14 II62~ 1.6,07 I6'6~ 17.41. 16 15 1.6.86 ~1620 15~28 ~5'49 ~.7'13 16 57 !6 77 14 O: 13 80 I3 ,4 'RI 1: ].,'I617 i4'.99 17~69 26.55 !7 68 ~.7 2 14,~9 {14 43 13 1:1616 1~ 9~ ~6.52 !7~86 15 2~ 17 ~ ~3'~6 I4 98 1 11612 ~.5'49 ~6235 1.5,99 1.4,78 !7 It 13,51 13 46 !.3 1i61t 15,28 '5'99 15:69 ~5:32 16,27 '3,.43 '3 27 11610 1~'92 .~:55 ~4~73 ]4.50 ]6'57 !.3-00 12 90 13 11609 !4.94 1 1I~ 1.3157 ~3,56 ~.4'08 ~2:5~ 12 78 12 !,2,83 13,56 13 54 144 1¢.21 13.41 !4 O0 1213 20 2 21,2 20'5 20,3 t. 3.45 14'2! 13 86 13 5 16~4 22.~ 22 12.99 14.63 !.4 38 1410 16 4, 20.. 21 14 08 13 B, 13 42 12'9 18.7 21,9 2] ,16 1.4 13 70 14,3! 13 52 14 59 11 1.5 60 14 8t 14 74 14 79 15 16 15 87 1.4 18 15 56 13,17 14 56 13,17 13 76 13,97 60 1.3'88 1.3 92 14;67 14 24 ~4.74 !4 09 !4,,7~ go g 5 17 4 20.~ 23 65 1016 18 7 21. 2:5 50 13'2 17 5 20.~ 25 91 12 2 19 2 23.2 22 o4 to:o 18 6 20.0 26 83 10.6 16 4 18.0 23 52 12.s 15.5 23 O0 12.5 18 2 54 11.3 18 4 11.6 lg 0 12,5 15 42 ll.6 16 8 18 21,3 28 26.0 24 27 6 2~ 0 26 6 27 23' ! 26 5 , 25 26 3 21.2 22 26 6 19.4 2'~.B 26 9 9 26 ~8,4 28 15,1 4 26 ~ 29,3 28 3.6 lB 2 23 22,8 26 13 14.2 18 27 3 ,15 1 3,10 10 86 13'4~ !1,74 12.3 16'0 21;5 21 5 25 .37 12,24 1 .55 1.2.6 14,7 18 2! 8 28. 96 13,90 55 !4 22 18 Il ,o 56 69 13 42 24 17 24 13 83 18 $0 83 13 85 24 13 78 24 14 ~! 69 ~ 46 4~ 02 { 42 03 36 O7 7~ ~ 07 08 ~ 28 61 20 94 69 14 97 4014 ~3 02 !3 58 961414 ~ 1 .90 55 14 13; SS 13; .4 O 1~51 1 ~,' 4~ 94 CO~iPA~!y . ~TLAMT~C RIC ~ELO WELL : 14- ~{4 PA~E 6 PA,..$3 PASS4 PASS5 PASS1 PASS2 PASS3 PASS4 PA855 AVE, AVE, ~'E~R ~E~R ~EAR NEAR NEAR FAR ~R F~R ~A~ ~R ~R F~R FT CU CU C~ C!! CU C[! Ct~ C~! CU CU ~P! G~P! GAPI G~P! G~P! CO CU 12.5 17 ] 22 1!.0 17 6 q.7 17 2 10.7 16 6 19 i1.0 17 2 2! 10.6 17,6 21 9 22 12 0 15.6 189 23 12:7 16,9 21 9 23 14 n 15,7 22 17:4 16,6 20 zl.5 14 e 20 6 23 24,6 29 24,6 22 22.0 24 22 7 30 7 23 i 25 6 29 9 29 9 30 6 26 12 4 17 13:4 1~ 1~,~ 17 1~. 17 12,~ 16 11.4 15 1~,4 17 13.0 1~ 12.6 1~ 1~.~ 16 3 23 0 23 9 22 7 23 3 24 0 22 2O 10.. I .0 20 I 11 ~ 16 9 19 g 18 5 20 , 2 26 ~ i6 6 22 ~. i7 2 20 13.5 17 ~ 20 i~.6 15? 2~ II,4 14 0 20 11.7 15 0 18 !o ~ 12 9 7.9 15 9 21 I0'.8 15 9 20 4 26 29,4 28. 9 29 28 24 28 25 24 26 :60 12 76 12 76 12 80 ~2 76 12 4 11 1 1 76 81 78 43 85 04 7! 36 17 55 84 65 6O 18 63 5 $7 $4 ! 6O 63 60 56 CO~PlNY : aT!,AN'I'IC RTCgFIELD COMPANY )EDTH PA$$t PAS89 PASS3 PASS4 PASS5 PASS1 PA$$2 PASS3 PASS4 PASS5 PASS1 PASS2 PASS3 PASS4 PASS5 AVE. AVE. ,"E~R MEAR NEaR NE~R ~!EA[{ F~R F~R FAR FAR F~R NEaR FAR FT C!i C~! CI~ Cl.., CIJ CI.i CU CI.t CU CU G~PI G.AP! GAP! GAP! GAP! CU CU L1559 14.0& 14.53 14.0~ 14,21 17.36 12.(30 [1558 14.7t J3.6q 15,04 14.1~ 14.59 ~2.15 12 557 ~4.6~ 14,~7 ~4.67 ~3.9~ 16 05 [1555 ~4.51 14.35 ~6,13 [1554 !5.67 ~4.55 t4,9~ [1553 15,93 !5.36 14.5~ [155~ t5'3~ 16 7~ 1~.9~ !6,3] 14 [1551 !5.11 17 80 ~4.63 ~5.64 14 [1550 15.61 14 96 ~4.9~ 15.47 [~549 1~,50 14 95 14.63 ~5.~ 11548 14.62 1.3 69 1"38 i5.7, 1~6. i1546 ~.5.4~ 13 31 11,06 13,6~ 11545 !6.30 1.4:72 11~55 14'06 !.4 I544 14.7~ t4,10 1 17 13.6t 11543 t. 4.44 !4.67 I 35 13.63 14 98 11542 13.38 14 67 !5.35 !3.63 13 86 11 54 1.2 11541 13.88 14 67 15,35 13'61 14 42 12 03 12 ii540 14,31 14 67 1.5,35 13~63 14 4~ 12 OJ 12 11539 13.89 15 28 1i'38 16,60 14 54 1:1 93 1! 11538 !3'43 17 40 13'60 ~0~24 11537 ~.3;86 15 79 ~5;03 1.9.96 J4 7g 1.2,~8 1.2 11536 15;67 16 30 18,54 19.35 14 85 14~24 12 11535 !7.08 19 22 19.68 22'86 16 30 15162 14 11534 18,08 ~0 16 !9,60 ~2,71 17 55 17'10 15 i1533 17,7~ 18 08 1..9,25 18,94 1153~ t5,28 I7 ]0 14'5~ 1.7,~ 19,3~ 12,99 14 i~:I"5'3 ~ 10I:3 !.5 2 i'8 ;:'6'9 11530 14'83 14 lj 14i38 !6;30 15;9~ 12,4~ 12 !.1529 J. 4~75 16.04 14,88 !~;'71. 1,6,71 12,32 1152s 15103 !5;9J~ 15~69 14,49 13,60 12'37 15;03 15 0 ~5~41 14,71 13,96 12'.17 11526 14'54 I4 0 !4~46 14'30 11525 ~5.02 I4.55 17.63 15'21 13~,23 12'91 1.2 I152~ 16'9~ 15 ~49 15 69 ~4'50 1 11523 16.1l t5 09 !6 68 t4'53 11522 iS'SS 14 7~ !.6 79 15.31 15,07 t2,83 ~2 11 52~ 16'57 !.5 40 15 52 !6,7t t5~81. ~3'37 ~1:519 16,36 1.6~59 J. 7 ;88 J6~69 17;47 1-!518 ~8,24 ~.8,15 !.7 40 16.96 1.7~68 13.46 13 1517 ~0.18 I9~25 t8.44 !7.75 15~6 1516 ~6"61 25.~5 ~9 83 20~58 11515 ~2.32 19~90 19 57 1~.5~ 18,1.9 15,79 15 11514 ~0,69 J. 7~19 t6 8~ ~7,85 18.22 :!5'63 14 11513 t8'72 ~7,J3 ~8 1:1 17~07 17~77 t5'21 5 1511. ~7,04 17,7~ 16~99 ~9.96 18'08 ,8~ I2.85 ll,S8 ;06 12.94 16,00 '76 t3.2~ 18.07 12.56 !2,99 13 27 12'71 12 13.92 15 61 !4 53 12 39 12 46 I1,84 13 ~.4.60 18 07 14:34 12~56 12 78 12.83 12 34 1.2' 97 !4.21 12 46 13.08 1.2 34 !2.6~ i2 95 12 78 14,35 1.2 61 12.31 12 4~ 12 46 13.67 13 07 11.59 12 99 1.2.78 13.42 12 07 12.3d 12 74 1.2 92 12.~7 1~ 86 12 37 12 70 1~ 05 11.8° 1! 18 12 41 12 40 11 '70 !1,87 11 71 ~2 46 12 38 11 74 1.1.88 1.2 13~00 12 79 13 I1.99 12 04 ~215~ 12 12.37 !.1.98 13 17 13.6 23 ~ 15.~ 21 0 25,! 23 13.3 19 4 23, 25 93 14.0 22 3 23,. 28 79 13'9 20 0 23.4 26 79 12.6 17 4 23 1 28 17 19,3 17 6 23 ~ 27 93 11 3 17 0 23 11:9 09 13 :4:6 i2 69 12 87 11 10 11 07 12 3~ 12 93 14 56 13 03 12 68 11 31. ~.2 30 13 78 13 81 67 !4 50 1.6 74 15 06 t. 4 06 13 79 61 1.4 11.63 12,35 12,22 12.3 18.5 21.1 24 8 26, 13.05 11.1 17.6 21.8 21 8 26. 18.8 24,5 20 5 31. 19,7 21,5 , 07 11 51 2612,06!.3,00,1 26 '2,06 13.;00 1.2 26 12,06 li~O0 11 26 12.06 1 O0 1.1 96 12'28 12,03 1.2 5 67 !3,56 88 12 50 14/13 .5'59 !3 10 16 99 16.21 15 03 1~:05 1,3,40 ! 84 12,27 6~ 12~46 j t2,75 ,2 12,96 53 ,.2'9~ Il 93 71 11.9 15 74 12.5 16 07 9.6 15 O0 !!.2 13 60 9.6 16 21 12,1 65 65 12.:. }66 44 11'7 17 93 21,~ 23 34 27,4 29 '07 23'~ 27 97 17'2 19 l0 ~3~,~ 15 :10 I6: 07 13.~3 19 09 11,4 19 47 i2'0 19 '46 10,8 93 1~:'8 93 10:5 18 93 9,9 19 ~0 9'9 14 71 14 ~ 16 33 15 4 20 iO 16 0 20 17 3 26 4 19 o 20 2 22 1 17 ~ 24 8 24 8 24 8 24 8 24 4 2O 26 4 37 2 5 2t 6 0 9 99 17 96 21 49 22 49 20 54 17 06 14 92 15 19.8 24 2~'6 25 ,~1,4 35 3~;0 31 23,1 27 21.1 19.8 1.7 18'~ 06 16.! 21,~ 25 1 25 8 19 5 2~ 6 i 23 23 5 21:;4 5 24~0 ~ 2~i2 38,0 ~ 31,7 36$4 3 22,8 2616 ,2 23,3' 2t 22,1 21;6 25 20'6 25 16;3 22 19,9 23'6 ~0 4 I3'35 12 74 }'2'81 t3 93 . 2,68 i:2 63 13'40 l~ 48 t. 4'45 13 94 14,53 15'8414 ~5,46 16 '53 14'90 14 49 t4,.07 14 75 14'1.~, 54. ~5,45 1,4 0 31 7 30 5 31 4 30 9 29 ! 29 2 31 30 30 26 28 0 26 3 30 :7 32, 3 36 '7 36 3? 0 31 6 25 6 ~ O6 12 O9 71 12 15 62 79 93 14 34 3~ 12 97 Ii 12 68 6~ 12 34 33 37 44 3 0! :10 60 9~ 1 2 97 8~ ~7 46 17 32 15, :79 ,69 15 49 14 04 14 17 COIVlPA~ : ATLA~JTIC R~C. HYTELD COMPANy wE~,h : 14-34 PAGE 8 )EPTH DA~$1 PA~$? PASS3 PASS4 DA$$~ DA$$~ PA8$2 PASS3 DA$£4 DA~$5 DA$SI PAS52 PAS&3 PASS4 PA855 AVE, AVE, ~C~R WE~,R ME~R WE~R NE~R FAR F~R F~R F'~R F~R NEAR FT Cl,) CU C~ CU CI~ CU CU C[! CU Ct! GAPI G~PI GAPI GRP! GAP! CU CU [1510 17.35 1.7.77 17.0~ ~8.60 16.04 16.54 16,25 15.54 15,30 L150o 1~.05 17.10 20.35 !.7,60 ~8'41 15.5P 15.60 14,$~ 16,15 L~50~ 16,27 15 80 ~7,91 17.5~ ~$.75 15,55 ~5,03 14.10 15,4~ L1507 18'74 16~60 ~9,(17 17.4) 17.71 ~5,87 ~4.77 L1506 19,10 t7 3~ 18,75 18 49 1.8,1B 1.6 04 16 19 L)504 18,.47 t7 27 !9,2q ~7 30 17;07 15,67 [7 L,$O3 ~6.9~ 1~ 7g ~9.1~ 16 )6 1'7.47 14.73 ~5 [1502 17.82 17 66 !6.85 16 22 16.30 14 81 !5 [1501 ~6,9~ 16 69 !8~44 17,08 16,68 14:2P 14 [!500 17,00 17 15 !9.10 1.6.6~ 18.04 ~4,7~ 14 [149q 17.3~ 16:07 ~8,8~ 16,7g 17'30 14.45 t4 [149~ 17'4~ 16.15 !9,66 18.9~ 17 14.06 15 [1497 !8,0~ ..16 [1496 !7,09, 18 [1495 )'1,55 16 [1494 19,32 t:8 L1493 ~1.2~ 17 [149~ ~2,83 1.7 [1491 ~9.47 [1490 ~8'60 ~7 [1489 15'91 17 1 48~ ~7'49 15 [.1487 16.4~ L1486 2~'50 [~485 2 .4~ [1484 20,07 19 [i483 !7~50 ~7 [i'48~ ~7.6q [1481 18'50 ~0, 29 !8'05 !8.07 16 ,43 1, b.65 16 52 1'1.52 17 0..9 1,6 6~ 16,91. 19 1.5 17 90 16,94 !8 41 15 57 18.05 19 58 16 5~ !7 04 !8 54 195 19 17 5O 18 96 2! 07 13 19 96 ~8, 88 15,71 17 61 1,5,51 17 47 !7,13 1.6 90 20.57 16 1520.11. 18 65 18 5 ~o 9~ 18,71 16 18 i66 22 !4 88 13 .63 13 1~ 13 9~ 15 B5 !5 24 1.5 69 t6 19 15 O~ 15 74 14 60 1.4 35 1:5 88 !3 9~ !4 ,43 14 23 15 ,33 1.6 08 17 .2417 63 18 2! 18 05 16 52 I5 56 15 :0'~ 15 '6':g~ i5 38 I5 70 1,5 15 15 56 14.V 20 5 24 6 29 2 !7~00 16,2 20 5 2~ 1615 16,0 2t 1 23 16.2 2O 1.5.05 15,28 16 29 6 25 t5 37 14,59 16 20 23.5 30 [1480 20'25 [1479 19;47 19:79 21 [1478 19'55 20 02 ! [1477 20'93 ~0 75 t: [1476 ~0,18 ~1 .10 21. [1475 19.08 90 1o !9 11474 18,79 ~0 2~ t9 t1473 ~8,6t 19.46 ~9 1:1472 18.1~ 19.27 !8 . 21 15 07 16 O0 15 11471 ~9.13 19.93 18.74 18,04 ~0, 11470 ~0,30 20.66 18'08 ~7,97 18.21.. 16 52 !6 1146q ~9'18 ~0,43 20,13 t, 9.49 18.08 1:6 .49 16 1,1468 19'18 18,5~ 19~60 ~9.25 19.86 t. 6 I1467 1.9'18 I8'94 ~8~93 19'07 t8,69 !6 49 t5 11466 18,60 18,55 17;38 19.4t !9;13 t1465 !9'80 t8,83 17,93 ~.9"82 17,96 15 89 115, t1464 18~94 !9.5~ 19190 18,90 I8,74 11463 18.96q !.8'54 !8,94 !8,80 18.61 15,63 14, 1146~ 19'99 18,9~, !8,50 t9~54 18,55 !.6'2~ 79 19,96 18 94 17.13 16 54 16 2. ~2 il 18,54 17.7~ t7;33 I7 ~7 19,52 93'63 ~6:85 ~6;04 !6 ~7 19.52 23.63 ~6 38 14.95 16 :~7 19,41 ~3,63 15 94 1.4 54 ~6 99 18.44 ~0,07 14 90 !5 6! 15 10 16~71 15'99 I5 69 15;99 14,47 16 SO !4,52 15.1~ 14 09 i4,01 14'6~ 14 04 14.56 14 !3 15 77 88 15' '67 14 77 14.26 14 5~ 14 14, 20 15 O0 !.4,94 13 75 14 42 14.54 14,38 13 63 ~4 24 ~4.13 14.4~ !4 85 14 43 13~61 1.5,36 14 94 15 55 13.3R !5'24 1.5 31 14.84 15,13 !.4 lO !5 s,7v 5o is: o 90 15 61 ~6,30 14 3 147~ !4,06 1.3 ~01399 ~3,61 63 1.5.09 !3,81 1,4 75 17168 15,63 !7 2 !9 4417;69 66 ~6 72 i7,94 1 95 !5 2!. !4;9~ 16 11. 1.6 33 !5;38. 15 ~zo'501515 57. 16,. ]9,47 71 17'05 1.6 ,38 1.8 49 16i~35 1.6 49 ~6 35 ~6 ~9 16 O0 ~6 7~ 1.5 03 I5 35 !4.,38 14 40 ~4.85 1~i7515 $515177 ~ 15 I6 55 1655 !5 .80 ~5 .5615'38 1.5401.5 74 15,16 15,61: t. 6 85 !5.35 16',:'19 t4 96 i5,36 16 67 iS 8 21,1 1 14.2 49 12.0 60 14 ~ 24 2 o 30 1 7 24 1~.6 24 10.o 21.2 24 18.0 25 8 28 8 33 7 3! 0 35 0 35 7 25 4 25 I 24 I 27 82 14,2 8 27 14 13 6 1 27 32 12 ~ 16 8 2' 4 24 8 16 7 21 ~ lg 21 33 14 5 16 2 21,6 24 ,4 ? o.o 29.5 06 20.9 ,37 3 74 21,2 ~2 4 :20 11 5 20 1. 22.6 7 59 15 3 19 9 ~5'0 77 25 0 3~,0 34,3 33.9 25 32 7 39;0 47'3 47;~7 44 28'7 33,6 38~2 42;2 44 19~5 25,3 25 !7'321,3 ~ i 2932"22 62'21'I 311 ,6~ 20,~ 25 84 ~9 3 ..99 18.~ 24 '25 4 29.6 6.38 i5;7 20 8 21 9 26 5' 6 86 I o 19 1o 20 10 16 :35 16 38 14 O0 i4 19 i5 50 i 5 77 ~5 04 1,5 93 15 05 15 t7'620 17,~ 25 !6 6 22 9 21. 3 21 8 24 52I 0 20 0 O : 29 4 29 2 28 2 23 6 24 6 28 9 31 0 29 '8 2.3 28 4;4 25,4 27 27'7 24,! 28 26,3 28 ~5'~ 29 6 32 30 28 30 36 29 28 29 24 26 29 29 29 5 35 30 26 29 5 ~4 28 210 35 16 54 05 15 58 27 15 55 74 15 87 99 ~ 73 82 14 81 91 14 28 O0 14 78 38 14 45 46 14 06 08 14 75 02 !3,63 1 }.94 98 8~ }~ .24 47 ~ 19 601574 91 14 35 49 13 9~ 14.23 16 08 18 .05 15,,56 15 ,70 :18 }7,19 7~7~ 0816'8~ 79 16~8 6I 15'94 49 49 ~ 59 89 941496 961503 99 16 22 COI,~PA~t¥ : ATLAIqjjT£ R]'CHFTELD COMPAk~¥ WgLb : i4-34 PAGE 9 )EPTH PASS1 PASS2 PASS3 PASS4 PASS5 PASS1 PASS? PA$$3 PA$64 PASS5 PA$$1 PASS2 PASS3 PASS4 PASS5 AV~ AVF. ~E~R NEAR Wg~R NEAR ME~R F~R F'~R F&R FAR F~R NEAR FAR ~ C~ Ci~ Ci,', Cu CU CU CU C[~ C~I CU GAPI GAPT GAP! GAP! GAP! CU CU t146! ~9.55 ~8,33 ~7,97 11460 !7,74 ~7,3g ~7,50 [1459 17.94 ~8,82 ~8,40 1145~ 18,74 19.13 17 [1457 18.55 18.54 17 3~ 18.57 17 94 ~5.36 X5 1~45R 20,60 2~,35 19 86 20,47 ~8 l~ ~6,85 16 [1455 20.86 20.77 ~0 8~ 22,25 20 7e ~7,54 ~7 [~454 2~.15 ?~.55 2i 5~ 23.60 2~ 7g [7.97 ~8 [1453 20.80 21,18 20,54 21.49 20. 8R 17,52 ~8 !1452 19,96 18.55 19.38 18,38 20,46 16,97 15 11451 17.93 '8 50 17.57 i8.15 17 75 i5,58 i5 [1450 !7.36 19 58 17,54 t7.~7 17 35 15,18 15 t144! ~l:bi 25 ~I 77 ~l.ll 20 60 t~ q { 1441 ,7 04 ~0 65 19 80 17 54 16 7~ ,& 9' 16 11440 ,6 93 18 8~ '8 08 I5 lO 18 22 13 56 16 1143g ~ 66 ~0 07 la ~, ,927 ,7 94 lV 7~ 16 1143~ 21 t 1.43'7 Po [1436 19 11435 19 t 1434 ~o 1t431~ ~0 04 19 97 20 65 ~1 97 ~0 54 ~0 9~ 20,.6~ 19 33 ~1 05 18 4621 8~ 23 82 20 86 22 52 1.9 74 19 21 21,24 19 33 t9'6'0 20 18.75 17.27 15.20 14,55 14 89 14.93 14 81. 15.1 i8.0 2~.4 25 6 35 '6.65 ,.7 la i4 50 15 22 14 53 14.84 ,4 76 2i 4 27.5 3010 34 ~ Il 42[3 35 4 49 16 25 19 08 19 08 16 27 16 ,80 !8 3O !6 68 4'3"I6 60 15 77 16 86 15 92 16 21 ~7 10 !.6 66 17 43 16,74 1.7'79 16 76 15.90 16,63 15 67 1.4.80 15 61. 15 14,5~ 17.4~ ~5 06 15 57 17 36 16 94 !7 83 17 O0 17 11. 16 90 17 11 16 90 1'1 11 16 90 ~7 11 15 90 17 1! 15 90 16 49 !3 35 1 22 15 05 18 15 18 72 17 61 15 7! 1,6 17 15 47 1.7 65 16 66 16 85 15 68 15 47 16 96 15 69 14 88 14 64 13 74 14 64 14 60 !7 50 17 77 18 27 19 52 18 77 17 74 . t7 53 16 58 17 5.$ 16 '00 15 25 ~5 04 15 30 1 58 26:2 32 86 24.3 32 35 20 O 22 60 15:~ 20 28 14.4 22 89 13,4 20 25 12.5 22 96 14.1 21 80 15.0 18 7 24 77 16 7 19 6 29 77 16 52 1 99 1 81 13 67 86 50 41 16 24 16 24 3 20 3 20 5 20 I 20 1 2O 7 22 6 19 7 24 7 21 6 22 24 95 23 0 28 70 18 5 2 31 18 8 22 4 42 5 40 7 40 3 34 9 2~,9 31 7 32 6 24,7 29 2 34 7 25.9 30 0 35 '6 3 32 3 27 9 23.3 3 23 3 29 29 29 6 25 5 26 ] 27 4 28 ~ 37 7 30 31 29 21~ 4 26 4 2t0 9 2 31 9 29 1 35 8 38 1 38 2 36 ~ 26 6 ~0 1143~ 1~ 6R 1,~ 8~ 19 16 ~8.38 11431 18 24 I~J, 30 17,75 18,25 !:, 49 1.5 11430 17 79 18 99 18,22 17.85 18 69 1.5 9, 8 20 36 19 88 ~0.91 19 O0 · 35 !9 22 15 11427 1~ 43 1~ it 1.1.426 ! 129 1.7r, 1 1.6'3~ 17 ,97 11425 I?.68 16 83 lb,29 17,35 17 43 14. 11~24 17,83 17,4~ !6.2~ 18.25 1~ 90 15. 11423 19.'7~ t7,55 17.97 t7.8~ 17 79 15 t1422 19.72 1,142~ ~9,99 '2,,1, I,1420 ~0.71 11419 20,13 20 114I.~ ~9.24 18 1141719.15'9 11416 1.9.71 11415 19,52 tld14 !7,97 11413 1.7,27 lO 19 02 20,63 60 20 27 20~5~ !9.57 19 04 19.54 1.9.44 !.9 90 i9,18 20,10 18 7~ I9~66 ~0,58 16 16 O0 16 61 16 75 ~6 2~ ~6 46 ~5 29 !5 15 15 36 1.5 56 15 02 1508 15 31 1.5 38 1.5 5~ ~6 3~ lb 16 56 14 31 14 91 16 85 16 3O 16 75 i6 80 16 ~0 17 9~ 17 63 16 45 15 lO !5 28 ~5 91 14 86 15 17 ,15 9~ 15 61 ~5 63 16 82 1 22 1~ 60 ~"1 35 1.7 43 !8 05 15 33 15 53 16 99 14 41 13 7{] 27 3{] 14 76 i5 10 ~4 ~75 13 5 16 I0 1.5 1. 16,32 16 60 16,32 16 35 15,~9 1.6 .82 15,96 !6 66 16,97 16 29 17,77 16 05 1b,66 17 3~ ~6.08 17 91 ~5.8~ !6 4 47 18 0 24 9 28 3 34 15 26,5 31 3 35 4 37 8 0 21,7 29 6 36 2 36 79 14..~ 2O '4 33 ~4,5 [9 5 30 10 17,7 22 1 27 4 30 29 25.5 29 21 27,7 3! 86 2 0 26 .4 27 5 34 30 18,,. 5 g 35 43 16.4 24 9 29,6 31 ~ 37 39 7 2 43 o 2 31 0 34 7 40 35 0 37 2 45 3 34 3 36 6 42 · l ii 55 15 74 94 55 15 60 16 86 17 ~6 36 15 33 15 57 16 07 16 55 15 04 14 93 8~ 97 16 66 15 24 15 79 15 68 1~ 83 1 7~ 15 72 16 99 16 7! 16 13 16 24 16 15 16 71 16 27 t5 29 9 50 82 36 85 54 97 52 97 58 1,8 46 49 21 99 94 68 05 65 91 56 9 25 08. 36 O2 3! 5~ $6 3 ~ 1! 27 8O COMPANY ! AT[,AMT!C RTCHFIE,r,D CC3~PANY WELb : 14-)4 PAGE 10 }EPT, PASS1. PAS82 PASS3 PASS4 PA$55 PASS1 PASS? PA$$3 PASS4 PASS5 PASS1 PASS2 PASS3 PASS4 PA$$5 AVE. AVF. NEAR NEAR NEAR NEAR NEAR FAR FAR FAR FAR FAR NEAR FAR FT CU Ct3 CU Cf! CU CU Cf,~ Ct} CU C[! GAPT GAP! GAPI GAP! GAP! CU CU L1412 18.72 ~8 41.) 17,7~ 17 54 ~8.66 [5.12 18:19 ~7,32 17:96 t8.5~ !,5.12 15.96 15.27 15.68 15 94 16 4 23.9 26 9 29 16.16 15 Il41[ 18.72 15,40 15,53 [1410 18,72 15,40 ~5.53 16,16 15 [1409 19,96 !5.40 15.17 16.13 ~5 [1408 ~9.66 !9 55 ~7,3~ ~7.96 17,40 ~6 93 16,75 15 53 16.16 ~5 [1407 i9.33 21 44 ~.90 19.30 16 82 ~:93 ~7,13 15~78 17.88.17 [1406 ~8.4] 20 5~ 19.6~ !.9,54 ~0:47 16.30 17.3~ !.7 44 17.65 17 [1405 ~7.]2 !9 24 [140g ~6'~ 15 94 18.10 16.0~ 17 $2 14 ~ 13,9~ 15 99 13.5~ !.4 L1403 ~5,71 17 19 15,35 ~.6,tl !6 ~0 13.03 13 [140~ 16,11 16.2~ ~7,33 ~,52 lb 65 15 16.90 %0.77 17.75 [.1401 . [1400 ~'t'52 17,1~ ~7 L1390 t9.80 16,9~ 15 [139R ~ 7~ !8,7~ 19.05 19.29 16 [1396 18'82 ! 46 !9 05 ~7.39 17 , 74 1.3,42 1.3 88 1,3 47 t. 3,00 13 08 13,58 !3 44 14,3~ 14 29 14,77 15 52 15,94 15 58 15.3~ 14 46 ~4,9~ 14 7 14,86 14.4q !5 25 ~5.2! 15 69 13,55 96 12.00 77 1.4 24 12,90 ?g 15 lg 1~ 74 ~ 36 20.~ 27 4 29 67 15 50 13 92 !.4 71 24,1 28 7 40 73 15 26 15 87 14 68 24.0 3t 4 37 51 15 51 ~5 44 15 17 26.~ 35 2 39 83 15 26 1.5 44 15 75 24,8 31 3 37 83 15 51. 15 44 15 40 24, .4 31,3 39 81 t5 56 14 94 15 26 ~ ~ 2].7 39 03 15 63 14 90 1.5 16 : 3 .4 33 85 ,~ 58 14,85 14 97 23'6 35 2 32 03 16~4 24,2 24 9 28 07 16'4! 24,2 24 9 28 O? 17 8 24.2 26 2 29 42 18.5 26 4 24 9 28 15 15,3 22 8 25 5 33 50 18,5 23 ] 29,5 31 05 19'8 25 4 34,7 32 46 13,8 22 3 27 1 30 57 15,7 21 6 30 ~ 3~ 44 16,9 24 ] 27 3 28 1 28 0 34 9 40 8 37 37 3 41 ~ 32 31 4 34 8 34 ~ 34 0 3t t1392 !7,72 19,24 !7 6! 19,13 1.6 [139J~ 17'80 20,80 17 55 20'18 16 L!390 ~a;lO 20'07 ~7 47 19,90 17 [i389 19~46 20,02 18 43 20,6~ 18 [138~ 30'91 ~0.57 18 63 21'35 18 [1387 ~9,90 20,19 !9 36 ~1,.4! 19 [i386 ~1~10 19,6~ ~0 10 ~9,40 20 [~385 i9'04 18,65 !~ 16 20,!I 20 [I383 19'08 t9,10 1~9 35 19,91 ~9 [1~82 18.83 16'82 t6 25 t8~96 ~.8 [1381 16'55 16,I5 15 55 19,86 18 [1380 15,86 15°63 15.55 17.80 17 [1379 15,~6 15;90 14 96 !5;35 t5 t1378 15,9~ 17;q9 !6 79 I7,79 t1377 !~;74 17'27 18.86 19.60 !;5 t1376 m..9.3~ 18,19 t9'o8~8,e5 17 t1375 ~0'97 ~0,4] 19,85 21'11 18 11374 ~3,46 21,6~ ~2,57 ~2.94 21 11373 23,58 22,25 23,18 ~2,88 22 t137~ ~8,38 17.61 19'96 18,02 t1371 ~8~43 1.7'05 ~7,65 17,04 t1370 18'2~ 18.36 20,10 ~0.72 17 [1369 20,27 20'44 18~7:1 20'0~ [1368 ~9.63 ~O'oP 18,3~ 20'24 [1367 !.8 9'7 18'7~ 20,1I 18.8~ t1366 ~7 63 ~9,24 20,11 ~8.27 ~9 11~65 18 35 18;46 90,11 19,~] !8 11~64 18 1~. I8.63 ~.9,6~ ~9,11 ~9 96 15,50 16 83 15 71 16,02 16 88 15 43 16'80 17 44 16 66 17~36 17 Z i5 16.96 16,66 16 16 !6'69 16~ 70 !.7;02 ~4,65 15 93 16,79 :14'05 ~5 57 14.i5 1.3,34 13 32 I3,77 13.~21 13 70 1'3.7g 13'47 13 $'a15 86:16 60 18 18 75 19 6t. 19: 22 19 8~ 19 O0 !7.21 16 65 !5 31 15 50 16 21 5n 17 2~ 21 16,77 16 94 1.6 25 !5 55 ~6 6!. 16 ~.6 80 15 ~9 16 9n 15 19 17 50 19 43 20 22 75 15 82 16 91 16 94 16 50 16 b60 lb 0..16 82 16 20 15,88 15 37 17.05 15 41 1.8,13 16 5 17.o8 7 1.7 3 79 16 73 I 5 166 32 1 O0 49 73 ~ 39 3~ 12 51 13 45 1 36 16 36 i0 18 13 17 66 ~0 05 1. 9 19 18 94 !.8 96 16 38 17 23 14 2I 16 11 15 91 16 04 '1.7 05 I6 08 !6 91 !5 O~ 15 63 I5 08 1.6,13 15 6~ 16.36 ~6 46 26,6 31 5 26 33 75 33 9 49 30 29 96 24 25 25 88 22 3 { 2~ 7 36 3 33 6 32 ~ 29 9 20 7 31 65 20 2 27 68 22 80 41 24 88 29 55 43 07 40 21 25 60 23 69 22 8 21 0 22 50 20 03 20 92 17 57 18 0 24 9 36 5 49 7 44 9 33 ~ 20 I 27 4 28 R 24 4 25 8 24 ~ 20 2 23 34 38 40 42 41 39 33 32 33 3! 3'I 27 36 48 39 31 32 30 30 25 2 39 ; 41 48 47 ~ 44 8 46 8 52 462 50 6 4 42 4 47 7 39 5 40 39 ~ 39 39 ,8 37 1 35 9 36 39 4 37 0 3~ 0 36 0 34 44 40 40 36 ~4 ~5 5:1 60 40 72 15 12 72 15 12 72 15 !~ 96 15 60 66 16 93 33 16 93 41 16 30 71 13 80 11 13 42 75 14 32 15 94 82 15 31 44 14 .92 71 14 486 85 14 9 80 15 50 10 16 O2 46 16 80 91 !7 36 · 04 6 99 10 ~ 69 08 02 83 i 79 55 15 86 1.3 77 96 13 7'8 92 13 7! 74 !4 5~ 32 15 8.6 97 18 18 4 82 4 31 ,63 16 61 35 16 80 .Ii i6 90 CI'I~PA~'I¥ : ATLANI'TC RICNF'[gLD CB~'iPA~'f ~gb~ : 14-~4 PAGE )EPTH PASS~ PASS2 PASS3 PASS4 PASS5 PAS~! PASS2 PASS3 PA$$4 PASS5 PA$$1 PASS2 PA$$3 PASS4 PA$~5 AVE AVE ~E~R WEAR NEAR WEAR NEaR FaR FAR FAR FAR FAR NEAR FAR ~T C~ C~! C~! C!! CU C~ C!t C[! CU CU G~PI GAP! GAP! GRP! GAP! CU C' ~136] I~.~5 ~8.9! 18,27 18,~4 18,25 16.74 ~6 24 ~6.~6 [136~ 18.21 ~8.80 !W.75 19,74 18.71 16.61 15:96 ~6,~5 [136~ ~9.10 ~9.18 1.8 79 19,3K 18 11 1.6"7~ 15,83 16,74 17,04 1.7 [1360 19.i0 ~0,~ 22 10 ~0,16 18 29 !6.71 17.40 !7.3] 17,71 ~7 [1359 18 96 90.4- 17 15 19.91 16 97 ~6 65 ~7'49 !5.05 16.8~ 14 [1~5~ 18 96 ~8.75 ~7 85 ~9.~7 16 97 ~6:65 17,07 ~5.07 1§,16 14 [1~57 ~1 79 18,52 ~7,72 18,21 16 97 ~8119 ~6o33 15,06 15,17 14 11~56 21 32 ~7,47 !7,80 17,52 1.6 97 ~8.7~ 15 80 ~5,42 14,47 14 ~1355 ~9 60 !~.0~ ~6.85 18.10 !.6.97 ~6 9~ ~5 56 ~5,10 ~4,57 1.4 ~1354 ~6 9~ !~,50 17,43 18 O~ 15 41 15 03 ~,46 ~4.50 15 ~6,8~ ~5 90 21.3 25 ! 30:6 3~ 10 25.2 27 5 30 ~: 35 77 25.2 28 1 35 0 36 85 25 3 27 8 34 ! 36 85 25 3 26 7 32 6 40 8 5 24 9 30 8 299 39 85 24 5 27 4 27 9 36 85 24 9 2~ 2 31 0 3! 22 22 16,24 16.05 21,4 26.7 29 2 34 6 33 0 35 1 36 9 39 0 34 4 34 7 34, 7 34, t7.13 t1353 16'5~ 17 94 16,79 1.6.80 17 91 14 74 14 11352 17.'72 t7~05 16,7~ !.6.50 18 1R 15 46 14 11351 17,90 17,04 16.79 16.90 17 43 15 8!. 14 11350 ~7.24 16.80 16.7~ 18.81 16 66 !4 9~ 14 1134~ ~.1~ 17,46 17,22 !7.74 17,11 14 13 ~4 [1349 !6,91 17.30 1.7,25 16,80 17.4t 14 05 11347 18,00 !8.21 17.1~ ~6,80 18,08 I4 1~ 14 11346 1~,71 18.00 17,7t 16.80 18.13 ~4 41 1.1345 17,10 17,44 1.8 20 16 S0 17,54 14 39 13 t1344 16. o 17,2 ii O~ 16 ~q 17 16 14 03 11343 ~7,44 ,6,44 16 65 lV 11 . ,41 14 O] !5 t1~42 )1.,32 ~0,80 ~9 99 18 24 17,13 ~7 90 ~7 t38 1 18.44 20 33 18,71 20 54. 15 11337 1.8 iO, 18 99 ~0 61 1.9,2~ 18 11336 20,88 21 41 ~1 58 19.5~ '9 11334 ~1,40 20 97 ~2.. 30 22'29 11331 18,2.4 18 11330 ~8,29 19 1.132o 19,25 1.9 H328 17.41 19 11327 ~,6P 17 11326 ~ ,~1 15 11325,'4.41 13 11324 !4 36 t4 11323 14 68 ~5 1132~ 15 86 15 11320 !6 74. 16 00 16.93 11319 !7 7~ 19 11317 ~2,19 ~0 6.t 19 , . 83 14 93 ~9.24 ~9 .79 14 65 ~8.35 18 74 14 13 16.33 17 99 !:,% 13 14.40 9~ 14 13 14 46 !l t4 34 14 06 25 15 IO 15 22 t4 85 ~6~3~ 15 6`1 16.82 15 50 !4,31 1.5,i0 14 34 14,31 14,60 !.4 26 14 31. 14,28 14 O~ 1,% 28 14 85 14 21 14 28 14 95 14 48 14 02 ~5 27 1,7 94 I8 38 1.9 36 17 79 17 ()~ I~'11 187 40 I. ,50 96 83 16'94 !6 69 17 .83 16.02 16 36 16 96 1.6.90 16 7416 65 15,50 3 1.2 66 1.6,10 15 41 1,2 19 12,87 14 ~ l~ 88 I.i.8~ 12 . 12~75 9 26,2 32 89 21 7 24 9 29 67 2014 25:' 29 71 21.6 24.9 29 31. 1.5~23 14 60 21 1. 25 5 29 30 15,17 14 38 17 6 24 3 27 96 14, 14 65 14.63 14 51 14 6~ 15 21 ~4 63 14 65 !4 64 14 42 14 39 1,4 47 15 19 1.7 55 1.7,90 17 60 1.8.96 19 64 17 6 22 4 2'8 99 17 6 23 0 27 3 29 08 16 , 25 0 313 29 29 47 19 11 17 7'1 16 68 16 68 15 67 1.6 84 17 33 16 43 16 32 17 '21 19 49 18 91 18 71 18 30 16,10 16 80 16,43 16 68 16.57 16 15,67 31 1.4,37 13 13,2¢'~ 12 93 12 ~I 11'0~ 1,2 ' 12'83 1'2 49 I2,02 . 3 31 7 36 31,6 34 34.4 34 6 30 3 36 6 29 5 38 ~ 44 75 26 5 30 94 21 5 22 33 23 ~ 26 25 27 86 27 05 25 91 22 55 24 10 27 75 25 56 12 61. 1:~ 88 12,54 13 35 1. 28 13 13 28 28 55 12.48 12 B5 13 14 11:~5 I4 25 34 1.7,30 15 74 !.3,85 13 99 t3,75 I ' 5 14 03 44 36 2.~,30 23,97 I 82 18,93 ~ 41. 1 96 20,91 16 71 53 87 2 ,8~ ~.57 ~0 43 18,93 18,96 I~17~ 19,69 18 49 3~ 7. ~1.43 19.50 ~4 !9 16.90 16,7~ 1.~1! 16.75 18 43 28 86 19.05 19,0a ~2 43 1.5.78 15.93 I. 30 16.57 ~6 91 43 3 29 7 30 9 28 8 ~0 ~ 28 56 15 . 6 29 43 26 4 3 ~ 33 ~ 42 6 46 7 63 6 48 5 34 8 29 9 6~ 7 4O 3 27 8 29 ~ 39 8 36 5 34 0 41 6 30 0 34 0 4~ 6 4 44. 3 33 2 33 4'/ 0 37 4 37 0 ~2 ? 78 COi'~PA~:¥ ; ATT,ANI'TC R~CNFTELD CO~v. PANY. WEI,b : 14-34 PAGE 12 )EPTH PASS1 PASS2 PASS3 Pk$$,i PASS5 PA~S1 PASS2 PA$$3 PASS4 PA$$5 PASS1 PA$$2 PASS3 PASS4 PASS5 AV~ AVE 'TEAR NEAR NEaR NEAR NEAR F~R FAR F~R FAR FAR NEAR FAR FT CU CT! CU C11 CI.J CI.I C!.I CI.I C!! C}.I GAP! GAPT GAP! GAP! GAP! Ct] CU L1314 71,15 20.~ 21.86 20.60 18 O~ 16 86 17.~0 1.1313 P5,8~ 74, ,.~ ~5.52 27,3~ 1.8 44 21~5~ 22,86 L1]l? 31,97 31.08 31.25 31,3~ 21 63 2~,54 29.11 [1311 ]6.29 34.9¢ 32.2~ 32.8~ 26 22 30.5R 29,99 [1310 25.93 24 ~? 76 O0 25.43 32 54 26.47 25,41 }.1lOP ~!~T 22,15 ~1,05 24,1~ 24 4~ 1~:6B 17.85 17 04 18,60 18 [1307 ~0 5 26.91 76,50 29.44 21. 04 2 57 23,10 20 2? 22,52 20 [1306 26.65 27,54 26,71 26,36 22 29 24.86 24~90 24 46 23 43 20 [1301 26,69 24,74 25 50 ~6.63 29 72 22,68 23 ~90. ?" 72 26 43 ~5 25 ~?,41 ~6 38 22 2? 24 [1 t129 36 t1294 30,21 22 02 21 99 21 24 24 04 17,24 19 1129] 20,77 20 97 20 97 21,21 23 93 !7,27 16 291 20,18 21 02 ~I 15 t. 9,2~ ~I 6347 1."~,50 1.~1 t 28 P 17;91 1,.9.21, !8 ll 1.5 0;93 ~5 18 14 t,::285 I4,6~ !.7.43 17 74 ,~.54 ,3.'03 ,3 t: 1:283 ~7.08 17,30 ~7 65 ~8 ~3~,~, . ~4,37 ~ 1'1279 10,47 14,9~ 15 53 1.3.85 !5, 7 12'49 I2 I127B ~6'86 14,94 ~6 58 16.24 14 i0 13,58 12 1.1277 16~13 1.5.77 t. 690 15.7R 16 52 ~3~64 12 11276 t9,54 t. 6 85 lq 77 ~8,00 '1.7 25 16.29 13 16 15 I9 6I 22.22 ~8 49 36.52 13 t:1275 20,10 1'1274 18,9i 17 II273 !.8,05 17 11271 20 49 20 11270 ~8 2 23 3 2 11269 23'19 11268 23,97 11267 2t,7! ~1266 ~0;0~ 1.8 21 18 15 18.32 21 22 16 60 ~7.25 19 35 ~'1 t8 16.90 17 33 20 57 ~9'75 16 47 22 4t 21~6,! ~7 74 25 O0 24'15 21 ~7 ~ 27 22,97 23 32 20 ~9 ~0,00 ~2 801~:01 14 85 1. 42 t4 69 1~!91 14 75 ~ 72 16 94 !90~ 19 96 ~9 07 ~9 8 20 O2 1 9 4 ~9 83 ~8 27,10 28,91. 31,3~ 28.50 25.63 24.13 23 20 57,7 58 4 65 9 69 40 36,6 47 n 45 5 56 85 48,6 68 29 74,8 83 2 82 0 94 71 63,7 73 7 72 8 79 02 54 4 07 0 68 0 80 85 68 5 75 7 75 3 82 86 68 5 74 7 83 8 80 72 71 63 O 74 3 757 81 08 24 18 23 58 24 25 59 2 69 1 71 0 87 :99~;88 '8 O0 17 85 61:4 70 0 82 ,90 ~ 25 1,7 5~ 16 93 55,3 61 4 .5 9 s7 19 ~8 58 0 50 1322 13 06 13 13 55 6 59 4 68 9 66 50 13 5! 13.98 13 18 48 9 48 0 42 1.2,46 '2 02 12 6i 47 9 44 1 558 61 42 !.3 42 ~2 9~ 13 24 48 I 44 94 15 35 ~6,0~ ~5 37 6~ g 57 9 70 8 74 05 t7.74 !8 38 180 g 1.77 1. 196 {82 85 ~9.16 18 44 15~ 1 184 6 173 ? 187 19. 11 ~54 9 166 ~ 164 8~ 17 49 95 Il, 1.5 47 16 17,24 17.54 17.15 201,1. 210 9 206 ? 228 2 187 25,33 151,.9 1.44.3 159 2 !,53 19 .57 10t'7 90.5 10'7 0 108 7 119 57 61 4 73 9 !.10 5 71 14, 16, 15 19, 15 19, 13 1.9.97 19,50 05 !7, ~8,50 63 16~2'4 ~5,96 16 1 84 0 61 3 78 9 93 3 90 0 79 0 76 0 ~ 70 3 8O 3 80 2 59 ~ 69 ? 72 ? 70 0 6 173 116 7 85,4 86 15 16 86 80 21 50 97 28 !4 29 30 57 18 68 15 7 86 41 22 57 46 22 94 08 25 33 49 25 50 69 22 68 88 23 77 72 22 27 O0 22 44 58 21 13 82 1,9 90 40 18 66 4 }0 8 i1249 12 83 19 02 I .90 O? CONPAN¥ : AT[,ANTTC RICHI'?~EL[.) WELb : 14.-34 PAGE: )EPTH PASS1 PASSU PAS$~ ~ASS4 PASS5 mAS~I PASS2 PASS] PA~SS4 PASS5 PASS1 PA$$~ PASS] PASS4 PASS5 AV~ AVg, ~E~R ~!g~R ~.!~AR ~E~R NE~R FIR FAR F~R FAR F~R NEAR FAR WT C!~ C~! Ci! C!! C[! C[! CU Cl! C!.! CU GAPI GAPT GAPI GAP! GAP! CU CU 11265 91.36 20 52 22.30 18.29 90.11 15,7~ 17.44 15.9~ 15.]5 16.97 76.~ 86 ~ 8~,~ 88.3 91.8 21.~I 15 7] 11264 25,05 24 74 26.49 24.44 ,7.93 ,.9.94 20,83 ,9.85 21i27 ,9.32 85., 19 94 102.] 108.~ ~5. 99. 11~63 ?~.52 77 65 77,57 28,20 71.80 23.60 23'38 22.19 24 29 21,52 103.~ 121~ 11~ 1~0,9 12i,1 29,52 23 60 ~1262 ~0.65 31 15 30,65 30.36 ?6,36 26.5? 27.57 25.69 26 86 25;90 ~30., z 149 150 ~ 65 26 52 ~0, 159,8 162,? ~26t 3~,55 ~ ~4 ~0,94 3~.t5 29,5~ ~9.4~ 29,~6 ~8.90 2e,]~ ~0,04 ~4,2 ~52 ~ ~49 ~ ~56,6 ~60,2 3~,.55 29 43 t64 174.2 1~260 32.48 32 9~ 32,1~ ~,1~ 3~,79 29,57 29,25 30.38 28,35 30,02 t49.6 ~82 ~56,6 ,48 29 57 ~125g ]1,71 ]2 9~ 32.36 31.54 31,7g 29.82 29~25 ]O,lg 28 6~ 30.02 183.1 182 ~ ~92 ~ 167.3 ~74.2 31,91 29 82 1125B ~0.00 33 51 ~0,04 ]2.11 30,6~ ?U.32 29,57 28.52 29'.61 29.74 175.2 200 ]93 z 205.3 ~94.? ~0,00 28 32 11257 30.40 30 29 79.55 30.6~ ~1,07 27o6~ 28.35 ~6"97 29 44 28,04 ~70.? 183 ~ 200 ~ 200 7 199.4 30.,40 27 61 11256 33.39 29 07 30.1~ 31.30 ~9,57 28.04 2~,18 27.80 27,' 47 28,00 206"~ 192 235 184 ! 204.2 33, 39 28 04 11255 32.1~ 30 35 31.29 31,47 28197 29,35 29,6" 2@,22 27 91 28.36 286.6 223 260 '95 9 243,1 32,11 29 35 * .~ 130 ? 26t ~ '19 ] 158,g 34..20_4~ 30 90 i~254 3~;,20 36.1t 3~.68 35,2~ 30,90 30.90 34,23 30.79 33.5~ 32,0! 245 ~03 1.34 95 2 109.5 34 79 11~52 35.57 3a.67 39.48 34,5!. 34.64 35.32 34:95 33 48 36,07 34.36 82,0 93 I 80 1~0 ! 126.3 ~:~~~ 35 32 , ilO ~ 35 98 64 1124~,~!,~ 35 73 ]5 O? ' 11~4~ ~"~',% 34 64 34 23 79 ll]~?j~t~, '~,.f)~__ 33 73 33 64 74 JAN ;5 3 3997 Oil & 6as C~s. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : D . S . 14 -34 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21010-00 REFERENCE NO : 97005 LIS Tape Verification Listing Schlumberger A1 aska Compu ting Cent er 24-JAN-1997 15:22 PAGE: **** REEL HEADER SERVICE NAME : EDIT DATE : 97/01/24 ORIGIN : FLIC REEL NAME : 97005 CONTINUATION # : PREVIOUS REEL : CO~E4ENT : ARCO ALASKA INC, D.S. 14-34, PRUDHOE BAY, 50-029-21010-00 **** TAPE HEADER **** SERVICE NAME .. EDIT DATE · 97/01/24 ORIGIN .. FLIC TAPE NAME : 97005 CONTINUATION # : 1 PREVIOUS TAPE : COI4~ENT : ARCO ALASKA INC, D.S. 14-34, PRUDHOE BAY, 50-029-21010-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 14-34 API lgUMBER: 500292101000 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-JAN-97 JOB 19%rMBER: 97005 LOGGING ENGINEER: G. SCHWARTZ OPERATOR WITNESS: D. VENHAUS SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FNL : 196 FSL: FEL: 1243 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 69. O0 DERRICK FLOOR: 68. O0 GROUND LEVEL: 39. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9. 625 1-1158.0 47. O0 7. 000 11925.0 29. O0 5.500 10782.0 17.00 4. 500 10864.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 27-0CT-83 LOGGING COMPANY: BASELINE DEPTH 88888.0 11573.0 11560.0 11556.5 11551.0 11532.5 11532.0 11517.0 11515.5 11505.5 11491.5 11486.0 11456.5 11434.0 11433.5 11429.0 11389.0 11380.0 11374.0 11366.0 11345.0 11341 0 11338 0 11330 0 11319 0 11318 5 11309 5 11305 5 11303 5 11300.0 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH SIGM 88886.0 88886.0 11571.0 11557.0 11554.5 11531.5 11516.0 11505.0 11434.0 11319.0 11305.5 11300.0 100.0 11550.0 11531.5 11516.0 11505.0 11491.5 11485.5 11457.0 11434.0 11428.5 11388.5 11378.5 11373.5 11364.0 11344.5 11340.5 11338.0 11330.0 11319.0 11309.5 11305.0 11303.5 100.0 REMARKS: The depth adjustments shown above reflect cased hole GR to open hole BCS GR and cased hole SIGM to open hole GR. Ail other TDTP curves were carried with the SIGM shifts. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11562.0 11298.0 TDTP 11587.0 11298.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .............. $ REMARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP No ** 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 24-JAN-1997 15:22 PAGE: 4 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 NTJMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 553992 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 553992 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 553992 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 553992 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 553992 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 553992 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 553992 O0 000 O0 0 i 1 1 4 68 0000000000 INFD TDTP CPS 553992 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 553992 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 553992 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 553992 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 553992 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11595.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. 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 24-JAN-1997 15:22 PAGE: TENS. TDTP -999. 250 CCL. TDTP -999.250 GR.BCS 18.280 DEPT. 11400. 000 SIGM. TDTP 10.269 TPHI. TDTP 19.559 SBHF. TDTP 31.581 SBHN. TDTP 38. 943 SIGC. TDTP O. 982 SIBH. TDTP 38. 943 TRAT. TDTP 1. 722 SDSI. TDTP 0.203 BACK. TDTP 103.319 FBAC. TDTP 24.276 TCAN. TDTP 61633.258 TCAF. TDTP 28565.945 TCN-D. TDTP 34824.805 TCFD. TDTP 12997.869 TSCN. TDTP 12912.146 TSCF. TDTP 5984.556 IArND. TDTP 2174.569 INFD. TDTP 438.721 GRCH. TDTP 17.719 TENS. TDTP 1725. 000 CCL. TDTP O. 000 GR.BCS 19.280 DEPT. 11285.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. 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 TENS.TDTP -999.250 CCL. TDTP -999.250 GR.BCS 74.560 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~zARY LDWG TOOL CODE START DEPTH GRCH 11562.0 TDTP 11587.0 STOP DEPTH 11290.0 11290.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11576.5 11572.5 11564.5 11560.5 11556.5 11548.5 11544.5 11540.5 11536.5 11528.5 11524.5 11522.5 11520.5 11518.5 11516.5 11514.5 11512.5 11510.5 11508.5 11506.5 11504.5 11500.5 11498.5 11496.5 11494.5 11492.5 11488.5 11480.5 11476.5 11474 5 11472 5 11470 5 11468 5 11466 5 11464 5 11462 5 11454 5 11452 5 11450 5 11448 5 11446.5 11444.5 11442.5 11438.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88887.0 88887.5 11576.0 11571.5 11563.5 11560.0 11555.0 11547.0 11544.0 11540.5 11536.0 11528.0 11525.0 11521.5 11518.0 11514.0 11509.5 11506.0 11498.0 11494.5 11474.5 11470.0 11466.5 11462.0 11454.0 11450.5 11447.5 11443.5 11439.0 11521.0 11516.5 11513.0 11508.5 11504.5 11500.0 11497.0 11493.0 11488.0 11480.0 11475.5 11472.0 11468.5 11465.0 11453.0 11449.5 11445.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 11432.5 11430.5 11428.5 11426.5 11424.5 11400.5 11396.5 11392 5 11388 5 11386 5 11384 5 11382 5 11380 5 11378 5 11376.5 11372.5 11368.5 11356.5 11352.5 11348.5 11336.5 11332.5 11324.5 11320.5 11316.5 100.0 $ 11431.0 11426.5 11386.5 11382.0 11378.5 100.0 11433.0 11428.5 11424.0 11400.0 11395.5 11392.5 11388.0 11383.0 11379.5 11376.0 11372.0 11367.0 11355.0 11351.5 11348.0 11336.0 11332.5 11324.5 11321.0 11316.5 100.0 REd, ARKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: TYPE REPR CODE VALUE 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 NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 553992 O0 000 O0 0 2 1 1 4 68 - 0000000000 SBHF TDTP CU 553992 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 553992 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 553992 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 553992 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 553992 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 553992 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 553992 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 553992 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 553992 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11586.500 SIGM. TDTP 10.270 TPHI.TDTP 19.942 SBHF. TDTP SBHN. TDTP 43.299 SIGC. TDTP 1.173 SIBH. TDTP 44.069 TRAT. TDTP SDSI.TDTP 0.230 BACK. TDTP 137.488 FBAC. TDTP 36.212 TCAN. TDTP TCAF. TDTP 22651.297 TCND. TDTP 30186.316 TCFD. TDTP 10455.047 TSCN. TDTP TSCF. TDTP 4768.953 INND. TDTP 2002.679 INFD. TDTP 341.940 GRCH. TDTP TENS.TDTP 1730.000 CCL. TDTP 0.000 DEPT. 11400.000 SIGM. TDTP 10.161 TPHI. TDTP 20.158 SBHF. TDTP SBHN. TDTP 39. 551 SIGC. TDTP O. 973 SIBH. TDTP 39. 551 TRAT. TDTP SDSI. TDTP O. 205 BACK. TDTP 145. 372 FBAC. TDTP 30.531 TCAN. TDTP TCAF. TDTP 27094. 047 TCND. TDTP 33621. 727 TCFD. TDTP 12308. 850 TSCN. TDTP TSCF. TDTP 5733. 745 INND. TDTP 2074.127 INFD. TDTP 398. 801 GRCH. TDTP TENS. TDTP 1690. 000 CCL. TDTP O. 000 31.177 1.720 48515.078 10214.256 -999.250 34.846 1.747 58750.211 12432.943 42.281 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: DEPT. 11290.000 SIGM. TDTP 12.422 TPHI.TDTP 17.073 SBHF. TDTP 40.603 SBHN. TDTP 50.316 SIGC. TDTP 2.225 SIBH. TDTP 56.950 TRAT. TDTP 1.498 SDSI. TDTP 0.333 BACK. TDTP 155.116 FBAC. TDTP 32.138 TCAN. TDTP 33747.352 TCAF. TDTP 17097.316 TCND. TDTP 27104.496 TCFD. TDTP 9827.750 TSCN. TDTP 7212.880 TSCF. TDTP 3654.239 INND. TDTP 2100.354 INFD. TDTP 360.602 GRCH. TDTP 62.594 TENS.TDTP 1655.000 CCL.TDTP 0.003 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUM~Jh~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11562.0 11292.0 TDTP 11587.0 11292.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 10 BASELINE DEPTH GRCH TDTP 88888.0 88888.0 88887.5 11572.5 11572.0 11568.5 11568.0 11564.5 11563.5 11560.5 11558.0 11556.5 11554.5 11552.5 11551.5 11548.5 11547.5 11544.5 11544.5 11532.5 11532.5 11528.5 11529.5 11526.5 11526.5 11524.5 11525.5 11520.5 11521.0 11508.5 11509.0 11504.5 11504.5 11500.5 11500.5 11496.5 11497.0 11492.5 11493.0 11488.5 11488.5 11484.5 11484.5 11480.5 11480.0 11476.5 11476.5 11472.5 11472.5 11468.5 11469.0 11460.5 11461.0 11456.5 11457.5 11454.5 11454.5 11452.5 11453.5 11450.5 11451.0 11448.5 11450.0 11446.5 11446.5 11444.5 11445.0 11442.5 11443.0 11438.5 11438.5 11434.5 11435.0 11432.5 11433.0 11430.5 11431.0 11428.5 11428.5 11426.5 11426.5 11422.5 11422.5 11418.5 11418.0 11414.5 11414.0 11412.5 11412.5 11410.5 11411.0 11408.5 11408.0 11404.5 11404.5 11388.5 11388.5 11384.5 11383.5 11380.5 11380.0 11378.5 11379.0 11376.5 11376.0 11374.5 11374.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 11 11372.5 11370.5 11368.5 11366.5 11364.5 11360.5 11358.5 11356.5 11354 5 11352 5 11348 5 11336 5 11332 5 11328 5 11324 5 11320 5 11316 5 100 0 $ 11371.0 11366.5 11358.5 11355.0 100.5 11372.5 11367.5 11363.0 11360.0 11355.5 11351.5 11348.5 11336.5 11333.0 11329.0 11325.5 11321.5 11317.0 100.5 ~S: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUNIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 553992 SIGM TDTP CU 553992 TPHI TDTP PU-S 553992 SBHF TDTP CU 553992 SBHN TDTP CU 553992 SIGC TDTP CU 553992 SIBH TDTP CU 553992 TRAT TDTP 553992 SDSI TDTP CU 553992 BACK TDTP CPS 553992 FBAC TDTP CPS 553992 TCAN TDTP CPS 553992 TCAF TDTP CPS 553992 TCND TDTP CPS 553992 TCFD TDTP CPS 553992 TSCN TDTP CPS 553992 TSCF TDTP CPS 553992 INND TDTP CPS 553992 INFD TDTP CPS 553992 GRCH TDTP GAPI 553992 TENS TDTP LB 553992 CCL TDTP V 553992 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11586.500 SIGM. TDTP 10.009 TPHI.TDTP 17.770 SBHF. TDTP SBHN. TDTP 43.309 SIGC. TDTP 1.352 SIBH. TDTP 44.060 TRAT. TDTP SDSI.TDTP 0.238 BACK. TDTP 177.429 FBAC. TDTP 39.820 TCAN. TDTP TCAF. TDTP 22518.328 TCND. TDTP 29341.695 TCFD. TDTP 10440.781 TSCN. TDTP TSCF. TDTP 4763.642 INND. TDTP 1965.548 INFD. TDTP 354.489 GRCH. TDTP TENS. TDTP 1610.000 CCL.TDTP 0.000 DEPT. 11400. 000 SIGM. TDTP 9 SBHN. TDTP 41 . 354 SIGC. TDTP 1 SDSI. TDTP O. 215 BACK. TDTP 184 TCAF. TDTP 26435. 602 TCND. TDTP 32647 TSCF. TDTP 5623. 442 INND. TDTP 1971 TENS. TDTP 1630. 000 CCL. TDTP 0 DEPT. 11292. 500 SIGM. TDTP 13 SBHN. TDTP 46. 904 SIGC. TDTP 2 SDSI. TDTP O. 396 BACK. TDTP 190 TCAF. TDTP 15274. 488 TCND. TDTP 26599 TSCF. TDTP 3268. 532 INND. TDTP 2082 TENS. TDTP 1640. 000 CCL. TDTP 0 33.427 1.647 46329.688 9800.818 -999.250 692 TPHI.TDTP 18.266 SBHF. TDTP 40.831 704 SIBH. TDTP 50.612 TRAT. TDTP 1.533 271 FBAC. TDTP 38.905 TCAN. TDTP 31553.273 129 TCFD. TDTP 9385.443 TSCN. TDTP 6751.969 962 INFD. TDTP 375.476 GRCH. TDTP 71.938 000 994 TPHI.TDTP 19.077 SBHF. TDTP 29.877 061 SIBH. TDTP 41.354 TRAT. TDTP 1.712 257 FBAC. TDTP 33.902 TCAN. TDTP 56401.750 984 TCFD. TDTP 12006.699 TSCN. TDTP 11997.912 013 INFD. TDTP 400.378 GRCH. TDTP 43.625 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAlV-1997 15:22 PAGE: 13 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION ' O01CO1 DATE · 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]f4~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREFIENT: 0.5000 FILE SUM~fARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11562.0 11290.0 TDTP 11587.0 11290.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.0 88887.5 11576.5 11576.0 11554.0 11553.0 11553.5 11551.5 11542.0 11540.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 14 11538.0 11534.0 11530.5 11519.5 11516.5 11512.5 11508.5 11506.0 11503 5 11500 0 11492 0 11491 0 11489 0 11486 0 11480 0 11462.5 11457.0 11448.0 11434.0 11433.0 11428.5 11417.0 11416.0 11400.0 11390.5 11373.5 11369.5 11363.5 11360 0 11342 0 11338 0 11318 5 11316 0 11309 0 11307.5 11305.0 11304.0 11300.5 100.0 $ 11537.5 11530.0 11519.0 11507.0 11505.0 11502.5 11500.0 11491.0 11488.5 11480.5 11456.5 11434.0 11416.5 11400.5 11390.5 11364.0 11342.5 11319.0 11316.0 11307.0 11303.5 11300.5 100.0 11534.5 11516.0 11513.0 11492.0 11485.5 11463.0 11448.5 11433.5 11428.5 11415.5 11373.0 11368.0 11359.0 11338.0 11319.0 11309.0 11305.0 100.0 REMARKS: This file contains Borax Pass gl of the TDTP. The depth adjustments shown above reflect Borax Pass gl GRCH to Base Pass gl GRCH and Borax Pass gl SIGMA to Base Pass gl SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 15 ** 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 NUMB SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMTDTP CU 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 553992 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 553992 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 553992 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 553992 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 553992 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 553992 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 553992 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 553992 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 553992 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 553992 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 16 ** DATA ** DEPT. 11586. 500 SIGM. TDTP SBHN. TDTP 86. 374 SIGC. TDTP SDSI. TDTP O. 471 BACK. TDTP TCAF. TDTP 10124. 488 TCND. TDTP TSCF. TDTP 1927. 972 INND. TDTP TENS. TDTP 1690. 000 CCL. TDTP 14 308 0 168 207 866 13236 170 2079 655 0 000 TPHI. TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP DEPT. 11400.000 SIGM. TDTP 9.990 TPHI.TDTP SBHN. TDTP 80.004 SIGC. TDTP 0.142 SIBH. TDTP SDSI. TDTP 0.196 BACK. TDTP 205.087 FBAC. TDTP TCAF. TDTP 23449.996 TCND. TDTP 19651.621 TCFD. TDTP TSCF. TDTP 4476.965 INND. TDTP 2207.089 INFD. TDTP TENS. TDTP 1665.000 CCL. TDTP 0.000 SIGM. TDTP SIGC. TDTP BACK. TDTP TCND. TDTP INND. TDTP CCL. TDTP DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 12.606 0.125 213.898 12965.949 2198.443 0.042 11290 000 102 342 0 288 14195 328 2720 664 1675 000 TPHI. TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 23.433 SBHF. TDTP 129. 407 TRAT. TDTP 44. 629 TCAN. TDTP 482 O. 102 TSCN. TDTP 352. 833 GRCH. TDTP 19.006 SBHF. TDTP 112.589 TRAT. TDTP 39.007 TCAN. TDTP 8538.260 TSCN. TDTP 369.086 GRCH. TDTP 10.997 SBHF. TDTP 142.803 TRAT. TDTP 39.187 TCAN. TDTP 6102.070 TSCN. TDTP 335.954 GRCH. TDTP 72.323 1.575 20255.945 3857.271 -999.250 58.839 1.578 44379.320 8472.693 49.984 76.960 1.182 20757.211 3978.309 84.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 17 DEPTH INCRE~IENT : 0. 5000 FILE SD2Vk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11562.0 11292.0 TDTP 11587.0 11292.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11577.5 11573.5 11569.5 11565.5 11561.5 11557.5 11553.5 11549.5 11545.5 11541.5 11534.5 11521.5 11517.5 11513.5 11509.5 11506.5 11505.5 11502.5 11501.5 11498 5 11497 5 11494 5 11490 5 11485 5 11482 5 11481 5 11478 5 11477 5 11474 5 11473 5 11469 5 11466.5 11465.5 11462.5 11461.5 11457.5 11453.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88887.5 88888.0 11577.5 11573.5 11570.0 11565.5 11561.5 11557.0 11552.5 11549.0 11545.0 11542.0 11534.0 11506.0 11502.5 11498.5 11495.0 11490.5 11482.5 11479.0 11474.5 11466.5 11462.0 11522.0 11517.5 11513.5 11510.0 11506.0 11502.5 11497.5 11485.5 11481.0 11476.5 11472.5 11469.0 11465.5 11463.0 11458.0 11454.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 18 11449.5 11446.5 11442.5 11441.5 11437.5 11433 5 11429 5 11425 5 11421 5 11418 5 11414 5 11410 5 11406.5 11402.5 11401.5 11397.5 11393.5 11390.5 11389.5 11386.5 11385.5 11382.5 11381.5 11378.5 11373.5 11369.5 11366.5 11365.5 11362.5 11361.5 11357 5 11353 5 11350 5 11349 5 11346 5 11341 5 11338 5 11337 5 11334 5 11330 5 11326.5 11325.5 11322.5 11321.5 11317.5 11313.5 100.0 $ REMARKS: 11446.0 11442.5 11418.5 11414.0 11410.5 11406.5 11403.0 11391.0 11387.5 11383.0 11379.5 11367.5 11363.0 11351.0 11347.5 11339.5 11335.0 11330.5 11327.0 11322.5 100.0 11450.5 11442.5 11438.0 11434.0 11429.5 11426.0 11421.5 11401.5 11397.0 11393.0 11389.5 11385.0 11381.5 11373.5 11369.0 11364.5 11361.0 11357.0 11352.0 11349.5 11341.5 11338.0 11326.0 11322.5 11318.5 11314.0 100.5 This file contains Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Borax Pass #2 GRCH to Base Pass #1 GRCH and Borax Pass #2 SIGMA to Base Pass #1 SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 19 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 SERVUNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF1B SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 553992 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 553992 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 553992 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 553992 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 553992 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 553992 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 553992 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 553992 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 20 NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU31v~ SAMP ELEM CODE (HEX) TENS TDTP LB 553992 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 553992 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 11587 000 94 204 0 386 10213 355 1910 313 1705 000 DEPT. 11400. 000 SBHN. TDTP 85. 555 SDSI. TDTP O. 156 TCAF. TDTP 23489. 000 TSCF. TDTP 4459. 500 TENS. TDTP 1641. 656 DEPT. 11292. 000 SBHN. TDTP - 999. 250 SDSI. TDTP -999. 250 TCAF. TDTP -999.250 TSCF. TDTP - 999.250 TENS. TDTP -999. 250 SIGM. TDTP 14.240 TPHI.TDTP 20.226 SBHF. TDTP 74.586 SIGC. TDTP 0.186 SIBH. TDTP 142.114 TRAT. TDTP 1.475 BACK. TDTP 229.617 FBAC. TDTP 50.443 TCAN. TDTP 19396.609 TCND.TDTP 12332.775 TCFD. TDTP 4677.883 TSCN. TDTP 3627.956 INND.TDTP 2082.109 INFD. TDTP 330.914 GRCH. TDTP -999.250 CCL.TDTP 0.000 SIGM. TDTP 9.930 TPHI. TDTP 18.925 SBHF. TDTP 64.775 SIGC. TDTP 0.112 SIBH. TDTP 122.805 TRAT. TDTP 1.575 BACK. TDTP 212.256 FBAC. TDTP 40.063 TCAN. TDTP 44444.000 TCND. TDTP 19535.500 TCFD. TDTP 8471.250 TSCN. TDTP 8437.500 INND. TDTP 2188.875 INFD. TDTP 391.711 GRCH. TDTP 57.313 CCL. TDTP 0.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 90.875 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 21 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: O . 5000 FILE SUFk~a~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11562.0 11290.0 TDTP 11587.0 11292.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88888.0 11577.5 11577.5 11573.5 11573.0 11569.5 11569.5 11565.5 11565.0 11557.5 11557.0 11553.5 11552.5 11545.5 11544.5 11541.5 11541.5 11537.5 11537.0 11533.5 11534.0 11529.5 11530.0 11526.5 11526.0 11525.5 11525.5 11521.5 11521.5 11517.5 11517.0 11513.5 11513.0 11509.5 11510.0 11505.5 11506.5 11502.5 11502.0 11501.5 11502.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 22 11498.5 11497.5 11493.5 11489.5 11485.5 11481.5 11477.5 11473.5 11469.5 11465.5 11461.5 11453.5 11449 5 11433 5 11429 5 11426 5 11425 5 11421 5 11413.5 11409.5 11405.5 11401.5 11398.5 11397.5 11393.5 11389.5 11385.5 11381.5 11378.5 11373.5 11369.5 11365.5 11361.5 11358.5 11357.5 11353 5 11350 5 11349 5 11346 5 11345 5 11341 5 11338 5 11337.5 11334.5 11330.5 11325.5 11321.5 11317.5 100.0 $ RE~IARKS: 11498.5 11426.5 11399.0 11379.0 11359.5 11351.5 11347.0 11339.0 11335.5 11331.0 100.5 11497.5 11493.0 11489.5 11485.5 11481.0 11476.5 11472.5 11469.0 11466.0 11461.5 11453.5 11450.0 11434.0 11429.5 11425.5 11421.0 11413.0 11409.5 11405.5 11400.5 11397.0 11393.0 11389.5 11386.0 11381.5 11373.5 11369.0 11364.5 11361.0 11357.0 11352.5 11349.0 11345.5 11341.5 11338.0 11326.0 11322.5 11318.0 100.5 This file contains Borax Pass #3 of the TDTP. The depth adjustments shown above reflect Borax Pass #3 GRCH to Base Pass #1 GRCH and Borax Pass #3 SIGMA to Base Pass #1 SIGMA. All other TDTP curves were carried with the LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 23 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 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 SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 553992 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 553992 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN TDTP CU 553992 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 553992 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 553992 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 553992 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INFD TDTP CPS 553992 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 553992 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 553992 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 553992 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11587. 000 SIGM. TDTP 15. 823 TPHI. TDTP 22. 460 SBHF. TDTP SBHN. TDTP 98. 599 SIGC. TDTP O. 085 SIBH. TDTP 153. 687 TRAT. TDTP SDSI. TDTP O. 478 BACK. TDTP 228. 353 FBAC. TDTP 54. 332 TCAN. TDTP TCAF. TDTP 8364. 564 TCND. TDTP 11387. 996 TCFD. TDTP 4181 . 059 TSCN. TDTP TSCF. TDTP 1583. 595 INND. TDTP 2074. 279 INFD. TDTP 330. 665 GRCH. TDTP TENS. TDTP 1680. 000 CCL. TDTP O . 000 DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 11400 000 55 464 0 201 29006 000 5514 500 1699 289 DEPT. 11290. 500 SBHN. TDTP 47. 178 SDSI. TDTP O. 346 TCAF. TDTP 24487. 523 TSCF. TDTP 4689. 887 TENS. TDTP 1660. 000 73.710 1.494 16295.723 3085.136 -999.250 SIGM. TDTP 10.187 TPHI. TDTP 17.307 SBHF. TDTP 44.666 SIGC. TDTP 0.382 SIBH. TDTP 66.168 TRAT. TDTP 1.546 BACK. TDTP 225.611 FBAC. TDTP 47.455 TCAN. TDTP 54570.000 TCND. TDTP 27080.500 TCFD. TDTP 11354.250 TSCN. TDTP 10375.500 INND. TDTP 2214.094 INFD. TDTP 464.922 GRCH. TDTP 76.563 CCL.TDTP 0.000 SIGM. TDTP 13.977 TPHI.TDTP 14.090 SBHF. TDTP 39.045 SIGC. TDTP 2.479 SIBH. TDTP 50.599 TRAT. TDTP 1.375 BACK. TDTP 231.769 FBAC. TDTP 48.373 TCAN. TDTP 45336.055 TCND. TDTP 31913.285 TCFD. TDTP 13125.096 TSCN. TDTP 8682.828 INND. TDTP 2541.204 IlVFD. TDTP 578.367 GRCH. TDTP 104.813 CCL. TDTP 0.855 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 25 **** FILE HEADER **** FILE NAIVE : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 7 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 INCRE~fENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3 TDTP $ RE~iA~KS: The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 2 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 26 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 553992 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 553992 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 553992 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN PNAV CU 553992 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 553992 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 553992 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 553992 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 INND PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 553992 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 553992 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11585.000 SIGM. PNAV 10.007 TPHI.PNAV 20.759 SBHF. PNAV 33.298 SBHN. PNAV 44.217 SIGC. PNAV 1.202 SIBH. PNAV 45.813 TRAT. PNAV 1.748 SDSI.PNAV 0.223 BACK. TDTP 75.595 FBAC. TDTP 17.919 TCAN. PNAV 48918.633 TCAF. PNAV 22449.254 TCND. PNAV 29787.934 TCFD.PNAV 10225.291 TSCN. PNAV 10217.570 TSCF. PNAV 4687.966 INND. PNAV 2007.845 INFD.PNAV 340.791 GRCH. TDTP -999.250 DEPT. 11400.000 SIGM. PNAV 10.140 TPHI.PNAV 19.596 SBHF.PNAV 32.098 SBHN. PNAV 39.945 SIGC. PNAV 1.005 SIBH. PNAV 39.945 TRAT. PNAV 1.727 SDSI.PNAV 0.207 BACK. TDTP 103.319 FBAC. TDTP 24.276 TCAN. PNAV 58922.516 TCAF. PNAV 27362.461 TCND. PNAV 33694.805 TCFD.PNAV 12436.563 TSCN. PNAV 12446.424 TSCF. PNAV 5780.004 INND.PNAV 2073.029 INFD.PNAV 412.592 GRCH. TDTP 17.719 DEPT. 11298.000 SIGM. PNAV 16.725 TPHI.PNAV 22.683 SBHF. PNAV 40.954 SBHN. PNAV 48.364 SIGC. PNAV 3.123 SIBH. PNAV 54.532 TRAT. PNAV 1.574 SDSI.PNAV 0.483 BACK. TDTP 115.988 FBAC. TDTP 28.878 TCAN. PNAV 26732.203 TCAF. PNAV 12061.436 TCND. PNAV 25090.578 TCFD.PNAV 8325.740 TSCN. PNAV 5696.469 TSCF. PNAV 2570.231 INND. PNAV 2107.753 INFD.PNAV 349.379 GRCH. TDTP 63.438 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-UMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMF~ARY VENDOR TOOL CODE START DEPTH TDTP 11587.0 $ LOG HEADER DATA STOP DEPTH 11298.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG IA~fERVAL (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~AA RAY TDTP THERMAL DECAY CART. TDTP THERMAL DECAY SONDE $ BOREHOLE AND CASING DATA 17-DEC-96 42.2 1250 17-DEC-96 11800.0 11594.0 11290.0 11587.0 1800.0 NO TOOL NUMBER CGRS A 862 TNC P 50 TNDP78 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 28 OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11158.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~MPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS/ BOR -20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): 1200 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 12000 TOOL STANDOFF (IN): REM_ARKS: TIED INTO BHCS DATED 27-0CT-1983. PURPOSE: TO FIND GOC & DETERMINE IF A CHANNEL EXISTS LOGGED THREE BASE TDT PASSES AND THREE BORAX PASSES TOTALS: SEAWATER FLUSH=280 BBLS; BORAX=lO5 BBLS DEAD CRUDE SPACER = 205 BBLS FOUND GOC AT 11526', NO CHANNELS SEEN ***THIS IS TDT PASS #1'******* $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 29 TYPE REPR CODE VALUE 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 NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 8 1 1 4 68 0000000000 DEPT FT 553992 SIGM PS1 CU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 SBHNPS1 CU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS1 CU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS1 553992 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PSi CU 553992 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PSi CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS1 CPS 553992 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 553992 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 553992 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 553992 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11595.000 SIGM. PS1 10.463 TPHI.PS1 20.715 SBHF. PS1 SBHN. PS1 44.042 SIGC. PS1 1.072 SIBH. PS1 45.195 TRAT. PS1 SDSI.PS1 0.290 BACK. PSi 123.260 FBAC.PS1 33.159 TCAN. PS1 TCAF. PS1 18271.102 TCND.PS1 23223.875 TCFD.PS1 8083.561 TSCN. PS1 38.072 1.737 39714.406 7841.665 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 3O TSCF. PS1 3607.654 INND. PSl 1671.278 GR.PSl 23.219 CCL.PS1 0.000 DEPT. 11400.000 SIGM. PS1 SBHN. PS1 40.044 SIGC. PS1 SDSI.PS1 0.205 BACK. PSI TCAF. PSl 28021.363 TCND. PS1 TSCF. PSl 5867.142 INND.PS1 GR.PS1 17.719 CCL.PS1 DEPT. SBHN. PS1 SDSI.PSl TCAF. PS1 TSCF. PS1 GR.PS1 11296 500 50 730 0 369 14664 498 3107 808 58 063 SIGM. PS1 SIGC.PS1 BACK. PSi TCND.PS1 INND. PS1 CCL.PS1 INFD. PSl 10.436 TPHI.PS1 1.154 SIBH. PS1 106.924 FBAC. PS1 34565.719 TCFD.PS1 2148.815 INFD.PS1 0.000 15.435 TPHI.PS1 2.230 SIBH. PS1 115.574 FBAC. PS1 26818.910 TCFD.PS1 2159.953 INFD.PS1 0.000 293.350 TENS.PSI 19.305 SBHF. PS1 40.044 TRAT. PS1 23.330 TCAN. PS1 12858.455 TSCN. PS1 448.306 TENS.PSi 20.786 SBHF. PS1 58.545 TRAT. PS1 27.938 TCAN. PS1 9330.596 TSCN. PS1 385.059 TENS.PSI 1725.000 32.089 1.708 60201.313 12605.012 1740.000 41.651 1.534 30983.699 6566.293 1695.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION · O01CO1 DATE · 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11587.0 11290.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 31 $ 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): 17-DEC-96 42.2 1250 17-DEC-96 11800.0 11594.0 11290.0 11587.0 1800.O NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMFIA RAY TDTP THERMAL DECAY CART. TDTP THERMAL DECAY SONDE $ TOOL NUMBER CGRS A 862 TNC P 50 TNDP 78 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 11158.0 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) : PRODUCED FLUIDS/ BOR -20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) '. 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): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 32 REMARKS: TIED INTO BHCS DATED 27-0CT-1983. PURPOSE: TO FIND GOC & DETERMINE IF A CHANNEL EXISTS LOGGED THREE BASE TDT PASSES AND THREE BORAX PASSES TOTALS: SEAWATER FLUSH=280 BBLS; BORAX=lO5 BBLS DEAD CRUDE SPACER = 205 BBLS FOUND GOC AT 11526', NO CHANNELS SEEN ***THIS IS TDT 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 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 NUM~ SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPS2 CU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TI{AT PS2 553992 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 553992 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 33 NAME SERV UNIT SERVICE API API API API FILE AU3M~ NUb~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCAF PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS2 CPS 553992 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 553992 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 553992 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 553992 O0 000 O0 0 9 i 1 4 68 0000000000 ** DATA ** DEPT. 11595.000 SIGM. PS2 10.534 TPHI.PS2 23.415 SBHF. PS2 SBHN. PS2 42.910 SIGC. PS2 1.124 SIBH. PS2 43.387 TRAT. PS2 SDSI.PS2 0.253 BACK. PS2 187.182 FBAC. PS2 63.718 TCAN. PS2 TCAF. PS2 20355.406 TCND. PS2 29141.309 TCFD.PS2 9698.750 TSCN. PS2 TSCF. PS2 4284.598 INND. PS2 2016.756 INFD.PS2 333.913 TENS.PS2 GR.PS2 247.375 CCL.PS2 0.000 DEPT. 11400.000 SIGM. PS2 10.542 TPHI.PS2 20.189 SBHF. PS2 SBHN. PS2 38.872 SIGC. PS2 0.993 SIBH. PS2 38.872 TRAT. PS2 SDSI.PS2 0.225 BACK. PS2 144.539 FBAC. PS2 30.531 TCAN. PS2 TCAF. PS2 26497.371 TCND.PS2 33245.398 TCFD.PS2 12181.879 TSCN. PS2 TSCF. PS2 5608.271 INND. PS2 2065.615 INFD.PS2 411.097 TENS.PS2 GR.PS2 42.281 CCL.PS2 0.000 DEPT. 11288.500 SIGM. PS2 10.872 TPHI.PS2 14.759 SBHF.PS2 SBHN. PS2 50.655 SIGC. PS2 1.996 SIBH. PS2 57.067 TRAT. PS2 SDSI.PS2 0.264 BACK. PS2 160.740 FBAC. PS2 32.540 TCAN. PS2 TCAF. PS2 20992.426 TCND.PS2 29306.102 TCFD.PS2 11139.092 TSCN. PS2 TSCF. PS2 4484.348 INND.PS2 2068.909 INFD.PS2 360.314 TENS.PS2 GR.PS2 61.875 CCL.PS2 0.000 28.539 1.837 46958.891 9884.348 1710.000 33.788 1.737 57340.539 12136.348 1670.000 42.136 1.453 39387.750 8413.910 1645.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION . O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 34 **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH TDTP 11587.0 $ 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): STOP DEPTH .......... 11292.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~4A RAY TDTP THERMAL DECAY CART. TDTP THERMAL DECAY SONDE $ 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) : 17-DEC-96 42.2 1250 17-DEC-96 11800.0 11594.0 11290.0 11587.0 1800.0 NO TOOL NU~I~ER CGRS A 862 TNC P 50 TND P 78 11158.0 PRODUCED FLUIDS/ BOR -20.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 35 FLUID LEVEL (FT) : 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): 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): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR CO~ RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): REFiARKS: TIED INTO BHCS DATED 27-0CT-1983. PURPOSE: TO FIND GOC & DETERMINE IF A CHANNEL EXISTS LOGGED THREE BASE TDT PASSES AND THREE BORAX PASSES TOTALS: SEAWATER FLUSH=280 BBLS; BORAX=lO5 BBLS DEAD CRUDE SPACER = 205 BBLS FOUND GOC AT 11526', NO CHANNELS SEEN ***THIS IS TDT PASS #3******** $ 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 3 6 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 553992 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS3 CU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 553992 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 553992 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS3 CPS 553992 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 553992 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 553992 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 553992 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11595.000 SIGM. PS3 10.573 TPHI.PS3 24.062 SBHF. PS3 SBHN. PS3 43.749 SIGC. PS3 1.142 SIBH. PS3 45.056 TRAT. PS3 SDSI.PS3 0.268 BACK. PS3 229.580 FBAC. PS3 78.823 TCAN. PS3 TCAF. PS3 20124.855 TCND.PS3 29061.988 TCFD.PS3 9648.301 TSCN. PS3 TSCF. PS3 4257.274 INND. PS3 1938.860 INFD.PS3 370.381 TENS.PS3 GR.PS3 127.375 CCL.PS3 0.000 DEPT. 11400.000 SIGM. PS3 9.994 TPHI.PS3 19.077 SBHF. PS3 SBHN. PS3 41.354 SIGC. PS3 1.061 SIBH. PS3 41.354 TRAT. PS3 SDSI.PS3 0.215 BACK. PS3 184.257 FBAC. PS3 33.902 TCAN. PS3 TCAF. PS3 26435.602 TCND.PS3 32647.984 TCFD.PS3 12006.699 TSCN. PS3 TSCF. PS3 5623.442 INND.PS3 1971.013 INFD.PS3 400.378 TENS.PS3 GR.PS3 45.375 CCL.PS3 0.000 36. 053 1. 849 47201. 008 9985. 047 1620. 000 29.877 1.712 56401.750 11997.912 1630.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 37 DEPT. 11291.000 SIGM. PS3 14.119 TPHI.PS3 SBHN. PS3 48.620 SIGC. PS3 2.593 SIBH. PS3 SDSI.PS3 0.463 BACK. PS3 186.358 FBAC. PS3 TCAF. PS3 14849.021 TCND.PS3 25962.938 TCFD.PS3 TSCF. PS3 3177.521 INND.PS3 2158.235 INFD.PS3 GR.PS3 67.188 CCL.PS3 0.000 17.443 54.040 38.917 9240.553 372.935 SBHF. PS3 TRAT.PS3 TCAN. PS3 TSCN. PS3 TENS.PS3 41.660 1.477 29748.645 6365.870 1640.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIk4BER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 11587.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 11290.0 17-DEC-96 42.2 1250 17-DEC-96 11800.0 11594.0 11290.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 38 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~ff~A RAY TDTP THERMAL DECAY CART. TDTP THERMAL DECAY SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11587.0 1800.0 NO TOOL NUFiBER CGRS A 862 TNC P 50 TNDP78 11158.0 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) : PRODUCED FLUIDS/ BOR -20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): REMARKS: TIED INTO BHCS DATED 27-0CT-1983. PURPOSE: TO FIND GOC & DETERMINE IF A CHANNEL EXISTS LOGGED THREE BASE TDT PASSES AND THREE BORAX PASSES TOTALS: SEAWATER FLUSH=280 BBLS; BORAX=lO5 BBLS DEAD CRUDE SPACER = 205 BBLS FOUND GOC AT 11526', NO CHANNELS SEEN ***THIS IS TDT BORAX PASS #1'*******. $ LIS Tape Verification Listing Schlumberger A1 aska Compu ting Cent er 24-JAN-1997 15:22 PAGE: 39 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 NUMB NOWiB SIZE REPR PROCESS ID ORDER # LO~ TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS4 CU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PS4 PU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS4 CU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNPS4 CU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS4 CU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS4 CU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS4 553992 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS4 CU 553992 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TCANPS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 IN-NDPS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS4 CPS 553992 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS4 LB 553992 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS4 GAPI 553992 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 4O NAME SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CCL PS4 V 553992 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 11595.000 SIGM. PS4 12.381 TPHI.PS4 22.693 SBHF. PS4 SBHN. PS4 77.469 SIGC. PS4 0.244 SIBH. PS4 110.861 TRAT. PS4 SDSI.PS4 0.297 BACK. PS4 300.488 FBAC.PS4 94.199 TCAN. PS4 TCAF. PS4 15715.180 TCND. PS4 17325.234 TCFD.PS4 6548.438 TSCN. PS4 TSCF. PS4 3002.194 INND. PS4 2157.171 INFD.PS4 339.959 TENS. PS4 GR.PS4 84.688 CCL. PS4 0.000 DEPT. 11400.000 SIGM. PS4 10.153 TPHI.PS4 19.258 SBHF. PS4 SBHN. PS4 80.688 SIGC. PS4 0.155 SIBH.PS4 113.782 TRAT. PS4 SDSI.PS4 0.205 BACK. PS4 205.585 FBAC.PS4 39.278 TCAN. PS4 TCAF. PS4 22996.457 TCND. PS4 19534.051 TCFD.PS4 8391.801 TSCN. PS4 TSCF. PS4 4388.594 INND. PS4 2140.556 INFD.PS4 375.009 TENS. PS4 GR.PS4 48.531 CCL.PS4 0.000 DEPT. 11289.500 SIGM. PS4 12.351 TPHI.PS4 10.433 SBHF. PS4 SBHN. PS4 100.686 SIGC. PS4 0.116 SIBH. PS4 139.294 TRAT. PS4 SDSI.PS4 0.262 BACK. PS4 215.972 FBAC.PS4 39.593 TCAN. PS4 TCAF. PS4 15236.805 TCND. PS4 13395.490 TCFD.PS4 6439.610 TSCN. PS4 TSCF. PS4 2919.060 INND. PS4 2156.073 INFD.PS4 329.529 TENS.PS4 GR.PS4 84.375 CCL.PS4 0.000 60.595 1.622 31563.859 6029.891 1665.000 58.514 1.581 43710.266 8341.570 1665.000 77.117 1.165 21997.281 4214.229 1680.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE . 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 41 FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUPR4ARY VENDOR TOOL CODE START DEPTH TDTP 11587.0 $ 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): STOP DEPTH .......... 11292,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY CART. TDTP THERMAL DECAY SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 17-DEC-96 42.2 1250 17-DEC-96 11800.0 11594.0 11290.0 11587.0 1800.0 NO TOOL NUMBER CGRS A 862 TNC P 50 TNDP78 11158.0 PRODUCED FLUIDS/ BOR -20.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 42 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): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): REMARKS: TIED INTO BHCS DATED 27-0CT-1983. PURPOSE: TO FIND GOC & DETERMINE IF A CHANNEL EXISTS LOGGED THREE BASE TDT PASSES AND THREE BORAX PASSES TOTALS: SEAWATER FLUSH=280 BBLS; BORAX=lO5 BBLS DEAD CRUDE SPACER = 205 BBLS FOUND GOC AT 11526', NO CHANNELS SEEN ***THIS IS TDT BORAX 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 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 43 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM PS5 CU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI PS5 PU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF PS5 CU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 SBHN PS5 CU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC PS5 CU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH PS5 CU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT PS5 553992 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI PS5 CU 553992 O0 000 O0 0 12 1 1 4 68 0000000000 BACK PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TCAN PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TCAF PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TCND PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TCFD PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 INND PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 INFD PS5 CPS 553992 O0 000 O0 0 12 1 1 4 68 0000000000 TENS PS5 LB 553992 O0 000 O0 0 12 1 1 4 68 0000000000 GR PS5 GAPI 553992 O0 000 O0 0 12 1 1 4 68 0000000000 CCL PS5 V 553992 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 11595.000 SIGM. PS5 13 318 TPHI.PS5 17.604 SBHF. PS5 68.914 SBHN. PS5 88.040 SIGC. PS5 0 267 SIBH. PS5 126.051 TRAT. PS5 1.415 SDSI.PS5 0.296 BACK. PS5 307 559 FBAC. PS5 86.911 TCAN. PS5 25444.652 TCAF. PS5 14290.465 TCND. PS5 13789 461 TCFD.PS5 5501.902 TSCN. PS5 4342.691 TSCF. PS5 2438.983 INND.PS5 2092 992 INFD.PS5 366.558 TENS.PS5 1725.000 GR.PS5 96.813 CCL.PS5 0 000 DEPT. 11400.000 SIGM. PS5 9 992 TPHI.PS5 18.956 SBHF. PS5 64.819 SBHN. PS5 85.106 SIGC. PS5 0 115 SIBH. PS5 121.865 TRAT. PS5 1.574 SDSI.PS5 0.157 BACK. PS5 212 256 FBAC. PS5 39.902 TCAN. PS5 44106.586 TCAF. PS5 23284.188 TCND.PS5 19477 730 TCFD.PS5 8433.932 TSCN. PS5 8372.727 TSCF. PS5 4420.023 INND.PS5 2202 978 INFD.PS5 389.825 TENS.PS5 1645.000 GR.PS5 55.781 CCL.PS5 0 000 DEPT. 11291.500 SIGM. PS5 13 986 TPHI.PS5 14.089 SBHF. PS5 81.729 SBHN. PS5 100.720 SIGC. PS5 0 102 SIBH. PS5 143.786 TRAT. PS5 1.267 SDSI.PS5 0.326 BACK. PS5 217 233 FBAC.PS5 44.060 TCAN. PS5 19232.250 TCAF. PS5 11953.104 TCND.PS5 12764 646 TCFD.PS5 5619.735 TSCN. PS5 3685.852 TSCF. PS5 2290.807 INND.PS5 2144 493 INFD.PS5 332.722 TENS.PS5 1690.000 GR.PS5 85.313 CCL.PS5 0 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAlV-1997 15:22 PAGE: 44 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11587.0 11290.0 TDTP $ LOG HEADER DATA DA TE LOGGED: 17 - DEC- 96 SOFTWARE VERSION: 42.2 TIME LOGGER ON BOTTOM: 1250 17-DEC-96 TD DRILLER (FT) : 11800.0 TD LOGGER (FT) : 11594.0 TOP LOG INTERVAL (FT) : 11290.0 BOTTOM LOG INTERVAL (FT) : 11587.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NI]MBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 45 GR TDTP TDTP $ GAM~A RAY THERMAL DECAY CART. THERMAL DECAY SONDE CGRS A 862 TNC P 50 TND P 78 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 11158.0 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) : PRODUCED FLUIDS/ BOR -20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): REMARKS: TIED INTO BHCS DATED 27-0CT-1983. PURPOSE: TO FIND GOC & DETERMINE IF A CHANNEL EXISTS LOGGED THREE BASE TDT PASSES AND THREE BORAX PASSES TOTALS: SEAWATER FLUSH=280 BBLS; BORAX=lO5 BBLS DEAD CRUDE SPACER = 205 BBLS FOUND GOC AT 11526', NO CHANNELS SEEN ***THIS IS TDT BORAX PASS #3******** $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Compu ting Center 24-JAN-1997 15:22 PAGE: 46 ** 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 NUMB AU3MB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 553992 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM PS6 CU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI PS6 PU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF PS6 CU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 SBHN PS6 CU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC PS6 CU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH PS6 CU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT PS6 553992 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI PS6 CU 553992 O0 000 O0 0 13 1 1 4 68 0000000000 BACK PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TCANPS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TCAF PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TCND PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 INND PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 INFD PS6 CPS 553992 O0 000 O0 0 13 1 1 4 68 0000000000 TENS PS6 LB 553992 O0 000 O0 0 13 1 1 4 68 0000000000 GR PS6 GAPI 553992 O0 000 O0 0 13 1 1 4 68 0000000000 CCL PS6 V 553992 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 47 ** DATA ** DEPT. 11595.000 SIGM. PS6 SBHN. PS6 95.879 SIGC. PS6 SDSI.PS6 0.370 BACK. PS6 TCAF. PS6 11972.773 TCND.PS6 TSCF. PS6 2265.933 INND.PS6 GR.PS6 107.875 CCL.PS6 DEPT. 11400.000 SIGM. PS6 SBHN. PS6 56.839 SIGC. PS6 SDSI.PS6 0.210 BACK. PS6 TCAF. PS6 27746.738 TCND. PS6 TSCF. PS6 5272.237 INND. PS6 GR.PS6 81.500 CCL.PS6 DEPT. 11288 SBHN. PS6 45 SDSI.PS6 0 TCAF. PS6 28777 TSCF. PS6 5502 GR.PS6 103 500 SIGM. PS6 050 SIGC. PS6 296 BACK. PS6 094 TCND.PS6 704 INND. PS6 563 CCL.PS6 14.019 TPHI.PS6 0.242 SIBH. PS6 306.887 FBAC. PS6 12803.613 TCFD.PS6 2050.972 INFD.PS6 0.000 16.772 139.378 94.299 5235.774 358.345 10.566 TPHI.PS6 17.627 0.415 SIBH. PS6 68.674 229.703 FBAC. PS6 47.722 26510.762 TCFD. PS6 11029.893 2192.921 INFD.PS6 458.572 0.000 12.785 TPHI.PS6 2.270 SIBH. PS6 239.245 FBAC. PS6 33870.461 TCFD.PS6 2484.113 INFD.PS6 0.000 12.180 46. 917 49. 753 14448.148 582. 539 SBHF. PS6 TRAT. PS6 TCAN. PS6 TSCN. PS6 TENS.PS6 SBHF. PS6 TRAT. PS6 TCAN. PS6 TSCN. PS6 TENS.PS6 SBHF. PS6 TRAT. PS6 TCAN. PS6 TSCN. PS6 TENS.PS6 65. 964 1.364 20617. 008 3901. 917 1680. 000 44.432 1.541 52293.133 9936.367 1685.000 35.616 1.345 51065.133 9764.582 1690.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/01/24 ORIGIN · FLIC TAPE NAME : 97005 CONTINUATION # : 1 PREVIOUS TAPE : COIW~4ENT : ARCO ALASKA INC, D.S. 14-34, PRUDHOE BAY, 50-029-21010-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1997 15:22 PAGE: 48 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/01/24 ORIGIN · FLIC REEL NAME : 97005 CONTINUATION # : PREVIOUS REEL : COMMENT · ARCO ALASKA INC, D.S. 14-34, PRUDHOE BAY, 50-029-21010-00 LVP OlO,HO~ VERIrTCAT~ON LISTING PAGE SE~VTC~ blAME :?DTT DATE ORTGTN CONTI~I!iTION # ** TAPE HEADrR O~TGT~ lOOO0 TAPE NAME 18714 ~ONT~I!ATION # t01 PREVTOUS TAPE CO~T8 ITAP£ COMMENT8 EOF ** F{LE HEAOE~ r~LE ~PE I~IT eOO! SERVICE NAME DATE { ~AX!MI)M LENGTH PREVIOUS rILE ** ~NFORNATI~N R~CORD$ ** MN~M CONTENTS WC, N I ALASKA TNC N PN I PRI{JDHOE BAY R a NG { ! 4E 00( 000 OiL 065 O( 000 000 006 000 000 OO4 LVP OIO,HO~ V~IFICI?IO~ I, ISTI~O Pl~ ~ COMPANY = AT~ANTIC RICHFIelD COMPANY W~r~I, = D~II, L SIT~ 14-34 fIELD m PRUDHOE BAY COUNTY n NOR?H SLOPE RORDU~H STAT~ ~ ~L~SKA JOP NU~BE~ AT A¢Ct 6~714 LDP~ ~,$IM~S TYPE FLI!TD mL!GNOSUI,rONAT~ DENSITY · 10,0 LB/G RM = 1.49 ~ 57 DF VISCOSITY = 14 $ RMF = .~7 a 57 DF P~ = 11-0 R~¢ = ~.4 9 57 Dr FLI.IID [r,O~S = 4,~ C3 ~ AT BHT m ,485 m 184 DF MATRIX SINOSTONE * DUAL ~NDUcT~O~ SPHERICALLY ~OCUSED LOG (P~L) * $ ~OREHOLE COMPENSATED LOG (RHC) , t, TTNO ~ENS~TY CO%PENSATE~ * COMPFNSATED NEUTRON LOG (bDT) * DATA FORMAT ~ECORD ** E~T~Y RLOCKS TYPE SIZE ~EPR CODE ENTRY 4 1 66 I ~ 4 7~ 60 0 ! 66 0 D~?UN SPECiFiCATiON ~LOCKS M~E~ SERV~E SERVZC~ }..!N~T AP[ AP! AP! ~P! 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