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176-016
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI WELL MPLETION OR RECOMPLETION REPAND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 2 ' Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ ❑ 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 01/22/2016 • __________ . 176-016- 315-687 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 2/16/1976 50-029-20198-00-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 3/9/1976 PBU 09-02 • Surface: 170'FSL,697'FEL,Sec.02,T1ON,R15E,UM • 9 KB Ref Elevations 17. Field/Pool(s): 54 • 1316'FNL,3968'FWL,Sec.12,T1ON,R15E,UM GL 20.5 PRUDHOE BAY,PRUDHOE OIL • Top of Productive Interval: BF 20.72 Total Depth: 1476'FNL,4255'FVVL,Sec.12,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10728'/8847' ADL 028327 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 717719• y- 5941618 • Zone - ASP 4 . 11199'/9214' • 74-017 TPI: x- 722426 y- 5940270 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 722718 y- 5940118 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No WI 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,FDC/CNL,GR/CBL,GR/CCL,Gyro 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" 94# H-40 36' 116' 36' 116' 32" 250 sx Arctic Set Cement 13-3/8" 72# MN-80 35' 2726' 35' 2726' 17-1/2" 4350 sx Arctic Set Cement 9-5/8" 47# Soo-95/MN-So 33' 11153' 33' 9178' 12-1/4" 1500 sx Class'G',115 sx Arctic Set Cement 7" 29# 13Cr80 10238' 11115' 8462' 9149' Scab Liner 175 sx Class'G' 24. Open to production or injection? Yes 0 No IZI 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): 7,26#x 5-1/2",17# 10294' 1017U/8410' SCANNED JUN 2 4 2016 x 4-1/2",12.6#, 13Cr80 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. a3ANp610 Was hydraulic fracturing used during completion? Yes 0 No l • RECEIVED et'IQ Per 20 AAC 25.283(i)(2)attach electronic and printed 8 P information FEB 1 2016 `(�Z I IV DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED n(n' VERIFIED See Attached AOGCC 1. . 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate 0" Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only / VTL- 5/3/« )7---5,4 RBDMS LL FEB 1 9 2016 _,...,VS s-9,, i �///G 28. CORE DATA • Conventional Core(s) Yes ❑ No 0 • • Sidewall Cores Yes 0 No 0 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 TVD Permafrost-Top Well Tested? Yes ❑ No I Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval separate sheets to this form,if needed,and submit detailed test information per 20 MC 25.071. Sadlerochit 10674' 8805' Base of Sadlerochit 11062' 9108' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Report,Well 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. Contact: Minge,David Email: David.Minge@bp.com Printed Name: Joe Lastuf J, f Title: Drilling Technologist ) Signature: 111 1, Phone: +1 907 564 4091 Date: 1 I b( j( 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD 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 11/2015 Submit ORIGINAL Only • WELL NAME: 09-02 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 10770' Set Posiset Plug 10758' 17.2 Gal Cement 10728' Set Whipstock 10730' 30.4 Bbls Class 'G' • • 09-02, Well History (Pre-Rig Sidetrack) / / Aff ® 4 /i /) //7�/ ; 4" i 10, (ELINE MILL/ POSISET PLUG/CEMENT/WHIPSTOCK). INITIAL T/I/O = 300/300/200. RIG UP 12/3/2015 E-LINE TO MILL XN NIPPLE. BEGIN PT. (ELINE MILL/POSISET/CMT/WHIPSTOCK). INITIAL T/I/O = 300/300/200 PSI. PT COMPLETE. RUN1: RIH WITH WELLTEC MILLL. MILL XN NIP AT 10265'. OD MEASUREMENT OF MILLING BIT = 3.80". RUN2: RIH WITH POSISET PLUG. SET TOP OF PLUG AT 10770' (DEPTH CORRECTED TO SLB JEWELRY LOG DATED 20-DEC-2008.) RUN3: RIH WITH CEMENT DUMP BAILER. DUMP-2.5' (4.3 GALLONS) OF CEMENT ON TOP OF POSISET PLUG RUN4: RIH WITH CEMENT DUMP BAILER. DUMP -2.5' (4.3 GALLONS) OF CEMENT ON TOP OF POSISET- (TOOLS COVERED IN ASPHAULTENES AND SOME ASPHALTENE BUILD UP IN TOOLS AS WELL.) RUN5: RIH WITH CEMENT DUMP BAILER. DUMP -2.5' (4.3 GALLONS) OF CEMENT ON TOP OF POSISET- (TOOLS COVERED IN ASPHAULTENES AND SOME 12/4/2015 ASPHALTENE BUILD UP IN TOOLS AS WELL.) RUN6: RIH WITH CEMENT DUMP BAILER. (ELINE CMT DUMP). INITIAL T/I/O = 200/300/200 PSI. RUN6: BAILER RUN 4/4. CEMENT DID NOT DUMP DOWNHOLE DUE TO ASPHALTENE BUILD UP IN ACUTATOR. RD AND CLEAN BAILER TOOLS. DECIDE TO PUMP HOT DIESEL FLUSH AND RETURN TO WELL LATER AFTER CEMENT SETS. WELL S/I AND SECURE. HAND OVER TO DSO. FINAL T/I/O = 12/5/2015 200/300/200 PSI. (ELINE BAILER/WHIPSTOCK). INITIAL T//I/O =150/200/200 PSI. LRS PUMP HOT DIESEL 12/7/2015 FLUSH AND FREEZE PROTECT. SLB RU/PT. T/I/O = 210/285/100 Temp = S/I Assist E-line (Pre CTD) Pumped 3 bbls meth and 50 bbls (50/50 mix) diesel/xylene flush and displaced TBG with 260 bbls of 180* F diesel down TBG. Let soak for 1 hour then flushed TBG with 90 bbls ambient diesel. RDMO. Hung info tags. SV/SSV/WV 12/7/2015 = Closed MV= Open IA/OA= OTG FWHP's T/I/O= 260/0/3 (dump bail/whipstock). RUN1: RIH WITH CEMENT DUMP BAILER. DUMP 2.5'(4.3 GALLONS) ON TOP OF POSISET PLUG.TAGGED TOC AT 10761' ELMD. NEW ESTIMATED TOC AT 10758'. RUN2: RIH WITH BAKER 7"WHIPSTOCK SET TOW AT 10725' ORIENTED AT 14.1 DEG/CCL TO TOW= 14.08'/CCL STOP DEPTH = 10710.92'. DEPTH CORRECTED TO SLB 12/8/2015 PERFORATION/JEWELRY LOG DATED 20-DEC-2008. 12/13/2015 CTU#3. 1.75" Coil 31.6 bbl CV. ***Arrive on Location***. Rig up, Begin weekly BOP test. CTU#3 1.75" Coil 31.6 bbl CV. Job Scope: Cement Squeeze. Continue BOP TEST. BOP test completed and a good test. MU 2.5" BDN. Had a fluid leak on surface equipment while RIH. POOH to fix. RIH while loading the well with 1%KCL and Diesel. Tagged the whip stock at 10755 ctm and corrected to 10725'. Pumped 30.4 bbls of 15.8 ppg class G cement leaving 2 bbls behind pipe. Held the squeeze pressure at 1800 psi for 30 minutes. Dropped 3/4" ball, pumped 70 bbl contaminate, cleaned out from 10733' up. POOH holding -500 psi on tubing, pumped freeze protect from 2500'. 12/14/2015 ETOC 10730' ELM. 12/15/2015 CTU#3. 1.75"Coil. Complete Rig Down. T/I/O= 0/200/200 Removed 6x7 Tree cap assembly& installed 6x7 test spool#4 &torqued to API spec.; PT test spool to 300 psi-low& 5000 psi-high (passed); Installed lubricator w/6" CIW'J"TWC #419 & PT to 300 psi low&3500 psi high (passed): Attempted to set TWC, Heating THA do to lack 1/16/2016 of turns while trying to set TWC into profile (2 turns); Made change out with day shift, job on going. T/I/O = 0/0/0. Set 6" J TWC#421 . @140"Throught tree and TS. Installed tree cap and PT'd to 500 1/17/2016 Psi. (PASS). RDMO. FWHP = 0/0/0. T/I/O = TWC/260/130. Temp = SI. WHPs. (Pre Rig). No wellhouse, flowline or AL line. IA FL @ surface. OA FL near surface. Bled IAP from 260 psi to 0+ psi in 10 min to slop tank (0.5 bbls). Bled OAP from 130 psi to 0+ psi in 34 minutes to slop tank (FTS, 0.6 bbls). Monitored for 30 minutes. IAP increased to 10 psi & OAP increased to 18 psi. Final WHPs = TWC/10/18. 1/20/2016 Rig in control of well on departure. 13:25. • • North America-ALASKA-BP Page 1 oS4.1 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date: X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/20/2016 00:00 - DRILL PROD1 14:00 - 16:00 2.00 MOB P PRE PJSM.TEST ESD.JACK UP RIG AND PULL OFF OF 09-01.MOVE OVER TO 09-02. -WSL VERIFIED CHOCK BLOCK IN FRONT OF DRIVE WHEEL -ESD SWITCH FUNCTIONED PRIOR TO MOVE AND MANNED BY TOOL PUSHER -ALL SPOTTERS VERIFIED RADIO COMMUNICATIONS DURING SAFETY MEETING -THE AGREED COMMAND OF"STOP" DISCUSSED DURING SAFETY MEETING -TEST ESD,BACK OVER WELL AND SPOT UP. RIG ACCEPTED @ 16:00 HRS,01/20/2016. 16:00 - 17:00 1.00 BOPSUR P PRE PJSM.SPOT CUTTINGS BOX AND FUEL TRAILER. -RIG UP GUAGE GUARDS AND SENSORS. -RIG UP TIGER TANK. 17:00 - 21:30 4.50 BOPSUR • P PRE PJSM.CYCLE TREE VALVES. -PERFORM LEAK TIGHT TEST ON MASTER VALVE AND SWAB VALVE TO 3500 PSI,OK. -N/D TREE CAP.N/U BOPE.INSTALL 2'SLB SPACER SPOOL. FUNCTION AND GREASE HCR VALVE. -WELL WORK TRANSFER PERMIT CLOSED OUT ON 09-01 WELL,NO ISSUES. 21:30 - 22:00 0.50 BOPSUR P PRE HOLD H2S/RIG EVACUATION DRILL. -ALL HANDS MUSTERED TO PRIMARY MUSTER AREA. -DRILL SITE OPERATOR NOTIFIED AND HEAD COUNT DONE. -AAR AND REVIEWED PROCEDURE FOR RIG EVACUATION. 22:00 - 23:30 1.50 BOPSUR P PRE PJSM.INSTALL TEST PLUG. -INSTALL NIGHT CAP AND FLUID PACK SURFACE LINES. -RIG UP TEST EQUIPMENT AND SHELL TEST 250/4500 PSI,5 MIN EACH,OK. 23:30 - 00:00 0.50 BOPSUR P PRE PERFORM INITIAL TEST ON BOPE AS PER AOGCC AND BP REQUIREMENTS. -AOGCC REP JOHNNIE HILL WAIVED WITNESSING THE TEST 23:30 HRS. Printed 2/1/2016 10:03:13AM . • North America-ALASKA-BP Page 221 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date: X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/me:2/16/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (us t) 1/21/2016 00:00 - 07:00 7.00 BOPSUR P PRE -PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,PTD#215-200,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5 CHARTED MIN EACH. -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER(3500 PSI) -ALL VARIABLE PIPE RAMS TESTED WITH 2 3/8"-3 1/2"TEST JOINT -2 3/8"PIPE RAMS TESTED WITH 2 3/8"TEST JOINT -BLIND RAMS TESTED ON OPEN HOLE 1 AGAINST TEST PLUG.. -ANNULAR TESTED WITH BOTH 2 3/8"AND 3 1/2"TEST JOINT -TEST FULL OPENING SAFETY VALVE -ALL TESTS ON ALL RAMS AND VALVES,250/ 3500 PSI/5 MIN EACH/CHARTED. -PERFORM ACCUMULATOR DRAW DOWN TEST. -FUNCTION BOP FROM BOTH REMOTE PANELS -ALL TEST WITNESSED BY DRILLER,RIG MANAGER OR BP WSL -AOGCC INSPECTOR JOHNNIE HILL WAIVED THE STATES RIGHT TO WITNESS THE TEST. -24 HOUR NOTIFICATION GIVEN TO THE AOGCC ON 1/19/2015 @ 07:45 HRS. 07:00 - 09:30 2.50 BOPSUR P PRE CONTINUE TESTING ON CRITICAL PATH -TEST BULKHEAD,COIL AND INNER REEL VALVE @ 250/4700 PSI. -PERFORM H2S/RIG EVACUATION DRILLS (OFF CRITICAL PATH) 09:30 10:30 1.00 i BOPSUR P PRE CIRCULATE DIESEL OUT OF REEL -FILL REEL WITH FRESH WATER FOR SLACK MANAGEMENT 10:30 - 15:00 4.50 BOPSUR P PRE PERFORM SLACK MANAGEMENT -CUT OFF BTT COIL CONNECTOR -INSTALL BOOT ON E-LINE -STAB ONTO WELL -PUMP SLACK INTO REEL -CUT 300'COIL -INSTALL SLB COIL CONNECTOR&TEST SAME -CIRCULATE 1 REEL VOLUME FORWARD -HEAD-UP WITH BHI UQC/LQC&TEST SAME 15:00 - 15:15 0.25 BOPSUR P PRE HELD PJSM FOR PU VALVE SHOP LUBRICATOR 15:15 - 17:45 2.50 BOPSUR P PRE PULL TWC -LOAD LUBRICATOR TOOLS ONTO RIG -RU LUBRICATOR AND STAB ONTO WELL -PRESSURE TEST 250 LOW/3500 HIGH -LATCH INTO TWC AND PULL FROM WELL -WELL ON A VACUUM -CLOSE MASTER/SWAB VALVES -RD VALVE SHOP LUBRICATOR 17:45 - 18:00 0.25 BOPSUR P PRE INSTALL NIGHT CAP -CIRCULATE ACROSS TOP TO FILL WELL -CLEAN RIG FLOOR Printed 211/2016 10:03:13AM • • North America-ALASKA-BP Page 3 ot$r Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date: X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 18:30 0.50 BOPSUR P PRE PJSM AND GREASE TREE VALVES. -HOLD PJSM WITH VALVE SHOP GREASE CREW. -GREASE MASTER AND SWAB VALVES. 18:30 19:00 0.50 BOPSUR P PRE FLOW CHECK WELL. -OPEN TREE VALVES AND VERIFY 0 PSI. -POP OFF NIGHT CAP AND FLOW CHECK 30 MIN-NO FLOW. 19:00 - 20:00 1.00 STWHIP P WEXIT PJSM AND MU MILLING BHA. -PU 2-7/8"XTREME MOTOR WITH 0.6°AKO. -MU WINDOW MILL AND STRING MILL. -WSL GAGE AND VERIFY MILLS 3.80"OD. -MU 2 JTS 2-3/8"PH6 AND CARRY SCRIBE. -MU 3"COILTRAK AND TEST MWD TOOLS. 20:00 - 22:30 2.50 STWHIP P WEXIT RIH WITH MILLING ASSEMLBY SURFACE TO 10,700'MD. -TEST OTS TO 250/3500 PSI FOR 5/5 MIN. -RIH 100'/MIN WITH 1.49/2.02 BPM IN/OUT. -MW IN/OUT:8.33/7.74 PPG. -LOG TIE-IN WITH-14.5'CORRECTION. -WELL FLUIDS:METHANOL FREEZE PROTECT TO 2500'MD,1%KCL TO WHIPSTOCK AT 10,725'MD. .-RIH CIRC 1%KCL DOWN COIL.TAKE ALL RETURNS TO TIGER TANK. 22:30 - 00:00 1.50 STWHIP P WEXIT DISPLACE WELL TO 8.6 PPG MILLING FLUID. -2.90/2.90 BPM IN/OUT WITH 1275 PSI. -MW IN/OUT:8.34/8.58 PPG. -TAKE KCL RETURNS TO TIGER TANK. 1/22/2016 00:00 - 01:30 1.50 STWHIP P WEXIT CONTINUE DISPLACE WELL TO 8.6 PPG MILLING FLUID. -3.17/3.17 BPM IN/OUT WITH 2210 PSI. -MW IN/OUT:8.65/8.35 PPG. -TAKE KCL RETURNS TO TIGER TANK. -RIH AND DRY TAG WHIPSTOCK AT 10,732' MD. -PU AND TAG PUMPS ON 10,732'MD. J 1�^' V' 01:30 - 06:00 4.50 STWHIP P WEXIT MILL WINDOW 10,732'-10,734'MD SVar4 -FS:2190 PSI MTR WRK:50-100 PSI WOB: 0.5-1.0K# 061414 -BPM IN/OUT:2.76/2.76 PVT:202 BBLS -MW IN/OUT:8.63/8.58 PPG -ECD/IA/OA:9.26 PPG/455 PSI/90 PSI -TIME MILL AT 1'/HR. 06:00 - 12:00 6.00 STWHIP P WEXIT MILL WINDOW 10,734.6'-10,736.2'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.60/8.56 PPG -IA/OA/PVT:625 PSI/143 PSI/169BBLS 12:00 - 16:00 4.00 STWHIP P WEXIT MILL WINDOW 10,736.2'-10,736.8'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.60/8.56 PPG -IA/OA/PVT:638 PSI/176 PSI/165 BBLS ""PERFORM MUD SWAP FROM USED POWERPRO TO FLOWPRO SYSTEM*** Printed 2/1/2016 10:03:13AM • S North America-ALASKA-BP Page 4Del Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date: X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 18:30 2.50 STWHIP P WEXIT MILL WINDOW 10,736.8'-10,737.1'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.60/8.56 PPG -IA/OA/PVT:638 PSI/176 PSI/165BBLS 18:30 - 22:00 3.50 STWHIP P WEXIT MILL WINDOW 10,737.1'-10,737.1'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:707 PSI/220 PSI/290 BBLS 22:00 - 00:00 2.00 STWHIP P WEXIT MILL WINDOW 10,737.1'-10,737.9'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:707 PSI/220 PSI/290 BBLS 1/23/2016 00:00 - 04:00 4.00 STWHIP P WEXIT MILL WINDOW 10,737.9'-10,741.1'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:717 PSI/242 PSI/288 BBLS -WT ON BIT FELL OFF @ 10,739.3'TO.6-1K. 04:00 - 07:30 3.50 STWHIP i P WEXIT MILL WINDOW 10,741.1'-10,745'MD -FS:2190 PSI MTR WRK:50.100 PSI WOB: .7-1.2 K# -BPM 1N/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:717 PSI/249 PSI/289 BBLS 07:30 - 09:30 2.00 STWHIP - P WEXIT MILL 10'NEW FORMATION F/10,744'-10,754' MD -MM IN/OUT:2.74/2.74 CIRC PSI:2153 -MW IN/OUT:8.52 PPG/8.48 PPG -IA/OA/PVT:708/259/284 -WOB/ECD:0.5-2K/9.03 PPG _ 09:30 - 12:00 2.50 STWHIP P WEXIT REAM AND DRESS WINDOW PER PLAN -MM IN/OUT:2.74/2.74 CIRC PSI:2153 -MW IN/OUT:8.52 PPG/8.48 PPG ***DRY DRIFT WINDOW(NO ISSUES NOTED) I .« 12:00 - 12:15 0.25 STWHIP P WEXIT FLOW CHECK 12:15 - 14:00 , 1.75 STWHIP P WEXIT POOH WITH MILLING ASSEMBLY F/10,755'- 200'MD -MM IN/OUT:3.82/3.25 CIRC PSI:2585 -MW IN/OUT:8.53 PPG/8.49 PPG -FLOW CHECK(GOOD) 14:00 - 14:30 0.50 STWHIP P I WEXIT LD MILLING ASSEMBLY -HOLD PJSM FOR LD MILLING ASSEMBLY -GET OFF WELL WITH INJECTOR(1410) -LD MILLING ASSEMBLY -GUAGE MILL:3.79 GO 3.78 NO GO -STRING:3.80 GO 3.79 NOGO 14:30 - 15:45 1.25 DRILL P PROD1 MU BUILD ASSEMBLY -HOLD PJSM ON RIG FLOOR -MU DIRECTIONAL/MWD TOOLS -GET ON WELL WITH INJECTOR(15:20) -INITIALIZE MWD TOOLS -PRESSURE TEST QTS Printed 2/1/2016 10:03:13AM TREE= aw WELLHEAD= FMC GEN 1 • r I SOY NOTES: ***CHROME LNR&TBG*** ACTUATOR= BAKER C 09-02 OKB.ELEV= 54' BF.ELEV= KOP= 3079' Max Angle= 47*@ 7000' 2231' H7"CAM BAL-O SSSV NP,ID=5.937" Datum MD= 103' Datum TVD= 8$00''SS 2985' -I 7"X 5-112"XO,D=4.892" 13-3/8"CSG,72#,MN-80,13=12.347" H 2726' \ / GAS LIFT MANDRELS ST MD ND DEV TYFE VLV LATCH PORT DATE 7"TBG,26#,13CR-80,.0383 bpf,D=6.276" -I 2985' 1 2998 2997 8 FM-10 DMY RK 0 06/07/15 2 4619 4434 42 FMIO DMY RK 0 08/26/91 3 5724 5221 45 RA-10 DMY RK 0 05/20/97 4 6401 5713 43 F1410 DMY RK 0 06/07/15 5 7035 6159 47 FIA-10 DMY FE 0 08/26/91 Minimum ID = 3.80" @ 10266' 6 7707 6626 45 FM10 DMY RK 0 08/26/91 4-1/2" OTIS XN NIP MILLED **7 8295 7055 42 FM-JO DMY RK 0 08/26/91 8 8840 7454 44 FMiO DMY RK 0 06/07/15 9 9424 7870 45 FMJO DMY RK 0 08/26/91 10 9797 8136 44 FM10 DMY RK 0 06/07/15 11 10126 8379 41 FM-O RKH) RKP 0 05/20/92 5-1/2'TBG, 17#, 13CRS0, .0232 bpf,ID=4.892' H10151' "*CANNOT PULL ST#7 AS OF 6!19/97 10151' H)-1/2"X4-112"X0,D=3.958" J 10153' --I BKR GBH-22 LOCATOR SEAL ASSY,D=? 10154' -19-5/8"X 4-1/2"BKR MODEL D PKR,13= 9-5/8"X 7"TEBACK SLV,D=? H 10222" 10168' --15"MILLOUT EXTENSION,ID=? 1 10173' --I ML.LOUT EXTSION XO TO 4-1/T,13=3,958" 9-518"X 7 BKR&LNR HGR,ID= , 10230' ' 10265' -I4-1/2"OTIS XN NP MLLE)TO 3.80"(12/4/15) 4-1/2"TBG,12.6#,13CR-80,.0152 bpi,D=3.958" - 10278' 10277' -4-1/2"BKR SHEA ROUT SUB,13=? 111 10278' -14-112"Tt18NG TA L,D=3.958" 1 10282' --I ELMD- r LOGGED 09/06191 10453' -17"MARKER JOINT 10474' H7"MARKER JONT 1072W _-17"BKR DELTA WHPSTOCK(12/08/15) CEMENTED WS IN PLACE(12/14115) -I -10730' '.!l4.cii:lilis -10758' HCMTDUMP(12/08/15) PERFORATION SUMMARY '____________.1 REF LOG: BHCS ON 03/10/76 10770' .-17"POSISET PLUG(12/04/15) NOTE GR does not correlate w/BHCS due to'HON deposits 10846' _-ITER WELL 350-700 HEX PLUG, ANGLE ATTOP PEFF•: 38*@ 10674' ME@ 10850',(11/11/12) Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE I __?? 1-I FISH-BP RUBBER ELEMENT(03/26/96) 1 SEE PAGE 2 FOR PERFORATION INFORMATION I I I I4Ikr11003' FISH 2 Smal Pieces of Spinner Housing PBTD H 11055' 111111111111111 7"LNR,29#,13CR-80,.0371 bpf,D=6.184" -I 11097' �1�11/1111/1111/1111� 11111111111 9-5/8"CSG,47#,MN-80,D=8.681" H 11153' 11/1111/111/1144411 1111111111 TD H 11199' DATE REV BY COMENTS ' DATE REV BY COMIVENTS PRUDHOEBAY UNIT 03/22/76 INTIAL COMPLETION 03/04/14 JMG/JMD SET PXN PLUG(02122/14) WELL: 09-02 08/25/76 ROW 34 RWO 03/14/14 JLS/JMD PULLED PXN PLUG(03/11/14) PERMIT No:'1760160 10/20/87 PAA 102 RWO 06/26/15 MUC/JMD GLV GO(06/07/15) AR Nb: 50-029-20198-00 08/27/91 RWO 12/11/15 CJS/JMD PLUG/CMfT/WS/MLL XN NIP SEC 2,T1ON,R15E,170'FSL&69T Fa 09/07/12 MSS/JMD GLV C/O(09/05/12) 12/18/15 SJW/JMI3 CMT SOZ(12/14/15) 11/14/12 JGIWJMD SET t-EX PLUG(11/11/12) BP Exploration(Alaska) thdf= CIVN SOY NOTES: ***CHROME LNR&TBG*** WELLHEAD= FMC GEN 1 09-02 ACTUATOR= BAKERC OKB.ELEV= 54' BF.EiEV= KOP= 3079' Max Angle= 47°@ 7000' Datum MD= 10733' Datum TVD= 8800'SS L PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 NOTE GR does not correlate w/BHCS due to-HOT deposits ANGLE AT TOP PERF: 38°@ 10674' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 10649-10666 S 06/03/97 3-3/8" 6 10674-10679 S 12/14/15 3-318" 12 10679-10694 S 12/14/15 3-3/8" 6 10694-10699 S 12/14/15 10699-10730 S 06/03/97 3-3/8" 6 10700-10710 S 12/14/15 10749-10799 S 06/03/97 3-3/8" 6 10780-10790 C 12/08/15 3-3/8" 6 10815-10825 C 12/08/15 10817- 10841 S 08/15/91 3-3/8" 4 10856-10866 C 09/08/91 3-3/8" 4 10872-10886 C 09/08/91 3-3/8" 4 10896-10906 C 09/08/91 3-3/8" 4 10940-10948 C 09/08/91 3-3/8" 4 10962-10972 C 09/08/91 •••••i•�• 11111111 11111/11�.�., ►111111111111111111111 111111111111111111111 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 03/22/76 INTIAL COMPLETION 03/04/14 JMG/JMD SET PXN PLUG(02/22/14) WELL 09-02 08/25/76 ROW 34 RWO 03/14/14 JLS/JMD RILED PXN RUG(03/11/14) PERMIT No: 1760160 10/20/87 PAA 102 RWO 06/26/15 MJGJMD GLV GO(06/07/15) AR No: 50-029-20198-00 08/27/91 RWO 12/11/15 CJS/JMD PLUG/CMI/S/WILL XN NP - SEC 2,T10N,R15E,170'FSL&697'FEL 09/07/12 MSS/AD GLV GO(09/05/12) 12/18/15 SJW/JWD CMT SOZ(12/14/15) 11/14/12 JCMJMD SET HEX RUG(11/11/12) BP Exploration(Alaska) • Q`ti OF ? • • �w„ • I%%ins THE STATE Alaska Oil and. Gas o,f AsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFMain: 907.279.1433 ALAS Fax: 907.276.7542 �Q �`�Ql� www.aogcc.alaska.gov John McMullen 064° 4 Y Engineering Team Lead BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-02 Sundry Number: 315-687 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair 44- DATED this /3y of November, 2015 Encl. RBDMM,NOV 16 2015 STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMM,N APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Re1)drill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 176-016 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20198-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? �s Will planned perforations require a spacing exception? Yes 0 No H PBU 09-02 . i3L�.+■. 5VizsE:P 9. Property Designation(Lease Number): 10. Field/Pools: %�N Ob 2015 _ADL 028327 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY rG CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Jun (measured): 11199 • 9214 ' 10846 8940 10846 Unknown,11003' Casing Length Size MD ND Burst collapse Structural Conductor 80 20" 36-116 36-116 1530 520 Surface 2730 13-3/8" 35-2726 35-2726 5380 2670 Intermediate Production 11120 9-5/8" 33-11153 33-9178 8150/6870 5080/4760 Liner 877 7" 10238-11115 8462-9149 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10674-10972 8805-9039 7",26#x 5-1/2",17#x 4-1/2",12.6# 13Cr80 10294 Packers and SSSV Type: 4-1/2"Baker Model D Packer Packers and SSSV MD(ft)and TVD(ft): 10170/8410 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for Commencing Operations: November 15,2015 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Minge,David Email David.Minge@bp.com Printed Name John NMy /. Title Engineering Team Lead / // Signature � Phone +1 907 564 4711 Date 1 ( /6 /( " ,. COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: CO 315 .- Ckci 7 Plug Integrity 0 BOP Test NO Mechanical Integrity Test 0 /��j Location Clearance 0 Other: 4 S500 p5.. cip f`"' F C /1'v Lo`., 2j/ Op ::)c.) a t Tern lc,t Pi'iC iii a+-& Olo fCrf eL'"- 6 !�' 1C cJ Spacing Exception Required? Yes 0 No Subsequent Form Required: /0--d--/tj - gie APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date/t/3_45-- y'- r 3. 'S ORIGINAL RBDMS';\VnV 16 2015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate .4 '4/r „,,- A /,`?,/>_ To: Alaska Oil &Gas Conservation Commission From: David Minge bD CTD Engineer Date: November 3, 2015 Re: 09-02 Sundry Approval Sundry approval is requested to abandon the 09-02 wellbore liner with a plug and cement squeeze the perforations, as well as, isolate the 09-02 wellbore as part of the drilling and completion of the proposed 09-02A CTD sidetrack. History and current status: 09-02 (parent bore)was last online in December 2013, and its production rates were uncompetitive at the Flow Station 2 facility. Average production rate of 09-02 before it was shut-in were: 2 BOPD; 12,553 bwpd (100%WC), 1.5 mmscfd formation gas. The 09-02A sidetrack will access two stagnation polygons around corner producer 09-02. There is also a partially swept target area between the injector(09-19) and the corner producer(09-02)which the sidetrack will test. Proposed plan: Drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around January 20st, 2016. E-line service unit will mill XN Nipple, Set Posiset Plug to isolate perforations below, set / whipstock and a Coil Tubing unit will cementsqueeze perfs to isolate between 7' and 9-%"casing and the perforations above the side track depth. Nordic 1 will a mill a 3.80"window in the 7"x9-5/8" liner and drill a Zone 2 well to-13,792 MD. The lateral will be completed with a 3-1/2"x 3-1/4" L-80 liner which will be cemented and perforated. This Sundry covers plugging the existing 09-02 perforations via the 09-02A liner cement job or liner top packer yf- set post-rig (alternate plug placement per 20 AAC 25.112(i)) and via posi-set plug and cement squeeze. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the curre nt wellbore and proposed sidetrack is attached for reference. -. d2e)]t-oz- /to, Dalt, r Za !c. t� 4V l�l7dLLr vt ' Urn cJ - t j_-c %_ > 4e- /6 `/' C� ) 3� ,�, CT (c 9 oc v3/ /: 9 /r-- co/icy( r-'CO/9cyr , /e1 e 184 ect wf(( eyerieocc=o a /010 f r ,'ppo or /Tocoiy de) I'll C ' f pr 0 dv&t,'4A f14 ,'N cfeGffC I war&-- Cyr. 1-4P &.- f( �P/4!4 z40 / qNr/ fiat,/ dde C.pn r red ge vv!ft/ r L fair cork. cher il,e raf toct aZ04 cll4-r,0/ 70 ?i-C"gale, r 7"c €pof O g 74,,e_ or Gf,//i� ,R/IV % e 11.oJ-el Cyr W0./ j I1 ?rceir et- 79g tv44 7e -r4 e. &O R w 4'j Over y0 Maki "7/vfpr''" %4 i wc/' 'cr 'Pcii f'I so 747- (o s Aevk/ ar//av ;I)/ ,'rh'r°'d reCOVB 1(0„.1 (4/ "'lira, at The /(�// • • Pre-Rig Work: Schedules November 15th, 2015 Mill XN nipple. Set 4-1/2" x 7" Posi-Set plug at 10,740' MD. Set 4-1/2" x 7" 1. E Delta Whipstock at 10,726' MD 2. C Squeeze Cement into perforations 3. V Pre CTD Tree Work. Set TWC Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10 f D w* psi/ft) to surface is 2,510 psi. s")) 2. Mill 3.80"window plus 10' of rathole. Swap the well to 8.5 pp_g drillingmud. 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD at—13,792' MD �� 5. Run 3-1/2" x 3-1/4" L-80 liner leaving TOL at—10,235 MD. Pig 6. Pump primary cement bringing TOC to L, 41 bbls of 15.8 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: Drift. LTP if necessary.*Set Live GLV's 3. F: Pressure test Liner top packer 4. T: ASRC flow back *Approved alternate plug placement per 20 AAC 25.112(i) David Minge CTD Engineer 564-4061 CC: Well File Joe Lastufka TREE= cxWill WELLI FAD= FMC •GSM 1 • S NOTES: ***CHROME LNR&TBG•** -ACTUATOR= BAKER C 0 9- /2 OKB.6_EV 54' �+ 'r+ �+ BF.ELEV= KOP= 3079' Max Angie= 470 @ 7000' 2231' Hr CAM BAL-O SSSV NP,D=5.937" Datum MD= 10733' 0 Datum TVD= 8800'SS A 2985' Hr X 5-1/2"XO,D=4.892" 13-3/8"CSG,72#,MN-80,D=12.347" — 2726' I/ \ / GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE r TBG,26#,13CR-80,.0383 bpf,ID=6.276" H 2985' 1 2998 2997 8 FMHO DMY RK 0 06/07/15 2 4619 4434 42 FM10 DMY RK 0 08/26/91 3 5724 5221 45 FMHO DMY RK 0 05/20/97 4 6401 5713 43 FMHO DMY RIC 0 06/07/15 Minimum ID = 3.725" 14265' ' 5 7035 6159 47 FMHO DMY RK 0 08/26/91 6 7707 6626 45 FMHO 0MY RK 0 08/26/91 4-1/2" OTIS XN NO-GO NIPPLE ' **7 8295 7055 42 FM-10 DMY RK 0 08/26/91 8 8840 7454 44 FMHO DMY RK 0 06/07/15 9 9424 7870 45 FMHO DMY RK 0 08/26/91 10 9797 8136 44 FMHO 0M' RK 0 06/07/15 11 10126 8379 41 FMHO FEED RKP 0 05/20/92 15-1/2'TBG,17#,13CR-80,.0232 bpf,ID=4.892" Li 10151' }---- *'CANNOT PULL ST#7 AS OF 6/19197 10151' H5-112"X 4-1/2XO,D=3.958" 10153' —{BKR GBH-22 LOCATOR SEAL ASSY,ID=? 10154' —19-5/8'X 4-1/2"BKR MODEL D PKR,D= 9-518"X 7"T1E33ACK SLV,D=? —1 10222' 10168' 15"MILLouT EXTENSION,ID=? — 10173' H MLLOUT EXTSION XO TO 4-1/2",D=3.958" 19-5/8'X7*BKR&LNR HGR,ID=? 10230' 10265' H4-1/2'OTIS XN ',D=3.725" M i 4--'' 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,D=3.958" H 10278' \ 10277' --i4-112'BKRSI-EA ROUT SUB,D=? 10278' H4-112'TUBING TAI_,D=3.958' 10282' H ELMD TT LOGGED 09/06/91 10453' —7'MARKER Jour 10474' Hi"MA RKER Jo1YT PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 NOTE GR does not correlate w/BHCS due to 1-10-1-deposits ANGLE AT TOP FERE: 38"@ 10674' 1-11. Note:Refer to Ptoduction DB for historical pert data SIZE SPF 14TERVAL Opn/Sqz DATE SEE PAGE 2 FOR FERFORATION I FORMATIONI 10846' ( MER WELL 350-700 FCC PLUG, I I I �ME@ 10850',(11/11/12) r ?? FISH-BP RUBBER ELEMENT(03/26/96) 11003' 1—IF-1S—H72—Small Pieces of Spinner Housing PBTD H 11 o5s' 7"LNR,29#,13CR-80,.0371 bpf,D= • 6.184" 11097' � ''``♦'�, ��d4D00 • I 9-518"CSG,47#,MN-80,D=8.681' 11153' ••+4/44��•• TD H 11199• .4. .4.44. DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/22/76 IMTIAL COMPLETION 03/04/14 JMG/JMD SET PXN PLUG(02/22/14) WELL: 09-02 08/25/76 ROW 34 RWO 03/14/14 JLS/JMD PULLED PXN PLUG(03/11/14) FERMIT No:'1760160 10/20/87 PAA 102 RWO 06/26/15 MIC/JM) GLV C/0(06/07/15) AA No: 50-029-20198-00 08/27/91 RWO SEC 2,T10N,R15E,170'FSL&697'FF3 09/07/12 MSS/JMD GLV 00(09/05/12) 11/14/12 JCMJMD-SET HD<PLUG(11/11/12) BP Exploration(Alaska) TFEE= cm, • ANYNOTES: ***CHROME LNR S TBG*-** • WELLHEAD= FMC GEN 1 ACTUATOR= BAKER 09-02 OKB.ELEV= 54' BF.l3EV KOP= 3079' J Max Angle= 47'@ 7000' O 1, Datum MD= 10733' Datum TVD= 8800'SS ` / Id PERFORATION SUMMARY R8 LOG: BHCS ON 03/10/76 NOTE GR does not correlate w/BHCS due to'NOT'deposits ANGLE AT TOP PERF: 38'0 10674' L. J. Note:Refer to Production DB for hisIorical pert data SEE SPF INTERVAL Opn/Sqz DATE 10649-10666 S 06/03/97 i !EMI 3-38" 6 10674-10679 0 07/23/97 • 3-38" 12 10679-10694 0 07/23/97 3-38" 6 10694-10699 0 07/23/97 - 10699-10730 S 06/03/97 3-38" 6 10700-10710 0 12/20/08 • 10749-10799 S 06/03/97 3-38" 6 10780-10790 0 12/20/08 3-38" 6 10815-10825 0 12/20/08 10817-10841 S 08/15/91 3-38" 4 10856-10866 C 09/08/91 3-3/8' 4 10872-10886 C 09/08/91 3-38' 4 10896-10906 C 09/08/91 3-38" 4 10940-10948 C 09/08/91 3-3/8' 4 10962-10972 C 09/08/91 I I 111111111•1•1 111j11111111111jvi 111111111111111111 1111111111111 , • 1W11V1���, DATE REV BY COMI�TTS DATE REV BY COMVENTS 1 PRUDHOE BAY UNIT 03/22/76 INTIAL COMPLETION 03/04/14 JMG/JMD SET PXN PLUG(02/22/14) WILL 09-02 08/25/76 ROW 34 RWO 03/14/14 JLS/JMD PULLED PXN PLUG(03/11/14) PERMIT No:'1760160 10/20/87 PAA 102 RWO 06/26/15 MJC/JMD GLV C/O(06/07/15) AR No: 50-029-20198-00 08/27/91 RWO SEC 2,T1 ON,R15E,170'FSL&697'FH.. 09/07/12 MSS/JMD GLV C/O(09/05/12) 11/14/12 JCMJMD SET I-EX RUG(11/11/12) BP Exploration(Alaska) TREE= CNV _ _ _ ____ I il WELLHEAD= FMC GEN 1 W 0 9_a 2 A S Y NOTES: ***CHROME LNR&TBG*** ACTUATOR= BAKER C 111 OKB.ELEV= 54' CTD Sidetrack 1 2231' --17"CAM BAL-OSSSV MP,D=5.937" BF.BEV= KOP= 3079' / 2985' Hr X 5-1/2"XO,D=4.892" Max Angie= 470 @ 7000' 0 Datum ND 10733' Datum TVD= 8800'SS tk GAS LET MANDRELS ST—MD ND DEV TYPE VLV LATCH PORT I DATE 13-3l8'CSG,72#,MN 80,D=12.347" — 2726' _ L/ 1 2998 2997 8 FMHO DMY RK 16 05/06!15 2 4619 4434 42 FMHO DM? RK 0 08/26/91 7"TBG,26#,13CR-80,.0383 bpf,D=6.276" H 2986' 3 5724 5221 45 FMHO DMY RK 0 `05/20/97 4 6401 5713 43 FMHO DMY RK 16 06/06/15 I I I5 7035 6159 47 FMHO DMY RK 0 08/26/91 6 7707 6626 45 FMHO DMY RK 0 08/26/91 "7 8295 7055 42 FMHO DMY RK 0 08/26/91 Minimum ID = 3.725" @ 10265' 8 8840 7454 44 FMHO DMY RK 16 06/06/15 9 9424 7870 45 FMHO DMY RK 0 08/26/91 4-1/2" OTIS XN NO-GO NIPPLE 10 9797 ' 8136 44 FMHO DMY RK 24 07/06/15 11 10126 8379 41 FMHO RKED RKP 0 05/20/92 —_ _ '*CANNOT PULL ST#7 AS OF 6/1W97 10151' --15-1/2"X 4-1/2"XO,ID=3.958' 5-112" TBG, 17#, 13CR-80, 0232 bpf,ID=4.892" 10151' / 10153' —)BKR GBH-22 LOCATOR SEAL ASSY,D=? 10154' H9-5/8"X 4-1/2"BKR MODEL D PKR,D= 10168' I--(5'MILLOUT EXTENSION,ID=? 10173' —1 MLLOUT EXTSION XO TO 4-1/2",D=3.958" 9-5/8"X 7"TEBACK SLV,D=? H 10222' _ . 01 3.70"BKR DEPLOY SLV,ID =3.00"@ 10,235'14 D 95/8'X7'BKR BLNR HGR,ID=? — 10230' i — 31, X-9phID=2913"@ 10,245'MD / 10265' —4-112"OTIS XN NP,ID=3.725" M 1�XN 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,D=3.958" H 10278' • /f / 10277' H4-1/2-BKR St-€AROUT SUB,13=? PERFORATION SUMMARY ' REF LOG: BRCS ON 03/10/76 " / 10278' —4-1/2"USING TAIL,D=3.958" NOTE GR does not correlate WBHCS due to"HOT"deposits A NG LE AT TOP PERF: 38'@ 10674' 10282' H ELND TT LOGO 09/06/91 Note:Refer to Roduction DB for historical pert data - 10453' —17"MARKER JO SIZE 1 SPF 1 INTERVAL I Opn/Sqz I DATE C'►'t'" / / JOINT —7"MARKERJONT SEE PAGE 2 FOR PERFORATION INFORMATION I I I I / /// 3-1/l"93`4STL13CR-80� ` 3-1/2'5c3-1/4"XO @ -10,640'MD Lt 19°/100' BUR L("Z�, 4-1/2"x 7"BakerTT whistock@ 10,726 'MD 38°sac@ wndow iii 7"hifhtabl:Bridge Plig @ 10,740' ' • I RA TAG @ TBD TD @ 13,792 MD 3-1/4"13CR Liiertp 11003' 1-FISH-2 Sma1 Pieces of Spinner Housing I--s PBTD H 11055' 4.....A 7"LNR 29#,13C R-80,.0371 bpf,D=6.184" —{ 11097 ►**•••4•••♦ ?? —I FISH-BP RUBBER ELEMENT(03/26/96) I X11....1..1 9-5/8"CSG,47#,MN-80,D=8.681" H 11153' 1.....*****•••••••••••1 TD - 11199' ►.......1.1........... DATE REV BY COMVBNTS DATE REV BY COMVENTS PRUDHOE BAY LI`IT 03/22/76 _IMTIAL COMPLETION 03/04/14 JMG/JM? SET PXN PLUG(02/22/14) WELL: 09-02 08/25/76 ROW 34 RWO 03/14/14 JLS/JMJ PULLED PXN PLUG(03/11/14) FERMI No: 1760160 10/20/87 PAA 102 RWO API No: 50-029-20198-00 08/27/91 RWO SEC 2,T10N,R15E,170'FSL&697'Fri 09/07/12 MSS/JND GLV C/O(09/05/12) 11/14/12 JCMJM? SET HEX PLUG(11/11/12) BP Exploration(Alaska) • • t. . 11 ~all mil e = 0- : LL V _8 f 5a a $ b Cc 1,1 M AIRE ° A a E 2 re U 3 IE Ys e . e J 1 c 1 - 6 0 -w o 'o m G a C E ho Ea G 7 " 3 3 e �` m g� 88 -E 5- E t 1., "� u o o1 I a _ — rayl Iyyl V U.�. a C a of C 00o s g Oq S U_ <CI 0 ' 1 6 111 r.1 I ,d : 14ICIIHII . UL. I:; o ; x o 1 c ,1 w /1 = Z , LL c F 111 a 111 2 1 II > I €g 1111 In m I— N -,T, nil 111 _ °m Eo ii 1 F. pri II SWll • �l1e ( z . IIr. rL I W a 111 Ikt r CL W e Y `� N 11 g 0 O C a m 2 1 N a V 11 4 2 him a_ V w LEt p '"r e N 1- Am J Q 1 "� 1 I 1 �� n r • G re o mg O E Z a° I — 0j v e , in 4) rca A I ge I 1� 1 i • 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 j in the upper left corner of Form 10-403 is checked. If the Abandon" or v" "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. tZ(q -0 lig Gyrodata incorporated `g2-`1' gyro/datc ; 23000 Northwest Lake Dr. Houston, Texas 77095 Precision Wellbore Placement T. (281) 213-6300 • F: (281) 213-6301 SCORED JUL 1 8 2.016 SURVEY REPORT BP Exploration Drill Site: 09 #09-02 Wellhead Prudhoe Bay, North Slope Borough, AK AK0715GCM1 49 6 July 2015 RIGHT PLACE FIRST TIME 1 ! www.gyrodata.com Gyrodata Incorporated gyro/data.23000 Northwest Lake Dr. Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 February 12, 2016 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 09, Well #09-02 Prudhoe Bay, Alaska Enclosed, please find one (1) copy, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME (SO\ www.gyrodata.com � ( Q \ oo o \ 7 / o Z / Q /a \ ƒ • \ o §d 2 9 / § \• & t E. §/ a / \ o ± d /$ » / e H / / / 0 0 ? 9 0 o 2 g / e o 2 0 a _ ^ / i 0 § ƒ / 0 / § / / (3 0 \ / ( $ / E-4 v) § • t y 2 0 ` U E 2 • $ / 2 - / 2 � « / a g 0 # % \ / § e / •° § § o• / ? / / / $ \ / \ /J\ . � b A 44 \ \ w + � o • v $ Q � d � 9 ' \ \ \ 2 \ Q 2 < 4.1 \\ fl H // . /o / \ Z bb on / / \ 2 \ \ \ r ) \ § \ \ - / - \ / f §/ d/ VD 0 0 \ / / § , / / / / \ U $ ƒ , N W 333344 WWWWW WWWWW WWW O VD VD CT ,, on v) )O ton M VD O ton 0 et O) M r` )O 7 a 'Ci) O co-! 7. t N M O MV) D\ Cl 00 et O 4n C 00 'O ,71- N Ii..4 O O O O O O O O O +-. .--, N M M M d- .O o0 Oi 0 N ,_i (2 r=" O o z 'TV qO000VO 00 r- 00Vo 0N � Vo7t 0 O00 � ., O Nh0 'r N Q\ N � '000 .--, r+ OMoo � ooM µ.� O O O O O co .--, . •--� N N N N M M M M M ct vi r` 0 H I W N M a H cri O � N VI O et M VO VO 00 .-, 00 N -. -+ ..n O fN 10 r+ co; 16 N 00 01 co; OO 4 r -. 16 O O 00 d' rt 00 4 CA O O) r, N * O) N VD VD V) �net d' MMMN NNN N N N ..., -, .., -, r, .� -, — ,, ,--. „, r. .-y ,-. * O O Q M00 N u> 00 O M VO Q) d: O M VO N N O M co >-, O O O H 4-4 4-4 N N N N M 4 4 4 vn 16 00 6 ,, U `H H � O CID ,n H 0 Q - z d W a � xv) 0 x Q x O aj O 0 0 0 0) Q) o. 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Q . •• •• • •~ • o a' 0.11--•-•••••,. • • • • Q OWino CO _ _ + - • • • 1 p a Ln • Ur) I --,---- ` i • + ___ -. • o .0 • 0 o ---- o rnz 1" • --- __� _____j J 0 i •• —• ('--•"—'_.-.� 0 N O p� Y rr• — M a) 1 • • • -- N •.:;' `-. �. 1 • _r..e.+ U o .--1 a1 _ _J_._.___.__ .__1_ .__.._ 1 • p0 r.0 u • • N r0 In • ai al -p 7,-c O n1 O O r rp X •: 1 I 1 I ' I , 1 I 11 I I I I 1 I I I , I , I I Tf 1 I p W N V I 1 - 0 Ln 0 LI o Ln o Ln O Ca --- J '' Cr; Cr; N N ,--I .-•i O O (1400T/60p) kLflJ ASS D 1JOG Survey QC - RGS-CT Continuous Specification Sheet gyrodata SURVEY QUALITY CONTROL - SPECIFICATION DATA s°"; 10B CALIBRATION VERIFICATION (ROLL TEST) System Parameter dGx dGy dmbo Mean Gravity Error* Stdev Gravity Error Standard Deviation 0.006 0.006 0.006 -0.00005 0.00002 Tolerance 0.033 0.033 0.087 0.00591 0.00720 Ivor)VFRTCTCAATTnN !Ar vhNCcP TNTTT.1,E..TSATTON) Gyro Compass Parameter Gyro noise dGx dGy dmbo Max corr coef Standard Deviation 0.055 0.005 0.004 0.005 0.18 Tolerance 0.141 0.033 0.033 0.087 0.43 Initialisation inclination standard deviation 0.08 Initialisation azirhuth standard deviation 0.41 Initialisation azimuth uncertainty in percent of error model -Tolerance < 100% 38% ACCELEROMETER;VEr 'ION (G-TO rt applic, ie for 2. :'lerome: systems G-Total Test Parameter Mean Gravity Error Mean Gravity Error Standard Deviation Error -0.00021 0.00001 Tolerance 0.00590 0.02664 CALIBRATION Tool Number I F0211 Calibration Date 01 Oct 2014 i OPERA NG TEMPERATU Calibration range From 40.06 To 119.98 Gyro operating range From 59.37 To 91.21 In-Spec if+/- 2.5 °C of Calibration "ONITTNE_IOrUS ORM,"CORRFCTIOr, Linear Drift Uncertainty 0.25 Random Walk Uncertainty 0.03 Tolerance 0.46 Tolerance 0.23 CONTINUOUS MISALIGNMENT CORRECTION Misalignment Parameter dMx dMy Cross corr coef Standard Deviation 0.00 0.01 0.08 Tolerance 0.18 0.18 0.70 DEPTH CONTROL Wireline Compar{y Schlumberger Line type 7/32" Encoder SF I Schlumberger Max Depth (TD)1 10799 CCL Corrected NO Zero Depth (Rig iup) RKB @ 54 ft AMSL Rezero Depth 8 Given pup joint depth NA Measured PJ NA Strech cor. At Tlt divided by TD/1000 .4630 Spec'- 1.5/1000 Dif. Between rigiip and rezero depths divided by TD/1000 .7408 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 INDIVIDUAL STAfrION R %of Total stations accepted Tolerance > 80% 100% Consecutive Interval out of Specification Tolerance < 100 m (300 ft) 0 feet SURVEY RUNNING TIME Rig up 7/6/2015 2:45:00 AM Rig down 7/6/2015 2:40:00 PM Start Inrun 7/6/2015 2:52:00 AM Field Survey Presented End outrun 7/6/2015 2:25:00 PM Lost Time Comments SURV-Q163 December 2011 Page 1 of 2 Created:25-7an-16 13:34 AK0715GCM149 i Survey QC - RGS-CT Continuous Specification Sheet • ACCEPTANCE SUMMARY Accept NAME AND DATE Yes/ No Pre-job calibration verification (roll test) Click here to enter text. Gyro Verification (Advanced Initialisation) Accelerometer verification (G-Total Test) Operating temperature within calibration range (+/- 2.5°) SIGNATURE Continuous Drift Correction YES Click here to enter text. Continuous Misalignment Correction YES Depth Control YE'' Individual Station Report YEs Note : Any modifications or amendments to this sheet must be reported to the client representative and the Gyrodata survey focal point. SURV-Q163 December 2011 Page 2 of 2 Created:25-]an-16 13:34 AK0715GCM149 bp RECEIVED 0 AUG 21 2014 AOG('iC BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOC. DATA) _ Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents Ev 1 CD-ROM Containing OPEN HOLE Digital Log Data: 01-14, 03-20, 04-03, 04-09, 04-101, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-111 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-111 B-241 B-251 C-10, L2 -07A, 0-02, M-04, M-05, U-14 Angela K. Please Sign and gancpdcgbp.com Doug Dortch Petrotechnical The information on this CD is to be used for BP Exploration (Alaska) Inc. business only. If you are not the owner or licensed user of this CD, any disclosure, copying or use of the information on this CD is prohibited. If you obtain this 1 • CD by error, please return the CD to the address shown below. BP will pay the postage. Thank you. Attn: State of Alaska. , Attn: Makana Bender 333 W. 7th Ave, Suite 1 Anchorage, Alaska 99501 If found please return CD to: BP Exploration PO Box 196612 Anchorage, AK 99519-6612 CD1of1 4Y . by 0 For External Distribution BPXA OH Log Data 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-24, B-25, C-10, L2 -07A, 0-02, M-04, M-05, U-14 18 -AUG -2014 Petrotechnical Data . en�R2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, January 16, 2013 7:39 PM G g�jj I f j ��13 To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, D &C Well Services Operations Elam Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Ryan.Holt @bp.com; Jessica.Sayers @bp.com Subject: OPERABLE: Producer 09- 02(PTD #1760160) Passing OART Post Seal -Tite IC Hanger Treatment All, Producer 09 -02 (PTD # 1760160) passed a warm outer annulus repressurization test (OART) from 01/06- 11/2013 with a buildup rate of ^'10 psi per day. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy SCANNED APR 11 NIB BP Alaska - Well Integrity Coordinator . GlbalWetis t rtJanizatior WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator PBP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, January 04, 2013 10:15 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon Subject: UNDER EVALUATION: Producer 09- 02(PTD #1760160) Seal -Tite IC Hanger Treatment for IAxOA Communication All, Producer 09 -02 (PTD # 1760160) passed an Outer Annulus Repressurization Test (OART) from 12/08- 12/13/2012 with a buildup rate of - 10 psi per day after a Seal -Tite IC Hanger treatment was pumped. At this time the well is reclassified as Under Evaluation so it may be placed online to perform a warm OART and further evaluate success of the Seal -Tite treatment. Thank you, 1 • • —cam i ?cec1O Regg, James From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 12(7-N + f 4't t3 Sent: Friday, January 04, 2013 10:15 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon Subject: UNDER EVALUATION: Producer 09- 02(PTD #1760160) Seal -Tite IC Hanger Treatment for IAxOA Communication All, Producer 09 -02 (PTD # 1760160) passed an Outer Annulus Repressurization Test (OART) from 12/08- 12/13/2012 with a buildup rate of — 10 •si . er da afte . - .I -Ti - .. • - - . u - t was pumped. At this time the well is reclassified as Under Evaluation so it may be placed online to perform a warm OART and further evaluate success of the Seal -Tite treatment. Thank you, Mehreen Vazir SCANNED APR 1 1 2013 BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Thursday, June 28, 2012 4:30 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, D &C Well Servic -s Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt E gr; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, 'IPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity - gineer; Walker, Greg (D &C); Clingingsmith, Mike J; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producer 09- 02(PTD #1760160) OA R: •ressurization Unmanageable By Bleeds AI I, Producer 09 - 02 (PTD #1760160) failed an Outer An' ulus Repressurization test from 06/25 - 27/2012 with a buildup rate of "380 psi per day. A positive pres re packoff test on the inner casing void (PPPOT -IC) also failed indicating that at least one of the wellhe, d seals have been compromised. The well is reclassified as Not Operable. The plan forward will be to evalua • the IC hangar for a Seal -Tite treatment. Please call if you have any questions or c• terns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator 1 RECEIVED STATE OF ALASKA DEC 2 7 2012 A OIL AND GAS CONSERVATION COMM O ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well J Plug Perforations ii Perforate 1 Other [X S G�re Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ tq t " s.4 r Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weil❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 176 -016 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ^ 50- 029 - 20198 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028327 PBU 09 -02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11199 feet Plugs measured 10846 feet true vertical 9216.52 feet Junk measured See Attachment feet Effective Depth measured 10846 feet Packer measured 10154 feet true vertical 8942.95 feet true vertical 8400.3 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 55 20" 94# H -40 30 - 85 30 - 85 1530 520 Surface 2697 13 -3/8" 72# MN -80 29 - 2726 29 - 2725.81 5380 2670 Intermediate None None None "• o e--- nom None None Production 11125 9 -5/8" 47# MN -80 28 - 11153 28 - 9181.02 6870 4760 Liner None None None None None None Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SCANNED JAN 18 2011 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker D Packer 10154 8400.3 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 23 9945 13959 1457 266 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorC] Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil K in Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry Printed Name Garry Catron , Title PDC PE Signature 1 Ems^ /A y ( `--- Phone 564 -4424 Date 12/27/2012 RBDMS DEC 2 8 2012jY 0 ..24 , 17-- Form 10-404 Revised 10/2012 (07/A02.- Submit Original Only • • 09 -02 176 -016 -0 Junk Attachment SW Name MD Date Description 09 -02 10706 3/6/96 IBP Rubber Element 09 -02 11003 2/27/98 2 Small Pieces of Spinner Housing i • Perforation Attachment ADL0028327 SW Meas Depth Name Operation Date Perf Operation Code Meas Depth Top Base TVD Depth Top TVD Depth Base 09 -02 6/3/1997 SQZ 10649 10666 8787.57 8801.02 09 -02 7/23/1997 RPF 10674 10679 8807.34 8811.3 09 -02 7/23/1997 RPF 10679 _ 10694 8811.3 8823.16 09 -02 7/23/1997 RPF 10694 10699 8823.16 8827.11 09 -02 12/21/2008 SQZ 10699 10700 8827.11 8827.91 09 -02 12/21/2008 RPF 10700 10710 8827.91 8835.82 09 -02 12/21/2008 SQZ 10710 10730 8835.82 8851.61 09 -02 6/3/1997 SQZ 10749 _ 10766 8866.61 8880.02 09 -02 12/21/2008 SQZ 10766 10780 8880.02 8891.05 09 -02 12/21/2008 RPF 10780 10790 8891.05 8898.93 09 -02 12/21/2008 SQZ 10790 10799 8898.93 8906.02 09 -02 12/20/2008 RPF 10815 10817 8918.6 8920.17 09 -02 12/20/2008 RPF 10817 10825 8920.17 8926.46 09 -02 12/20/2008 SQZ 10825 10841 8926.46 8939.03 09 -02 11/11/2012 BPS 10856 10866 8950.8 8958.63 09 -02 11/11/2012 BPS 10872 10886 8963.34 8974.3 09 -02 11/11/2012 BPS 10896 10906 8982.12 8989.93 09 -02 11/11/2012 BPS 10940 10948 9016.44 9022.66 09 -02 11/11/2012 BPS 10962 10972 9033.53 9041.29 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SET SQZ SQUEEZE SL LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028327 Casing Length Size MD TVD Burst Collapse CONDUCTOR 55 20" 94# H -40 30 - 85 30 - 85 1530 520 PRODUCTION 11125 9 -5/8" 47# MN -80 28 - 11153 28 - 9181.02 6870 ' 4760 SURFACE 2697 13 -3/8" 72# MN -80 29 - 2726 29 - 2725.81 5380 2670 TUBING 2958 7" 26# 13CR80 27 - 2985 27 - 2984.25 7240 5410 TUBING 7559 5 -1/2" 17# 13Cr80 2985 - 10544 2984.25 - 8704.5 7740 6280 TUBING 105 4 -1/2" 12.6# 13Cr80 10173 - 10278 8414.76 - 8495.51 8430 _ 7500 • • i • Dail Report of Well Operations Y p p ADL0028327 T /I /O = SSV /200/200. Temp = SI. Assist Seal -Tite w /LLR on IC packoff (Mitigate IAxOA comm). AL spool dropped. IA & OA FLs near surface. Bled IAP & OAP to 0 psi in 15 min (gas). Held open bleed on IA & OA for an additional 2 hrs during Seal- Tite operations. Seal -Tite rigged up to IC and bled to 0 psi and pumped diesel to flush IC void. Established LLR of 100 mL /min @ 3500 psi. IC void left with 1100 psi. Heater installed in wellhouse to keep wellhead warm. Continue operations next day with pumping Sealant. Job in Progress. Final WHPs = SSV /0/0. 11/29/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 14:15 hrs. T /I /O = SSV /3 /30. Temp = Sl. Assist Seal -Tite, Seal IC Packoff (Mitigate IAxOA comm). IA & OA bled to 0 psi and open bleed held on both throughout operations. Seal -Tite pumped 500 mL Gly -Flo into IC to try to establish a seal @ 3500 psi. Could not establish a seal, LLR of 5 mL /min @ 3500 psi. After 3.5 hrs Seal -Tite injected 250 mL Tur -Flo on top of Gly -Flo to create a successful seal in IC. Held 3500 psi on IC for 1 hour with no pressure loss. IC left pressured to 3500 psi to cure. Heater left in the well house to keep tree @ same temperature, tree cap bled to 0 psi. Will return tomorrow to monitor IC pressure. Job in progress. Final WHPs = SSV /0/0. 11/30/2012 SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 15:15 hrs. T /I /O = SSV /2/18. Temp = SI. Assist Seal -Tite, Monitor IC pressure (IAxOA comm). AL spool dropped. IC pressure @ 3500 psi, no pressure loss overnight. Had to use Seal -Tite pump to check IC pressure, Tur -Flow in jewelry plugged 5k gauge. IC left pressured to 3500 psi. Heater installed in wellhouse to keep tree warm. 12/1/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 09:00 hrs. T /I /O = SSV/1530/80. Temp = SI. OART (Eval IAxOA comm, Post Seal -Tite retreatment). IA FL @ -6401' (sta #4 dome, 343 bbls). OA FL near surface. Bled OAP from 80 psi to 40 psi in 2 min, gas. Monitored 1 hr, IA FL unchanged, IAP unchanged, OAP increased 10 psi. Final WHPs SSV/1530/50. 12/8/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1100 T /I /0 = SSV/1670/80. Temp = S1. OART day 2 (Eval IAxOA comm). IAP increased 140 psi, OAP increased 30 psi. IC hanger 1700 psi. 12/9/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1300 T /1 /0 = SSV /1670/80. Temp = SI. OART day 3 ( Eval IAxOA comm, Assist Seal - Tite). Increased IC hanger void to 3500 psi for 45 min, bled off to 2500 psi then SI. WHPs unchanged overnight. 12/10/2012 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1600 TWO= SSV/1750/70. Temp.= SI. OART (Eval IAxOA comm. Post Seal -Tite treatment) day 2. IC harnger 2220 psi. IAP increased 80 psi., OAP decreased 10 psi., IC hanger increased 520 psi. Note: Heater installed in Wellhouse. Tree cap bled to 0 psi. SV, SSV, WV= C. MV= 0. IA & OA OTG. NOVP. 12/10/2012 171/0= SSV/1850/100. Temp = SI. WHP's. (OART day 3, Post Sealtite treatment). IAP increased 180 psi & OAP increased 20 psi overnight. IC void pressure @ 1800 psi. 12/11/2012 SV, WV & SSV = C. MV = O. IA & OA = OTG. NOVP. 1125. • Daily Report of Well Operations ADL0028327 - T /1 /O = SSV/1890/85. Temp = ST. OART day 4 (Eval IAxOA comm, Post Seal - Tite). ALP = 1890 psi, AL open @ casing valve. No IA companion valve. IC void = 2000 psi. IAP increased 40 psi, OAP decreased 15 psi, and IC void increased 200 psi overnight. 12/12/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 1100 hrs. T /I /O= SSV/1950/92. Temp= SI. OART (Eval IAxOA comm). ALP= 1950, open @ casing valve w/ no companion. IC void= 1850 psi. IAP increased 60 psi, OAP increased 7 psi & IC void decreased 40 psi overnight. OART tags pulled. 12/13/2012 SV, WV & SSV =C. MV =0. IA &OA =OTG. NOVP. 1545 hrs. T /I /0 = SSV/1950/110. Temp = SI. Monitor IC void (Post POP). No IA companion valve. AL open, ALP = 1950 psi. IC void = 2150 psi. IC void increased 300 psi & OAP increased 18 psi overnight. Heater installed in well house, tree cap bled to 0 psi. 12/14/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 08:30. TREE = C ?J — ' ViIB..LFEAD= FMC GEN 1 • SAW NOTES: "* CHROME LNR & TBG*** . ACTUATOR — BAKER c 09 02 KB. ELEV = -- - -- _- _.__._._ 54' BF.a.E Max Angle = 4 7 " @ 7 D ar I 2231' H` T" CAM BAL -O SSSV MP D = 5.937" Datum MD = 10733' III Datum TVD = __ _... 8800' SS / 2985' H 7" X 5-1/2" XO, D = 4.892" I 113 -3/8" CSG, 72#, MN 80, D = 12.34T H 2726' I/ / GAS LEFT MANDRELS ST MD TVO DEV TYFE VLV LATCH PORT DATE I7" TBG, 26ft, 13CR - 80, .0383 bpf, D = 6.276" H 2986' 1 2998 2997 8 FMIO DOME RK 16 09/05/12 2 4619 4434 42 FM10 DM1' RK 0 0826/91 1A 3 5724 5221 45 FM-10 OW Fitt 0 05/20/97 4 6401 5713 43 FM-ID DOME RK 16 09/05/12 5 7035 6159 47 F140 OW RK 0 08/26/91 Minimum ID = 3.725" @ 10265' 6 7707 6626 45 FM-ID DMY RK 0 08/26/91 4 -112" OTIS XN NO-GO NIPPLE "7 8295 7055 42 FM-ID DMY RK 0 08/26/91 8 8840 7454 44 FM-I0 DONE RK 16 09/05/12 9 9424 7870 45 F M-ID DMY RK 0 08/26/91 10 9797 8136 44 FM-10 SO RK 24 09/05/12 11 10126 8379 41 FM-ID P1<8) RKP 0 _05/20/92 1 5 TBG, 17 #, 13CR .0232 bpf, ID = 4.892' -- I 10161' F----- 'CANNOT PULL ST#7AS OF 6't9N9T 10161' H5-12 " X4-1/2 "X0, ID= 3.958" I N 10163' H BKR GBH LOCATOR SEAL ASSY, D=? I 10154' H9-5/8" X 4-12" BKR MODEL D PKR, D= I I9 -5/8" X 7" TEBACK SLV, D = ? H 10222' 10168' — I5" MILLOUT EXTENSION, ID = ? I9 518' X T BKR LNR HGR, ID = ? I 1023p' 10173' H Mt LOUT EXT510N XO TO 4-12', D= 3.958' I I 10265' H4-112" OTIS XN t4 , ID= 3.725" I 1 4-12" TBG, 12.6#,13CR80, .0152 bpf, D= 3.958" H 10278' I 10277' —lain- BKR sl-EAROUT SUB, ID = ? I 10278' H4 -12" TUBNG TAL, D = 3.958" I 10282' H ELM) TT LOGGED 09/06/91 I 10453' (--17' MARS JOINT I 10474' H7" MARKet JOINT I PBO:ORATION SUMMARY' I REF LOG: BHCS ON 03/10/76 NOTE: CR does not correlate wIBHCS due to 'HOT" deposits ANGLE AT TOP FERF: 38° CO 10674' Note: Refer to Production DB for Inistorical pert data I SIZE I SFF I Ma2VAL I Opn/Sqz I DATE SEE PAGE 2 FOR PERFORATION INFORMATION L10846' I 14TE2 WIIL 350 -700 FOX PLUG, I I I I ili ME ' 10850', (11/11/12) I ?? HASH - BP RUBBER ELEMENT (03126/96) I I 11003' H FISH - 2 Small Pieces of Spinner Housing I PBTD 11056' X44144441 17" LNR, 29#, 13CR 80, .0371 bpf, D = 6.184" H 11097' 1/144444444444444141444144 • 441 14444444414 1 9-5/8" CSG, 47 9, P14-SO, D = 8.681" H 11153' 4 4. 900041 TD H 11198' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MB 03/22/78 INITIAL COMPLETION 09/05/12 RCT /JMD GLV C/O (09/01/12) WELL: 09 - 08/25/76 ROW 34 RWO 09/07 /12 RCT /JMD PULL PXN PLUG (09/03 /12) PERMYT No: '1760160 10/20/87 PAA 102 RWO 09/07 /12 MSS /JMD GLV GO (09/05/12) API No: 50 -029- 20198 -00 08/27/91 RWO 11/14/12 JCM/JMD SET HEX PLUG (11/11/12) SEC 2 T1ON R15E 987.19 FEL 1306.86 FM. 01/13/09 RRDISV A DPERF/REPERF (12/20/08) 0828/12 LEC/JMD SET PXN PLUG (08/25/12) BP Exploration (Alaska) - BEE= CAN • LLEAD= N S NOTES: *** CHROME LNR WE FMC GE 1 ACTUATOR- = 09-02 ELB/ = BF. ELEV = KOP= 3079' ngis 1 L GUT= MD= 10733' DaturiTVD= SS PERFORATION SUPAARY f LOG: BHCS ON 03/10/76 NOTE: GR does not correlate vd6HCS due to 'HOT' deposits ANGLE AT TOP FEW: 38° @ 10674' Note: Refer to Product= DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 10649- 10666 S 06/03/97 3-3/8" 6 10674 - 10679 0 07/23/97 3-3/8" 12 10679 - 10694 0 07/23/97 3-3/8" 6 10694 - 10699 0 07/23/97 10699 - 10730 S 06/03/97 3-3/8" 6 10700 - 10710 0 12120/08 10749 - 10799 S 06/03/97 3-3/8" 6 10780 - 10790 0 12/20/08 3-3/8" 6 10815 - 10825 0 12/20/08 10817 - 10841 S 08/15/91 3-3/8" 4 10856 - 10866 C 0908/91 3-3/8" 4 10872 - 10886 C 09/08/91 3-3/8" 4 10896 - 10906 C 09/08/91 3-3/8" 4 10940 - 10948 C 09108/91 3-3/8" 4 10962 -10672 C 09/08/91 4116 411 1/ WOW.) •••••••• I•••••••■ v.*** • ••ft •••••••••• ■••••••••••, •••••■••••• 1•••••••••• Matt.A.A.A.A.A1 DATE REV BY CONSENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03122/76 IMITAL COMPLETION 09/05/12 RCT/JMD GLV ('10 (09/01/12) WELL: 09-02 08/25/76 ROW 34 MO 09/07/12 RCT/JRID PULL PXN RUG (09/03/12) PERMIT Pb: '1760160 10/20/87 PAA 102 IMO 09/07/12 AASSIJND GLV (‚/0(09/05/12) AR No: 50-029-20198-00 08127191 RWO 11/14/12 JCIMJAAD SET 3-1/2" PG (11/11/12) SEC 2 TiON R15E987.19 Fa 130686 FM_ 01/13/09 RRD/SV ADP/HR- (12/20/08) 08/28112 LEMIND SET PXN RUG (08/25/12) BP Exploration (Alaska) STATE OF ALASKA RECEIVED AL•:A OIL AND GAS CONSERVATION COMMON DEC 13 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon [] Repair Well Plug Perforations [✓j Perforate L( Other U AOGCiv' U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: BP Exploration (Alaska), Inc Name: Development el Exploratory ❑ -' 176 -016 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 r 50- 029 - 20198 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028327 - r PBU 09 -02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): , To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11199 feet Plugs measured 10846 feet true vertical 9216.52 feet Junk measured 11003 feet Effective Depth measured 10846 feet Packer measured 10154 feet true vertical 8942.95 feet true vertical 8400.3 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 55 20" 94# H -40 30 - 85 30 - 85 1530 520 Surface 2697 13 -3/8" 72# MN -80 29 - 2726 29 - 2725.81 5380 2670 Intermediate None None None None None None Production 11125 9 -5/8" 47# MN -80 28 - 11153 28 - 9181.02 6870 4760 Liner None None None None None None Perforation depth Measured depth See Attachment feet FEB 2013 SCANNED True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker D Packer 10154 8400.3 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 406 9127 12590 247 Subsequent to operation: 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development El r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 E -mail Nita.Summerhaysabp.com Printed Name Nita Summerhay Title Petrotechnical Data Technician Signs l /L�i trAPri .. , iii 1 /,/ice: - ._ Phone 564 -4035 Date 12/13/2012 RRDMS DEC 14 2012 E ' !L 17.'1. Form 10-404 Revised 11/2011 / ,',/;'7/ Submit Original Only . • Daily Report of Well Operations ADL0028327 ACTIVITYDATE I SUMMARY INITIAL T /I /O = 300/240/0 PSI SET 3.5" (350 -700) INTERWELL HEX PLUG @ 10850' MID ELEMENT (TOP SET @ 10846') (PLUG SPECS = 8.46' OAL / 3.5" MAX OD) (TAKES 3 1/2" GS TO PULL) FINAL T /I /O = 300/240/0 PSI 11/11/2012 ** *JOB COMPLETED. WELL LEFT SHUT IN ON DEPARTURE*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL • • Perforation Attachment ADL0028327 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 09 -02 9/26/91 APF 10649 10666 8787.57 8801.02 09 -02 6/3/97 SQZ 10649 10814 8733.57 8863.81 09 -02 10/16/87 APF 10674 10730 8753.34 8797.61 09 -02 10/17/87 SQZ 10674 10948 8753.34 8968.66 09 -02 4/1/88 RPF 10674 10730 8753.34 8797.61 09 -02 8/15/91 SQZ 10674 10972 8753.34 8987.29 09 -02 9/8/91 RPF 10674 10730 8753.34 8797.61 09 -02 6/24/97 RPF 10674 10694 8753.34 8769.16 09 -02 7/23/97 RPF 10679 10699 8757.3 8773.11 09 -02 12/21/08 RPF 10700 10710 8773.91 8781.82 09 -02 5/1/77 PER 10749 10799 8812.61 8852.02 09 -02 4/1/88 RPF 10749 10799 8812.61 8852.02 09 -02 10/19/91 RPF 10749 10766 8812.61 8826.02 09 -02 12/21/08 RPF 10780 10790 8837.05 8844.93 09 -02 12/20/08 RPF 10815 10825 8864.6 8872.46 09 -02 5/1/77 PER 10817 10841 8866.17 8885.03 09 -02 11/11/12 BPS 10846 10972 8888.95 8987.29 09 -02 8/15/91 SQZ 10855 10856 8896.01 8896.8 09 -02 5/1/77 PER 10856 10866 8896.8 8904.63 09 -02 11/22/87 RPF 10856 10866 8896.8 8904.63 09 -02 9/8/91 RPF 10856 10866 8896.8 8904.63 09 -02 5/1/77 PER 10872 10886 8909.34 8920.3 09 -02 11/22/87 RPF 10872 10886 8909.34 8920.3 09 -02 9/8/91 RPF 10872 10886 8909.34 8920.3 09 -02 5/1/77 PER 10896 10906 8928.12 8935.93 09 -02 11/22/87 RPF 10896 10906 8928.12 8935.93 09 -02 9/8/91 RPF 10896 10906 8928.12 8935.93 09 -02 5/1/77 PER 10940 10948 8962.44 8968.66 09 -02 11/22/87 RPF 10940 10948 8962.44 8968.66 09 -02 4/1/88 RPF 10940 10948 8962.44 8968.66 09 -02 9/8/91 RPF 10940 10948 8962.44 8968.66 09 -02 11/22/87 APF 10962 10972 8979.53 8987.29 09 -02 4/1/88 RPF 10962 10972 8979.53 8987.29 09 -02 9/8/91 RPF 10962 10972 8979.53 8987.29 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED I I I • • I III RPF REPERF II Casing / Tubing Attachment ADLOO28327 Casing Length Size MD TVD Burst Collapse CONDUCTOR 55 20" 94# H-40 30 - 85 30 - 85 1530 520 PRODUCTION 11125 9 -5/8" 47# MN -80 28 - 11153 28 - 9181.02 6870 4760 SURFACE 2697 13 -3/8" 72# MN -80 29 - 2726 29 - 2725.81 5380 2670 TUBING 2958 7" 26# 13CR80 27 - 2985 27 - 2984.25 7240 5410 TUBING 7559 5 -1/2" 17# 13Cr80 2985 - 10544 2984.25 - 8704.5 7740 6280 TUBING 105 4 -1/2" 12.6# 13Cr80 10173 - 10278 8414.76 - 8495.51 8430 7500 • • TREE= • OW E U- D= FAACGEJ 1 • SA NOTES: *"' CHROME LNR & TBG *'* I ACTUATOR = BAKER 09-02 KB. a.EV = 54' BF. ELEV= KOP= 307g Angle Mu Angle 47° To 7000' 1 I� D 2231' 7" CAM BAL -O SSSV NP, - 5.937" fr " .. Datum MD = 10733' • Datum TED = 8800' SS 2985' H 7" X 5-1 /2" XO, ID= 4.892' 1 13 -3/8' CSG, 72#, M4-80, D = 12.347" H 2726• / GAS LFT MANDRELS ST MD "ND DEV 'TYPE VLV LATCH FORT DATE TB 17" G, 26#, 13CR-80, .0383 bpf, D= 6276" H 2985' 1 2998 2997 8 MHO DOME RK 16 09/05/12 2 4619 4434 42 FM10 DMY RK 0 08/26/91 A 3 5724 5221 45 RHO DMY R( 0 05/20/97 4 6401 5713 43 FMIO DOME RK 16 09/05/12 5 7035 6159 47 FMlO DMY RK 0 0826/91 Minimum ID = 3.726" @ 10266' 6 7707 6626 45 FM-10 DMY RK 0 08/26/91 4 -112" OTIS XN NO-GO NIPPLE *'7 8295 7055 42 FMiO 0MY RK 0 08/26/91 8 8840 7454 44 FMIO DOME FE 16 09/05/12 9 9424 7870 45 FWD DMY FE 0 08/26/91 10 9797 8136 44 RHO SO RK 24 09)05/12 11 10126 8379 41 F M 1O FEB) RKP _ 0 05/20192 1 5-1/2' TBG, 17 #, 13CR-80, .0232 bpf, ID = 4.892' -1 10161' 1 'CANNOT PULL ST1t7 AS OF 6/19+97 10151' H5 -1/2" X 4-1/2" XO, D = 3.958' I ��� 10153' _I-181(R GBH-22 LOCATOR SEAL ASSY, D = ? 1 10164' 1—{9-5/8" X 4-1/2' BKR MODE.. D PKR, D = 1 19-5/8" X 7' TEBACK SLV, D = ? H 10222' 10168' — 15" MILLOUT EXTENSION, D = ? 19 518" X T BKR 8 LNR HGR, D = ? — 10230' 10173' H OUT �S XO TO 4 -1/2 ", D = 3.958" 1 10265' H4 -112' O1' XN NP D = 3.725" 1 II I 4-112' TBG, 12.6#, 13CR -80, .0152 bpf, D = 3.958' H 10278' 1 10277 -- H4- 1/2' BKRSI-EAROUTSUB, D =? 1 11 1 10278' H4 -1/2" TUBING TAL, D = 3.958' 1 1 1 10282' J-1 OJYD TT LOGGED 09/06/91 1 10453' H7" MARKER Jaw I 10474' H 7" MARKER JOINT 1 FERFORATION SUMMARY FIEF LOG: BRCS ON 03/10/76 I NOTE: GR does not correlate w/BHCS due to 'HOT deposits ANGLE AT TOP FERF: 38° @ 10674' - ----Th „,'-- Note: leer to Production DB for historical pert data ` SIZE SPF NTERVAL Opn/Sgz DATE il ` SEE PAC E 2 FOR t ORAT INFORMATION , 10846' NTER WELL 350- 7001-EX PLUG, 1 ME@ 10850', (11/11/12) II 1 - ?? FISH - BP RUBBER ELEMENT (03/26!96) 1 1 11003' FISH - 2 Stre1 Places of Spinner Housing 1 PBTD 11066' vr: r � �- 1 7” LNR, 29#, 13CR -80, .0371 bpf, D = 6.184" H 1109T 1' 1 � 1 1 , � 1 1 1 1 1 1 1 1 1 1 1 � 1 v 1 1 9- 518" CSG, 47 #, IAN -80, D = 8.681" H 11153' . M4 t1 � • � 1 � • � t1 � • � • � •1 TD 11199' ' 4 ' 4 ' 4 ' 4 ' 4 ' 4,4 ' 4 ' 4 ' 4 DATE REV BY COMMENTS DATE - REV BY COMMENTS PRUDHOE BAY UNIT 03/22/76 INITIAL COMPLETION 09/05/12 RCT /JMD GLV C/O (09/01/12) WELL: 09 - 02 08/25/76 ROW 34 RWO 09/07 /12 RCT /JMD PULL PXN PLUG (09/03 /12) PERMIT No: 9760160 10/20/87 PAA 102 RWO 09/07/12 MSS /JMD GLV C/O (09/05/12) API No: 50- 029 - 20198 -00 08/27/91 ' RWO 11/14/12 JCM/JMD SET I-EX PLUG (11/11/12) SEC 2 T1ON R15E 987.19 FE- 1306.86 FNL 01/13/09 RRDISV ADPERF /REPERF (12/20/08) 08/28/12 LEC/JMD SET PXN PLUG (08/25 /12) BP Exploration (Alaska) T R E E = aw WELLHEAD = FMC GEN 1 • SAS NOTES: "* CHROME LNR & TBG *'• ACTUATOR= BAKER C 09 -02 KB. H_EV = 54' BF. ELEV= - = 0 700' ... .... .......... -- Max fl�z Angle = 47° •� 7000' Datum MD = 10733' Datum TV D = 8800' SS \ / 11 PERFORATION SLR A RY REF LOG: BHCS ON 03/10/76 NOTE: GR does not eonelate w/BHCS due to NOT' deposits ANGLE AT TOP PERF: 38" fp 10674' Note: defer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sgz DATE 10649 -10666 S 06/03/97 3-3/8" 6 10674 -10679 0 0723/97 3-3/8" 12 10679 -10694 0 0723/97 3-3/8' 6 10694 -10699 0 0723/97 10699 - 10730 S 06/03/97 3-3/8" 6 10700 -10710 0 12/20/08 10749 -10799 S 06/03/97 3-3/8" 6 10780 - 10790 0 1220/08 3-3/8" 6 10815 - 10825 0 1220/08 10817 -10841 S 08/15/91 3-3/8" 4 10856 -10866 C 09/08/91 3-3/8" 4 10872 - 10886 C 09108/91 3-3/8" 4 10896 -10906 C 09108/91 3-3/8" 4 10940 -10948 C 09/08/91 338' 4 10962 - 10972 C 09/08/91 • 1 �1� 1 �1 � 1�1 ,* 14.4 04 4 DATE REV BY CONSENTS - DATE REV BY CONVENTS PR DHOE BAY UNIT 03/22/76 INITIAL COMPLETION 09105112 RCT /JWD GLV CIO (09/01/12) WELL: 09-02 08/25/76 ROW 34 RWO 09/07/12 RCT /JWD FULL PXN PLUG (09/03/12) PERMIT No: '1760160 10/20/87 PAA 102 RWO 09/07/12 MSS/JND GLV C/0 (09/05/12) AR No: 50-029-20198-00 08/27/91 RWO 11/14/12 JCMIJIID SET 3-1/2" 1-EX PLUG (11/11/12) SIC 2 T10N R15E 987.19 Fa 1306.86 FP& 01/13/09 RRDtSV ADPERF/REPERF (12/20/08) 08/28/12 LBJJIAD SET PXN PLUG (08/25/12) BP Exploration (Alaska) 1 0-oz P.� 1 7(6 ►erg Regg, James B (DOA) From: Vazir, Mehreen [Mehreen.Vazir @bp.com] , 10 Ik t«/ Sent: Saturday, October 13, 2012 6:16 PM ("l To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: NOT OPERABLE: END 1- 57/R -23 (PTD #1881140), 09 -02 (PTD #1760160) Producers with Sustained Casing Pressure During TAR Hello Jim, Guy, I wanted to provide an update on the following two producers that were found with sustained casing pressure on the OA during TAR activity. 1- 57/R -23 (PTD # 1881140) 09 -02 (PTD # 1760160) ✓" Both wells remain shut in at this time and we are planning to perform Seal -Tite wellhead treatments as the __ ---- diagnostics indicate failure of the wellhead seals on the IC hanger. Once the treatments are completed, BPXA will make further notification for plans to return to production. Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator SCANNED APR I 7 20 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@ BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.VazirPBP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, June 18, 2012 3:28 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; AK, D &C Well Services 0 erations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt E r; AK, RES GPB East Wells Opt Engr; AK, RES END Production Optimization Engineer; Igbokwe, Chidiebere; Stechauner„�Bernhard; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, 1 "S END Facility & FieldO &M TL; AK, OPS END OIM; AK, OPS END Operations Lead Tech Cc: AK, D &C DHD Well Integrity Engineer Subject: NOT OPERABLE: Producers with Sustained Casing P ssure During TAR All, 1 Regg, James B (DOA) Ph'-) 17(,016o From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Thursday, June 28, 2012 4:30 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; Igbokwe, Chidiebere Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Clingingsmith, Mike J; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producer 09-02(PTD #1760160) OA Repress urization Unmanageable By Bleeds w Producer 09-02 (PTD #1760160) failed an Outer Annulus Repressurization test from 06/25 -27/2012 with a buildup rate of —380 psi per day. A positive pressure packoff test on the inner casing void (PPPOT-IC) also failed indicating that at least one of the wellhead seals have been compromised. The well is reclassified as Not Operable. The plan forward will be to evaluate the IC hangar for a Seal-Tite treatment. Please call if you have any questions or concerns. Thank you, Gerald Murp/zy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Email: AKDCWelllntegrityCoordinator(aD_BP.com From: Vazir, Mehreen Sent: Thursday, June 21, 2012 3:02 PM To: AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team L d; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, RES;Facility uctio ptimization Engineer; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FSO ; AK, OPS FS2 DS Operators Cc: AK, D&C DHD Well Integrity Engineer Subject: UNDER EVALUATION: 09-02(PTD #1760160) and 09-01 (PT760) Producers with Sustained Casing Pressure During TAR w The following producers are being placed UnderValuation so they can be POP'd. Once POP'd a warm TIFL will be performed on each well. If the TIFL fail , a plan forward will be determined for further diagnostics. 09-01 (PTD #1750760) 09-02 (PTD #1760160) rk Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, June 18, 2012 3:28 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D&C Well Services Operations Tead Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, RES END Production Optimization Engineer; Igbokwe, Chidiebere; Stechauner, Bernhard; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS END Facility & FieldO&M TL; AK, OPS END OIM; AK, OPS END Operations Lead Tech Cc: AK, D&C DHD Well Integrity Engineer Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During TAR Al I, The following producers were found to have sustained casing pressure on the IA during shut down for turnaround activity. The immediate action is to perform a TIFL on each of the well— sTo eva uaT Te fior-Wrepressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well with a plan forward. 03-31 (PTD #1840920) 04-24 (PTD #1853010) 09-01 (PTD #1750760) 09-02 (PTD #1760160) The following producers were found to have sustained casing pressure on the OA during shut down for turnaround activity. The immediate action is to perform an OA Repressurization Test to evaluate if the IAxOA communication is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying of the plan forward. END1-57/R-23 (PTD #1881140) 09-02 (PTD #1760160) All the wells listed above are reclassified as Not Operable until start-up operations commence and are stable or the well passes a pressure test confirming integrity. Afters rtt ua p, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over -pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, Mehreen Vazir SCMNED (Xwrrwle: Gerald ;lfurph ) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AI<DCWelllntegrityCoordinator@BP.com 03/30/11 Schlumberger NO. 5715 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD P1 -07A BJGT -00020 PRODUCTION PROFILE dO 4 1-63'1 03/05/11 1 (j /4 1 S -18B BL65 -00020 MEMORY DDL � /(� -() i 02/22/11 1 3n t 1 13 -09 BG4H -00035 LDL U' 1.10 l ,,e_. ! �^j — / � 02/20/11 1 O 1 09 -02 - BBSK.00052 RST 1 ( a 0 02/16/11 1 a 1 D -16A BG4H -00034 RST (\ - C) as 02/19/11 1 .anfrt 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ,4 APR a 2- ( • vI ,�1,.., 03/24/11 S _'-"_---__- °_- NO. 5709 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -20 BBSK -00054 PRODUCTION PROFILE ?L' ' ' IrMr•r i 1 09-46 BMSA -00006 Uias 1.•iICd89;2.1 J' b(k D T.!7 t] 1 14 -05A BBKA -00090 PRODUCTION PROFILE ! tr ' ' GtM 1 _ 12-30 BBSK -00055 LDL / M 03/06/11 1 1 D -22C BCRD -00086 SCMT ♦ � a, 03/04111 a • , _ _ 1 09 -02 BBSK.00052 . . . . . . . . . . . .� a r 6 02116/11 1 . O , 1 09-41 BBSK-00053 PRODUCTION PROFILE F. b 03/03/11 1 Ar, 1 15-05A BCRD-00084 mammwL']L' ritxt. ' Plikafl• 1 11-15 BCRD -00083 USIT .- O 02111/11 _ 6 1 1 • F -35 BG4H -00037 PRODUCTION PROFILE ) ')1 - 6 1 02122/11 1 / rcefr,) 1 Z -31 BJOH -00009 INJECTION PROFILE 1.,/ Ar - 02/12/11 1 FJ,al.. 1 06-16 BCRO -00090 PRODUCTION PROFILE 'I -- • .. 3 03/07/11 1 yti: 1 1 X -17 BJOH -00008 RST , — 02/11/11 1 WA 174 1 H-20 BBSK -00051 RST ' n 02/13111 1 t 1 , 06 -20A BNWP -00003 RST �(�b 00'4* 'n 02/17/11 1 - o$'. 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suits 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 0 n 1 , MAR 2 6 2011 �, i ( f , , , '''a1sQ'Nli to ' x Producer 09 -02 (PTD #1760160) IAxO communication manageable by bleeds Page 1 j Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Monday, March 07, 2011 11:55 AM � 5(+5-11( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Longden, Kaity Subject: Producer 09 -02 (PTD #1760160) IAxOA communication manageable by bleeds Attachments: 09 -02 TIO Plot 03- 06- 11.doc .� All, An OA repressurization test was conducted on Producer 09 -02 (PTD #1760160) between 2/23 -3/6. The OA pressure increased —56 psi /day making it manageable by bleeds. Therefore, the well has been reclassified as Operable and may continue on production. Please notify Well Integrity if the OA pressure build -up -rate increases. A TIO plot has been included for reference. «09 -02 TIO Plot 03- 06- 11.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) {1q MAR r LOh ` Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, February 20, 2011 8:36 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DO ', 'K, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Oper. ors; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Opera s Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB -st Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); V- ir, Mehreen; Quy, Tiffany Subject: Producer 09 -02 (PTD #1760160) Sustained OA P sure Above MOASP All, Producer 09 -02 (PTD #1760160) has been found to have sustained casing pressure on the OA. The wellhead pressures were tubing /IA/OA equal to 660/1550/1550 psi on 02/19/11. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. Plan forward: 1. DHD: Outer Annulus Repressurization test (OART) 3/15/2011 PBU 09 -02 PTD 1760160 3/7/2011 TIO Pressures Plot Well: 09 -02 4,000 - 0 3,000 - — Tbg —!— IA 1000 - --A- OA OA --.- OOOA on 1,000 • 12/18/10 01/01/11 01/15/11 01/29/11 02/12/11 02/26/11 .,,�.,re.,..w, , .r.. _ . ��. . . 1 Producer 09 -02 (PTD #1760160) Sust1ed OA Pressure Above MOASP • Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, February 23, 2011 12:27 PM `S Vf 4 l To: Regg, James B (DOA); AK, D &C Well Integrity Coordinator Subject: RE: Producer 09 -02 (PTD #1760160) Sustained OA Pressure Above MOASP Attachments: 09 -02 OA Pressure History - 02- 23- 11.pdf Jim, I have attached the TIO plot for your reference. The OA pressure didn't exceed 1000 psi on 2/5/11. However on 02/13/11, the gross fluid rate increased substantially causing the OA pressure to exceed 1000 psi due to thermal influence. The OA pressure was bled on 02/13 and monitored for the next 4 days without any noticeable build -up -rate. Torin From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] q r, Sent: Wednesday, February 23, 2011 9:58 AM To: AK, D &C Well Integrity Coordinator Subject: RE: Producer 09 -02 (PTD #1760160) Sustained OA Pressure Above MOASP Please send pressure history in tabular form for past 30 days - can't tell definitively from graph if pressure exceeded 1000psi in OA during pressure increase leading up to and following what appears to be a pressure bleed around 2/5/11. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, February 20, 2011 8:36 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Vazir, Mehreen; Quy, Tiffany Subject: Producer 09 -02 (PTD #1760160) Sustained OA Pressure Above MOASP All, Producer 09 -02 (PTD #1760160) has been found to have sustained casing pressure on the OA. The wellhead pressures were tubing /IA/OA equal to 660/1550/1550 psi on 02/19/11. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. Plan forward: 1. DHD: Outer Annulus Repressurization test (OART) 2. WIE: Evaluate for Seal -Tite treatment A TIO plot and wellbore schematic are included for reference. «Producer 09 -02 (PTD #1760160) TIO Plot.doc» «Producer 09 -02 (PTD #1760160) wellbore 2/23/2011 Producer 09 -02 (PTD #1760160) Susteed OA Pressure Above MOASP Page 2 of 2 schematic. pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/23/2011 • • 09 -02 OA Pressure: 02 -23 -11 Date IA OA C 2120/20 eer 700 70 2/19/2011 700 500 2/18/2011 1500 1500 2/17/2011 1720 400 2/16/2011 1720 400 2/15/2011 1720 400 2/13/2011 1720 1020 2/12/2011 1740 990 2/11/2011 1740 990 :;- 2/8/2011 1760 980 2/7/2011 1760 920 2/6/2011 1760 380 2/5/2011 1760 1000 1 700 980 2/3/2011 1700 960 2/2/2011 1680 920 2/1/2011 1680 900 1/31/2011 1680 880 1/30/2011 1680 840 1/29/2011 1680 800 1/28/2011 1680 740 1/27/2011 1680 740 1/26/2011 1680 700 1/25/2011 1680 620 1/24/2011 1720 620 1/23/2011 1720 500 1/22/2011 1720 500 1/21/2011 1760 500 1/20/2011 1760 440 1/19/2011 1720 ' 420 Producer 09 -02 (PTD #1760160) Sustod OA Pressure Above MOASP • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, February 20, 2011 8:36 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Vazir, Mehreen; Quy, Tiffany Subject: Producer 09 -02 (PTD #1760160) Sustained OA Pressure Above MOASP Attachments: Producer 09 -02 (PTD #1760160) TIO Plot.doc; Producer 09 -02 (PTD #1760160) wellbore schematic.pdf All, Producer 09 -02 (PTD #1760160) has been found to have sustained casing pressure on the OA. The wellhead pressures were tubing /IA/OA equal to 660/1550/1550 psi on 02/19/11. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. Plan forward: 1. DHD: Outer Annulus Repressurization test (OART) 2. WIE: Evaluate for Seal -Tite treatment A TIO plot and wellbore schematic are included for reference. «Producer 09 -02 (PTD #1760160) TIO Plot.doc» «Producer 09 -02 (PTD #1760160) wellbore schematic.pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator FED 2 8 2011 Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/23/2011 PBU 09 -02 PTD #1760160 2/20/2011 TIO Pressures Plot Well: 09 -02 4,000 • 3,000 - —0— Tbg --•— IA 2,000 - -A- OA 00A - -- 000A . ■■ On 1,000 - 12/25)10 01/01/11 01/08/11 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 TREE = CIW WELLHEAD = FMC GEN_1 • SAFE r ES: * ** CHROME LNR & TBG * ** ACTUATOR BAKERC 09-02 KB. ELEV = 54' BF. ELEV= KOP 3079' Max Angle = 47 @ 7000' I 2231' 1-17" CAM BAL -0 SSSV NIP, ID = 5.937" I _ Datum MD = 10733' r ." 6 ". Datum TV D = ry "_._ 8800' SS 2985' 1-1 7" X 5-1/2" X0, ID = 4.892" 113 -3/8" CSG, 72 #, MN -80, 1D = 12.347 " I--{ 2726' \ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7" TBG, 26 #, 13CR -80, .0383 bpf, ID = 6.276" HI 2985' 1 2998 2997 8 FMHO DOME RK 16 09/24/07 2 4619 4434 42 FMHO DMY RK 0 08/26/91 3 5724 5221 45 FMHO DMY RK 0 05/20/97 4 6401 5713 43 FMHO DOME RK 16 09/24/07 5 7035 6159 47 FMHO DMY RK 0 08/26/91 6 7707 6626 45 FMHO DMY RK 0 08/26/91 Minimum ID = 3.725" @ 10265' * *7 8295 7055 42 FMHO DMY RK 0 08/26/91 4 -1/2" OTIS XN NO -GO NIPPLE 8 8840 7454 44 FMHO DOME RK 16 09/24/07 9 9424 7870 45 FMHO DMY RK 0 08/26/91 10 9797 8136 44 FMHO SO RK 24 09/24/07 11 10126 8379 41 FMHO RKED RKP 0 05/20/92 5 -1/2" TBG, 17 #, 13CR -80, .0232 bpf, ID = 4.892" H 10151' I * *CANNOT PULL ST #7 AS OF 6/19/97 -- _�` 10151' I--I5 -112" X 4 -1/2" X0, ID = 3.958" I 10153' 1.1 BKR GBH-22 LOCATOR SEAL ASSY, ID = ? I 9 -5/8" X 4 -1/2" BKR MODEL D PKR, ID = I 19-5/8" X 7" TIEBACK SLV, ID = ? H 10222' 1015410168' 1—I ' —{" MI EXTENSION, !D = ? I 9 -5/8" X7" BKR & LNR HGR, ID = ? I 10230' 10173' H I MILLOUT EXTSION XO TO 4-1/2", ID = 3.958" I I 10265' H4-1/2" OTIS XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, 13CR -80, .0152 bpf, ID = 3.958" f 10278' 10277' — I4 -1/2" BKR SHEAROUT SUB, ID = ? I 10278' H4 -1/2" TUBING TAIL, ID = 3.958" I I 10282' H ELMD TT LOGGED 09/06/91 I 10453' H7" MARKER JOINT I 10474' 1--17" MARKER JOINT I PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 NOTE: GR does not correlate w /BRCS due to "HOT" deposits ANGLE AT TOP PERF: 38 @ 10674' Note: Refer to Production DB for historical pert data J__L SIZE ( SPF 1 INTERVAL 1 Opn /Sqz 1 DATE SEE PAGE 2 FOR PERFORATION INFORMATION ?? I-1 FISH - IBP RUBBER ELEMENT (03/26/96) 4114f , ■ 11003' I-1 FISH - 2 Small Pieces of Spinner Housing - I PBTD I 11055' "� "�•�• ♦ "�•�•% t 111N1 11 7" LNR. 29 #, 13CR -80, .0371 bpf, ID = 6.184" I 11097' 1. 1�1�1 +1�1 7 0 " 4" 19 -518" CSG, 47 #, MN-80, ID = 8.681" — 11153' ` 1 111 11 11 1 1 1 1 11 TD I-1 11199' I. Al. .4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/20/76 ORIGINAL COMPLETION 09/14/07 KSB /TLH GLV C/O 9/7/07 & 9/10/07 WELL: 09-02 08/26/91 LAST WORKOVER 09/24/07 RCT /PJC GLV C/O & PULL PLUG @ 10265' PERMIT No: r 1760160 09/17/01 RN /TP CORRECTIONS 11/10/08 PP /SV FISH CORRECTIONS API No: 50- 029 - 20198 -00 03/12/03 BHC /TLH PERF CORRECTIONS 01/13/09 RRD /SV ADPERF /REPERF (12/20/08) SEC 2 T1ON R15E 987.19 FEL 1306.86 FNL 10/10/05 JLW /PAG TREE CORRECTIONS 09/09/06 CJN /TLH PXN I I P SET BP Exploration (Alaska) TREE = CM/ WELLHEAD = FMC GEN 1 SAFET'TES: * ** CHROME LNR & TBG * ** ACTUATOR= BAKER C 09-02 _KB. ELEV = 54' BF. ELEV= KOP = 3079' Max Angle = 47 @ 7000' Datum MD = 10733' LOT Datum TV D = 8800' SS R I PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 NOTE: GR does not correlate wIBHCS due to "HOT" deposits ANGLE AT TOP PERF: 38 @ 10674' Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 10649 - 10666 S 06/03/97 1 3 -3/8" 6 10674 - 10679 0 07/23/97 3-3/8" 12 10679 -10694 0 07/23/97 3-3/8" 6 10694 - 10699 0 07/23/97 10699 - 10730 S 06/03/97 3 -3/8" 6 10700 - 10710 0 12/20/08 10749 - 10799 S 06/03/97 3 -3/8" 6 10780 - 10790 0 12/20/08 3 -3/8" 6 10815 - 10825 0 12/20/08 10817 - 10841 S 08/15/91 3-3/8" 4 10856 - 10866 0 09/08/91 3 -3/8" 4 10872 - 10886 0 09/08/91 3-3/8" 4 10896 - 10906 0 09/08/91 3 -3/8" 4 10940 - 10948 0 09/08/91 3 -3/8" 4 10962 - 10972 0 09/08/91 !! ! !Nl 1 * * ►NN1lN11I 11 11111 ■ 1 1111!11 + i i 1 /UMW a 1 a 1 i i i 1 i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/20/76 ORIGINAL COMPLETION 09/14/07 KSB /TLH GLV C/O 9/7/07 & 9/10/07 WELL: 09 -02 08/26/91 LAST WORKOVER 09/24/07 RCT /PJC GLV C/O & PULL PLUG @ 10265' PERMIT No: 1760160 09/17/01 RN /TP - CORRECTIONS 11/10/08 PP /SV FISH CORRECTIONS API No: 50- 029 - 20198 -00 03/12/03 BHC /TLH PERF CORRECTIONS 01/13/09 RRD /SV ADPERF /REPERF (12/20/08) SEC 2 T1ON R15E 987.19 FEL 1306.86 FNL 10/10/05 JLW /PAG TREE CORRECTIONS 09/09/06 CJN /TLH PXN I IP SET BP Exploration (Alaska) Operable: Producer 09 -02 (PTD #1760160) OA pressure manageable by bleeds Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 1(14-0( Sent: Friday, January 14, 2011 7:42 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr Cc: Longden, Kaity; King, Whitney; AK, D &C Well Integrity Coordinator Subject: Operable: Producer 09 -02 (PTD #1760160) OA pressure manageable by bleeds All, Producer 09 -02 (PTD #1760160) was recently evaluated for IAxOA communication. An OA repressurization test started on 01/03/11 showed aER-up -rate —8 psi /day. This rate of increase is currently manageable by bleeds. Therefore, the well has been reclassified as Operable and may be placed on production when convenient for operations. - Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, December 28, 2010 5:23 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Longden, Kaity; Janowski, Carrie Subject: UNDER EVALUATION: Producer 09 -02 (PTD #1760160) Sustained Casing Pressure on the OA All, Producer 09 -02 (PTD #1760160) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing /IA/OA equal to 1170/1640/1640 on 12/27/10. The well has been reclassified as Under Evaluation for diagnostics. The plan forward is to evaluate the IAxOA communication through the wellhead with a pack -off test and perform an OA repressurization test to monitor build -up -rate. A TIO plot and wellbore schematic have been included for reference. « File: 09 -02 TIO Plot 12- 27- 10.doc » « File: 09- 02.pdf » Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/14/2011 UNDER EVALUATION: Producer 094 (PTD #1760160) Sustained Casing P1sure on the OA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Tuesday, December 28, 2010 5:23 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DSOs Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Longden, Kaity; Janowski, Carrie Subject: UNDER EVALUATION: Producer 09 -02 (PTD #1760160) Sustained Casing Pressure on the OA Attachments: 09 -02 TIO Plot 12- 27- 10.doc; 09- 02.pdf All, ✓ Producer 09 -02 (PTD #1760160) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing /IA/OA equal to 1170/1640/1640 on 12/27/10. The well has been reclassified as Under Evaluation for diagnostics. The plan forward is to evaluate the IAxOA communication through the wellhead with a pack -off test and perform an OA repressurization test to monitor build -up -rate. A TIO plot and wellbore schematic have been included for reference. «09 -02 TIO Plot 12- 27- 10.doc» «09- 02.pdf» Please call with any questions or concerns. _ 1 3/<< ZQpF Thank you, Nk P- 53r) f -, ` cP / 640f Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator � p _ 3), ck Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570-9630 ' `? " ff' Pager (907) 659 -5100 Ext. 1154 1 t 1 1`1t 12/28/2010 PBU 09-02 PTD 1760160 12/28/2010 TIO Pressures Plot Well: 09-02 4,000 1111 3,000 - —411— Tbg - IA 2,000 - 00A — 40— 000A On t000 10/02/10 10/09/10 10/16/10 10/23/10 10/30/10 11/06/10 11/13/10 11/20/10 11/27/10 12/04/10 12/11/10 12/18/10 12/25/10 • TREE = CM/ I WELLHEAD = FMC GEN 1 • SAFETYOES: * ** CHROME LNR & TBG*** ____ _ ACTUATOR = BAKER C 09-02 , KB. ELEV = 54' BF. ELEV = n . KOP = . 3079' Max Angle = 47 @ 7000' I 2231' I--17" CAM BAL -0 SSSV NIP, ID = 5.937" I Datum MD = 10733' • Datum TV D = 8800' SS 2985' H7" X 5 -1/2 " XO, ID = 4.892" I 13 -3/8" CSG, 72 #, MN -80, ID = 12.347" H 2726' / GAS LIFT MANDRELS ST MD TV D DEV TYPE VLV LATCH PORT DATE 17" TBG, 26 #, 13CR -80, .0383 bpf, ID = 6.276" I—I 2985' 1 2998 2997 8 FMHO DOME RK 16 09/24/07 2 4619 4434 42 FMHO DMY RK 0 08/26/91 I ii 3 5724 5221 45 FMHO DMY RK 0 05/20/97 4 6401 5713 43 FMHO DOME RK 16 09/24/07 5 7035 6159 47 FMHO DMY RK 0 08/26/91 6 7707 6626 45 FMHO DMY RK 0 08/26/91 Minimum ID = 3.725" @ 10265' * *7 8295 7055 42 FMHO DMY RK 0 08/26/91 4 -1/2" OTIS XN NO -GO NIPPLE 8 8840 7454 44 FMHO DOME RK 16 09/24/07 9 9424 7870 45 FMHO DMY RK 0 08/26/91 10 9797 8136 44 FMHO SO RK 24 09/24/07 11 10126 8379 41 FMHO RKED RKP 0 _05/20/92 * *CANNOT PULL ST #7 AS OF 6/19/97 15 -1/2" TBG, 17 #, 13CR -80, .0232 bpf, ID = 4.892" H 10151' - q I 10151' I-15 -112" X 4 -1/2" XO, ID = 3.958" I '�� 10153' I-1 BKR GBH-22 LOCATOR SEAL ASSY, ID = ? I 10154' I- 19 -5/8" X 4 -1/2" BKR MODEL D PKR, ID = I 9 -5/8" X 7" TIEBACK SLV , ID = ? H 10222' 10168' H 5" MILLOUT EXTENSION, ID = ? I 9 -5/8" X 7" BKR & LNR HGR, ID = ?I 10230' 10173' I-I MILLOUT EXTSION X0 TO 4 -1/2 ", ID = 3.958" I I 10265' H4 -1/2 " OTIS XN NIP, ID = 3.725" I 14 -1/2" TBG, 12.6 #, 13CR -80, .0152 bpf, ID = 3.958" I 10278' 10277' - -I4 -1/2" BKR SHEAROUT SUB, ID = ? I I 10278' 1-14-1/2" TUBING TAIL, ID = 3.958" I A I 10282' I-I ELMD TT LOGGED 09/06/91 I 10453' Hr MARKER JOINT I 10474' H7" MARKER JOINT I PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 NOTE: GR does not correlate w /BHCS due to "HOT" deposits I ANGLE AT TOP PERF: 38 @ 10674' Note: Refer to Production DB for historical pert data MI SIZE 1 SPF 1 INTERVAL 1 Opn /Sqz ( DATE I SEE PAGE 2 FOR PERFORATION INFORMATION I I ?? H FISH - IBP RUBBER ELEMENT (03/26/96) I ■ H I 11003' I--I FISH - 2 Small Pieces of Spinner Housing I PBTD H 11055' 69. .iv 17" LNR, 29 #, 13CR -80, .0371 bpf, ID = 6.184" I 11097 ��t +• t1 • • I 1 • 00 * 19 -5/8" CSG, 47 #, MN -80, ID = 8.681" H 11153' ♦; ��� +1� ���R.1 I TD I-1 11199' 1 .161.4.. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/20/76 ORIGINAL COMPLETION 09/14/07 KSB /TLH GLV C/O 9/7/07 & 9/10/07 WELL: 09-02 08/26/91 LAST WORKOVER 09/24/07 RCT /PJC GLV C/O & PULL PLUG @ 10265' PERMIT No: 1760160 09/17/01 RN /TP CORRECTIONS 11/10/08 PP /SV FISH CORRECTIONS API No: 50- 029 - 20198 -00 03/12/03 BHC /TLH PERF CORRECTIONS 01/13/09 RRD /SV ADPERF /REPERF (12/20/08) SEC 2 T1ON R15E 987.19 FEL 1306.86 FNL 10/10/05 JLW /PAG TREE CORRECTIONS 09/09/06 CJN /TLH PXN I IP SET BP Exploration (Alaska) TREE = CIW WELLHEAD = FMC GEN 1 410 SAFETY.ES: * ** CHROME LNR & TBG * ** ACTUATOR = BAKER C 09-02 ... .................... . KB. ELEV = 54' BF. ELEV — KOP = _ 3079' Max Angle = 47 @ 7000' Datum MD = 10733' Datum TVD = 8800' SS Ii PERFORATION SUMMARY / REF LOG: BHCS ON 03/10/76 NOTE: GR does not correlate w /BHCS due to "HOT" deposits ANGLE AT TOP PERF: 38 @ 10674' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 10649 - 10666 S 06/03/97 3 -3/8" 6 10674 - 10679 0 07/23/97 3 -3/8" 12 10679 - 10694 0 07/23/97 3-3/8" 6 10694 - 10699 0 07/23/97 10699 - 10730 S 06/03/97 3 -3/8" 6 10700 - 10710 0 12/20/08 10749 - 10799 S 06/03/97 3 -3/8" 6 10780 - 10790 0 12/20/08 3-3/8" 6 10815 - 10825 0 12/20/08 10817 - 10841 S 08/15/91 3-3/8" 4 10856 - 10866 0 09/08/91 3 -3/8" 4 10872 - 10886 0 09/08/91 3 -3/8" 4 10896 - 10906 0 09/08/91 3 -3/8" 4 10940 - 10948 0 09/08/91 3 -3/8" 4 10962 - 10972 0 09/08/91 iWi'AWAla l i l i l a l i l DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/20/76 ORIGINAL COMPLETION 09/14/07 KSB ITCH GLV C/O 9/7/07 & 9/10/07 WELL: 09 -02 08/26/91 LAST WORKOVER 09/24/07 RCT /PJC GLV C/O & PULL PLUG @ 10265' PERMIT No: 1760160 09/17/01 RN /TP CORRECTIONS 11/10/08 PP /SV FISH CORRECTIONS API No: 50- 029 - 20198 -00 03/12/03 BHCITLH 'PERF CORRECTIONS 01/13/09 RRD /SV ADPERF /REPERF (12/20/08) SEC 2 T10N R15E 987.19 FEL 1306.86 FNL 10/10/05 JLW /PAG TREE CORRECTIONS 09/09/06 CJN/TLH PXN I IP SET BP Exploration (Alaska) OPERABLE: 09-02 (PTD #1760) OA Pressure Manageable by Blee• Regg, James B (DOA) Page 1 of 2 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, March 21, 2009 3:16 PM ~°°,z 3~Z~1', Z~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East ``~~`` (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Phillips, Patti J Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 09-02 (PTD #1760160) OA Pressure Manageable by Bleeds Attachments: 09-02 TIO Plot.doc ff All, Well 09-02 (PTD #1760160) has been reclassified as Operable. The wellhead packoff seals were tested and passed confirming na IAxOA communication across the wellhead. An OA repressure test was completed showing an OA pressure build-up rate of approximately 50 psifday. As the OA repressurization is manageable by bleeds, ~ the well has een rec assi le as pera e. A recent TIO plot has been included for reference. «09-02 TIO Plot.doc» Please let us know if you have any questions. Thank you, Anna laud e, 1~'. E. Welt Integrity Coordinator GPB Wells Group Phone: (907} 659-5142 Pager: (907} 559-5100 x1154 ~, From: Aubert, Winton Sent: Wednesday, March 04, 2009 2:42 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Hang R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Phillips, Patti ] Ce: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 09-02 (PTD #1760160) Sustained OA Pressure All, Well 09-02 was found to have sustained pressure on the OA, indicating IAxOA communication. T/I/O pressures ~ on 03/04/2009 were SSV/1520/1320 psi. The well has been reclassified as Under Evaluation and placed on a 28- day clock, during which time the well will be put online. Forward plan for the well is: 1. W: PPPOT-IC 2. O: Put on production 3. D: OA repressurization test 4. WIE/WIC: evaluate whether IAxOA communication is manageable. 3/24/2009 OPERABLE: 09-02 (PTD #17660) OA Pressure Manageable by Blee• Page 2 of 2 A TIO plot and wellbore schematic are attached. / Please call or E-mail questions or concerns. Thank you, Winton Aubert Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/24/2009 PBU 09-02 PTD 176-016 3/21 /2009 TIO Pressures ~:.. ~ O~ ;i ~ . l 3,000 --~- T bg -/- IA 2.000 ~ OA -~~~-~~~ ~ OOA ~`~ OOOA 1: X00 ~- 0 n _ - - i 1212710~i 01 '0.3109 01 li 0103 01 it ?109 01 f2~3lU9 01131 I09 0210?109 0211 X3109 02121 x'09 02!23103 03/07/09 03:'1 X109 031:'1 !m:~ ~ti u PBU 09-02 PTD 176-016 3/4/2009 TIO Pressures ~,~~1Q ?.~~j~j ~.r~~o 1,UG0 ~ Tbg ~ IA -~- OA -' OOA - - OOOA ~- On 12iQ6~U~ 1 ~?1i0$ 12t2~?U$ 1~~~~7r0$ U~i03,rU9 ~1r~1U~i1g U1r1??U9 Q1r'z41~9 ~11~31,~09 ~~?U?lll'~ ~'?114ia9 Q~r'~11~'~ 11~~~28r0~ TREE = clw WELLHEAD = FMC GEN 1 ACTUATOR= BAKERG KB. ELEV = 54' . _...m._..._~_._.a.._...~_ BF. ELEV = _______.._... ~..,.~ ____ KOP = 3079' Max Angle = 47 @ 7000' Datum MD = 10733' Datum ND = 8800' SS 13-318" CSG, 72#, MN-80, ID = 12.347" 7" TBG, 26#, 13CR-80, .0383 bpf, ID = 6.276" Minimum ID = 3.725" @ 10265' 4-1/2" OTIS XN NO-GO NIPPi_E 5-1/2" TBG, 17#, 13CR-80, .0232 bpf, N? = 4.892" ~-i 10151' I9-5I$" X 7" TIEBACK SLV, ID = ?J-~ 10222 9-518" X 7" BKR &LNR HGR, ID = ? 10230' 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" ~--j 10278' PERFORATION SUMMARY REF LOG: BRCS ON 03!10/76 NOTE: GR does not correlate wlBHCS due to "HOT" deposits ANGLE AT TOP PERF: 38 @ 10674' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE I SEE PAGE 2 FOR PERFORATION INFORMATION ?? -i FISH - IBP RUBBER ELEMENT {03126196} 11Q03' FISH - 2 Smal! Pieces of Spinner Housing PBTD -j 11055, 7" LNR, 29#, 13CR-80, .0371 bpf, ID = 6.184" 11097' 9-518" CSG, 47#, MN-80, ID = 8.681" 11153' TD 11199' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/76 ORIGINAL COMPLETION 09/14/07 KSBITCH GLV CIO 9!7!07 & 9110107 08/26/91 LAST WORKOVER 09/24107 RCT/PJC GLV CIO & PULL PLUG @ 10265' 09/17/01 RN/TP CORRECTIONS 11/10/08 PP1SV FISH CORRECTIONS 03!17103 SHCITCH PERF CORRECTIONS 01/13/09 RRDISV ADPERF/REPERF {12120(08} 10/10105 JLW/PAG TREE CORRECTIONS 09/09106 CJN/TLH PXN TTP SET PRUDHOE BAY UNIT WELL 09-02 PERMIT Na: X1760160 API No: 50-029-20198-00 SEC 2 T10N 815E 987.19 FEL 1306.86 FNL BP Exploration {Alaska) -o ~ I SAFETY NOTES: *** CHROME LNR &TBG *** 2231' J--~ 7" CAM BAL-O SSSV N1P, ~ = 5.937" 29$5' -r" X 5-112" XO, ~ = 4.892" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2998 2997 8 FMHO DOME RK 16 09/24107 2 4619 4434 42 FMHO DMY RK 0 08/26/91 3 5724 5221 45 FMHO DMY RK 0 05!20/37 4 6401 5713 43 FMHO DOME RK 16 09(24!07 5 7035 6159 47 FMHO DMY RK 0 08126/91 6 7707 6626 45 FMHO DMY RK 0 08126(91 "`7 8295 7055 42 FMHO DMY RK 0 08/26191 8 8840 7454 44 FMHO DOME RK 16 09124(07 9 9424 7870 45 FMHO DMY RK 0 08/26/91 10 9797 8136 44 FMHO SO RK 24 09!24107 11 10126 8379 41 FMHO RKED RKP 0 05/20/92 2726' 29$5' "GANNV / YVLL 51 if! HJ VY O!7 `Jl`J! 10151' ~- ~5-112" X 4-112" XO, ID = 3.958" 10153' BKR GBH•22 LOCATOR SEAL ASSY, ~ _ ? 10154' 9-518" X 4-112" BKR MODEL D PKR, ~ _ 10168' S" MILLOUT EXTENSION, ID = ? 10173' M€LLOUT EXTSK3N XO TO 4-112", ID = 3.958" 10265' 4-112" OTIS XN NIP, ID = 3.725" 10277` 4-112" BKR BREAKOUT SUB, ID = ? 10278° 4-112" TUBNVG TAIL, ~ = 3.958" 10282' ELMD TT LOGGED 09/06191 10453' 7" MARKER JOINT 10474' 7" MARKER JOitYf TREE = CM! WELLHEAD = FMC GEN 1 ACTUATOR= BAKERC KB. ELEV = _ BF. ELEV = 54; __ ___ KOP - 2. 3079' . . . ~.. Max Angle = -Datum MD = -.: .-. 47 @ 7000' ------- 10733' -Datum TVD = 8800' SS -O Z SAFETY NOTES: *** CHROME LNR 8 TBG *** ~' PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 NOTE: GR does not correlate wlBHCS due to "HOT" deposits ANGLE AT TOP PERF: 38 @ 10674' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 10649 - 10666 S 06/03(97 3-318" 6 10674 - i 0679 O 07/23/97 3-318" 12 10679 -10694 O 07!23/97 3-3/8" 6 10694 - 10699 O 07123!97 10699 - 10730 S 06!03/97 3.3/8" 6 10700 - 10710 O 12/20!08 10749 -10799 S 06/03!97 3-318" 6 10780 - 10790 O 12120/08 3-318" 6 10815 - 10825 O 12/20/08 10817 - 10841 S 08/15/91 3-318" 4 10856 - 10866 O 09108!91 3-318" 4 10872 -10886 O 09/08/91 3-3/8" 4 10896 -10906 O 09/08/91 3-318" 4 10940 - 10948 O 09108/91 3-3/8" 4 10962 - 10972 O 09/08!91 DATE REV BY COMMENTS DATE REV BY COMMENTS 03!20/76 ORIGINAL COMPLETION 09f14/07 KSB(TLH GLV C/O 9/7107 & 9110107 08t26/91 LAST WORKOVER 09124/07 RCT/PJC GLV C(O & PULL PLUG @ 14265' 09/17101 RNlTP CORRECTIONS 11110/08 PP/SV FISH CORRECTIONS 03!12/03 BHC/7LH PERF CORRECTIONS 01/13/09 RRD(SV ADPERFIREPERF (12!20108} 14/10/05 JLW/PAG TREE CORRECTIONS 09109106 CJNITLH PXN TTP SET PRUDHOE 8AY UNfT WELL: 09-02 PERMIT No: 1760160 API No: 50-029-2019$-00 SEC 2 T10N R15E 987.19 FEL 1306.86 FNL BP Exploration (Alaska) ~ - • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS %~ ~~~ ~~~ ~~r 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated ~ Other (JAR Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Timefxrt~nsion 0 , Change Approved Program ~ Operat. Shutdown ~ Perforate 0 ~ Re-enter Suspended Well., " 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Nu 6dr::y,~ /~ Name: Development ~' ~ Exploratory ~-~ 176-0160- 3. Address: P.O. Box 196612 StratigraphlC ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-20198-00-00 , 7. KB Elevation (ft): 9. Well Name and Number: 54 KB PBU 09-02 . 8. Property Designation: 10. Field/Pool(s): ADLO-028327 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11199 - feet Plugs (measured) None true vertical 9216.52 - feet Junk (measured) 11003' Effective Depth measured 11055 feet true vertical 9105 feet Casing Length Size MD TVD Burst Collapse Conductor 85 20" Surface - 85' Surface - 85' Surface 2696 13-3/8" 72# MN-80 Surface - 2726' Surface - 2726' 5380 2670 Production 9179 9-5/8" 47# MN-80 Surface - 11153' Surface - 9209' 6870 4760 Liner 877 7" 29# 13CR-80 10220' - 11097' 8451' - 9138' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 7" 26# 13CR-80 13CR-80 SURFACE - 2985' 5-1/2" 17# 13CR-80 2985' - 10151' 4-1/2" 12.6# 13CR-80 10173' - 10728' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR MODEL D PKR 10154' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: . ~ ~ ~~~ ~ ~ ~~~C 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 6 61 7631 219 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ - Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ 'Gas r WAG ~ GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12/22/2008 ~ ~/'~ 09-02 176-0160 PERF ATTACHMENT • • Sw Name Operation Date Pert Operation Code Meas De th Top Meas De th Base Tvd De th Top Tvd Depth Base 09-02 5/1/77 PER 10,749. 10,799. 8,866.61 8,906.02 09-02 5/1/77 PER 10,817. 10,841. 8,920.17 8,939.03 09-02 5/1/77 PER 10,856. 10,866. 8,950.8 8,958.63 09-02 5/1/77 PER 10,872. 10,886. 8,963.34 8,974.3 09-02 5/1/77 PER 10,896. 10,906. 8,982.12 8,989.93 09-02 5/1/77 PER 10,940. 10,948. 9,016.44 9,022.66 09-02 10/16/87 APF 10,674. 10,730. 8,807.34 8,851.61 09-02 10/17/87 SQZ 10,674. 10,948. 8,807.34 9,022.66 09-02 11/22187 APF 10,962. 10,972. 9,033.53 9,041.29 09-02 11/22/87 RPF 10,856. 10,866. 8,950.8 8,958.63 09-02 11/22/87 RPF 10,872. 10,886. 8,963.34 8,974.3 09-02 11/22/87 RPF 10,896. 10,906. 8,982.12 8,989.93 09-02 11/22/87 RPF 10,940. 10,948. 9,016.44 9,022.66 09-02 4/1/88 RPF 10,674. 10,730. 8,807.34 8,851.61 09-02 4/1/88 RPF 10,749. 10,799. 8,866.61 8,906.02 09-02 4/1/88 RPF 10,940. 10,948. 9,016.44 9,022.66 09-02 4/1/88 RPF 10,962. 10,972. 9,033.53 9,041.29 09-02 8/15/91 SQZ 10,674. 10,972. 8,807.34 9,041.29 09-02 8/15/91 SQZ 10,855. 10,856. 8,950.01 8,950.8 09-02 9/8/91 RPF 10,674. 10,730. 8,807.34 8,851.61 09-02 9/8/91 RPF 10,856. 10,866. 8,950.8 8,958.63 09-02 9/8/91 RPF 10,872. 10,886. 8,963.34 8,974.3 09-02 9/8/91 RPF 10,896. 10,906. 8,982.12 8,989.93 09-02 9/8/91 RPF 10,940. 10,948. 9,016.44 9,022.66 09-02 9/8/91 RPF 10,962. 10,972. 9,033.53 9,041.29 09-02 9/26/91 APF 10,649. 10,666. 8,787.57 8,801.02 09-02 10/19/91 RPF 10,749. 10,766. 8,866.61 8,880.02 09-02 6/3/97 SQZ 10,649. 10,814. 8,787.57 8,917.81 09-02 6/24/97 RPF 10,674. 10,694. 8,807.34 8,823.16 09-02 7/23/97 RPF 10,679. 10,699. 8,811.3 8,827.11 09-02 12/20/08 APF 10,815. 10,825. 8,918.6 8,926.46 09-02 12/21/08 APF 10,700. 10,710. 8,827.91 8,835.82 09-02 12/21/08 APF 10,780. 10,790. 8,891.05 8,898.93 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 09-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/20/2008 12/21 /2008'' """WELL SHUT IN ON ARRIVAL*** INITIAL T/I/O = 1950/1800/600 PSI PERFORATE INTERVAL 10815-10825 WITH 3-3/8" POWER JET 6SPF 60 DEGREE PHASE PERFORATIONS LOGGED JEWELRY LOG FROM 7981'-10974.5' FOUND FLUID AT 3440' WITH WHP = 175 PSI """JOB CONTINUES ON 21-DEC-2008*** '""*JOB CONTINUED FROM 20-DEC-2008""" PERFORATE INTERVAL 10780'-10790' AND 10700'-10710 WITH 3-3/8" POWER JET 6SPF 60 DEGREE PHASE PERFORATIONS WELL LEFT SHUT IN, SSV OPEN, VALVES OPEN TO GAUGES, DSO NOTIFIED FINAL T/O = 1500/800 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 METH 2 Total STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stirnulate~X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 54' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchora~le~ AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 170' FSL, 697' FEL, Sec 2, T10N, R15E, UM. 9-02 At top of productive interval: 9. Permit number/approval number: 1145' FNL, 1272' FEL, Sec 12, T10N, R15E, MM. 76-16 At effective depth: 10. APl number: 1269' FNL, 1055' FEL, Sec 12, T10N, R15E, UM. 50-029-20198 At total depth: 11. Field/Pool: 1308' FNL, 986' FEL, Sec 12, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11199 feet Plugs (measured) PBTD Tagged @ 10905' MD (9/24/97). true vertical 9216 feet Effective Depth: measured 10905 feet Junk (measured) true vertical 8989 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 85' 20" 250 Sx AS 85' 85' Surface 2696' 13-3/8" 4350 Sx AS 2726' 2726' Production 9179' 9-5/8" 1050 Sx Class G 11153' 9209' &115SxAS Liner 877' 7" 175 Sx Class G 11097' 9138' Perforation Depth measured 10674- 10699'; 10856 - 10866'; 10872- 10886'; 10896- 10906'; 10940- 10948'; 10962- 10972' true vertical 8807 - 8827'; 8951 - 8959'; 8963 - 8974'; 8982 - 8990'; 9016 - 9023'; 9033 - 9041' 4.5", 12.6#, 13 Cr80 Tail @ 10278' MD. Packers and SSSV (type and measured depth) Baker D Packer @ 10154' MD; Camco BaI-O SSSV @ 2231' MD. . 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 244 1209 2533 - 264 Subsequent to operation 499 1444 4334 - 255 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~:2~ ~ . ~'/'~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-2 DESCRIPTION OF WORK COMPLETED MUD ACID STIMULATION TREATMENT 9/24/97: RIH & tagged PBTD at 10905' MD. 9/27/97: Performed a CTU Mud Acid Stimulation for latex cement filtrate damage removal as follows: MIRU CTU & PT equipment. RIH w/CT mounted inflatable packer while loading the wellbore w/Crude. Inflated & set the packer at 10740' MD (mid-element), then opened the treating ports above the packer & pumped stimulation fluids to treat the open perforation interval located above the packer at: 10674- 10699' MD (Z4/3) Ref. Log: BHCS 3/10/76. Pumped: a) 25 bbls 3% NH4Cl Water, followed by b) 34 bbls 60% Diesel - 30% Xylene - 10% Musol, followed by c) 50 bbls 12% HCl w/10% Xylene @ 1.5 bpm, followed by d) 22 bbls 9% HCl - 1% HF, followed by e) 28 bbls 12% HC! w/10% Xylene @ 1.5 bpm, followed by f) 150 bbls 3% NH4CI Water. Released & POOH w/packer displacing CT w/Meth Water. Rigged down. Returned the well to production w/gaslift & obtained a valid production test. STATE OF ALASKA A,_,-,SKA OIL AND GAS CONSERVATION COMMISSIur~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate.__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 170' FSL, 697' FEL, Sec 2, T10N, R15E, UM. At top of productive interval: 1145' FNL, 1272' FEL, Sec 12, T10N, R15E, UM. At effective depth: 1269' FNL, 1055' FEL, Sec 12, T10N, R15E, UM. At total depth: 1308' FNL, 986' FEL, Sec 12, T10N, R15E, UM. 5. Type of Well: Development _X Exploratory _ Stratagrapic _ Service _ 6. Datum of elavation (DF or KB feet): 54' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 9-02 9. Permit number/approval number: 76-16 10. APl number: 50-029-20198 11. Field/Pool: Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vedical Casing Length Conductor 85' Surface 2696' Production 9179' 11199 feet 9216 feet 11010 feet 9071 feet Size 20" 13-3/8" 9-5/8" Liner 877' 7" Plugs (measured) Junk (measured) Fill Cleanout to 11010' MD (6/16/97). Cemented Measured depth True vertical depth 250 Sx AS 85' 85' 4350 Sx AS 2726' 2726' 1050 Sx Class G 11153' 9209' &115SxAS 175 Sx Class G 11097' 9138' Perforation Depth measured 10674 - 10699'; 10856 - 10866'; 10872 - 10886'; 10896 - 10906'; 10940 - 10948'; 10962 - 10972' true vertical 8807 - 8827'; 8951 - 8959'; 8963 - 8974'; 8982 - 8990'; 9016 - 9023'; 9033 - 9041' Tubing (size, grade, and measured depth) 7", 26#, 13 Cr80 Tbg @ 2985' MD; 5.5", 17#, 13 Cr80 Tbg @ 10151' MD; 4.5", 12.6#, 13 CrS0 Tail @ 10278' MD. ~ackers and SSSV (type and measured depth) Baker D Packer @ 10154' MD; Camco BaI-O SSSV @ 2231' MD. .RE ,E!VED AUG '7 1997 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see attached ;~la~s~ 9il ORIGINAL 14. Prior to well operation Subsequent to operation OiI-Bbl 271 9O Representitive Daily Average Production or Injection Data Gas-Mcr Water-Bbl 1305 2485 1417 2524 Casing Pressure Tubing Pressure 246 266 5o Attachments 116. Status of well classification as: I Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~::'~~ "]'~ . ~ Title: Ensineerin9 Supervisor Form 10-404 Rev 06/15/88 Suspended_ Service _ SUBMIT IN DUPLICATE 9-02 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/23/97: MIRU & PT equipment. RIH w/perforating gun & shot 20' of reperforations as follows: Reperforated: 10679- 10699' MD (Z4/3) Ref. Log: BHCS 3/10/76. Used a 3-3/8" carrier & the shot perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid well test. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate__ Plugging Perforate _X Pull tubing __ Alter casing _ Repair well _ Other_.X 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 70' FSL, 697' FEL, Sec 2, T10N, R15E, UM. At top of productive interval: 145' FNL, 1272' FEL, Sec 12, T10N, R15E, UM. At effective depth: 269' FNL, 1055' FEL, Sec 12, T10N, R15E, UM. At total depth: 308' FNL, 986' FEL, Sec 12, T10N, R15E, UM. 5. Type of Well: Development _X Exploratory Stratagrapic _ Service _ 6. Datum of elavation (DF or KB feet): 54' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 9-02 9. Permit number/approval number: 76-16 10. APl number: 50-029-20198 11. Field/Pooh Prudhoe Bay' Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Conductor 85' Surface 2696' Production 9179' 11199 feet 9216 feet 11010feet 9071 feet Size 20" 13- 3/8" 9-5/8" Liner 877' 7" Plugs (measured) Junk (measured) Fill Cleanout to 11010' MD (6/16/97). 0RIGIN L Perforation Depth Cemented Measured depth True vertical depth 250 Sx AS 85' 85' 4350 Sx AS 2726' 2726' 1050 Sx Class G 11153' 9209' & 115 Sx AS 175 Sx Class G 11097' 9138' measured 10674- 10694'; 10856- 10866'; 10872- 10886'; 10896- 10906'; 10940- 10948'; 10962- 10972' true vertical 8807 - 8823'; 8951 - 8959'; 8963 - 8974'; 8982- 8990'; 9016 - 9023'; 9033 - 9041' Tubing (size, grade, and measured depth) 7", 26#, 13 Cr80 Tbg @ 2985' MD; 5.5", 17#, 13 Cr80 Tbg @ 10151' MD; 4.5", 12.6#, 13 Cr80 Tail @ 10278' MD. Packers and SSSV (type and measured depth) Baker D Packer @ 10154' MD; Camco Bat-O SSSV @ 2231' MD. 13. Stimulation or cement squeeze summary see attached Intervals treated (measured) Intervals treated (measured) OiI-Bbl 442 170 Representitive Daily Average Production orlnjection D~a Gas-Mcr W~er-Bbl 2771 15902 1421 2847 Casing Pressure Tubing Pressure 247 282 Prior to well operation Subsequent to operation Suspended _ Service _ 5. Attachments I16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ 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 SUBMIT IN DUPLICATE 9-2 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES FOR WATER SHUTOFF 5/20/97: RIH & tagged PBTD at 10860' MD. 5124197: RIH w/CT to bottom & pumped gelled sand slurry containing 1500 lbs of 20/40 mesh sand to spot an isolation sand plug across the lower open perforation intervals located at: 10856- 10866' MD (Z2) 10872- 10886' MD (Z2) 10896- 10906' MD (Z2) 10940- 10948' MD (Z2) 10962- 10972' MD (Z2) Ref. Log: BHCS 3/10/76. Made final top of sand plug tag at 10804' MD. POOH w/CT. Rigged down. 5126197: RIH &tagged PBTD at 10814' MD. 6/2/97: An Acid Wash & Cement Squeeze for Water ShUtoff were performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/Hot 1% KCI Water & RIH w/CT to sand plug. PU & reciprocated the acid wash across the open perforation intervals located above the sand plug at: 10649- 10666' MD (Z4) 10674- 10730' MD (Z4/3) 10749- 10766' MD (Z2) Ref. Log: BHCS 3/10/76. Pumped: a) 25 bbls 2% NH4CI Water, followed by b) 25 bbls 50% Diesel/40% Xylene/10% Musol, followed by c) 75 bbls 12% HCI - 10% Xylene w/3% Acetic Acid, followed by d) 25 bbls 6% HCI - 0.75% HF w/3% Acetic Acid, followed by e) 25 bbls 12% HCI - 10% Xylene w/3% Acetic Acid, followed by f) 100 bbls 2% NH4CI Water, followed by g) 154 bbls 1% KCl Water down tubing & 210 bbls Crude down backside, followed by cement. Pumped 10 bbls Latex Acid Resistive Cement, followed by 40 bbls LARC w/20 ppb aggregate, followed by 22 bbls LARC, to squeeze off the open perforations above the sand plug (listed above). Placed 71 bbls of cement behind pipe w/no squeeze pressure bump. POOH w/CT pumping Seawater & Meth Water. RD. 6/3/97: A CTU Cement Resqueeze for Water Shutoff was performed as follows: MIRU CTU & PT equipment. RIH w/CT pumping Hot 1% KCI Water to sand plug top, then PU & pumped 10 bbls Latex Acid Resistive Cement, followed by 41 bbls LARC w/20 ppb aggregate, followed by 17 bbls LARC w/1% Fibers bwoc, to resqueeze the perforation intervals (above). Took several pressure breaks building to 2600 psi final squeeze pressure; held for 45 minutes. Placed an additional 53 bbls of cement behind pipe & POOH leaving a cement plug in the wellbore from 10550' MD to the sand plug. Jetted OOH w/biozan past jewelry, then switched to pumping Crude & Meth Water. Rigged down. 6/6/97: RIH & tagged top of cement plug at 10568' MD. 9-2 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES FOR WATER SHUTOFF 6/15/97 - 6/16/97: RIH w/CT underreamer (5.75" blades) & reamed through the cement plug from 10568' to top of sand plug. Jetted through the sand plug to uncover the lower open perforation intervals (listed above). Circulated biozan gel to clean out cement cuttings & sand to 11010' MD. POOH w/underreamer. Rigged down. 6/24/97: RIH w/perforation gun & shot reperforations at: 10674- 10694' MD (Z4/3) Ref. Log: BHCS 3/10/76. Used a 3-3/8" carrier & shot perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned well to production w/gaslift & obtained a valid production test. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.9296 Company: 3/2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # ... Log Description Date BL Prudhoe Bay "'~ :::~' Floppy RF Sepia Mylar Disk D.S..1-2~i'x'~ .... LEAK DETECTION 021 9951 1 1..... D.S. 4-1-'~ TUBG PUNCHER RECORD 021 895; I 1 D...S. RESERVOIR SATURATION 0221 95: I 1 ... D.S. CNT-G 0221 95 1 1 ~ D.S. 4-19'''--) PERF RECORD 021 795 1 1 D.S. 4-~3~ PERFRECORD 021995 I " 1 D.S. 4.'4~""--D ..PERF RECORD ' . 021 395 I 1...... D.S. 6-3,,~J) PRODUCTION LOG 022195 1 1 D.S. 7-4A'~,,4 PERF RECORD 021 595 1 1 D.S. 9-2%'~,~ ( INFLATABLE BRIDGE PLUG 021 795 1 1 D.S. 9-11 ~ PERF RECORD 021 895 1 1 D.S. 9-45 ~ PERFRECORD 022095 1 1 D.S. 13-20~,~o INFLATABLE BRIDGE PLUG 021795 1 1 D.S. 11-4A---,,~ PROD PROFILE 022095 1 1 D.S. 15-11% ~ ; PROD PROFILE 022095 1 I .. D.S. 18-1,~,,, ~- i DUAL BURST TDT-P 021 895 1" 1 D.S. 11-0~4~ 9 5 0 5 8 DUAL BURST TDT-P 0211 95 1 D.S. 44-~'- q5 95057 DUAL BURST TDT-P 020595 1 . ..... ,-, Please sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED Alask~ 0tl & Gas Cons. Commission Thank you. Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-i'N: Sherrie R CF. IV F..D FEB 0 8 1995 Alaska 0il & 6as Cows. Commission Anchorage NO. 9236 2/7/95 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Floppy RF Sepia Mylar Disk D.S. 1-22A CBT SONIC IN OPENHOLE 01 1 2 9 5 I I .... D.S. 3-24 CNT-D 01 1 295; I 1 D.S. 4-38 USiT 01 30951 I 1 ..... D.S. 4-43 DUAL BURST TDT-P 0119 95; 1 I , , D.S. 4-40 DUAL BURST TDT-P 01 1 7951 I 1 ..... D.S. 9-2 PROD PROFILE · 01 1 6 9 5 I ' 1 , D.S. 9-16 INJEC PROFILE 01 1 595i 1 1 , , · · D.S. 13-30 LEAK DETECTION 01 1 7'9 5i 1 1 ....... D.S. 15-41 STATIC PRESS SURVEY 01 1 3 9 5~ 1 1 D.S. 15-35 SHUT-IN BHP SURVEY/JEWELRY 01 1 4 9 51 I 1 D.S. 16-21 INFLAT BRIDGE PLUG SET RECORD 01 1 5 9 5 I 1 ,, D.S. 15-30 95017 DUAL BURSTTDT-P 123094 - ~1 · ., ., , ' -/55- '77- SIGNED' ~- '~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Date' Subject: From/Location' Telephone: To/Location: September 12, 1994 Kinley Caliper Survey's Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution P.O. Box 100360.~Z~.chorage, AK Transmittal #: 94106 99510~ ~lk' Number of Records: i Well ~Log Bate i Tool Type i Contractor · l ! 03-01 i 08-07-94 i Caliper Survey i Kinley i 03-28 i 08-07-94i Caliper Surve,v i Kinley i 09-02 i 08-08-94i Caliper Survey/ i Finley i 12-15 l 08-05-94 ! Caliper Survey i Kinley ! 17-07 ! 08-06-94 ! Caliper Survey ! Kinley Karla Zuspan Distribution: Central Files ANO-8 Geology BPX ~.~ Exxon State of Alaska ac. ., .s. n. a dretur i aoo Please~g e ARCO Alaska. inc. Is a Subsidiary of At]anticRIchfleldCompany ARCO Alaska, inc. Date: Apr 14, 1994 P.O. Box 100360, , _horage, AK Transmittal #: 94034 99510,~ ~ Subject' ARCO Cased Hole Finals From/Location: Telephone: To/Location' John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well i Number 01-09A 01-11~ Ol-33 03-01 71~-gq ! 03-02 03-19 03-29 .."% 03-29 Log Date~ Tool Type (M-D-Y)i 04-02-94 iv' Perf Record /04-43 ~q~lS!< 04-43 i ~,04-43 04-44 03-25-94 i TDT-P i 03-18-94 03-28-94 !./ TDT-P 03-27-94 i,~ Perf Record 03-22-94 i/ Leak Detection · 03-22-94 ~ Bridge Plug .~ Leak Detection !/ Bridg~ Plug i,/ Bridge Plug v/ TDT-P 03-27-94 7yq~q?-i 03-31 03-27-94 03-29-94 Run, Scale 1 5" 1 5" 1 5" 1 5" 1 2" 1 5" 7~-tt~ i 7f~-5c~ 09-03 ]"/-~Oi 09-19 '~%-'Z~ 09-27 ~-~i 11-04 ~1~ i 11-17 ~5-~ 11-24A ~-5~ 12-06A ~Z-~i 13-20 ~~ 14-03 ~-~ ~ 14-23 ~ ~14-28 ~2-i~ 14-28 i ~%14-28 J~S-I~& 14-35 Contractor Sch Sch Sch , ,, Sch Sch Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1~ 5II Sch 03-29-94 / CNTG ~ 1, 5" Sch 03-10-94 ¢' USlT ~ 1, 5" Sch ., v' USIT 1, 5" Sch 03-13-94 03-29-94 511 04-45 / USIT Cement 1, 5" Sch 05-08 03-14-94 v' Prod Profile ~ 1, 5" Sch 03-18-94 Sch ! 5II 04-03-94 i¢' Perf Record ~ i~, Perf Record ;' 03-21-94 !-/ Bridge Plug 03-30-94 ,- Prod Profile 06-19 07-08 07-23 09-01 1~, 5tI Sch Sch 1, 1"&5" Sch 09-02 03-17-94 J Prod Profile .. 1, 5" Sch 03-29-94 Sch 04-01-94 03-16-94 03-22-94 03-16-94 03-29-94 03-18-94 1, 1 "&5" 03-15-94 03-28-94 ,1 511 , 5II , 5tI , 5II 1, 1"&5" 1, 1 "&5" , 5II Prod Log Perf Record : 03-21-94 / Prod Log / Perf Record ¢- Patch setting ..... ./ Perf Record 1, 1"&5" , 5II , 5II 1,5" .. Prod Profile '," Leak Detection - CNL 03-19-94 -~ Prod Profile 03-15-94 ,/Leak Detection ' 1, 5" 03-28-94 03-17-94 , 5Il 1, 2"&5" Sch Patch Setting Bridge Plug CNL 03-15-94 i~- Perf Record i,/ TDT-P Sch Sch Sch Sch Sch .. Sch Sch Sch Sch Sch Sch Sch ! Sch 03-14-94 i¢" Leak Detection i Sch ' 03-14-94 i¢- Perf Record i 1, 5" i Sch 03-20-94 : 1, 5" j Sch Number of Records: 38 v ARCO Alaska, Inc. is a Subsidiary of Aflanl~cRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-7-'~-]'~ 2-20.93 Leak Detect Run 1, 5" -7~-.~[~(/~....~1-9 12-22-92 Peri Record Run 1, 5" '-.1-9 3-18-93 Prod Profile Run 1, 5" 1-10--.'7,~L~ 3-5-93 Prod Profile Run 1, 5" qg--1 . 1-24A 2-s-93 PITS Run 1.5' 2-11-- '~'~-{~ 2-23-93 Prod Profile Run 1, 5' ~C)--/~ --2-13 ' 2-13-93 Peri Record Run 1, 5' 3-1--7~'--~ 1-8-93 Prod Profile Run 1, 5' '7~--ES --3-9 11-12-92 Peri Record Run 1, 5" 3-34A--~-~ 1-28-93 Prod Profile Run 1, 5" '-/~.- \~ ---4-12 9-19-92 Collar Log Run 1, 5" ' 4.24--~5~-~ 3-6-93 Leak Detection Run 1, 2'&5' ~'7~--~ ~5-6 2-13-93 Prod Profile Run 1, 5" 5-11--]~'~ 8-13-92 TMD Run 1, 5" ~:~ {C)~ -- 5-22 2-9-93 Peri Record Run 1, 5" 6-3--'~- ~ 1-22-93 Peri.Record Run 1, 5" '-~ ~ .-43-10 2-16-93 Prod Profile Run 1, 5" 6-18~-~ 1-22-93 Peri Record Run 1, 5` 6-18; 2-22-93 Prod Profile Run 1, 5" ~'~\~ -6-19 2-16-93 Prod Profile Run 1, 5" - 2-15-93 Prod Profile Run 1, 5" i~!~ ~-9-2 . 2-8-93 Prod Profile Run 1, 5` 9-7'"?/~-~ 3-9-93 Prod Profile Run 1, 5" ~'~ ~--/ -"9-16 3-9-93 In# Profile Run 1, 5" c~}'~ 9-42-~)-~- 2-20-93 Temperature Log Run 1, 5" --9-49 2-6-93 Prod Profile Run 1, 5" 11-1A~c[~-[~7_2-14-93 GR/Collar Run 1, 5" 11-1A; 3-19-93 GR/Collar Run 1, 5" ~c~-- ~/2 { --13-30 2-19-93 Prod Profile Run 1, 5" 13-33~,~_~0/~12-14-92 Tracerscan Run 1. 5" c~_O| 13-33/ ..... 12-14-92 Tracerscan Log Run 1, 5" --14-5A 3-19-93 PITS Run 1, 5" ~/14-28 3-2-93 Baker IBP/Collar Run 1, 5" ~o'1"- ~. '"~14-28 3-8-92 Baker IBP/Collar Run 1, 5" * 14.34-~{~12-10-91 TMD Run 1, 5" ~'-~ ~ -~16-25 2-26-93 Prod Profile Run 1, 5" 16-26-°1~--t~2-28-93 Prod Profile Run 1, 5" /~--(0~. --16-28 2-28-93 Prod Profile Run 1, 5" ** 16-29A°C/2--/;{~3-1-93 Prod Profile Run 1, 5" ~L-~O0 --17-15 11-16-92 Peri Record Run 1, 5" ~.17-16 1-12-93 Peri Record Run 1, 5" Have A Nice Dayl ~ Sonya Wallace ATO-1529 APPROVED_~ Trans# 93049 CKulco HIS Camco Camco Camco Camco HIS Camco HIS Camco HIS Camco Camco HIS HIS HIS Camco HIS Camco Camco HIS Camco Camco Camco Camco Camco Camco Camco Camco Camco HIS HIS Camco Camco Camco HIS Camco Camco Camco Camco HIS HIS # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIP~ #BPX # STATE OF ALASKA The correct API# for 14-34 is 50-029-21010-00. The coorect well name for this lo~ is 16-29A. STATE OF ALASKA 0 ~ J G IN j~ ALASKA~-'. AND GAS CONSERVATION CC .... /IlSSION REPORT uF SUNDRY WELL OPERATIONS 1. OPerations performed: Operation shutdown Stimulate X Plugging ,, Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 170' FSL, 697' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 1145' FNL, 1272' FEL, Sec. 12, T10N, R15E, UM At effective depth 1269' FNL, 1055' FEL, Sec. 12, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Properly Prudhoe Bay Unit 8. Well number 9-2 feet 9. Permit number/approval number 76-16 10. APl number 50 - 029-20198 At total depth C;0P, S. 11. Field/Pool 1308' FNL, 986' FEL, Sec. 12, T10N, R15E, UM .Atlcho_r~ga Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11199' feet Plugs(measured) Fill @ 10945' MD (9/23/92) true vertical 9216' feet Effective depth: measured 10945' feet true vertical 9038' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 85' 20" 250 sx AS 85' 85' Surface 2696' 13-3/8" 4350 sx AS 2726' 2726' Production 9179' 9-5/8" 1050 sx CIG & 115 sx AS 11153' 9209' Liner 877' 7" 175 sx CIG 11097' 9138' Perforation depth: measured 10674-10730'; 10749-10766'; 10856-10866'; 10872-10886'; 10896-10906'; 10940-10948'; 10962-10972' true vertical 8807-8852'; 8867-8880'; 8951-8959'; 8963-8974'; 8982-8990'; 9016-9023'; 9033-9041' Tubing (size, grade, and measured depth) 7", 13 CR-80 Fox, 26#@ 2985' MD; 5-1/2", 13 CR-80 Fox, 17#@ 10151' MD; 4-1/2", 13 CR-80, 12.6¢f, Tbg Tail @ 10278' MD Packers and SSSV (type and measured depth) Baker "D" pkr @ 10154' MD, Camco Bal-0 SSSV @ 2231' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2483 6777 13392 2928,-~'' 4679 13738 Tubing Pressure 308 392 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 here,by 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 Date SUBMIT IN DUPLICATE Q1~/19 r"ll~l~ pr,' .o,W .IWP 9-2 DESCRIPTION OF WORK COMPLETED ROPE PERFORATING w/ACID & FRACTURE TREATMENT OF ZONE 3 5/12/92: MIRU & PT equipment. RIH w/CT & pumped sand slurry containing 70% 20/40 mesh & 30% 100 mesh sand, to place a sand plug isolating the perforations at: 10749 - 10766' MD (Z2) 10856 - 10866' MD (Z2) 10872 - 10886' MD (Z2) 10896 - 10906' MD (Z2) 10940 - 10948' MD (Z2) 10962 - 10972' MD (Z2) Ref. Log: BHCS 3/10/76. Tagged final sand plug top at 10730' MD. POOH w/CT. Rigged down. 5/15/92: Pumped 900 lbs of coarse CaCO3 to place a cap on top of the sand plug to 10728' MD. 5/17/92: RIH & set a 4.5" Shear Plug in the tubing tail at 10253' MD, for ROPE treatment. 5/19/92: MIRU & PT equipment. Performed an Acid ROPE Treatment (Really Overpressured Perforation Extension), on the perforations located above the sand plug at: 10674 - 10730' MD (Z3/4) Ref. Log: BHCS 3/10/76. RIH w/CT & reversed 275 bbls Dead Crude to remove water from above the shear plug. Pumped nitrogen down CT & lifted 235 bbls Crude back to surface, then pumped 30 bbls 15% HCl & 10 bbls 50% Diesel/ 50% Xylene on top of shear plug. Pressured up to 4000 psi on plug pumping nitrogen, then pumped 20 bbls 50% Diesel/50% Xylene down CT & pressured up to rupture the shear plug at 4800 psi. Pumped 285 bbls Seawater displacement. POOH w/CT. Rigged down. 5/20/92: RIH & pulled ruptured shear plug. 8/23/92 8/24/92: Tagged sand top at 10758' MD. cap on top of plug to 10737' MD. Returned well to production. RIH w/inflatable bridge plug & set at 10740' MD, then dumped CaCO3 8/26/92: MIRU & PT to 8100 psi. Pumped a Hydraulic Fracture Treatment using 16/20 mesh Carbolite proppant, through the perforations above the bridge plug (listed above). Pumped 400 bbls Pre Pad @ 30 bpm, then Shutdown. ISIP @ 1800. Resumed pumping 15 bbls Pad @ 30 bpm, followed by 89 bbls Slurry with proppant stages @ 1 - 10 ppg, followed by Shutdown. Placed 8,870 lbs of proppant into the formation. Rigged down. 8/30/92: Performed a proppant fill cleanout down to top of bridge plug at 10732' MD. 9/22/92: RIH & pulled bridge plug, then cleaned out the CaCO3/sand plug down to 11000' MD. 9/23/92: Tagged bottom fill at 10945' MD. Returned well to production with gaslift and obtained a valid welltest. RECEIVED NOV - !992 G, .... Cons, (;ornmiss~Or~ Alaska 0il & ',,- Anchorage ARCO ,~l~.sl~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-31-92 REFERENCE: ARCO CASED HOLE FINALS 2-11 ??-~ 7-14-92 Prod Profile Run 1, 5" * 2-23ST~-/~ 7-14-92 Prod Profile (Flexstak) Run 1, 5" ~/--/~ 2-35 7-13-92 Leak Detect Run 1, ~' 3-7 ~-$'~ 7-6-92 Inj Profile Run 1, 5" 3-10 ?~/ 7-7-92 I!~j Profile Run 1, 5" 3-14 ?f--~- 7-10-92 Prod Profile Run 1, 5" 4-25 ~d-~/~ 7-5-92 Static Temp Run 1, 5" ~/- / ~/~ 4-42 7-5-92 Inj Profile/Temp Run 1, 5" 5-3 g~/~ p~. 7-6-92 Prod Profile Run 1, 5' 9-2~--/~ 7-4-92 Prod Profile (Flexstak) Run 1, 5" 9-27 ~o~C-~ 7-10-92 Leak Detect Run 1, 5" 9-29~,~"--I~g 7-7-92 Prod Profile Run 1, 5" 9-36~J--~-o~ 7-5-92 Prod Profile Run 1, 5" 12-2 ?~.-~- 7-14-92 Inj Profile Run 1, 5" 12-23 ~P {/~'~ 7-14-92 Inj Profile Run 1, 5" ~°£~'2~ 13-23A 7-4-92 Inj Profile Run 1, 5" ~'~ -~/ 13-25 7-7-92 Inj Profile Run 1, 5" ~P'-J'/14-2 7-11-92 Gas Entry Run 1, 5" ~-.~/~16-18 7-11-92 Prod Profile (Flexstak) Run 1, 5" Calnco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the attached copy as receipt' of data. RECEIVED BY Have A Nice Day! Sonya W~ll_~ce AT0-1529 APPROVED Trans# 92167 /? # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL The correct well name is 2-23ST. # PHILLIPS PB WELL FILES. R&D # BPX # STATE OF ALASKA TEXACO RECEIVED AUG 1 0 1992 Alaska Oil & Bas (;OHS. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 1-15 2-9-92 3-7 2-27-92 4-7ST 3-1-92 4-7ST 3-13-92 4-9 ?d'3~, 3-15-92 4-15 3-1-92 4-42 3-1-92 5-12 ~-~ 2-11-92 TM 2-18-92 7-1 2-18-92 9-1 2-28-92 9-2 2-8-92 9-18 3-14-92 9-27 2-7-92 9-31 2-8-92 Prod Prof Run 1, 5" Camco InJ Profile R~m l, 5" ~mco Jewelry R~_m 1, 5" Camco Prod Prof R~m 1, 5" Camco InJ Prof R,m 1, 5" Camco InJ Prof R~m 1, 5" Camco PITS R~_m 1, 5" Camco Prod Prof R~m l, 5" Camco Jewelry Run 1, 5" Camco Prod Prof R~m 1, 5" Ch_taco GR/CCL/Jewelry Run 1, 5" Camco Prod Prof Run 1, 5" Camco Prod Prof R~n 1, 5" Camco Prod Prof Run 1, 5" Camco InJ Prof Run 1, 5" Camco Prod Prof Run l, 5" Camco Prod Prof Run l, 5" Camco RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 Please sign and return the attached copy as receipt of data. commission APP R OV E~sk Cor~s. Trans# 9207~-~~¢~~° # CENTRAL FII~S # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHIL~ PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct well name for this log is 4-7ST. STATE OF ALASKA ~.'. ': : ALA~,,,A OIL AND GAS CONSERVATION COMMISSK.,N "~ ~ ~' ~' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing X Stimulate. Plugging .. Perforate .... Alter casing X Repair well Other X WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 170' FSL, 697' FEL, Section 2, TION, R15E, UM At top of productive interval At effective depth 1269' FNL, 1055' FEL, Section 12, TION, R15E, UM At total depth 1308' FNL, 986' FEL, Section 12, TION, R15E, UM 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB = 54 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 9-02 9. Permit number/approval number 76-16 / N/A (Cons Order #258) 10. APl number 50- 029-20198 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 11199 feet Plugs (measured) 9216 feet 11072 feet Junk (measured) 9118 feet Size Cemented Measured depth 85' 20" 250 sx AS 85' 2696' 13-3/8" 4350 sx AS 2726' 9179' 9-5/8" 1050sxCIG& 115sxAS 11153' 877' 7" Squeezedoff 175sx CIG 11099' True vertical depth true vertical Squeezed off Tubing (size, grade, and measured depth) 7" 13 Cr-80 Fox 26# @ 2985'& 5-1/2" 13 er-80 Fox 17# @ 10278' Packers and SSSV (type and measured depth) Baker 'D'Packer@ 10154'; Camco 'Bal-O' V F D _ __ - 13. Stimulation or cement squeeze summary See Attached Activity Summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska OJi & Gas Cons. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Prgduction or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run .... Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'"~ "' lf~'~ ~ Title Workover Superintendent Date ! / I ?/' ~'.2_ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT DS 9-2 AUDI 4 KILL: 10.0 08/10/91 (1) TD:ll199 PB:l1074 SUPV:GDM KILL WELL. - MW: 8.5 Seawater RIG ACCEPTED @ 20:00 HRS, 8/9/91. R/U HARD LINES. BLED GAS OFF. R/U HOWCO. DAILY:S63,590 CUM:$63,590 ETD:S63,590 EFC:$1,097,000 KILL: 9.0 NDNU: 9.5 PTBG: 5.5 08/11/91 ( 2) L/D TBG. MW: 8.5 Seawater TD:ll199 PUMP SEAWATER DN TBG, ANNULUS. PUMP 300 BBLS HEC PILL. PB:l1074 MONITOR WELL. N/D TREE. N/U BOPE. TEST BOPE. PULL HGR. SUPV:GDM POOH W/ 7" TBG. L/D SAME. DAILY:S36,299 CUM:$99,889 ETD:S99,889 EFC:$1,097,000 PTBG: 13.5 PPKR: 10.5 08/12/91 ( 3) P/U STORM PKR. MW: 8.5 Seawater TD:ll199 POOH W/ 7" X 5-1/2" TBG. L/D SAME. TEST BOPE. RIH W/ PB:l1074 SPEAR. SUPV:GDM DAILY:S27,435 CUM:$127,324 ETD:S127,324 EFC:$1,097,000 PPKR: 24.0 08/13/91 (4) TD:ll199 PB:11074 SUPV:GDM RIH W/ MILL. MW: 8.5 Seawater RIH W/ RTTS. SET @ 25' ATTEMPT TO SET NEW PACKOFF. NO GO. POOH W/ RTTS. RIH ~/ SPEAR. TAG FISH @ 10233' JAR FREE. SPOT 200 BBLS HEC PILL. POOH. RIH. ENGAGE ~BR @ 10414'. POOH. RIH W/ MILL. DAILY:S50,648 CUM:$177,972 ETD:S177,972 EFC:$1,097,000 PPKR: 24.0 08/14/91 (5) TD:ll199 PB:l1074 SUPV:GDM POOH. MW: 8.5 Seawater RIH W/ PRT, MILL. TAG @ 10433' MILL ON PKR F/ 10433'-10436'. CHASE PKR TO 10%44'. POOH. RIH W/ SPEAR. TAG PKR @ 10745'. ENGAGE PKR. SPOT 100 BBLS HEC PILL. POOH. DAILY:S38,210 CUM:$216,182 ETD:S216,182 EFC:$1,097,000 PPKR: 8.0 COUT: 10.0 TCSG: 6.0 08/15/91 ( 6) RIH W/ RNP. MW: 8.5 Seawater TD:ll199 POOH W/ PKR. L/D SAME RIH W/ CSG SCRAPER TO 10660'. PB:l1074 POOH. L/D SAME. RIH ~/ HOWCO RBP TO 3040'. TEST 9-5/8" SUPV:GDM CSG. RIH. DAILY:S37,146 CUM:$253,328 ETD:S253,328 EFC:$1,097,000 TCSG: 22.0 LPRF: 2.0 08/16/91 ( 7) RIH W/ VERTILOG. MW: 8.5 Seawater TD:ll199 SET RBP @ 10663'. TEST CSG. SET RTTS @ 35'. N/D BOPE. PB:l1074 REPLACE PACKOFF. TEST SAME. N/U BOPE. TEST BOPE. L/D SUPV:GDM RTTS. SPOT 100 BBLS XCD ON TOP OF RBP. REL RBP. POOH. N/U PERF FLANGE. R/U ATLAS. RIH W/ VERTILOG. DAILY:S166,787 CUM:$420,115 ETD:S420,115 EFC:$1,097,000 BP/AAI SHARED SERVICE PRUDHOE BAy UNIT ACTIVITy SUMMARy NORTH SLOPE LPRF: 8.0 08/17/91 TD:ll199 PB:11074 S UP V: GDM FISH: 24.0 08/18/91 ( TD:ll199 PB:l1074 SUPV:GDM 9) FISH: 24.0 08/19/91 ( 10) TD:ll199 PB:11074 SUPv : GDM SQZ : 24.0 08/20/91 ( 11) TD: 11199 PB.' 11074 SUPV : GDM SQZ : 24.0 08/21/91 ( 12) TD:ll199 PB:11074 SUPV:MCH SQZ : 24.0 08/22/91 ( 13) TD: 11199 PB:11074 SUP V : MCH DS 9-2 AK AUDI 4 FISH: 16.0 8) WASHOVER FISH. CONT'D RUN VERTILoG F/ 10660,_SURF. R/D FLANGE. N/U MW: 8.5 Seawater FLOWLINE. RIH W/ OVERSHOT. TAG FISH @ 10551, W/ OVERSHOT TO 10887, · · POOH. RIH DAILY:s79 220 CUM:~499,335. ETD:S499,335 EFC:$1 097,000 MILL ON CSG. ' CLEAN OUT FILL F~ 10887,_11009 . PUMP 50 BBLS XCD SWEEp · MW: 8.5 Seawater POOH 10 STDS. RIH. POOH. RIH W~ MILL. TEST BOPE. MILL F~ 10748'-10751,, 10758, . DAILY:s57,782 CUM:~557,117 ETD:S557,117 RIH. EFC: $1,097,000 MiLL ON CSG F/ 10758'-10760, POOH. RIH W~ MILL. MILL F~ · MW: 8.5 Seawater 10760'-10765 - REAM TO 10812; PUMP 50 BBLS XCD SWEEP. POOH. RIH W/ MULESHOE. ' DAILy: $32· 770 CUM: $589,887 ETD: $589,887 WOC. EFC: $1,097,000 RIH. CIRC. PUMP 13 B W/ 05 GP BLS WAT 1.1~ S D47 o_ ER - MW: 8.5 Seawater YIELD ~,_12o D-65, 22% ~^_100 ~BLS (488 SX) , , ' ~P W/ ~ ..... '-~, u~00, .5% XE67749 ~ __G CMT W~ 3000 PSI (59 BBLS ~ 15.8 PPG. - ou~TEm. POOH 20 STDS. REC CIRC. SQZ' TAG CMT @ 10443,. INTo FORM, 7 BBLS 10590, CiD~ , . TEST CMT BACK). POOH. RIH. DAiLY.~73 "~ ~ WOC. · WASH TO 10654,. POOH TO · ,376 CUM: $663· 263 ETD: $663,263 EFC:$1 097,000 M/U BHA. · WOC. CIRC. DRLG CMT F~ 10616'-11044, TEST MW: 8.5 Seawater PS/, 100 PS/ BLED OFF. REV CIRC. PO0~. PERFs TO 1500 M/U BHA. DAILY:s26,417 CUM:$689,680 ETD:S689, 680 POOH. EFC : $1,097,000 RIH W/ JET BASKET. JET JUNK INTO BASKET M~..8_. 4. Seawater DRLG JUNK, CMT. REV CIRC. 5 ' nan w/ BIT & JB. POOH. STD SHORT TRIP. TEST CSG. DAILy: $25,951 CUM: $715,631 ETD: $715,631 EFC: $1,097,000 RECEIVED Alaska Oil & ~as Cons. CommissiO~ Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT DS 9-2 AUDI 4 RCSG: 24.0 08/23/91 (14) TD:ll199 PB:l1074 SUPV:MCH POOH. MW: 8.4 Seawater POOH. R/U WEATHERFORD. RIH W/ 7" 13 CR LNR ON DP. CIRC. PUMP 25 BBLS WATER, 175 SX 'G' CMT @ 15.8 PPG. REV CIRC. L/D CMT HD. POOH. DAILY:S79,821 CUM:$795,452 ETD:S795,452 EFC:$1,097,000 COUT: 10.0 TCSG: 10.5 RPKR: 3.5 08/24/91 (15) RIH W/ TAILPIPE ASS'Y. MW: 8.4 Seawater TD:ll199 RIH W/ SCRAPERS. TAG CMT @ 10967'. DRLG CMT, LC, CMT TO FC PB:l1074 @ 11055'. REV CIRC. TEST LNR LAP REV CIRC TO SEAWATER. SUPV:MCH POOH. RIH W/ PKR & TAIL ASS'Y. DAILY:S41,426 CUM:$836,878 ETD:S836,878 EFC:$1,097,000 RPKR: 7.5 RCMP: 16.5 08/25/91 (16) RIH W/ TBG. MW: 8.4 Seawater TD:ll199 RIH W/ BAKER 'D' PKR. SET @ 10153'. POOH. TEST BOPE. R/U PB:l1074 WEATHERFORD. RIH W/ 5-1/2" 13 CR TBG. SUPV:MCH DAILY:S66,160 CUM:$903,038 ETD:S903,038 EFC:$1,097,000 NDNU: 9.0 RCMP: 15.0 08/26/91 (17) RMOVE RIG. MW: 8.4 Seawater TD:ll199 RIH W/ 7" X 5-1/2" TBG. STING INTO PKR. DISP W/ 137 BBLS PB:l1074 DIESEL. LAND TBG. R/D WEATHERFORD. N/D BOPE. N/U TREE. SUPV:MCH TEST TREE. RIG RELEASE @ 06:00 HRS, 8/26/91. DAILY:S297,006 CUM:$1,200,044 ETD:S1,200,044 EFC:$1,097,000 ARCO AI_A:SKA, if,lC, F'.O. BOX 'iO<)'S60 ~'::~ i -~ C H U I,; ~'::~ t~, l~"., A [.. A J';' i< A DA'i b. ' 'l 'i-8-9t t;(b.f:t-'t",:FiNCE' ARCO CASED HuLi:. .. . -,. · . - ~--Ti9t "':' :' RECORIL) RUN RUN RECORD RUN RUH '~'J~'~- 3 .--'"' :2- 7 2 - 9' t C C L ( TO .S'PO'I' AVA POGL. H) RUN ~f t - t 8 ,~'-'5- t 8--89 TMD **COI~RECTED** I-,.'.UN "~ .X-k-"~_t i --t 8 '--~" 7-i 2-9t i'MD RUN "'b~~ ':-, - ::?:'.:::;' - 7-.-. ',:.-'.:g - '? ii:),? iq I.':.: t..I i'..~ I z'C'F'LEA,S'E $:1:6N ~ND RETURN THE ATTACHED COPY AS RECEIP"I' OF DRTA i&2, 5' I..IL,? , 5 FtL_ L? , ~ HL;~ , b- H L.. S' , H t._ , 5 ,~'CH , 5 I--IL S' , 5 HL$ , 5 f<l"~DAY ~ ' HAVE A MI._," . S'ONYA WAL_L..ACE AF'F'ROVED A'¥O- 1 529 'T'F,:AN£':~ 9 i CEN'FRAL FILES :~ F'HII_L IF'$ CHEVh:ON Pig WELL, FIL. E~ D & M R & D EXTENSION EXPLORATION ~: BPX EXXON ¢ 3']'A'I"E OF ALA£'KA MAI:;:A i"HUM T[:'XACO MOBIL F'.O. BOX iC, 0S6,3 r-':iNCHf'tI:;'AG~ ALASKA $' :.. 1 0 D A T E ' i ,':', .... o =.'- c:, ~ REFERENCE' ARCO CASED HOI..E FINAl_.,.? ~/1~1~~,~(5__245-23~ 9-7-9t9"-7-9t GR/ccLF'ROD F'ROFILE r~' \~C~ 5-28 ~ 9-:22-9i GR/C:CL ~' 6-4 ~ 8-7-9~ F'ERF BREAKDOWr-~ %.~2~--~' 9-6~ 9-7-9J LEAK DETECT ~:,' --,4 ~ 9 -- :~ ,:2 -- 9 i F:' R U L;'P N U P ]. L. k:. -' ~-_oi, PROD F'ROF]:LE jl.,~? 1o-5:~ 8-'2 F'L. IEA:'~I:Z SiGN AND RETURN THF A'TTACHED COF'Y RECE]:VED BY ........ ",.:;Iii: ,q .N.l.t.;!.-_ L:r-'::"~! ,~-.,~ ~ ~ '~ 3.'ONYA WAi~ Ac.o' A T 0 - i 5:2 9 RUN i, RUN i, RUM i, t-tUt,.! i, RUN i, RUN i, R Ui'".~ i , iN:UN i, RUN i, A2 RECETF'T UF' DA'FA. A F:' F' R C.',"v',r.': i)~ '¥ R A N ;_:,' :~- ':2 i/t3 4 4 l.'.: A H C F.) CAHCO C.' ~'.":~ t.t L: U C;AF~CCJ CAMCO C A ~'": C I'-j r',.; R i'i C t'-~ CAPiCO AR(.'.:O ALA2KA, !NC., ~-- P ~ C), B 0 X i (')(") S 6 (') A N C: H 0 R A (; E, A L A Z K A 9 9 5.' i (') F.:EFEREi"~!CE' ARCO CAZED HOLE F:iNAi._.~' c~--'~"~--9t, ,...,- CE:L_-F'ERF RI_IN i , '35" t "',~'-'.5-'9t CL]I_-F'EI;,'F RUN i., ~f." ?-26--9i CCL-F'E:.i'<F' RUN i 9-24--'9~ VERTIL. OG RUN i ,'~,-."";- c~ i VERTTLOG RUN · ,.- : ,~. _ ATLAS A'TLAZ ATLA:? ATLAS A 'T L. A .~' I:'I..EA2E ;?iGN AND I;'-]TUF,'N T!-iE ATTACHED COF'Y AS' RECEIF'"I' OF DAT.A. A , /OCT .-, ]:, ,,. .Cons ComF~i~s~Jn :,. L. H ~ ~-~ WALLACE AlaskaOil ° 6':'''e ~1~c.~0~'~" E D,,,, ' ~/,,X'a,,[~o.' .......... ~' u,',o'""" r'r, ns ,.,,.,~ - C.,',mmission... ..... DISTRIBUTION ~ ~.~_NI Rr-~L FII_E2' ~ F'HILLIF'2 "' CHEVRON PB WELL FILE~ D & M R & D · ~ EXTENS' l ON E'XPLORAT l ON. ~ _RF'~',, · , EXXON ~ ~r~TE OF ALASKA HARATIaON TEXACO ~ HOBIL ARC[] ALASKA, INC. P.O. BOX i00S6(~ ANCHOR. AGE: ALA~KA 99~. . . DATE · 9-i 9-9t REFERENCE' ARCO CASED HOLE FINALS °-i,... 6 o-o-oi, , , F'FRF RECORD RLIN. I , .,~-<" /5-28 9-6-9t CBT ,;:UN i, 5' x.~_..:~p, m_6_9i CET RUN i ~" * 9-2 9-8-9t F'ERF RECORD RUN i, 5" PLEASE SIGN AND RETURN THE: ATTACHED COF'Y AS' RECE:IF'T OF DATA. FIAVE A NICE DAY! SONYA WALLACE ATO-t 529 APPROVED TRAN$.'~ 9i $CH $CH $CH $CH D I STR. I BIJT ]: ON CENTRAL FILES CHEVRON D&M EXTENSION EXF'LORATION EXXON MARATHON MOBIL $ PHILLIPS PB WELL FILES R & D ~.,."' BF'X ~- STATE OF ALA£'KA TEXACO · . THE CORRECTED TOP LO[; INTERVAL FOR 9-2 I5' i(:,320'. RECEIVED OCT 0 3 1981 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INC~ F'~O~ BOX i00360 ANCHORAGE, ALASKA 995i DATE · 8-S0-9t REF--EI-':eENCE' ARCO CASED HOLE FINALS' 7-.3 8-f 5-9t PERF RECORD RUN i: 5' 7-i7 8-i 2-9i CCL (TtJBING CLJTTER) RUN 7-i7 8-t7-9t VERTiLOG RUN i, 5' 7-t7 8-2t -9t PFC RUN t , 9-') "-i 6-9 _ o t VERTILOG RUN t, ., .... ., , t. ULL~R/PERF RLIN t 5 9 4 8 i p_ot .... i ~ .~ 9-5 8-i 0-9i COLLAR/PERF RUN 9-26 8-i 7-9t COLLAR/PERF RUN iS-i0 8-i4-9~ COLLAR RUN t , 5' t 4-4 8-i i -9t CCL/PERF RUN ia-~, 0 o°-~t-gt F'ERF RECORD RUN i 5-2.5 8-i 5-9t COLLAR/PERF RUN . ~8--iS 8-~i-~i PDK-tOO/GR/CCL RUN t ~' i 8-t 6 8-22-9i CNL RUN PLEASE SIGN AND RETURN ]'HE ATTACHED COF'Y AS RECEIF'T (iF DATA. SONYA WALLACE ATO-i 529 ,S'CH SCH A 1"LAS ATLAS ATLAS A-FI_AS A'I"L. A 3.' A"t'I_AS Al'LAS SCH ATLAS ATLAS £'CH AFt_AS Al'LAS SCH DISTRIBUTION CENTRAL FILES C H E V R 0 N EXTENSION EXF'LORATION EXXON HARA'I'HON MOBIL · "- F' H I L. L. 'r F' $ F'B WELL FILES R' & D '"' B PX · "- ;S"i'A'riT OF- ALA;i,,"I<A T E X A C 0 ARCO ALASKA, INC. F'. O. BOX ANCHORAGE, ALASKA 995i (-} DATE' 8-26-9t REFERENCE' ARCO CA'SE S-2S .8-6-9t S-2S 8-7-9~ 6-6 7-°4-9J~ 7- t 4 '~-°°-9 i 7-i 7 8-9-9i 7-i 7 8-t ~9-9' ~ 7-t 9 7-°7-9t 7-28 8-9-9t 7-3S 7-29-9 i 9-2 7-29-9t 9-9 7-29-9 t i S-4 7-25-9 t i 4-i i 7-2f-9t * i 4-t 5 7-2t-9i i 4-S0 7-2i -9i PLEASE SIGN RECEIVED BY D H'OLE FINALS PROD PROFILE RUN GR-CCL RUN CC[.-F'ERF RUN CCL-PFC (F'ACKER) RUN PROD F'ROFILE RUN F'ROD PROFILE RUN TUBING CUTTER RLJN TUBING CUTTER RUN P I TZ, RUN CCL--F'ERF RUN i'MI) . RUN PROD F'ROFiLE RUN CC:ILl_AR RUN JEWELRY . RUN STA't'IC TEMP SURVEY RLJN STATIC TEMP SURVEY I;:UN STATIC TEMP Z,URVEY RUN AND RETURN THE ATTACHED COPY AZ, RECEIPT OF DA'I' HAVE A NICE DAY! $ONYA WALLACE AT0-i529 i'RANZ,:~ '9 t~57 ' i ; t, t, t, t, i, i, t, i, ..,.q" F; A H C Fi_ _ 5" Al'LAS 5" ATLA3' 5" ATLAS 5 · CAHCO 5" CAi'tCO _,'~'" Al'LAS 5 ' ATLAS .,-=~'" CAHCO 5" A TLAZ, 5 ' HLS 5' CAPiCO 5" CAMCO 5" CAMCO 5" CAMCO 5" CAMCO 5" CAMCO * T HE D I S]"R I B ~J'i" ]: ON CENTRAL FILES ~ F'HIL. LIF'e r" I - i ~ -- ~HE'vRUN PB WELL_ F'ILE:S D & M R & D EXTENSION EXPLORATION $ BPX EXXON ~ Z'FATE OF ALASKA MARATHON TEXACO MOBIL CORRECTEt) TOP LOG .INTERVAL FOR i4-iS IS i~)6<9(3', ARCO ALASKA, INC. F'~O. BOX 'i00S60 ANCHORAGE, ALASKA 99~ ~ -DATE' 8-t 6-9t REFF.-"RI.:]NCE' ARCO CASED HOLE FINALS ~.. 2--S 7-'..'6-~.. , i CNL.-GR RUN i , _.."~'" 2-2.3 8-:3-9i COI_L. AR-PEI~:F RUN i, '5" 3-23 7-26-9i TUBING CUTTER ' RUN i , 5' -11-~~-~5 7-"25-9i F'FC-GR (F'ACKER SETTING) RUN 5-~ 3 7-3~--9 ~ F'FC RUN ~/-~5-32 8-3-9~ COLLAR/F'ACKER RUN 7-2 7-°6-~,. , CNL-[;R RUN 7""~ 7 7-3~ -9~ COLLAR RUN , ,_.. ¢-3i-9i COLLAR-F'EF:F RUN t , 9-2 8-t-~i TUBING CUTTER RUN t .. 5" ~-e 8-i-~i COLLRR-F'ERF RUN i , 9-t8 7-22-9t COLL~F:-F'ERF RUN i, 5" ** 9-.30 7--24-~i CNL-[;R RUN t , t 2 '~ ~-oz-' '-,_ , ,_ i ~t CNL-GR RUN PI...EA,g.E $I(.;.N AND RETURN THE ATTACHED COF'Y AS RECEII::'T OF DATA,. RECEIVED BY ~~/~_..~.. FtAVE A NtCE DAY! ~ON. YA WALLACE TRANS'~ 9 i A i"LAS A TL A ;:," A 'f' I_ A ATI_A,?;' A 'i' LA .? A'i'LAS ATLAS ATLAS ATLAS ATI_A~ DISTRIBUTION '"' CENTRAL FILE~~ '1~ - · ,,-"'- CFtE;,/RON D & M · f,: EXTENSION EXPLORAi"ION · I~ EXXON fiARATHON · '~ MOBIL '"' P H I L L t I-'" .? F'B WELL. F']:L..E:,5,' R & D '~' BF'X "ti' · "" ,gTA'f'E OF AL.A~'KA TE£XACO * "f'HE COF;.:RE-"CTED AF'I~ FOR 2-o :1:2 ,:~: ,'.'; - n ':~ ,;, - -::, ,-:.', ¢; ';";.' ~.x-. THE CORRECTED AF_Z. IL~ FOR'..~9-3(;, iS' 5;~-6,'29-2t4i i ,. ARCO ALASKA, INC. F'.O. BOX i00360 .... ANCHORAGE, ALASKA 99_ DATE' 8-5-9i . ~ REFERENCE' ARCO CASED HOLE FINALS DUAL BURST TDT-P DUAL BURST TDT-F' DLJAL BURST TDT-P GR-CCL PERF'/JUNK -BASK ET/PACK ER LEAK DETECT LEAK DETECT CNL RUN i, 5' SCH RUN ~, 5" SCH RUN i, 5' SCH RUN t, 5' CAMCO RUN i, 5' SCH '~' CAMCO RUN t, - RUN i, i',2',&S'CAMCO RUN 6, 5' SCH PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA, RECEIVED B¥~-_~__ HAVE A NICE DAY! SONYA WALLACE APF'ROVED AT0-i529 TRANS~ 9Jr237 DISTRIBUTION '-'- CENTRAL FILES -.-'" CHEVRON '"- EXTENSION EXPLORATION - EXXON '~r MARATHON MOBIL -Ir PHILLIPS PB WELL FILES R & D BF'X STATE OF ALASKA TEXACO * THE CORRECI'ED LOGGING INTERVAL IS 3'?()0' - lO700' ~n¢bor~ d°fz~nTJSSiot~ ARCO ALASKA, INC. F'.O. BOX 108568 --- ANCHORAGE, ALASKA 9. DATE: 7-5t -9t REFERENCE: ARC q/~).~ t - t B 6-26-9t t -22 7-5-9t t -24 6-27-9t t -25 7-4-9t 2-9 6-29-9t 5-5 6-23-9t 9-2 7-8-9t 9-55 7-8-9t i3-iO 7-6-9i t 4-i 4 7-5-9t '* i 7-t t 6-'~0-9t.- t 7-t t 6-20-9t t 8-7 7-5-9t t 8-t7 7-5-9t 0 CASED HOLE FINALS PROD F'ROF'ILE RUN RUN PROD PROFILE RUN PROD PROFILE PROD PROFILE ~g~ 07 ~ RUN RUN LEAK DETECT LEAK DETECT Al~s~ Oil & G~s~n~b~°°s' t~mm~$~NRuN LEAK DETECT RUN LEAK DETECT RUN't LEAK DETECT RUN CASING INSPECTION CAI. IF'ER RUN t LEAK DETECT RUN PROD PROFILE RLIN PROD PROFILE RUN PROD F'ROFILE RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA HAVE A NICE DAY! SONYA WALLACE AT0-t529 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA I'EXACO * THE CORRECTED BOTTOM LOG INTERVAL I$ 4,900 FEET ARCO ALASKA, INC. '~' F'.O. BOX t00360 ANCHORAGE, ALASKA 995t DATE: 7-26-9t REFERENCE: ARCO CA~ED HOLE FINALS t-t0 &-2&-91 PROD PROFILE 9-2 &-t9-9i LEAK DETECT ~q~-44 6-J~-~ PERF RECORD t2-~ 6-t D-~t COLLAR LOCATOR RUN t, 5' RUN RUN t, 2'&5' RUN t, 5' RUN t, RUN RUN RUN t, 5' RUN t, 5' RUN RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY ....... HAVE A NICE DAY! £ONYA WALLACE. AT0-t529 CAMCO CAMCO CAMCO CAMCO CAMCO HL$ HL.~ HL$ HR~ CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTEN;~ION EXPLORATION EXXON MARAI'HON MOBIL F'HILLIF'S F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO JUL 2 $ 1991 .41aSka Oil ~ Gas Cons. 4nchorage ¢°rnrnission ARCO ALAS'KA, INC~ P.O. BOX i00S6;'J ANCHORAGE~ ALASKA 99~0 DATE · 6/20/90 IR E F-- E R E bi C E · ARCO CA;'].'ED HOLF F'INAL'2 · i ,,~:. ~-'-28-9,'--', F't:;:Oi.~i~r':TION F'ROI..-IL_E.' ~.'IIRVEY RUN i ~':'" -- :;.'. _.:. ...'. .... ,..: ......... : _:' 9-2 6-3--9,:7,. TEHPERATURE I ..... OC- RIIhi, i , ..,.':-.'" 9-4 A--.'-~,-c;.."('') ...... TEHPERATURE LOG RLJN i , ..,'~" o ~=: ,x~ _ "~] _ 0 (.';, ...... F' '" ^ I i r.~ . -- ' 1L-.r~,-ERMT RF_ ;~UI;,'VEY RUN i '7. ..... ,(, A_. -- ...7':; -- c,,, ,:::,. i' E M P E R R T U R Iii: 5' I..IR V E Y R U N i , _:.'::" '?.-':~'. 6-4-'.z,'n. ._. TEHPERA'i't ...... IF'IL: I._nG RUN i , ~',." 9-* i 6 a.-m(:; * ', --, , ~ TEHPERATIIRE I..F)G RUM i ~ .... ! ...: '?-i,_,° ,5 .- z, - m,':',, ,., TEHPEI;:ATURE /~IJRVEY. IN;UN, i , ':*_, ' 9-2,3 ,4--3-9(:, TEH!::'ERATURE LOG RUN i , 5" ~-"~.,:~. .*-4-m;-'; "FEHF'ERATUIkI:: ;S'UF;,'VFY RUN i , 5" : :~...*, ~.j : .... ("-.. .... ....":'~::.,. ,.:,: .... ._,', -- m,"-~, .~. TEHPERA'i'"UF('E L. OG RUN i , ':::..,." i 2-4A ~-3':E)-90 LEAK DFZ-I"FJCTION RUi"~ i ':~'" · ~ i 3:.--7 _,~":-3()--9n. ,, i'EHP/5;P]:i'INER G;'"L. SIJRVEY .... RUN i , '::'_:." C I':~ I'l Ii I"j C A ,,'.~ C 0 C: A m C' 0 C A r.~ C 0 S A i'~ C 0 C ~:; r.~ C 0 r:~ I"i I..: I.J C ~':~ H C 0 C A i'"~ C 0 C A H C 0 F'L. EA,?;E ~:rGN AND RETURN "I-HE A'FTACHiED COF'Y A,~:; RIECEIF'F OF DATA, I:;.:E C [.~. ]] V E D ii:',-" REC ~'E~ i',!!C:E DAY! JUN 2 2 1990 . Commi$$Wn · ~' :". i F:' _ .. % ,.:. ,.~,._L_ Y H 0 F F F:'I< E' F' Aln~k~ Oil & B~s Cons. A 'r O - i.~.':-' 2 9 Anchorage ' AF'F'ROVE- ""' 'i'RANS':~ 9°':,9226 D I ,$'TR I BU l' I ON · ,~"~ CENTRAl_ I--ILE~ ~'~ C 1"I IE V R C] N D & M "'- EXTENSION EXF'LORATION ·'Il' :~ EXXON MARATHON ~ MOBIL F'H:[I_L I F'3' F'B WELL FILES R & D ~: BPX .it. .,~ ~TA'i-E OF' ALA3'KA TEXACO ARCO At_A~-*KA, INC F', O, BOX t ANCHORAGE, ALA$1<A 995t DATE' 9-t 8-89 REFERENCE' ARCO PRESSURE DATA 4-5 8-3(~--89 BHP--,S'TA'r I C GRADIENT CAMCO 4-19 8-29-89 BHP--~'TATIC GRADIENT CAM(](] 7-28 8-29-89 BHP--~S'TAT l C; GRADIENT CAMCO 9-'~,= 7-5.-89 BHP--$TATIC GRAD£ENT 9-32 9-2-89 BHP--~TATIC GRADIENT CAMCO 9-36 9-2-89 BHP--YTATIC (;RADIENT CAMCO i2-28 8--i 3-89- BHP--FLOWING GRADIENT CAMCO ~ 2--3t 6-~-89 BHP--3*'fATIC GRADIENT CAMCO i "2-S:f 6-5-89 BHF ....STATIC; GRADIENT CAMCO i3-t4 8-t¢-89- BHF'--S'TATIC GRADIENT CAMCO t4-37 9-2-89 BHF'--~'TATIC GRADIENT CAMCO ~6-6 8-i 3-89 ~ BHP-aS*'¥ATIC GRADIENT CAMCO i 6-t 8 8-2t -8-9 BHf:'--F'LOWING GRADIENT HRS' t6-28 8-t3-89 BHF'--£TATIC GRADIENT CAMCO 8-,.:.~ 8--i t--89 BHP--S'TATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-t ~'~.9.. 6as Con . Anchorage DISTRIBUTION CENTRAL FILES ~ ,PHILLIF'~' CHEVRON PB WELL FILEY D & M ~ R & D EXTENSION EXPLORATION ~ BPX EXXON ~ STATE OF ALASKA MARATHON $ TEXACO MOBIL ARCO ALA,S'KA, I f:'.C)~ BOX t 0(')36(') ANCHOF~AGE, AI_A,~'I( 99~t0 /W DATE:: 7-t 7-89 EI"E.I',E. Nt.,E: ARCO CASED HOI_E FINAi_$' S-'t t 6'-'29-89 SF'INNER ..?tJRVEY 3-t 2 6-29-89 .'-';'F'INNEF:: ;:~'tJI:;:VE;Y 3""t 5: 7-7-89 i"li:~Hl::' ,.'¢'LIRYEY · .5-',:..,,.7-9-89 'f'EHP $ tJl:~'.V E Y .5-3 7-i "-89 'I'EHF' SL.IF~CVEY 9-'2 '?-5-89 I"E:HF' ,~tJI:::V E Y 9-6 '7"'.S" 89 'I'EHP ,S'URVE:Y 9-7 '?-.5-89 T'EMP :'~'tJRYE Y 9-"9 7-'.5-89 TEi:MP St..IF(VEY 9-28 '?""5- Ei9 TI:FMF' ,.'J;tJ F(V Ii:' Y t t-'2 7-7-89 TEHP ,.~'LJI:~:VE;Y t t-7 7-9-89 TEHI=' SUF:,'VEY t t .... t 6 7-'t 0-89 TIEMI::'3'URVEY t 2-2.5 6-30-89 'f'EHl:',S'tJRVEY t 2"25 6-'30""89 SI::'INNIFi:( ,.~'UI:(VEY i 6'-20 7-8-89 TEMP ~,'tJRVEY I:;:UNt , 5" RtJ N t , '5 ' RUN t, '.:.>" I*:tJN~, 5" R U N t , '3" RtJN ~., .,':~" R U N t , '5" RUN t , 5" Rt. JNt , 5" F::tJNt , .5' RUN 1, 2"&5" RUN t, 2"&5' RUN t, 2"&5' I;:UN t, .5' RUN ~, 5" RtJ N I, '5 ' F'I..I:£A,.?E ,.?IGN AND REI'URN THE ATTAC;I'.II:ED COF:'Y HAVE A NICE DAY! ', 'tOO~ A I:: F:' R 0 V E D ~ ...... I) ISTRIBUTION F'H iLt.. I F:'S F'B WELL. F'ILEE.? R & D BF:'X .. STAI'E OF ALA,.?KA TEXACO 0 i' .I. :; 0 f'I 0 'f' I ,'.9 L) 'f' .1'. ,S' 0 "1' I ,~; 0 'f' ;1: ,? 0 'f' I 0 'f' I ,".,,~ O'i'l$ OTIS OTIS 0 '1" I S 0 T I S 0'1'ZS ARCO ALA£'KA, F'.O. ANCHORAGE, ALA~'KA 995i DATE: i e-?-88 REFERENCE: ARCO CASED HOLE FINAL~' ~. RUN "~ 5 ' 4-2."$ 9-30-88 F'RODUCTION ...... ' ..... '~"'~ .... %,?-:~- , ~ -"-,?,i~':~4.~:-:~?,:,', RUN i 4-28 iG-i-88 ?'-2 9'- ~ 7'-88 9 .... 24 '.',' .... 2 '::', "" ~ .,.... 1 2-t 9 ~ ~9-~88 t 4.-'~ o-°3-88 i4-'S7 9-29 .... 3S i6 .... i6 9-29-88 i 6-i 6 9-t 6-88 F'RODUCTION RUN i, 5" PRODUCTION PROFILE RUN t, 5 · F', r4: ~;} I::, !.J (:: -i" l ti)i'-~ F-' f;.'. o F' ~: L. !~; R t.J N COLLAR/F'ERF RUr'4 4, INJECTION PROFILE ''~' ' .... '--' ..... ': ",-'~','RUN CNL----(;AMMA RAY I:~tJN i , 2 "&5" COL_L. AR/F'EF(F' RUN i, GAHH~ ~AY (PRINTED A3' "FIELD," RUN ACTUAL. L.Y A FINAL) PI_EA*,.S'E SIGN AND RETURN 'i"14E ATTACHED COF'Y A,S' RECEIF'i" OF DATA, O'i" i LL' -'" $CH ,S'C Fi CAMCO (.';: A i"i C 0 A'i'L A ., CAMCO A l'l.. A;,,-' A i'L.. A ,~' CAMCO R~:-"CE I VED BY .......................................................... HAVE A NICE DAY! ~'At...L Y FIOFF'ECI< ER ATO- i 529 D I $ 'f' R I B U T i 0 N CENTRAL FII..E~ CHEVRON. D & M EXTENYlON EXPLORAFION EXXON MARATHON MOBIL. '" PHILLIP,? 'lC PB WELL FILE,~ R & I) .,. ,t; A F' C -..'"' .,S'TATE OF AI..A~'KA '"'..- TEXACO STATE OF ALASKA ~' 0 fi I G IN A L ALASKA OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 76-16 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20198 4. Location of well at surface 9. Unit or Lease Name 170'FSL, 697'FEL, Sec. 2, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number l145'FNL, 1272'FEL, Sec. 12, TION, R15E, UM 9-2 At Total Depth 11. Field and Pool 1308'FNL, 986'FEL, Sec. 12, TION, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 54' RKBI ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 2/16/76 3/9/76 3/20/76* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost ll199'MD, 9216'TVD l1072'MD, 9118'TVD YES]I~ NO [] 2186' feet MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL, BHC, GR~ FDC/CNL~ GR/CBL~ GR/CCL~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf, 85' 32" 250 .~× AS 13-3/8" 72.0# MN-80 Surf. 2726' 17¥' 4350 sx AS cmt 9-5/8" 47.0# MN-80/ Surf, 11153' 12¥' 1500 sx Cla.m~ G & 115 .~ AR nm~ SOO-95 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) 10674-10702'MD 8807-8852'TVD 1/12 spf 7"/5~" 105a~' ]daR/., 10749-10799'MD 8867-8906'TVD 1/8 spf 10856-10866'MD 8950-8958'TVD 1/2 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10872-10886'MD 8963-8974'TVD 1/2 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10896-10906'MD 8982-8989'TVD 1/2 spf N/A 10940-10948'MD 9016-9022'TVD 4-1/2 spf 10962-10972'MD 9033-9041'TVD 4-1/2 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July, 1977 Flowin ~ Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO Date of Test Hours 10/1/77 4.0 TEST PERIOD ~ 1874, 3 1614.6 0 1 o ~-~/~,~, II Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.1342 0 24-HOUR RATE ~ 11246 9688 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AUG - 9 1988 None Alaska 011 & gas Co~ Commission *Note: Perforated well 5/4/77. Workover performed & perforations squeezed 10/20/87.' Reper£orated 11/22/87. Reperforated 4/1/88. Form 10-407 Submit in duplicate CONTINUED ON REVERSE SIDE Rev. 7-1-80 NAME Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 10674 ' 11062' 31NC:~T OF ATTACHMENTS FORMATION TESTS Include interval tested, pressure data, all flu~(Js recovered and gravity, GOR, and time of each phase. 8807' 9110 ' N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,~-~.~ ~ ~ Title Opr._Engr. Mgr. 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 iniection, 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. . II~em 21' IndiCat~ Whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 .' STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMM~,.,,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. BOX 100360~ ^nchorage~ ^K 99510 4. Location of well at surface 170'FSL, 697'FEL, Sec. 2 TION R15E UM At top of productive interval ' ' ' 1145'FNL, 1272'FEL, Sec. 12, TION, R15E, UM At effective depth 1269'FNL, 1055'FEL, Sec. 12, TION, R15E, UM At total depth 1308'FNL, 986'FEL, Sec. 12, TION, .R15E; UM 11. Present well condition summary Total depth: measured 11199 feet true vertical 9216 feet Plugs (measured) 5. Datum elevation (DF or KB) 54' RKB Feet 6. Unit or Property name PrlJdhn~ Ray Ilnit 7. Well number 9-2 8. Approval number , 8-201,/ 9. APl number 5O-- 029-20198 10. Pool PrtJdhoe Bay Oil Poo! Effective depth: measured 11072 feet true vertical 9118 feet Casing Length Size Junk (measured) Cemented Measured depth True Vertical depth 12. Conductor 85 · Surface 2696 Production 9179 Perforation depth: measured true vertical Tubing (size, grade and measured depth) 20" 250 sx Arcticset 85' 13-3/8" 4350 sx Arcticset 2726' 9-5/8" 1050 sx Class G & 11153' 115 sx Arcticset 10674-10730', 10749-10799', 10856-10866', 10872'-10886', 10896'-10906', 10940-10948', 10962'-10972' 8807-8852', 8867-8906', 8950-8958', 8963-8974', 8982-8989', 9016'-9022', 9033'-9041' 7", 26#, L-80 LTC Mod to 2897', 5½", 17#, L-80 from 2897'MD to 10544'MD Packers and SSSV(type and measured depth) Bal-O SSSV @ 2186'MD. Brown 3-H Packer @ ln434'Mn Stimulation or cement squeeze summary Intervals treated (measured) 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 3200 2800 700 270 5400 9500 2900 6~LO 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 <~;~. ~:..~-, Signed Title Operations Engineering Manager Form 10-404 Rev. 12-1-85 STAT17/9-2- M.R.Miller (263-4276) Date 5/'~, ~ Submit in Duplicate DS 9-02 PERFORATING SUMMARY OF OPERATIONS Began perforating operation on 3/31/88. SI well, RU perforating unit, pressure tested equipment. RIH with guns #1 and #2, perforated interval 10962-10972' MD (4 spf), flowed well to cleanup. Perforated interval 10940-10948' MD (4 spf), flowed well to cleanup. SI well, began POOH, stranded wire. Pumped seawater to kill well. POOH, no shots fired, RD. Continued perforating oPeratlo~t~ge,~4~-~,_z~pressure tested equipment. RIH with guns #1 -~--------and #2, perforated inter~a~._10962-10972' M~.D (4 spf) and 10940-10948' MD (4 spf), flowed well to cleanup. SI wel];'-PE)~'H;-alC~hots fired. RIH with gun #3, perforated interval 10774-10799' MD (1/8 spf), flowed well to cleanup. SI well, POOH, all shots fired. RIH with gun #4, perforated interval 10749-10774' MD (1/8 spf), flowed well to cleanup. SI well, POOH, bottom shot only fired. RIH with guns #5 and #6, perforated interval 10702-10730' MD (1/12 spf), flowed well to cleanup. SI well, POOH, all shots fired. RIH with guns #7 and #8, perforated interval 10749-10758' MD (1/8 spf) and 10674-10702' MD (1/12 spf), flowed well to cleanup. SI well, POOH, all shots fired. Secured well, RD, returned well to production. P. fi ~ P,I']>:: i 6) C)}:/-, D~TF' R'FFFRFbJCE' ARCO CA,9F!) ,Ltf!l !::' FTNAI ! FAk' T)I!rTFfT:TT FIN I:['! !F.J ~ ~Fll t. AI-7 AND F'F--F,'I:fqRAT]'i"JR ! OC 1-711H t F' T.,. 'r, .':'., F;.' I .IN 1 F-:'I:?f]F.,!II~TTF1N F'!;:f.1FTI F ;.:lin 'i Ti, J..II::1.".TTFli':.~ I:'I;:f-.II:"I'I.F' K41JN ~ f]f]t I ;.":;F-:.' ,-.t',i'Jh I:'F!;.'t:fliF-;:;~TTN[':, l..FIf.-, I;.'IIN 'i. F:' !;: f! i".': ! 1 f': T T fi i'-J I::' 1:;: f'l I: 1' ! I: t:;: I I N 't . I.~ANH;~; F;.'A¥/.'71:'I'NhJFI;,'/14YhF,:ffl ! FIl~ t;:!]N 'i . '!i'.'- A 'T ~'~:, F' F,' ,..t; F.' / T !:' H ,r.:, F' F;.' A 'T'I I I:;,' F I. I"i I~ I~: I I ;J 'l ; TF-.'i":i!::'. /t::--'1 FI bJ ,""i I: T F: I:;: / I ET;hK DFTr:P. TTFiN R'lli'J ~i . I::' T ",," .':-? F? 1.1 i'-J 'i . !::' !:;: f'i T) ! ! f": T T 1.'1 i',J F' F[: f.1 F T I F R 11 t',J~ . 1' N. I1::' 1.": .1" T I''i N F:' I:;.' ['i F' T I I::' I:;.' I.! N 'l . F'I !.=A.'-'?F.. Z'!'Oi',J AND RI=T!!F:.'N 'T'i4F A'TTAf]I4F'£, Rf]F'Y A.? RFP. FrTI:'T t-IF hA'FA. I! II · II I! I1 I-: A i'-4 f'; f'l f']. A Pi f".' I-i P. Aid f'] f.1 C .A H f'. 1"I 1': F A 1:;.' f'. A M f'.' fl [7'. A H i"': ri F: A Pi f': f".' A N f".' fi fi ,'.'.', M f: f] f'.' A M f": fl ,q.'FRE 17 VF' ,~ I=.-,' Y ...................................... HAVF A W'I'RF DAY~ ~'F:.F,,F.,Y R F i~-1 N.r=. -f' T ATO-t .-' ..t] .' ~ ~ Alaska Oil a (;as Cons. Comraibsioa' .' ~ ''' ;anchorage .-- ~_. I:: T. ! !:7 .'::..' "~ F:' I--I 1'1 I.. '( !::' ..q '"' f"blC';-"~:f'ih~ PR IAFI I F'r t I: ? .~,: 1::' '.':<' T lc hJ Z T FI bJ I!:' ';'-"-: !::'! ri 1:;: ;:'.'-, 'T' 'r f'l i,J ..!~ ....... ;,7 A F' f": ......... ~,. r.:-vvn ...~ '"' ,?TATF I-I Al ih ek' 6 i"i A F-: A TI-4 Iq N ~ T F :K A f". ri ~'- Pti.iRT I. .... ~ STATE OF ALASKA .... ~ ALASKA oIL AND GAS CONSERVATION CL~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well R EVI 5ED OIL I~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of OPerator 7. Permit Number ARCO A1 aska, I nc. 76-16 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20198 .. 4. Location of well at surface 9. Unit or Lease Name 170' FSL, 697' FEL, Sec. 2, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1145' FNL, 1272' FEL, Sec.12, T10N, R15E, UM 9-2 At Total Depth 11. Field and Pool 1308' FNL, 986' FEL, Sec.12, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 54' ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.i Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/16/76 03/09/76 03/20/76* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDePth(MD+TVD) 19. Directional Survey I 20. Depth where SsSV set I21.Thickness°fPermafr°st 11199'MD, 9216'TVD 11072'MD, 9118'TVD YESx] NO [] 2186' feet MD 1900' (approx) _ 22. Type Electric or Other Logs Run DIL, BHC, GR, FDC/CNL, GR/CBL, GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 85' 32., 250 sx Arcti~..~.f. 13-3/8" 72.0# MN-80 Surf 2726' 17-1/2" 4350 ,sx Ar¢l;icset cmt , 9-5/8" 47.0# M1~-80/Soo-95 Surf 11153' 12-1/4" 1050 sx Cl~ G ~ 115 s; Arcticset 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) Perforated w/0.5 spf, 120° phasing 7"/5-1/2" 10544, 10855'-10865'MD 8976'-8983 'TVD 10872'-10886'MD 8989'-9000'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10896'-10906'MD 9008'-9016'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10962'-10972'MD 9060'-9068'TVD Perfs f/10749'-10948' 700 9al 1~% HC1 (ln/?d/RT) Perforated w/0.5 spf, 0° phasing Perfs f/10749'-10948' 225 sx Class C;, (1d/?d/R71 10940 ' - 10948 ' MD 9042 ' -9048 ' TVD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) July, 1977I Fl owi n.q Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS.MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/1/77 4.0 TEST PERIOD I~ 1874.3 1614.6 0 1o 33/~z~ RCM Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1342 0 24-HOUR RATE 11 246 9688 0 27.0 28, CORE DATA None ~;~ ! ~... : *Note~ Perforated ~ell 5/4/77, Workover performed & perforations squeezed 10/20/87, Reperforated 11/22/87o Form 10-407 WCS/19:DANI Submit in duplicate~/J Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' GEOLOGIC MARKERS NAME Include interval tess. ed, pressure data, all fluids recovered and !]rarity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Sad] erochil: 1067L~ ~ 8807 ~ N/A Base Sad1 erochi t~ 11062t 9110~ 31: LIST OF ATTACHMENTS Addendum (dated 12/29/FI7 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ Title Associate Engineer Date (~-- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut~in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL' 10/3/87 9-2 RU pump truck. Initial pressure on tubing & casing 800 psi. Pumped 420 bbls down tubing 8.5 seawater. Pressure dropped to 400 psi. RD pump truck. ~)ri 11 i ng Supervisor ADDENDUM WELL' 9-2 10/24/87 MIRU Camco. RIH w/blind box and attempt to tag ball at 10544'. POH. RIH w/DB plug and set at 10495' WLM. RD. Pressure tubing to 3000 psi; ok. MIRU Otis wire- line unit. RIH, pull prong at 10495', POH. RIH and retrieve DB plug. POH. RD Otis. D'ril Ting Supervisor ' ~,Oate~ ARCO Alaska, Inc. Prudhoe Bay cngineeri~g Post Office Box 100360 Anchorage, Alaska 99510~0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 22, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-2 Permit Number: 76-16 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/MRM:sd Enclosures cc: Standard Alaska Production Co. File Pl(9-2)W1-3 MAR 2 3 1988 Alaska Oil & Gas Cons. C, ommisslo~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AIq3B 6132 C ..... STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMM,,,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~' Operation Shutdown ~ Re-enter suspended well ~ Alter casing L~ Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order - Perforate,~' Other 2. Na,~r~c~f Ql~era;tor AlasKa, Inc. 3. Address P. 0. Box 100360, Anchorage, Afl,, 99510 4. Location of well at surface 170'FSL, 697'FEL, Sec. 2, T10N, R15E, UM At top of productive interval 1145'FNL, 1272'FEL, Sec. 12, TION, R15E, UM At effective depth 1269'FNL, 1055'FEL, Sec. 12, TION, R15E, UM At total depth 1308'FNL, 986'FEL, Sec. 12~ TION, R15E, UM 11. Present well condition summary Total depth: measured 11199 feet Plugs (measured) true vertical 9216 feet 5. Datum elevation (DF or KB) 54' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 9-2 8. Permit number 76-16 9. APl number 5O-- 029-20198 10. Pool Junk(measured) Effective depth: measured 11072 feet true vertical 9118 feet Casing Length Size Cemented Prudhoe Bay Oil PO~ RECEIVED MAR 2 19 8 Alaska 0il & Gas Cons. Commissio[ Measured depth Alichorati{te Vertical depth Conductor 85 20" 250 sx Arcticset 85' Surface 2696 13-3/8" 4350 sx Arcticset 2726' Production 9179 9-5/8" 1050 sx Class G & 11153' 115 sx Arcticset Perforation depth: measured true vertical 10856' -10866' 10872' -10886' 10896' -10906' 10940' -10948' 10962' 10972' 8950' -8958' 8963' -8974' 8982' -8989' 9016'-9022' 9033' 9041' Tubing (size, grade and measured depth) 7" 26# L-80 LTC IVied to 2897' Packers and SSSV (type and measured depth) Bal-0 SSSV @ 2186'MD, Brown 3-H Packer @ 10434'MD 12.Attachments Description summary of proposal ~ Detailed operations program , 5½" 17# L-80 from 2897'MD to 10544'MD BOP sketch 13. Estimated date for commencing operation HaY'ch 25, 1988 14. If proposal was verbally approved Su}).,*.'ou~.:{et}t l¥~rk Beporhcd on ~ Name of approver Date approved 15. I hereby/~ertify that the foregoing is true and correct to the best of my knowledge Signed ~/~, ~ 2~~.~ , Title Operati ons En~]i neeri ng Manager Date ~2/2'~ Commission Use Only Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity ~ BOP Test ,~ Location clearancel, " A,r,~proved Form 10-403 Rev 12-1-85 Approval No. ~_ ,¢~} / STAT17/9-2- M.R.Miller (263-4276) by order of the commission Date ~ '-,2 ¢~'O~' Submit in triplicate DS 9-02 PROPOSED ADD/RE-PERFORATIONS APl # 50-029-20198 PERMIT # 76-16 ARCO Alaska, Inc. proposes to add new perforations and reperforate previously perforated intervals in DS 9-2 within the Sadlerochit Sand from the Prudhoe Bay Unit. The proposed perforation intervals are as follows: Interval. MD Footaae. ff. Reoerf/Addoerf 10674-10730 56 Addperf 1 0749-10799 50 Reperf Reference Log- BHCS (3/10/76) All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure. ARCO AI_A~I(A. TWC. P.O. BOX ANCHORAGE, AI_A~KA 99510 DATE- REFERFNCF- ARCh CAYED HOI_F FINAl... PWDW2-t tt-6-~7 COI...I...AR/PFRFORATTnN 4-D9 t?-20-R7 ROll..AR/PERFnRATTnN 5-~0 ~-6-R~ CRI../.AR/F'ERFnRATION 9;¢~i~! .t¢-R-R7 CAXINR RIIT.TFR 9-5 ~t-t3-R7 COI...L_AR 9-5 tt-8-87 COI..t. AR 9-f5 9-2~-87 COI_I...AR t S-t 9 t G-~ 6-~7 COt. I.. AR?PERFORATION I G-28 ~ -G-88 ;' COI...I...AR/F'ERFORATI~N I4-26 ~-7-~D COI..I...AR/F'ERFORAT~ON t~-S5 ~t-5-87 COI...I...AR t5-~t t0-24-87 COI...I.AR t ?-t t '~ ~ .. -~-8_, COLLAR/PERFORATTON t 8-3 ~ ~-24-~? COl. I...AR 18-9 4~ ~ ~ ............ ~-..- ~...6- _ 7 CO! I...AR./F'ERFORAT I ON RECEIPT OF DATA., RECEIVED BY HAVE A NICE DAY~ F'EGG~ BENNETT DI~' 'I~IJTT..N ',tas~ Oil & Ancho~§e -,-'"'CENTRAl... ._ F T I...E,.S - -,- PHI t.. 1., I P,.S' $ CHEVRON F'R WEI..I... F'T.[.F,.q D & M ~ EXTEN,~I ON EXF'I...ORAT I ON · ,S' A F' C - A.gKA ,- EXXON "" -:'>''" .-,- ,~TAT F. AI._- MARATHON ~,- TEXACO MOBIl... ARCO ALASKA, INC. F'.O. BOX t00~68 ANCHORAGE, ALASKA 995,0 DATE · ~-~ 5-88 REFERENCE: ARCO CASED HOLE FINAL , -t5 ~t-28-87 CN/GR/MtJL. TI-$PACE/£NDSTNE MATRIX RUN , 2 ,5- 1,-3~)-87 CNF'/GR MULTI,'PACE RUN ,, 5" %~-2 ,t-,4-87 F'DK - ,ce RUN ,, ~~ t t -22-87 ' PFC RUN t 2-4-87 F'FC RLIN ~ , ~ t I -~ 2 t t -t 9-87 F'DK - t ~ RUN t , ~t2-28 tt-3~-87 CN/GR HULT~SF'ACE RUN t, ~ tt-29-87 CN/GR HUI_TISF'ACE R[JN t ~ 5-22 ~ ~ -25-87 PFC RLIN ~ , t6-28 tt-t4-87 PDK - t8~ RUN t, RECEIVED BY~~.,.~'~_'~~~O !.~.~ H A V E A N~ D A~.~,(~ OiJ & _GAS. ~n$. PEGGY ATO-~ TRANS ~88(~29 APPROVED DI£TRIBUTION WAI WAI WAI WA,I: WAI WA~ WAI WAT WAI WAZ WAI CENTRAL FILES $ PHI'LL_IF'$ CHEVRON PB WELL FIL. E$ D&M R&D EXTENSION EXPLORATION ~ ~ SAF'C EXXON ' $ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL ARCO ALASKA, INC. P..O. BOX t00J60 ANCHORAGE, ALASKA DATE' t-t2-88 REFERENCE' ARCO CASED HOLE FINAl._ t _no.... t ..:.'"'-t 3-8.7 PUMP-IN TEMF'ERATi_IRE ,,~I. IRVEY RI. IN '--'-..5-I 4 t":'-1,:.. 6-87 LEAK DETECTION RUN ~6-8 t2-t t-87 PRODUCTION F'ROF]TI...E ~ .6.--t :5 t 2-t 2-87 F'RODI.ICT.T. ON PROFILE RI.iN ~&-t8 t2-t t-87 F'RODI..ICT.T. ON PRnF.TLE RIIN '-"'"'--'9-2 t ,,.°.,.-t 9-8'7 PRODUCTION PROFILE RI.IN ~.9-5 12-24-87 F'RODUCTION PROF.T. LE RUN '~ 9-5 t 0-50-8? PFC LO.I.., RUN ~ 9-3 I O-SO-R7 VERTII..OG RI,.IN ~9-5 1-5-88 PRODUCT.ION LOG RUN ~9-t4 t2-t9-87 STEP RATE IN,..IECT.T. ON PROF.T. LE RUN ~t 1-t7 t2-t7/t8 F"];'I'S RUN ~t 1-27 t2-t4-87 FL. OWMETER RUN iS-2 12-23/24 PRODIJC'I'ION .F'ROFII_E RUN ~13-t4 t O-i 0-87 PRISM RUN %tS--29 12-25-87 PRODUCT.liON F'ROFII_EE RUN "'~-'i3-33 t2-i3-87 PRODUCTION FIROFILE RI..IN %i4-6 t2-2(3-87 F'RODUCTION PROFIt_E RUN ~ i4-1i i2-28-87 FI._OWMETER .?URVEY RUN ~ t 5-9 i 2-27-8'7 F'RODUCT]70N F'~N~'r~ ',=' RUN ~-'15-22 ti-2-87 VERTI[_OG RLIN t6-7 t2-26-87 F'RODUCTION F'ROFII...E RUN i7-t2 iO-t i-87 DIFF/TEMF'ERATI_IRE/GR RUN t7-i'2 i0-it-87 PRISM RIJN 5' 5' 5" 5' 5" 5' 5' 5" 5' 5" 5' ..5" 5" ..5' 5" .5" .5' 5" 5' 5" F'LE~SE $.T.C-N AND RETt.IRN T.,H~F.,._~_~aTT~},~ COF'Y A,~ RECEIPT OF DATA, RECEIVED BY ..... HAVE A NICE DAY! PEGGY BENNETT ~,,~:~: ~tncn0ra[t~' - ATO-i 529 · TRAN$ ~ 88.0,-_ 6 ~ AF'F'ROVED D I ,~TR :[ BI.I T T. ON CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ~CH CAMCO CAMCO CAMCO CAMCO ATLA~ CAMCO CAMCO CAM~O CAMCO CAMCO CAMCO WA:[ ATLAS ~ CENTRAl_. F:[ I._ES ~- F'H :[ I...I._ I P,~ '"' CHEVRON PB WELL I) ,& M R ,..N I) ~ EXTENSION EXF'LORATI ON $~ ,?AF'C ~ EXXON ~ STATE OF HARA ]"NON '"w TEXACO II. -,,- MOBIl... F I L. IF ,'~ A I...A.~ K A STATE OF ALASKA .... ALA,.,.~A OIL AND GAS CONSERVATION CCi .ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other Stimulate [] Plugging [] Perforate [] Pull tubing WORKOVER 2. Name of Operator ARCO Alaska, In~;, 3. Address P.O. Box 100360 Anchora~e~ AK 99510-0360 4. Location of well at surface 170' FSL, 697' FEL, Sec. 2, TION, R15E, UM At top of productive interval 1145' FNL, 1272' FEL, Sec.12, TION, R15E, UM At effective depth 1269' FNL, 1055' FEL, Sec.12, TION, R15E, UM At total depth 1308' FNL~ 986' FEL~ Sec.12~ TION~ R15E~ UM 11. Present well condition summary Total depth: measured 11199'MD true vertical 9216'TVD 5. Datum elevation (DF or KB) RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 9-2 8. Approval number 7-%64 9. APl number 50-- 10. Pool Prudhoe Bay 0il Pool feet Plugs (measured) None feet Feet Effective depth: measured 11072 'MD true vertical 9118'TVD feet Junk (measured) None feet Casing Length Size Conductor 85 ' 20" Surface 2696' 13-3/8" Production 9179' 9-5/8" Cemented Measured depth 250 sx Arcticset 85'MD 4350 sx Arcticset 2726 'MD 1050 sx Class G & 11153'MD 115 sx Arcticset ~ueVertical depth 85'TVD 2726'TVD 9209'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 7"/5-1/2", L-80, tbg w/tail ~ 10544' Packers and SSSV (type and measured depth) 3-H pkr @ 10434' & Bal-O SSSV ~ 2186' 12. Stimulation or cement squeeze summary Intervals treated (measured) All perforations Treatment description including volumes used and final pressure 700 ~lal 10% HC1 & 225 sx Class G 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) 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 Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/7 Submit in Duplicat~/ 10/09/87 10/10/87 thru 10/12/87 10/13/87 Title :-~: North. Slope-Borough IStat, Alaska ell no. ADL.-~28327 9-2 W/O Recompletion ~da~ m~o~ed API 50-029-20198 . - -' 1Amos w.,. l Hour Prior status If a W.O. I0/6/87 0900 Hrs, 21.66% 153' - Bullhead' sq. sea w~r @ 0900 hre,. 10/06/87. A~C ~o kill perf well f/10,264'-10,270'. Att to 9-$J8" @ 11,153' ~11,006' Fill, Circ crude f/tbg 8.5 ppg sea wtr Bullhead sqz dn 5½" tbg; monitor well. ND tree. NU & tat BOPg. RIH w/spear, pull hgr to flr. Well out of balance. Circ crude dn 5½" tbg. 9-5/8" @ 11,153' i1,006' PBTD, POH w/mill 8.5 ppg sea wtr Circ, POH w/5½" tbg. RIH w/spear, spear fsh @ 410', pull; tbg parted, POH w/fsh. RIH w/5½" wrk string & OS. RU DA; unable to get into fsh @ 475' WLM, RD DA, POH w/wrk string. RIH w/4-3/4" mill on 3½" DP, mill on fsh @ 474', POH. RIH w/spear; rec'd some contrl in. RIH w/spear, POH; no rec'y. RIH w/4-3/4" mill. 9-5/8" @ 11,153' 11,006' Fill, 11,072' PBTD, POH w/fsh 8.5 ppg sea wtr Mill @ 475', POH. RIH w/4" tapered mill, mill to 480', POH. RIH w/5½" OS, latch fsh @ 475'. RU DA, cut tbg @ 10,200' & 2220', POH, RD DA. POH w/5½" tbg & 5½" tbg fsh. RIH w/OS, mill over fsh @ 2215'. latch fsh, CBU, pull 10 stds, monitor fluid loss. M&P HEC pill, POH w/5½" tbg fsh & PBR stinger. PU OS, RIH, tag fsh @ 10,310', wrk over fsh, CBU, POH; no rec'y. Redress OS w/6-1/8" grapple, RIH, wrk over fsh @ 10,310', rotate out of pkr, circ, POH w/fsh. (Accum fluid loss = 3679 bbls). 9-5/8" @ 11,153' 11,006' Fill, 11,072' PBTD, POH w/8½" shoe 8.5 ppg sea wtr POH; no rec'y. MU wsh pipe, RIH, tag TOF @ 10,310', wsh & rm to 10,392' (top of pkr). Mill'pkr f/10,392'-10,395', POH. The above is cor~tL For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. i I Title Date 0/29/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Inatructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District I County or Parish Alaska North Slope Borough I Lease or Unit Prudhoe Bay ADL #28327 Complete record for each day while drilling or workover in progress Field Date and depth as of 8:00 a.m. The above is correct 10/14/87 10/15/87 10/16/87 10/17/87 thru 10/19/87 10/20/87 State 9-5/8" @ 11,153' 11,006' Fill, 11,072' PBTD, Tst BOPE 8.5 ppg sea wtr POH w/wsh pipe. RIH w/wsh pipe, mill over pkr @ 10,395' gas bubble, POH, LD wsh pipe. Tst BOPE. · Circ 9-5/8" @ 11,153' 11,035;, Wsh fill 8.5 ppg sea wtr Tst BOPE. RIH w/OS, engage fsh @ 10,826', POOH, LD PBR/pkr & tailpipe. TIH w/BHA, tag fill @ 11,010', wsh & drl to 11,033' Alaska 9-5/8" @ 11,153' 11,048;, TIH w/RTTS 8.5 ppg sea wtr Drl to 11,048', short trip to 10,638'. RU DA, rn GR/CCL + 10' perf gun, shoot 1SPF, 120° phasing f/10,730'-10,720' & 10,684'-10,674', RD DA. PU RTTS & set @ 2700'. 9-5/8" @ 11,153' 11,048' WLM PBTD, Prep to rn .tbg 8.5 ppg sea wtr TIH to 10,592', set RTTS, tst to 2500 psi, POH. TIH, wsh 10,749'-10,965', pmp 700 gal 10% HC1 across perfs, rev~'out, POH to 10,593'. Est IR @ 3 BPM, 700 psi. TIH to 11,048', pmp 225 sx C1 "G", POH to 9870' & sqz w/final psi of 1000. Bled off, POH, LD 2-7/8" tbg. TIH w/BHA, drl to 11,048' & pmp 2 sweeps during drlg. Displ w/cln sea wtr. Tst perfs to 1000 psi; good. POH, LD DP. RU DA, PU FB-1 pkr, RIH; stopped @ 5420', POH, RD DA. Chg rams & prep to rn 3-H pkr on tbg. 9-5/8" @ 11,153' 11,048' WLM PBTD, NU tree Well no. 9-2 W/O 8.5 ppg sea wtr Chg rams & tst. NU tree. Rn~180 jts, 5½", 17#,,L-80 LTC tbg. ND BOPE. For form~reparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 Date 10/29/8tTM ~ ~:.',~'> Drilling Supervisor and-Gas Company Daily Well History-Final Report Iltatructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Fhtel Report" should be submitted also when ol3erations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State Alaska I :' North Slope Borough Alaska Field Ikease orUnit I Well no. Prudhoe Bay ADL #28327 9-2 W/O Auth. or W.O. no. ~Title A81657 Cap/AS1649 Exp I Recompletion Pool #102 Operator I A.R.Co. W.I. I ARCO Alaska, Inc. I 21.66% Spudded or W.O. begun ~Date Hour Workover [ 10/6/87 Date and depth Complete record for each day reported as of 8:00 a.m. 10/21/87 AP1 50-029-20198 rTotal number of wells (active or inactive) on this cost center prior to plugging and abandonment of this well Prior status if a W.O. 0900 Hrs. . 9-5/8" @ 11,153' 11,048' WLM PBTD, RR 8.5 ppg Diesel NU & tst tree to 5000 psi. Displ well w/diesel. Set pkr. Tst tbg to 3000 psi; leaked to 2400 psi w/no increase on csg. Press ann to 2500 psi f/30 min; OK. Set BPV. RR @ 2100 hrs, 10/20/87. Old TD New TD PB Depth 11,048 ' Released rig Date K nd of rig 2100 Hrs. 10/20/87 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil [Single Producing method I Official reservoir name(s) Flowing ] Sadlerochit Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P, i C.P. Water % GOR Gravity Allowable Effective date corrected For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARC. fl Ala.~ka, Thc. Anchorage, A la..~ka 995'1 ~ DATE: tt-9-87 REFERENCE: ARCO Cased HoLe Final. t-3 9-5-87 t-7 8-22-87 CoLLar t-tt 7-tt-87 CoLlar t-t2 7-tt-87 CoLLar 1-2¢ 7-tj-87 Co[Jar 2-t2 7-22-87 CoLLar 4-22 7-24-B7 Collar 5-4 8-2t-87 fiol. l. ar 5-t3 7-26-87 Collar 5-t7 9-23-87 Vertit 6-7 7-t2-87 Collar 7-tt 7-t0-87 Col. l.a~ 9-2 1 0-t 5-87 Co tlar 9-34 8-2t -87 Co I. I. ar I t-26 7-3t -87 t t-27 6-22-87 Co t I. ar t t-27 7-3t-87 Co Ilar t2-t5 7-t0-97 ColLar t 2-4 5 9-~-87 Co I. I.~r t ~-t 8-~t -87 Co t 3-t 0 9-3-87 Co I. I. ar t~-t4 8-$7-~7 Collar (Perforation Io9) (Perforati,o~ I..o~) (Perforaft.n (Perforation [.o~) (Perforation l..o~) (Perforatio~ Log) (Perforation Log) (Perforation Log) ocj (Per foraf ion (Perforaf. ion Log) (Per rorer i~n (F'erforatim') l.og) (Per forat ion l..ocj) (Perforation L..o~) (Perforation l_og) (Perfora~.ioH [.09) (Pet-rotation Log) (Perforation Log) (Perforation Log) Ptea.~e sign and return the a_~.%a~-.bed copy a.~ receip ~ ~' ...... Anchorage TRAN$ ~87606 ~ Approved. DIXTRIBLITION Run Run Run Run Run Rttn R.n Rt~n Run Rtl~ Run Run R.n Run Run RI.tn ~ of Atlas At Lag At la.~ Atlas At la..~ At ta..~ At la..~ At I. as At In..~ At' I.a~ At l'a.~ AtLas At la.~ At la.~ At I.a~ At[ag Atla~ Af I~.~ A~ I.a~ Central. Fil. e~ Chevron D&M Extension Exploration Exxon M~rathon Mobil. Phi I. I. i p..w F'B Well Ft le.~ SAPC State of. AI. aska Texaco ~-' ~" STATE OF ALASKA ...... ' ALASKA OIL AND GAS CONSERVATION L, oMMISSION V~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Opera~or 7. Permit Number ARCO Alaska, Inc, 76-16 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20198 4. Location of well at surface 9. Unit or Lease Name 170' FSL, 697' FEL, Sec. 2, T10N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1145' FNL, 1272' FEL, Sec.12, T10N, R15E, UM 9-2 At Total Depth 11. Field and Pool 1308' FNL, 986' FEL, Sec.12, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 54' I ADL 28327 12. DateSpudded 13. DateT.D. Reached 14. DateComp.,Susp. orAband. I I ]15'WaterDepth'if°ffsh°re 116iN°'°fC°mplet'°ns 02/16/76 03'/09/76 03/20/76W N/A feet MSL . 17. Total Depth {MD+TVDt 18.PlugBack Depth {MD+T'VDI 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost ll199'MD, 9216'TVD l1072'MD, 9118'TVD YES ~ NO [] 2186' feet MD . 1900' (approx) 22. Type Electric or Othe~ Logs Run DIL, BHC, GR, FDC/CNL, GR/CBL, GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 85' 32" 250 sx Arcti cset cmt ,,. 13-3/8" 72.0# MN-80 Surf 2726' 17-1/2" 4350 sx Arcticset cmt 9-5/8" 47.0# MI-80/Soo-95 Surf 11153' 12-1/4" 1050 sx Class G & 115 s: Arcticset 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 7"/5-1/2" 10544 ' 10434 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Perfs f/10749'-10948 700 gal 10% HCl (10/20/87). Perfs f/10749'-10948 225 sx Class G (10/20/87) 27. PRODUCTION TEST .... Date First Production Method of Operation (Flowing, gas lift, etc.) July, 1977 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 10/1/77 4.0 TEST PERIOD II~ 1874.3 1614.6 0 1° 33/64I 861 (corr) Flow Tubing Casing Pressure CALCULATED .~ OIL-BBL GAS-MCF __~,~%~,~- WATER-BBL OIL GRAVITY-APl Press.1342 0 24-HOUR RATEI~ 11246 9688 0 27.0 . ~ ¢~,~,~ 28. CORE DATA ~,~.'f~ ~ BriefNonedeScription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. --~,~,.}.~ ,,,~. t.' ~ ¢~%~[~t\C~,, ~Note: Perforated well 5/4/77. Workover performed & perforations squeezed 10/20/87. ' ' WC3/~5:DANI Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit Base Sadlerochi t MEAS. DEPTH 10674 ' 31. LIST OF ATTACHMENTS None 11062 ' TRUE VERT. DEPTH 8807 ' 9110' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed r~ ~]~.?' .~''//-/A..___ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, In- Prudhoe B=x ~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 9-2 Permit No. 76-16 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve detailing work to be DFS/PVL/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 9-2)W1-3 RECEIVED Oil & Gas Cons. Commiss!~';: WELLS2/38 ARCO Alaska, Inc. is a Subsidiery of AtlanticRichfieldCompany AR3B 6132-C STATE OF ALASKA ALA._ .A OIL AND GAS CONSERVATION COk ,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing Time extension [] Change approved program [] Plugging [] Stimulate ~Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator AR ~(l A 1 ~ .~ k~: Tn r 3. Address P.O. Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 170' FSL, 697' FEL, Sec. 2 TiON, RI5E, UM At top of productive interval ' 1145' FNL, 1272' FEL, Sec. 12, Ti0N, Ri5E, UM At effective depth 1269' FNL, 1055' FEL, Sec. 12, T10N, R15E, UM At total depth 1308' FNL~ 986' FEL~ Sec. 12~ T10N~ R15E~ UM 11. Present well condition summary Total depth: measured 11199 feet true vertical 9216 feet Plugs (measured) 5. Datum elevation (DF or KB) 54' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 9-2 feet 8. Permit number 76-16 9. APl number 50-- 029-20198 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 11072 true vertical 9118 Casing Length Size Conductor 85 ' 20" Surface 2696 ' 13-3/8" Production 9179 ' 9-5/8" feet feet Junk (measured) Cemented Measured depth 250 Sx Arcticset 85' 4350 Sx Arcticset 2726' 1050 Sx C1 G & 11153' 115 Sx Arcticset True Vertical depth 85' 2726' 9209' Perforation depth: meas~r~74_10730, 10896-10906'; 10940-10948'; 10962-10972' true vertical 8767-8817'; 8893-8932'; 9042-9048'; 9060-9068' ~bing(size, grade and measured depth) ; 1749-10799'; 10817-10841'; 10856-10866'; 10872-10886'; 8946-8965'; 8977-8984'; 8989-9000'; 9008-9016 RECEIVED 5½", 17#, MN-80 LTC AB-MOD @ 10585' MD Packers and SSSV (type and measured depth) 9-5/8" Baker SAB Packer 0 10436' MD,-. 5-1/2" Otis RQY SSSV n~p~,.t~, i~'~22~;',,/MD 12.Attachments Description summary of proposal ~_ Detailed operations program ~m BOP sketch [] :,~...:~,,..-, 0il & Gas Cons. C0mmissi.,,$L: 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby/-certify that the~oregoing is true and correct to the best of my knowledge Signed ,¢~¢~¢,¢~ _.,~ ,~.~¢_.~ Title Operations Engineering Manager Commission Use Only Conditions of approval Approved by ~/, ~/~ Form 10-403 Rev 12-1-85 WELL S / 38 Date /¢,~1~'~. ... so representative may witness ] Approval Notify[] Plug commission integrity ~ BOP Test ~ Location clearanceI No. -'~-" 27 ~¢ P. V. Lantero, 263-4312 by order of ¢ the commission Date ~¢//,o/~~ Submit in triplicate Drill Site 9-2 Procedure o , , . . , . Obtain a valid well test. Contact the Drill Site Engineer concerning any questions about well test. Load 50 bbls. of filtered fresh water (150°F minimum) for blending the EDTA. Load 126 bbls. of filtered 2% NaCI water for blending the scale inhibitor. Flush pumper with 2 bbls. of filtered fresh water. Mix the remaining 2000 gals. (48 bbls.) of filtered fresh water with 1550 lbs. of Na2EDTA and check pH, iron content, and EDT^ content. Flush pumper with 2 bbls. of filtered fresh water and mix the following blend: 1500 gals Exxon 'Corexit 1694' 8600 gals of 2% NaCI water 40 gals of surfactant MIRU pump trucks and transports. Pump the following fluids: A. 48 bbls. of EDTA with additives B. 238 bbls. of scale inhibitor blend NOTE: - Add 10 gals. of liquid diverter per 10 bbls. of scale inhibitor blend into displacement tanks to pump trucks. (6 lb resin/foot of interval). - All fluids should be filtered to 2 microns on suction C. 1300 bbls 2% NH4CI water D. 250 bbls. of dead crude E. 5 bbls. of diesel 10. Shut in well for 12 hrs. RD and release equipment. 11. Obtain a valid well test. RE,CEI¥'EI) Oil & Gas Cor~s. Commissi~; ARCO Alaska, In Prudhoe Bay ~-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 29, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-2 Permit Number: 76-16 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, a. F. $cheve DFS/sd Enclosures cc: Standard Alaska Production Co. JoAnn Gruber, ATO 1478 File PI(DS9-2)W1-3 Gas Oons. CommJssjo~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B - 6132-C cc' M. R. Miller, ATO 1580 B. J. Nye, ATO 1584 0~'" ..... 2 ':.,, Oil & Gas Cons. Anchorage STATE OF ALASKA --' ALA,. ,A OIL AND GAS CONSERVATION COl, ,~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of.Request: Abandon [] Suspend E3, Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate'~ Other ' 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchoraqe, AK 9951_0 4. Location of well at surface 170'FSL, 697'FEL, Sec. 2 TION, R15E, UM At top of productive interval ' 1145'FNL, 1272'FEL, Sec. 12, TION, R15E, UM At effective depth 1269'FNL, 1055'FEL, Sec. 12, TION, R15E, UM At total depth 1308'FNL~ 986'FEL~ Sec. 12, T10N~ R15E, UM 11. Present well condition summary Total depth: measured 11199 feet true vertical 9216 feet Plugs (measured) 5. Datum elevation (DF or KB) 54' RKB feet 6. Unit or Property name Prudh0e Bay Unit 7. Well number 9-2 8. Permit number 76-16 9. APl number 5O-- 029-20198 10. Pool Prudhoe Bay 0il Pool Effective depth: measured 11072 feet true vertical 9118 feet Casing Length Size Junk(measured) Cemented Measured depth True Vertical depth Conductor 85 Surface __ 2696 Production 9179 20" 250 sx Arcticset 85' 85' 13-3/8" 4350 sx Arcticset 2726' 2726' 9-5/8" 1050 sx Class G & 11153' 9209' 115 sx Arcticset Perforation depth: measured 10749-10799' 10817-10841' 10856 10866' 10872-10886' 10896-10906' 10940-10948' true vertical 8893-8932' 8946-8965' 8977-8984' 9008-9016' 9042-9048' Tubing (size, grade and measured depth) 7" 26# L-80 LTC Hod to &897' 5½" 17# L-80 LTC Hod to 10544' Packers and SSSV (type and measured depth) 9-5/8" Brown 3-H pkr @ 10434'; 7" Camco Bal-O SSSV Nipple @ 2186' 12.Attachments , 8989-9000, ~ ~ "; ":-~: ii;':'"' ? r,,!.;~?:~ [ii[ ~ ~as Co~s, ' ..... Description summary of proposal ~ Detailed operations program ,~ 'l~'~)'~)"'sketch~t~0~'ag9 13. Estimated date for commencing operation October, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~certify th~at the foregoing is true and correct to the best of my knowledge Signed~¢~'/~~~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity D BOP Test D Location clearance Approved Co~V ,%~urned Approved by Form 10-403 Rev 12-1-85 STAT17/9-2 Approval No. Commissioner by order of the commission Date ?d '~.~ ~0~ Submit in triplicate ~ ARCO Alaska, Inc. proposes to add perforations in DS 9-2 for a selected interval within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operations. Proposed Perforation Interval' 10962-10972'MD (10) Ref' BHCS 3/10/76 Anchorage STATE OF ALASKA .... AL/-,._.,A OIL AND GAS CONSERVATION CO~ .,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~'~ Time extension .~ Change approved program [] Plugging ~ Stimulate © Pull tubing,~ Amend order ~ Perforate ~ Other,~ of Operator 5. Datum elevation (DF or KB) 2. Name ARCO A~aska, Inc RKB 54' feet 6. Unit or Property name / 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit 4. Location of well at surface 7. Well number 9-2 170' FSL, 697' FEL, Sec. 2, TION, ELSE, UH At top of productive interval 8. Permit number 1145' FNL, 1272' FEL, Sec.12, TION, R15E, UN 76-16 At effective depth 9. APl number 1269' FNL, 1055' FEL, Sec.12, TION, R15E, UM 50-- 0~-20198 At total depth 10. Pool 1~08' FNL, 986~ FEL, Sec.12, T10N, R15E, UN Prudhoe Ba~/ Oil Pool 11. Present well condition summary Total depth: measured 111 99 ' MD feet Plugs (measured) N o n e true vertical 921 6 ' TVD feet Effective depth: measured I 1 072 ' MD feet Junk (measured) None true vertical feet 91 1 8 ' TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 85' 20" 250 sx Arcticset 85'MD 85'TVD Surface 2696' 1~-3/8" 4350 sx Arcticset 2726'MD 2726'TVD Production 9179' 9-5/8" 1050 sx Class G & 1115:~'MD 9209'TVD 115 sx Arcticset Perforation depth: measured 10749'-10799', 10817'-10841', 10856'-10866', 10872'-10886', 10896'-10906', 10940'-10948' true vertical 8893 ' -8932 ' , 8946 ' -8965 ' , 8977 ' -8984 ' , 8989 ' -9000 ' 9008'-9016', 9042'-9048' Tubing (size, grade and measured depth) 5-1/2" 17# MN-80 LTC AB-MOD ~ 10585'MD Packers and SSSV (type and measured depth) 9-5/8" Baker SAB pkr (~ 10424'_: 5-1/2" Otis "RO" R.c;.~\/ ~ppl,~ _~ 12.Attachments Description summary of proposal ~i[ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved ?"¢..,:- ;' " Name of approver Ai.i¢:~ ....... ,.,,o Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S i g n e~ "?"~ ~,, ,~~~_.~., ~ ~ ~;, (~:R~,~¢,~ TitleAssoci ate Enqi near Date ~//'P/Z3 7 .... /'"~ ~ Commission Use Only ( LWK ) 5A2/85 Conditions of approval Notify commission so representative.may witness I ApproYal No. ?~ [] Plug integrity [] BOP Test [] Location clearance ~ ~,ox~ t~e~,~~"~,¢-~ ~'L.._ " ' ' ' -. ~ by order of ,.-. Approved by " " Commissioner the commission Date ~,'~%.~/-~z'~ Form 10-403 Rev 12-1-85 Submit in triplicat~. DS 9-2 WORKOVER PROCEDURE SUMMARY 1) Load the well with seawater. 2) MIRU WW1. Set BPV. ND tree, NU and test BOPE. Spear tubing below the hanger and retrieve the top 408' of 5-1/2" tubing. A 6/21/87 IB showed parted tubing. 3) RIH with an overshot and latch onto stub. Shoot circulation charges above the PRB. Shoot squeeze perforations as required between 10674' and 10730'. Pump a 50 bbl Bridgesal (not Litesal) kill pill, and displace the annulus to weighted brine or seawater. 4) POOH with tubing and PBR stinger. 5) RIH and latch PBR barrel. Rotate out of K-anchor and POOH with fish. 6) RIH and mill SAB packer. assembly. CBU. POOH and lay down packer/tailpipe 7) RIH with bit and scraper, chasing junk and scale to 11000'. CBU above perfs. 8) PU a 9-5/8" RTTS and TIH to 10600'. Test 9-5/8" casing to 2200 psi. 9) TOH and pick up 500' of stinger with a blinded jetting nozzle. 10) TIH to 10950'. Jet the kill pill out of the perforations (10948'- 10749') by pumping seawater at the maximum rate possible. Reciprocate each joint several times before laying it down and working uphole to the next set of perforations. 11) After CBU, shut the rams and establish injection below a 0.62 psi/ft frac gradient. This would equate to a maximum surface pressure of 1600 psi with a full column of 8.5 ppg seawater. If injection at several bpm cannot be established below frac gradient, rewash the perforations. Weight the workover brine so that the well is several hundred psi overbalanced. 12) TIH to 11000' With rams open, pump 30 bbls of 100 cc/30 min fluid loss, Class G ~nd displace with weighted brine. 13) Sting out of the balanced plug several hundred feet. Pump several bbls of brine to ensure tubing is clear of cement. Shut the rams and squeeze for i hour with the equivalent of a 0.62 psi/ft gradient. 14) Slowly release the pressure and TOH keeping the hole full and over- balanced. WOC. 15) TIH with bit and cleanout to original PBTD at 11072'~: GDH/O49a DS 9-2 WORKOVER PROCEDURE SUMMARY (cont'd) 16) PU new completion assembly consisting of: o 5-1/2", 17#, L-80 tailpipe with a 5-1/2" Otis "XN" nipple. ° 9-5/8" x 5-1/2" permanent packer with seal assembly. o 5-1/2", 17#, L-80, LTC-MOD, IPC tubing with GLM's from the packer to 2900'. Class B tubing may be used to within 2 joints of the lowest live valve. ° 7", 26#, L-80, LTC-MOD, IPC tubing from 2900' to surface with a 7" Camco SSSV at 2200'. o 7" FMC tubing hanger. 17) Land tubing. Set BPV. ND BOPE. NU tree and test. Displace packer fluid. Drop ball and set packer. Test tubing and annulus. Shear out catcher sub. 18) Release rig. Reperforate with limited shot density. 7-29-87 ~ 000 P, I BOP , TACK, ANNULAR PREVENTER 6 PIPE RAHS 5 BLIND RAHS TUBIN6 HEAD . , . , 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 11 4. 13-5/8" - 5000 PSI BLIND RAMS t2 5. 13-5/8" - 5000 PSt PIPE RAMS 13 6 13-5/8"-5000~SI ANNULAR: ~. .... !:14 ACCUMUI ATOR CAPACITY TEST 1 . CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT iS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 2500 PSi AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PiPE RAMS, INCREASE PRESSURE TO 5000 PSi AND HOLD FOR 10 MINUTES, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES. IF ANY. 'WITH 5000 PS1 UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTPEAM. BLEED SYSTEM TO ZERO PSI, OPEN PiPE RAMS. BAC,~.OFF ~.UNNIN6 JT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR !0 MINUTES. BLEED TO ZERO PSI, OPEN BLIND RAMS AND RECOVER TEST PLUB, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES APE SET IN THE DRILLING POSITION, TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. S!GN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. JG NOVEMBER-21 , 1986 AR.m-~ AL~skm Inc Anchorage, ALaska pCCERENP~- ARR..'-! P;-p-=.----.,._~re )}a±a : '...-'... t~-.- ~- ............... ~ -:,.. .-.: ~:. ..,, "." ~ f4 ' ..:,- ,....:. ~-~ 6-S6 (.'.; r e'n +.. "--- 3-31 ~'~-6-86 "' ~: ..:'~ *: ic ,'.]'r a d i er.,*,. ~3-32 4-9-86 £i-a !' i c C-tad i e'n't' ~ 3-33 -,'"-2'i - 8,-'", .--71 ~ t ~ c:..'.":r a d. i e'~':.. '"': ~ ~-~" 4-i 6-S6 :- i. ~-~- · G-.,- ,..., ..Z.-q- : IC au ....... "--- 4 - '"'- - -? _,-,'~ - o 4 - S 6~ ~ £."t 3 + ~ c..G '.-..- a ~ i ~ r,. t-_ . ~4-D 4-£4-86 ,~?-b.~ I' J cit, r.-':,4 i.-=,~'", '~- ,*-~ ..4 4 "'-' '-: ~' ~-:~ ~ "' -' ..: .; -' c, ct, :. ~ ,, i C L,-. i- .-.Eid i · .? .,_, '~:e_., Sta + Gr '~ ' ~ ~D_ ~., .4 _'-., £ _C.) ' . ~' :.-. . -~ .:.,.., ,_,o f;.-!:.a+ i c ~_,r.-.--~d i e'n* ._ ~' -':.'-,: 4-2'-:':--86 :'--:i-a1'. ~c bt-ad ~' ~_: ~ . ---i ~-~(::: ~'-";:'-P'/" ~+ ~' '-'~- ' ~ ~i 4-i i 4-'..-'-u.::, 5:±,a t i c G'.--a" ....... . u . '~ 4-29 ~'- 4 _:. : ~:-S6 F '~ owing brad ~ e;-~--". ~-.-.- z_,, 4-2e,-86 :".':.at i c ,'_-.;;-ad :: i. :...~ -? · ~i6-13 4-26-8,4 ~:'ta",:ic Gradie'nt .-. . -"i -.?-5 4-2-'-' -° z '"~' "'~: ..ad ..... ;, :..,;, ... ,..~ ,. , ~ L.i" ; ~_::. : :~) ...'~ ,'.'. C .'F..~ C .a ~'~", C c} C a ,i c c, ~: a i','~ c c) C ..'.4 f,iC C, C .-'-, i'll (7. '.7) C: -.5 f~i C 0 C a hie 0 Ca mc o Ca f~iC 0 Ca i~ic o Ca mc o (.:a i'¢~c o Ca mc o Ca ~c. o G a mc o F'l.~a--.= si='.,] a'nd rs~u'~"'n th,= at~.sched' ' copt,-' az. rece p-i: of ..~a,4 ';.'a_. P ..... i ._-..= J g'...-' D ] L: ~ +: l L:' L: T ] 0 N December ll, 1985 Reference: ARCO Cased Hole Einals DS 9-2 11-20-85 Prod Prof/Fluid ID~Spinner Run 1 5" Camco DS 9-5 11-20-85 Spinner/Fluid ID Run 1 5" Camco DS 9-6 11-20-85 Spinner/Fluid Id Run 1 5" Camco DS 9-11 11-21-85 DS 9-13 11-21-85 Spinner/Fluid Id/GR Prod Prof/Fluid Id~Spinner Run 2 5" Camco Run 2 5" Camco Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-I 4 29F Trans # 509 DISTRIBUTION Chevron D&M Exploration Services Extension Exploration Exxon Marathon Mobil ARCO AI.a.'-;ka, Inc. F'~O, Box I003~60 Anchorage, AI.a.s'ka 995~0 DATE· Pt~rch t4 t9°~-i REFF'RENCF2" ARCO Pre.'s':~ure Dat,..-~ g. £',, 9--6 /,,,/ i 0-t 2-84 * D.:9, I 4---;~1 9-20-84 D.£'. t4-Si 1 '~ ' q ~..--,~i 0--,. 4 D~$. i6-4~/' '2-8-85 ~ D.$. i6-t6,/' 9-t2-84 West Bay 5,'t:at;e CDBR CDBR I::'re.s.sure Bui Ld-up Homer PI. otx w/I. is't.'ing F:'Lowing P;"es'.sure & Gradient: F're.s.sure FaLL Off "~-13-85 .?t'a'~ i c: :gurvey .,4. . G 0 ,~c h ~;' ur v e y.~; Li. 0 DA copy as rece i p t- o'f' TRAN£. -.-04_> da 'l'a . D 13'TR I BUT ]: ON Ch evY on Exp I. orm¢ Jori ,~ervice.s Ext'en~ion E'xpLora¢Jon Exxon Mara'thon Mobi L Mobil. E & P Phi L L PI-ud'hoe Bay Weir $oh i o State of ALaska Texaco Fi /.e~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 995'10 Telephone 907 276 1215 Date: February 28. 1985 Reference: ARCO Pressure Data ~972-~i!~qP, ressure Survey 15-17 Pressure Survey 14-9B Pressure Survey 11-30-84 GO 1-25-85 GO 10-28-84 Otis ~eceipt of data° Received by Pam Lambert ATO 1429C Trans# '.~5--~ Anchorage Chevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco A- (:) ...... i -:::, 2 '!:-:: F:' C h e v r o r., :() & ?i ':' '.' + i o ,? e r,, i ... e.'.-':.- E...:, p L (::, r a . n .... "' Iii: x t' e n ~: i c,'n E x p I. o r a t i o'n E x x o I] G e -I.- .I.- y i".'i .:':i )" .:':i 'J' ~ .......... · Iii] F; i ;"~a L s' Chevron Mol:, i L ,..."'"' & i"i i"i (:.', l::, i t.,...'::' ,..,:::: F:' Exp Lora 't i c,n ,~r-',rv i ce.'.=,' F'h i t. !. E x t e n s' i o n E x p L o r a ± i o n F"~" u. d h ,::.', e !(': a '::..-' i..,J e I. I. E x x o n t::.: ,!!,. i) 6e -I: 't y 2oh i o l'iar?:'~*h,"',n, .... State of ALa.sl<a ARC[) Alaska ~:'-'~ O~ Box Anchorage: A[as'ka DATF..'- l)pcemk.',er 2t , q .-.,~!!','~ f.-Ic', L e F'in a 1.-.=: ... ¢., .., [,F' .',/5:F:' i 'nrter C F S/j.",' p i 'ri'net D i f f T e mr.:, k_,:::, g i.':, i f 'i" T e m p C':F:'S? Sp i r~ner C,F:'S/S F~ inner '." I /:/ .'Y' .-'f" '~ :rx/ I'I,':. ,-' ~.~F', ,S"p i'nne'r Log f" i', t / ~.4 t"' I-.' I ~, / Il&,;-;' ":; I / i'-.:; C" .; ' [.-l'~.." , ,,;:-/ Ghk &-"r-:' i'nr~e'.,- Locj C.N/MS/GR Sp inr~er L_c:,cj ,?r" i'nner Log T · ¢,p i l'ii'i£.-'i- ~. 'n j F:' r c, f i L e/,::. Z'-;' F' i 'n n e r / ]" e m p ,,':' i n .j F' r o 'f" i L e Zi; F..~ i 'n n e ~ / ~ e mr.:, / I 'n J F' r c:, 'f" i L e i n i F' r o -r- i 1. e / ;!-:." i::' i 'n 'ne r /'i" ,.'.:-:, m ,5;p i 'ri'net L. c:,g I n i j::' r o f i L e/,S' F' i 'n 'ne r ,-"" 'T e m u.l" ,:':../',? F-:' I 'rtl'tel" D i 'I" 'f" 'f' e m p L o ,.:j .4.,. h e a 4.: -i.- 8 C: h e d (:: o F:' Y a z.: T r.:, ..... c ,:.':, i F-' .4. (; 0 i} (.'.;. [) C.O (;-0 !) f-:~ C ,"'a fn C. 0 }::) A .U C a'l fi'i C C) !) A C a iff C: el, C a ffi (: o C .am c: o C: i:i fii c: (3 C .F.i m C: 0 C a m c: c.', C]: .:'i~ m c (:': t..'t L., R'ece i red By .... HAVE: A HAF'PY NEW Y' E A !:;.'.~ I<eLt. y NcFar [and A i" 0-" 1 4 2 9 F' TRANS .... "' :. ~r ::';i- :i 'Y Ch ev1- Ol'l D & f'i ["'xp i. ol'a4,.'ioi] Services: ["' x 't' e n s i o'n ["' x p t. c:, r a t' i o r, Ex×on ARCO Alaska, In( Prudhoe Ba~, '"ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regiona. l Operations Engineer March 19, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 Permit No. 75-76 DS 9-12 DS 9-2 Permit No. 76-16 DS 9-13 DS 9-3 Permit No. 76-35 DS 9-14 DS 9-4 Permit No. 76-40 DS 9-15 DS 9-5 Permit No. 76-47 DS 9-16 DS 9-6 Permit No. 76-48 DS 9-17 DS 9-7 Permit No. 76-58 DS 9-18 DS 9-8 Permit No~ 76-70 DS 9-19 DS 9-11 Permit No. 76-84 DS 9-20 Permit No. 77-7 Permit No. 77-8 Permit No. 77-25 Permit No. 77-36 Permit No. 77-37 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File PI(DS as above)W1-3 ARCO Alaska. Inc. is a Subsidiary of AtlantlcRIchfleldCompsny ~.. STATE OF ALASKA ~ ALASK ')IL AND GAS CONSERVATIONL MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2.'Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-16 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20198 OTHER [] 4. Location of Well 170'N & 697'W of SE cr Sec. 2, T10N, R15E, UM 1145'S & 1272'W of NE cr Sec. 12, T10N, R15E, UM 1308'S & 986'W of NE cr Sec. 12,. T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. 54' RKB I ADL 28327 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-2 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 add perforations on DS 9-2 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10674-10680' MD 10954-10972' MD Ref: BHCS 3/10/76 RECeIVeD UAR 2 2 ]984 Alaska Oll & Gas Cons. Com~iss/oe 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Approved bV Approved Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-I-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and G-~-Company AI,~ ~,~ I~ Pos[ O~fice Box ~r,~.,~.;r...::;e. A!aska 99510 'Te~,~ohene 907:277 5637 May 20, 1980 Reference: ARCO Magnetic Tape D.S. 9-2 1/13/80 Tape #60362 ase sign and return the attached copy as receipt data. ,~: ~ K. J. Sahlstrom North Engineering TRANSMITTAL #326 DISTRIBL~ION North Geology Ex~xon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology Harathon State of Alaska Chevron %RCO C. if an¢l Oas Corr~pan¥ ;.~. :l ,.)ivisio,~ ol AilanbcRichtietdCompany ARCO Oil and Gas-D-ompany , ,"! ~- ' i{ .- ~., February 27, 1980 Reference' Enclosed is a Cased Hole Log for the following ARCO well' '9-2 9/18/78 Differential Temperature Run 1 ~./Please sign and return the attached copy as receipt of data, K. J. Sahlstrom North Engineering TRANS~ITTAL #130 DISTRIBI~FION North Geology ~xxon R & D Mobil Drilling Getty. Eng. ~nager Phillips D & M Sohio ~eolo~, ~larathon State of Alaska Qzevron Re fo z'cncc' }ir~ciosc.J afc Cased tlole l.ogs £or thc' £ol.]owing D.S. 3-!2 12/119/79 CCL ~ Por_F. Record Run 1 I3.5. 5-13 12/17/79 CCL Nun 1 ~,,-'"" Please sign and return the attaC]~cd copy as receipt of data. 2 f~ 5" (same 'l. og) [-II E. J. Sahlstrom ?,iort]~ l"i~gJneerJng AtlaQ~i~i,C~hfi.al6 Corn p a ny No.r~h American Producing Divisior~ North A)as?--'qstrict 'Post Office~ ,300 Anchorage, Alaska 99510 Telephone 907 277 5S37 January 5, 1979 Reference' Enclosed are the following cased hole logs: ~ CCL 9/27/78 ~~5~._~;~; CNL 10/27/78 D~'~S76-Z3 CCL.. 11/07/78 ~DS 9-0 Fluid Density 10/29/78 L/DS 14-2 CCL 10/31/78 ~DS 9-2 Diff. Temp. 10/29/78 ~/DS 9-2 Spinner 10/31/78 v'DS 7-5 CCL 10/12/78 ~-'DS 9-2 Long Spaced CNL 10/29/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering T~NSMITTAL #011 North Oeo].ogy Drilling E,~g. Ma:tager Geology State of Alaska D & M DISTRIBUTION EXXOFI Sohio Mobil Mara thou Phillips Chevron (;.ct t AtlanticRic. hfieldCompany North American Producing Division North Ala~ ....... 'istrict Post Offic~ ,( 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject::DS__~q~k~. Permit No. 75-76 Permit No. 76-16 Permit No. 76-35 DS 9-4 Permit No. 76-40 DS 9-5 Permit No. 76-47 DS 9-6 Permit No. 76-48 DS 9-7 Permit No. 76-58 DS 9-8 Permit No. 76-70 DS 9-9 Permit No. 76-76 DS 9-10 Permit No. 76-82 Dear Sir: Enclosed please find a Completion Report for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB:lr Attachments · SUBMIT IN D1J~'L.~]ATE* STATE OF ALASKA (Se,~othor in- st r[i('t/ons on r e'vel'yt~ sbic) OIL AND GAS CONSERVATION COMMITTEE ii ii i WELk COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 0F WELL: OiI,W~;LL ~ ~ASWELL ~ Va~ ~ Other b. TYPE OF COMPLE~ON: w ~:L~, C,v~ rx B.~CK nESVR. Other ~--~--~- ~ 2, NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. ~ox 360 Anchorage_. Alaska_ Qqq]~ 4. LOC~.T:O~ or WELL (R'~port location clearly and in acc'6rdr~nce with any S-tSte ~-e~-uf;e~ts)* At surface 170'~N & 697'W of SE cr Sec 2, T1ON-R15E, At top prod. interval reported below At total de]'p~t_~~51S ~t 1272'W of NE UM cr Sec 12, T10N-R15E, UM 1308'S & 986'W of NE cr Sec 12, T1ON-R15E, UM 5. API NUML~CAL CODE 50-029-20198 6. LE~E D~iGNATiON ~D SER~L NO. ADL 28327 7, 1F INDIA2g, ALLOTTEE OR TRIBE NAME 8. UNIT,FA~R2VI OR L~ISE NAME Prudhoe Bay Unit 9. W~L NO. DS.-9-2 (31-12-10-15) 10. FIELD AIND POOL OR WILDC-~AT ,, ' l-'ruonoe Prudhoe Bay Field-oi1 Pool 11. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) .. .q~n 1 2.; T1ON-R1 12. PER2VIIT NO, 2-16-76 t 3-9-76 ! 3/20/76 (5/4/77% ! 54' n'KP,, :'~'. "i'OTAL DEPTH, NL~n~?~VD~9. PLUG, BACK M~VD~0. IF IV~ULTIPLE COIVLPL.: J 21. INTERV^LS ~DRII.LEB 11~19~ MD/9216 _L'~1.o72 MD/qllR .J g~n~lo I All P~ODUCIN~ [~RVAL(S), OF ~IS CO~P~TIO~--TO,P, BO~OM, ~A~E (~D AND ~)~ - -- ~23. %VAS D.RECTIONAL .... 20" [_94 ~ -Vat:ac~ 9-5/8" 7 ~-Butl; 26. LINEX 10,750'-10,800' 10,817'-10,841' 10,856'-10,866' 10,872'-10,886' 1Q~..896,.-10~906' Top Sadlerochit 10,674'MD, 8807'TVD Base Sadlerochi~_ 11.062'MDr 9110'TVD 24.TYPE ELECTEIC AND OTHE2~ LOGS RUi[I DIL. BHC, .GR. FDC/CNI, and ~P/CBT,. ~P./C~T. , ~, CASING RECORD (keport all strings set in well) s00- 9 [ -a6I i i: i '. J Y PERFORATIONS OP~ TO PRODU~O~ (tn%crval, size and number) 10,940'-10,948' S UP, VEY MADE ye_= CI~MLNTING RECOtLD I /'~?.,IOUNT PULLED 250 -=× Ar_~ticset cmt.! 4350 1050 115 J27. TUBING RECO[~J) SCi-L]EEN (iX~.D) [SIZE DEPTI:~ SI~]~[' (MD~ ~ PACKER SET (2,fiD) B-I/2 qo.~a~, t 10.436 N/: ._. w/4 s,h. ots per ft. 30 ,-. PRODUCTION ~'~ :"! O. h,: ~ i': ' ': ~'/" DATE FiRS~P I~fiOl.9if~'~ION ! P~P~ODUCT10:N lX{T".I[{OD (Flowh*g, ['.a3 lift, parnp[ng--size and type of pu~p) [V~ ~,:Li;'SqSXYvs', Producing or ':'.... July, 1977 ~) j Flowing ___ I ..... ~-:'~ I Producing ! I ITEST PEiEOD 10~ 4.0 Ile 33/6~ ~' ! 1874,3.,I 161!.6 I ~ O, J 861 ..... ~~CXgI~G PRESSURE ICA~C~T~ OI~BBL. GAS--r~CF. ~' k~--BB . [OIL GnAvITY-~I (CORR,) :~sa J p~-HOUr, ~T~ ~342 ... J 0 ] > 11246 I 9688 I O j .PT_n. ~... ~ ~is~osr~:;os o~ ~,s (so[k; u, ea Y~r yuet, wntea, etc.) ' ],~:s'r w~r~'~ss~ ,~ " t _ Reinj qcted 32. LIST OF ATTACHMENTS 33, I hereby certify that the forego~anCmattachetl, informatlon is complete and correct as determined from all-available records . -- SIONE~~ '~ fff.~".~, Dis t. Dr !g_Zalgl: ~,v~I,: , . . -- · i ii *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given ~n other spaces on this forr-r~ and ~n any attach?:~ents. Items 20, and 22:: If this well is completed for separatc prcduction from r"'ore than one ~nterval zone (multiple completion/, so state ~n item 20. and in item 22 show the c, cJuc,ng interval, or ir'~ter'vals, top(s), bottom(s) and name (s) (if any) for only the interval reported in iter'm 30 Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperateiy produce.J, show- ing the acklitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 54. SUMMAIIY OF PC)}:[MA'I~'ION TESTS I N('L.UI)I N~; I NTEI/VAL TE.qTED. I'ltE.~kSUIIE DATA ~ ~OVEIII~S OF OIL. GAS. 35. G~GIC MARK~ WAT~ AND MUD i ,, T~p Sadler~ch .t 10,674 8807' Base Sad/eroch_~ 11,062 9110' ,",,, ,, , , , ~,~ , , , ~ ,u , , 3fl. COII.E DATA, Aq'I'ACII BRIEF D~CRIPI~ONS OF LITttOLOGY, POROSITY. Ff/AC~H~, APP~ DIPS AND DETECTEI) S}IOWS O~ OIL, G&S O1l WA~I. ,, , North Alaska District Engineering TRANSMITTAL . . · ' ..... "'~:. ' "' -' '. -- _ - .... -"?o~ .~'~. · ':_.. . .... ...-..-z - '- - . . ' ... ''f~-~ '~":' '~ .~ .... -- . ,:. . Transmitted herewith are the following for' the . · Run No.. -. , .. · · . BHC Sonic/Caliper. Log BHC Sonic/Caliper - G~ar~ma Ray Log ' BHC Sonic/Gamma Ray Log Caliper/CCL .' :' Cement Bond L0g/VDL .... Compensated Fomation Density L6g' Compensated Neutron-Formation Density Compensate4 Neutron Log Core Analysis - Interval Core' No, .- Core Description (SWC) - Inten~al Core Description (Cony.) - Core No. DirectiOnal Survey,..- Gyro Sing.l~ Shot -" ' ~ltishot Drill Stem Test'- Test No. -Dual Induction' Laterolog. Formatio~ DenSity Log ' Formation Density Log/Gamma Ray Can~n.a Ray/CCL Laterolog Location Plat .-- ~'Hcrolaterolog - Microlog - ~udlog- Inter~al Sample Log (A.R. C~:') - Intenral · Synergetic Log · TVD-DIL : · TVD-Porosity Log-' .' .. "From' J.A. Rochon/ R. A. I,oRue . . 'r "- 7 ." Well Nmme': .~ ~.. - ! :'-.i -', · . . .... .. - . subj'ect we!l"-' ~ I'X) ~L".P-'g! ~7~' .. Scale' Xerox' Sepia . .. .. BL Line . .- . .. . . : Receipt Ackmo~,_Jlcdged For: -~ ~xlr, l~onovah-Jac!:son Please retm~ receipt to: l-~lmn_ tic Richfield Company · '~orth Alaska Engineering - P. O, Box 360 Anchorage. Alask,q qq ql fl ~[t'ianti~i~ich field Corn pany North American Producing Division Alaska Post Office.. ..x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ~ ..... :' ~ ;" ' January 13,%978 Reference: Dear Gentleman: The ~llowing material is being submitted he~wit]~. Please acknowledge receipt by signing a copy of this letter and returning it to this office. D.S. 9-1 I).S. 9-3 D.S. 9 5 D.S. 9-6 D.So 9-7 D.S. 9-8 D.S. 9-9 D.S. 9-11 D.S. 9-12 Initial Transient Pressure Survex Nov. 14/77 Nov.27/77 Nov. 24/77 Nov.21/77 Nov.18/77 Dec.18/77 Dec,6/77 Dec. 10/77 . Dec.'17/77 Dec.21/77 Initial Static Gradient Pressure Survey D.S. 9-13 Nov.20/77 · D.S. 9-14 Nov.18/77 D.S. 9-16 Nov. 21/77 ~~Truly YourS~i ~ ~ o~ovan 3ackson (/ \ ' North Alaska Dis.t~,~ Engineering CONBi) NTiAL STATE OF DIVISION OF OIL To' North Alaska District Engineering TRANSMITTAL From: J. A. Rochon/D. R. Jackson Date' Jtme 7~. 1977 Well Name' D.S. #9-2 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Conpensated Formation Density Log Corapensated Neutron-Fo~nation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (S;,gC) - Interval Core Description (Cony,) - Core No. Directional Survey - Gyro Single'g-hot 5~ltishot Drill Stem Test - Test No, Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat 5Kcrolaterolog Microlog ~dlog - Interval Sample Log (A.R. C6.') - Interval S~mrgetic Log T~q)-DIL ?¥~-Porosity Log Collar Lo~ 5" Fluid Density 5" Xerox Sepia BL Line ea. J ea. ea. / ea. Receipt Ackmowledged For: Please return receipt to' ic Richfield Company N~th Alaska Engineering ~nager P. O. Box 360 Anchorage, Alaska 99510 #469 Atla~icRichfieldCompany North Amerir. c.~ Producing Division North Ala~ ,strict Post Offic .,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS ~(_ (1.3-12-10-15 ) ~ DS 9-2~1-12-10-15) Dear Sir' Permit No. Permit No. 75-76 76-16 Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned wells. Very' truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure STATE of ALASKA DEPARTMENT OF NATUP~L RESOURCES Division of Oil and Gas Conservation TO: ~--- Thru: FROM: Hoyl e H. Hami 1 ton Director Lonnie C. Smith Chief Petroleum Engineer DATE : May 11, 1977 Harold R. Hawkins Petroleum Inspector SUBJECT: To ~itness Subsurface Safety Valve and Surface Control Safety Valve Tests for Arco DS 9-2 TUe~sday, May 3, 1977 - I went directly to DS 9-2 from DS q~-lO to witness SSSV and SCsV. La-n~y Butner, supervisor for Arco, picked me up and took me to DS 9-2. Lanny Burner said the SSSV was set and control lines were tested to 5000 psi and held OK, The SSS¥ was closed and then opened with 1600 psi on tubing. The SCSV was closed and bled dorm above the valve to ~00 psi from 1600 psi and I observed this pressure for 15 minutes. The SCSV was opened and the SSSV was closed, but did not hold. The SSSV was opened and closed half a dozen times to free any debris that might be in the valve seat. The SSSV was finally closed again and 1600 psi above SSSV was bled down to 500 psi. I observed this pressure for 20 minutes. There was no buildup indicating the SSSV held and did not leak. In su?~nary_: I observed the Subsurface safety valve and surface control safety valve tests with no leakage.. Tests were satisfactory. Attachment () () ;¥: () () _ () () () () ., a 0il and Gas ConServation Commi'. e ~r~lg Permit No '~'~-/"' Field Inspection Report ..... " ,' ~:~ Well/Platfm Sec,7~ T/~'~/RI ' ..... Operator ,~,:;.~, ~,? =,-~,~ .... . ...... Represented by,~ ~_/~.,,-~ Name_ . & ' Numbe r ~,..~:~',." .(;~ .... -., ':~ S~sfac~o~y Type ~nspec~ion SatisFactorY Type ~nspec~on Yes No __Item ( ) Location,General Yes~ No Item (). BOPE Tests 1. Well Sign ( ) ( ) 15. "Casing set ~ 2. General Housekeeping, ( ) ( ) 16. T6~t fluid-( )wt,)mud ( ) oil 3. Reserve Pit-( )open( )filled ( ) ( ) 17. Master Hyd. Control Sys.- ~sig 4. Rig ( ) ( ) 18. N~ btls. , , , ps~g (:X:) Safety Valve Tests ( ) ( ) 19 R~mote Controls 5. Sufffa'Ce-No. Wells / - '( ) ( ) 20. Drilling spool- "outlets 6. Subsurface-No. Wells~_ ( ) ( ) 21. Kill Line-( ) Check valve ( ) Well Test Data ( ) ( ) 22. Choke Flowline ( ) HCR valve 7. Well No~. , , , ( ) ( ) 23. Choke Manifold No. valvs flgs _ _ ( ) ( ) 8. Hrs. obese( ., , , ( ) ( ) 24. Chokes-( )Remote( )Pos.(~dj. __ ( ) ( ) 9. BS&W , , , ( ) ( ) 25. Test Plug-( )Wellhd( )csg( )none ( ) ( ) 10. Gr. Bbl~ ~, , , ( ) ( ) 26. A. nnular Preventer, psia ( )Final Abandonment ( ) ( ) 27. Blind Rams,~psig ( ) ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & KellY-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve ~sig ( ) ( ) 14. Pad leveled ~-~ ( ) ( ) 31 Safety Floor valves-( )BV ( )Dart Total inspection observation time ~ ~r~/days Total number leaks and{or equip, failures Remarks ~$,.S,.'~,F~ ~'~ /+~~.~" {~0~/~ O,R,D ') ~/~/~,'?~' .,.~.~/ r{' ' ' - ~ ] ~t~ .l~r ..~ _~ _ · _ _ ..., ._ - , ,~ ~ ~ .... ~-~ / cc' .~,'~ /~,-(~_ No~f~ ~n d~s or when read~ Inspected bv~t/~/ '., AtlanticRichfieldCompany North Americ~ Producing Division North Ala'"" strict Post Offic,_ Anctlorage, Alaska 99510 Telephone g072775637 March 24, 1977 Mr~ Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 ..... J 2 Fh'g I IF ,", j s [. ,~ .' '; ......... CONFER: FILE: . m . . .=%-.._.::._. _: ~ Subject' Drl]_.!_~ (13-12-10-15) Permit No. 75-76 (31-12-10-15) Permit No. 76-16 url ~F~iqye'-~9~6 (31-11-10-15) Permit No. 76-35 Drill Site 9-4 (13- 2-10-15) Permit No. 76-40 Drill Site 9-5 (31- 3-10-15) Permit No. 76-47 Drill Site 9-6 (13- 1-10-15) Permit No. 76-48 Drill Site 9-7 (31- 2-10-15) Permit No. 76-58 Drill Site 9-8 (33-36-11-15) Permit No. 76-70 Drill Site 9-9 (31- 2-10-15) Permit No. 76-76 Drill Site 9-10 (11- 6-10-16) Permit No. 76-82 Dear Si r:. Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure iq i.! (i Il:IV i! D ~:vlslon ol Oil and O~3 Oon6erwt;oa Anc',hnr2CFl Form t 0-403 REV. 1-10-73 Submit "Intentions" In Trlpllcate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~ GAS r'~ OTHER WELL~ WELL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 697'W & 170'N of SE cr Sec. 2, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB . Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20198 6. LEASE DESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Drill Site 9-2 (31-12-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay- Sadlerochit 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 12, T10N, R15E, UM 12. PERMIT NO. 76-16 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABAN DON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detalls, and give pertinent dates, includingestlmated date of starting any proposed work. · .Began perf. operations @ 1800 hrs on 4/30/77. Tstd tree, csg, tbg & wireline BOPs. Pulled dummy valve. Perf'd intervals 10,940'-10,948', 10,898'-10,906', 10,872'-10,886', 10,817'-10,841', 10,774'-10,799', 10,749'-10,774'. w/4 shots per ft. Ran Amerada bombs. Flowed well on 48/64" choke w/FTP of 1500 psi @ 6363 BOPD. SI well. Ran & set ball valve. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production .Dept @ 0020 hrs on 5/4/77. RECEIVED · 16. I hereby certify that the foregoing is true and correct TITLE District Drilling Engineer (This space for State office use) APPROVED BY ..... :CONDITIONS OF APPROVAL, IF ANY: ..... : ..... TITLE ......... DATE See Instructions On Reverse Side DRILL SITE #9-2 PERFORATION ANq~ CLEAN~ RECORD May 1-3, 1977 D.S. #9-2 was drilled to a bottom hole location in the northeast corner, Section 12, T10N, R15E, Prudhoe Bay Field. Depths of interest are: Measured Dept~. Subsea Depth, Zone Top of Sadlerochit Gas/Oil Contact Perforations (Ref: t HCS/GR of 3/10/76) Water/Oil Contact Base of Sadlerochit Junk Left in Hole 10674' 8753' UBS Not Present ~ - 10750-10800' 8813-8852' LBS 10817-10841' 8866-8884' LBS 10856-10866' 8896-8904' LBS 10872-10886' 8909-8920' LBS 10896-10906' 8928-8935' LBS 10940-10948' 8962-8968' LBS 11040' 9039' SMB 11062' 9056' SMB None The first gun (a dual select-fire) was positioned to perforate the interval -10940-10948' M.D. with the choke set initially to 3/4". Upon firing, the well began flowing at 2800-3000 BOPD at zero FTP. With the well flowing, the gun was repositioned to perforate the interval 10896-10906' M.D. Upon firing, no noticeable pressure or rate response was seen and the well continued to flow at 2800-3000 BOPD. Within an hour the FTP and rate began to increase. One hour and 23 minutes into the flow, CaC12 water and gas surfaced. FTP was 330 psig and, because of the gas, the turbine meter was bypassed. ~e well was flowed for an additional one hour 39 minutes until samples indicated the presence of no water. Final FTP was 410 psig. During this flow 408 barrels of fluid was recovered of which 238 barrels was diesel, 25 barrels was CaC12 water, and 145 barrels was reservoir fluid. A Fluid Density Log was run indicating the CaC12 water interface at 10714' M.D. It was decided to run the second gun and flow the well a second time for cleanup. The second gun (a dual select-fire) was positioned to perforate the interval 10872-10886' M.D. SITP was 1200 psig. The well was opened on 36/64" choke and FTP was 800 psig 2 minutes later when the gun was fired. A small increase of 20 psig was noted and, with the well flowing, the gun was repositioned to perforate the interval 10856-10866' M.D. FTPwas 900 psigwhen the gun was fired. No noticeable pressure increase was noted. The well was SI momentarily after five minutes flow and was then reopened on a 1" choke for a second cleanup flow. The well was flowed for an additional 2 hours 2 minutes at an average rate of 8417 BOPD, recovering the estimated 15 barrels of CaC12 water remaining and 698 barrels of reservoir fluid. The third gun was positioned to perforate the interval 10817-10841' M.D. SITP was 1400 psig. The well was opened on a 50/64" choke, and after 8 Drill Site #9-2 Perforation and Cleanup Record Page 2 minutes flow with FTP of 960 psig, the gun was fired. The pressure surged and then fell back to 960 psig when the well was SI five minutes later. The fourth gun was positioned to perforate the interval 10775-10800' M.D. SITP was 1390 psig. The well was opened on 1" choke and was flowing at 1020 psig four minutes later when the gun was fired. The pressure surged and FTP was 1120 psig five minutes later when the well was SI. The final gun was positioned to perforate the interval 10750-10775' M.D. SITPwas 1440 psig. The well was opened on 1" choke and FTP was 1160 psig when the gun was fired. FTPwas 1180 psig five minutes later when the well was SI. An Amerada pressure bomb was used to dete~nine the 8800' ss static pressure, 4356 psig. The well was flowed on 3/4" choke at an average rate of 636? BOPD for 1 hour, resulting in 265.3 barrels of oil production. The initial FTP was 1350 psig but had increased to 1500 psig just prior to SI with a wellhead temperature of 54°F. The Amerada showed a maximum drawdmvn (just prior to SI) of 121 psi, resulting in an approximate PI of 52.6 STB/psi. BHT was 190°F and final SITPwas 1650 psig. The total estimated volumes of oil and gas produced during perforating operations were 1315 barrels of oil and 986 MCF gas. 7/21/77 FoKm 10-403 REV. 1-10-73 Subml t "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS O-N WELLS (Do not use this form for proposals to clrfll or to deepen Use "APPLICATION FOR PERMIT--" for such PrOPosals.) 99510 O,L i-G1 GAS F-1 WELL~ WELL' ' OT--ER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360 Anchorage, Alaska 4. LOCATION OF WELL At surface 697' W & 170' N of SE Cr Sec. 2, T 10 N, R 15 E, UM 54' RKB 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Check Appropriate Box To Indicate Nature of Notice, Re 14. 5. APl NUMERICAL CODE 50- 029- 20198 16. LEASE DESIGNATION ANO SERIAL NO. ADL 28327 7. IF INDIAN, ALLOTTEEOR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Drill Site 9-2 (31-12-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T 10 N, R 15 E, UM 12. PERMIT NO. 76- 16 )ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF J__._j FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate , SUBSEQUENT REPORT OF= WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The down hole safety valve will and tested upon conclusion of job. Estimated start date- i JUNE 1977 be i nsta 11 ed 16. I herebY certify that the f_oregoing is true and correct SIGNED TITLE District Drilling Eng.ineer' DATE (This space for State office use) APP.OVED a¥.,~ L/~~. ,~'~<')~¢,,,~¢~'~/T,TLE Pe t:ro leum En~!! neet CONDITIONS OF APPROVAL, IF ANY:J See Instructions On Reverse Side DATE 3-30-77 Approved Copy Returned To' ~--~-~ ATLANTIC RICHFIELD CO~7~\~f North Alaska District Engineering TRAN SM I TTAL. CONFIDENTIAL DISTBIBUTED TO: STATE OF ALASKA ,:;I"~isiON OF OiL & GAS- Date: Oct. 11, 1976 From: J.A. Rochon/p. Hellstrom' Well Name' Drill Site # 9-2 Transmitted herewith are the follm~ing fOr the subject well' Run No. Scale Xerox BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Sh~t Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gmvma Ray/CCL Laterolog. Location Plat blicrolaterolog Microlog Mudlog- Interval Sample Log (A.R.Co'.)-Interval) Synergetic Log TVD-DIL TVD-Porosity Log SI! Sepia BL Line Receipt Acknowledged For: Date' Please return receipt to: Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99510 AtlanticRichfieldComp~ny September 8, 1976 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: ~31-12-10-15) 31-34-11-15) Dear Si r' Enclosed please find the subsequent Sundry Notices for the above mentioned wells. Very truly yours, C. R. Knowles District Drilling Engineer CRK/jw Enclosures Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10-,73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1, OIL ~ GAS D WELLt'"] WELL OTHER 2. NAME OF OPERATOR ALl anti c Ri chfi el d C0mpan.y 3. ADDRESS Of OPERATOR P. 0. Box 360, Anchorage, AK 4. LOCATION OF WELL At surface 99510 170'N & 697'W of SE cr Sec 2, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20] 98 6. LEASE DESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 9-2 (31-12-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., l., R., M., (BOTTOM HOLE OBJECTIVE) Sec 12, T10N, R15E 12. PERMIT NO. 76-16 )crt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT Or ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Accepted rig @ 1600 hrs 8-14-76. Pulled & LD 5½" 17# MN-80 8rd LT&C (A-B) tbg. Press tstd 9-5/8" csg. Ran & set Baker retrievable BP @ 3000'. Chgd 5" to 9-5/8" rams. RIH & cut 9-5/8" csg.@~. Retrieved 9-5/8" pk-off. Pulled & LD 9-5/8" csg. No ~sumitomo .p_._i_p__e. PU 9-5/8" csg patch & 9-5/8" 47# J&L S-95 butt csg. Engaged & set patC~ w/3-~--0-~#. Installed 9-5/8" csg slips & emergency pk-off. NU BOPE. Installed csg pk-off & press tested 5000 psi for 30 min. NU BOPE. Tag sand plug @ 2983'. RIH & open FO @ 2314'. Place 425 bbls Arctic Pack in 9-5/8" x 13-3/8" anul. Close & press tst FO. Ran in & retrieved Baker BP. Displaced 0il Faze mud w/CaCl~ water. Press tstd 9-5/,8," csg w.3000-psi OK. RIH to top of PBR & circ w/CaCle wt~. LD 5" DP. RU & run 5½ 17# 8rd LT&C (A-B) tbg w/RQ nipple @ 2215'. Stab into PBR barrel. Spaced out and landed tbg. Press tstd tbg hgr 5000 psi OK. Tstd control lines. Press tstd xmas tree. RIH & opened XA sleeve @ 10,305' Displ tbg w/diesel thru sliding sleeve. Close & press tst XA sleeve. Note' "XN" nippie 10,345', Baker SAB pkr 10,436', "X" nipple 10,520', shear sub 10,593'. Ran & set dummy valve in RQ nipple. Press tstd control lines 5000 psi for 15 min. Ran GR/CCL & dummy gun to 11,010'. Press tstd tbg & tbg anul. Released ri9 @ 1800 hrs 8-24-76. ~ . . 16. IherebycQrtifyth, th, foregoing is true andJ[orrectSiGN~~~~~~ ~~TITLE ~JJ/~f~ f~ DATE' (This space for State of~e'~t~) ~/' APPROVED BY CONDITIONS OF APPROVAL, IF ANY.. TITLE DATE See Instructions On Reverse Side ~tlanfic~ic. hfieldCompany North Ame~ddF~n Producing Division North A~ :strict Post Office ~¢ox 380 Anchorage, Aiask~ 99510 Telephone 907 277 5637 July 9, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE' DS 9-2 (31-12-10-15) Permit No. 76-16 Dear Sir' Enclosed please find the Sundry Notices and Reports on Wells for the above mentioned well. This report covers the, re-entry to replace the 9-5/8" casing collars. Very truly yours, C. R. Knowles District Drilling Engineer CRK/jr Enclosure JUL 1_ 4 19'76 O~l¢iON O~ OIt AND GAS J:orm 1~403 REV. 1-10-73 Submit "1 ntentions" in Triplicate .~. & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) APl NUMERICAL CODE $O-OZ9-Z0198 6. LEASE DESIGNATION AND SERIAL NO. ADL 28327 1. OIL ~ GAS r-'-I 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL ~'g~.~J WELLI I OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESS OF OPERATOR '9.WELL NO. P. O. Box 360, Anchorage, AK 99510 DS 9-2 (31-12-10-15) 4. LOCATION OF WELL At surface 170'N & 697'W of SE cr Sec 2, T10N, R15E, UM 13. ELEVATION5 (Show whether DF, RT, GR, etc.) 54' P~K8 14. Check Appropriate Box To Indicate Nature of Notice, Re: 10. FIELD AND POOL, OR WILDCAT ?rudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec'12, T10N, R15E 12. PERMIT NO. 76-16 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AcIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ . REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) . . (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated dam of ~artin9 any proposed work. A statistical possibility exists at DS 9-2 that excessive hardness may occur in the casing collars of the 9-5/8" casing through the permafrost zone. As of this date, the 9-5/8" casing in DS 9-2 has not failed, but the likelihood that. failute will occur is sufficient enough to justify replacment of the 9-5/8" casing to a depth of approximately 2350 feet. The existing completion assembly will be rerun with the addition of a sliding sleeve. Prior to setting the packer and nippling up the xmas tree, all work will be done in a calcium chloride brine with a 300 psi over balance. The completed well will be left unperforated with diesel in the tubing down to the PBR. This work will commence.about August 15, 1976. JUL 1 1976 I hereby certify that the foregoing is true and correct APPROVED BY.~ /"' ..... ' ...... CONDITIONS OF APPROVAL, IF A~Y'.TM TITLE District Drilling Enginee= DATE ,, ?~/Z~ TITLE See Instructions On Reverse Side DATE Approved Returned = 'Z-/~-- -T& To' ......... rth Alaska District Enginee: .... '~ C0Ni~lD~"i'l~ T R A N S M I T T A L D~TIHI~UTED TO: STATE' OF ALASKA DIVISION OF OIL & G~ Date- May 20, 1976 From: J.A. Rochon/W. Toliver Well Name' D.S.#9-2 (51-12-10-15) Transmitted herewith are the following for the subject well' Run No. Scaie Xerox /, BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VOL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey = Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density' Log Formation Density Log/Gmmna Ray G mn~na Ray/CCL Laterolog Location Plat b[icrolaterolog · · Microlog bfl~dlog- Interval Sample Log (A.R.Co.~-Interval) Synergetic Log TVD-DIL TVO-Porosity Log ~2"&5" 2"&5" Sepia. BL Line Date: ~.~-~~ / 9~-~ Please return receipt to{ ~lantic Richfield Company ~North Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99510 AtlanticRichfieldCompany North Am~-~3n Producing Division North Ala ~istrict Post Office Bo× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 2, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 Subject' DS 9-2 (31-12-10-15) Permit No. 76-16 Dear Si r' We are enclosing the Well Completion Report along with the Well History and Directional Survey for the above-mentioned well. Very truly yours, C. R. Kno~]es D~st~ict D~i]]~ng. Eng~nee~ CRK/cs Enclosures SUBMIT IN L, .,."~, JATE* STATE OF ALASKA ',se .... th(.-tn.. st ructions on OIL AND GAS CONSERVATION COMMITTEE WELk cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OH, oas ~ w ELL W ELL DR Y Other b. TYPE OF COMPLE~ON: NEW ~ WOn[( ~ DEEP- ~ PLUG ~ DIFf. ~ WEI.I, OVER EN BACK RESVR. 2. NAME OF OPERATOR ~t]antic R5chfSe]d Company . 3. ADDRESS OF OPERATOR P. 0. Box 360, Inchorage, Alaska, 99510 ORIGINAL 5. AP1 NU2VLE~ICAL CODE 50-029-201 98 6. LEASE DESIGNATION AND SERZAL biO. ADL 28327 7. iF INDiA. N, ALLOTTEE OR rl'ltlBE NAi~ZE Other ~ ' ,' ,-' t~; ! [ , 10v FIE~'~D POOL, OR WI~C&T 4. ~,OC,,.TmN OF WELL (Report location ctearly and in accordance with any State requirements)* xt~u~a~170,N & 697IW of SE cc Sec 2, TION-RI5~i~.~ At top prod. interval reported below 1145'S & 1272'~ of NE cr Sec 12, TION-RI5E, ~t total dep~ 1308'S &,986'W of NE cr Sec 12, TION-R15E, UM Prudhoe Bay-Sadl erochit ,.~,' sEC..o~c=.~w~r.. =.. ~., ~O=TO~ =o~ Pool Sec 12, TION-R15E 12. P~TI:~IT NO. 76-16 ~:~' ~*=~ sP~' {~' ~==''E ='~' =~C=~ l'I~' ~A~ ~°=~ susP °= A~A~'2-16-76 3-9-76 { 11,072~ & 91 18'~'?'~'~' {1~' ~v*=IONS 'DIla' }~' 1~,~' ~' ~=C)'II~' =~v' ~A~I~G}~'~D54' 'RKB INTERVAI,SDRiLI,ED BY 11,199' & 6' ll ,0721 & 9118' ,o=~ ~oo~.~ All None PRODUCING !N~VAL(S), OF ~IS COMP~TION--T&P, BOSOM, NAME (MD AND ~)~ ,23. %VAS D!ttECTIONAL ~ S UH.VEY MADE NONE !YES I 24.TYPE ELECTRIC AND OTHE~ LOGS RUN DIL, BHC, GR, FDC/CNL and GR/CBL CASING RECORD (Report all strings set in well) 20Il 94~- Vetcd ,'40}85'below,pa ?~" '1250 sx ArctiCset cmt 13:3/8" 72g - Butt[ ~N-SO[ 2~26'~ 17¢ [4350 sx Arcticset cmt ' 9:5/8" 47g Butt l ~N-80[ 11,153' 1 ,l/41 1050 sx Class a cmt als00-95[ ,,,,.,. .[ 115 Arc~icset 2nd 26. LINEX EECO~ [ 27. TUBING ~. PERFORATIONS OP~ TO PRODUC~ON ' (interval size and number) 29. ACID, Si:CT, i:]iA(71 GEE, C~,iENT SQU/i2fZE, ETC. D~IIi lr{'I'~V.~ (MD) AM,OUNF AND I'=[ND OF MA'IEi[iAL US~ N/A "N/A i i i iii P~OD UCTI ON DATE ~ST PI~OD[FCTION I ~ODUCTION MEI[IO'D (Fiowii~, ~:~3 lif~, pmmp[ng--size and type of pump) N/A FUOW, TUBING- · IV, 1;;LL :YL"ATUS ( Produciag or ~Iq-OURS 2'ESTE~D '{]CItO:(E SiZE {TES'I~~IPP'OD'N FOR CA~Na Pa~SSU~ ~zs (8old, u~ed for ~uel, vented, etc.) OIL~B BL. GAS--rVrCF. 1 32.LIST OF ATTACHMENTS _Dr_illing History and Gyro Survey WATER--BBL. { OIL GRAVITY-A_I~I(COi:LR. ,~ ITEST \V ITN ESF, I~D 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available records *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lanJs and leases in Alaska. Item: 16: Indicale wh~c[~ elevation is used as reference (where riot ot[~er,,r,,..ise $}qo,:v~! for c!eF~th measure- menl's c'j~ven ~n c,~her spaces on this for:~ and ~r'~ any Items 20, ~nd 22:: If th~s well is completed for separ~]t¢. F)rcc]z;cti©n from F,~ore thaF, one ~r~terva! zone (mull~ple completion), so state tn item 20~ and in ~te?~ 22 show the top(s), bottom(s) and name (s) (if any) for only the interval rel)orled ir~ ~ter~ 30 Submit a separate report (parle) on this form, acJe~.lL~ately identified, for each additior~al i?te:val to be seperatel¥ procl~:ce."{ show- ing the ackJitional data pertinent to such ~nterval. Item26: "Sacks Gen"tent": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , , 34. SUMMAI{Y OF F()~MATI£)N T~'I'.~ IN('LUI)IN(; I NTEItV^L TE.qTED, I)IIE~SU~E DATA ~'~OVEItlB' OF OIL GAS. 35 G~GIC WAT~[ AND MUD ~AS. '~ r~u~ v~.. Top Sa, dlerochit 1 0,674", 8807' Base Sadlerochit 11,062" 911 ~' 3fl. COlIE DATA. A'I'I'ACII BRIEF DBCRIpI~ONS OF LITIIOLOGY, POROSITY, FIIAC~R~. APP~NT DIPS AND IIE'I'E(YI'EI) S}IOW8 OF OIL., GAS Oll XVAT~I. i i ~ ~ ,, ~ ,~ , i A PETROLANE COMPANY of Atlantic Richfield COMPANY D. S. 9-2 WELL NAME Prudhoe LOCATION JOB NUMBER A376 G0056 TYPE OF SURVEY Gyro-scopic SURVEY BY Jay Martin OFFICE Alaska DATE 3-~1-76 R E C 0 R D._O.F A L L C A L C U L A T ! ON s..__ E_E_R.FOR.h! E _~_~P.T_H.__A NG L.'.'E .... D.F-_~3 H 5.E_A ..................... D..! R. EC D.!.$...T. AN C E ..................... ANGL_~ ..........D.EG/..~_O.O.E~_ ......... D_I D M DEG, D N1 S ___2_00 ...... q .... O ....j_~.9..,__9~ ........... 1..~5..,..99 ........ 525.,00E .............. !..I.5.97 ..... N .......... 2_~t, O0 W 11_8_,A.3 N .... ~...$__4~ .... 4_~__W ......Q_,.750 _. -53,79 .... $.90_~_0_. _0 ...... 2~?_,..9_~ _24.5_,.99 ......... S26-_00E ..... _~_!_5_,._9.?__N ~__,._.0.0 w i 1..s._,_4~ ~ ...... l_l .... 4.!__E.~ .... tN_ O_..QO.Q~ .-5_Z_, 0: ............... ]1.l./". ....... N ............. 2_3_,_ F. ........... l_,%7,..8.0 ....... ~._.%i B.6__2..9_J,~ ....... ..... ~..0_0.~0~5___~_9_9_,_9.8 .... 5.4.5_,_98 ........... 532.,.0.0~ ......I,i.4..,_~ 8_~L. 23_,.I_1__W_ __i__!6_, 69 .... ~_%__25 ...... 20,_W .......0_, 160_ .............. ~.. .. ..... ,._ ~..~.' .... 7~_0 O .Q~5.9_9_,_9~ 5.~3_,..9_8 .... 53_2_,.0.0.%~~_._9.4_:~ __22,83 W 1_!..6.,~.! N ii 19~ W _0_,3.9~0 -- B O_Q Q__.0_~_~9.9_,78 .... 7.4~_.,.....8 ...... S 3 z,.,.~ 0._ ............ ,.! .... ,_9 .._J~ ...... ~=2,_8..3__,N .... ,.~6 · 21 .... 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W .... 0.~ 0,.0.__ -~ ~ i 0.~ ~.700 ...... ~ ...... _0~1_59~_,_9D ~645,_90 .... 553., OOE .......... ~0,9., ~F_..~ ......22..~.~ .... W .... !_l_l, 82 _k__l.l ...... ~.4 ..... ~_!__W ........ O_,~ 50~ -50,.~,_7 .................. 7__q.~ .... w ..... .~_._0_~5 ..~~_9_. 23 _1.20.0 ..i .....O_ 1_7.9_9_..._8 1_74.~_..,8 _.55_5,00E !C.~.,A6 N 2~._3.3~W _ .... 1!0,5~ N l~ ' ' ~' ~' "gOO 0 55 ~P, 99 ,~,7 i~4~.~7 S41.OOE !07..3!+ N 20.08 ~,,' 200..,0 0 30 1999.86 1045.86 Se4.00E !06.42 N ~9_.?~. W 2100 m 0 2099.86 2045.86 S~a,~O~ " _ ltl,g4 W 2200 0 30 2!99,~6 2145,56 ?.~!$.00E !06.18 N !8.5~ w _2 3 O 0 ....... - · O0 ........... . ¢ OOE ~08,&~ N 17,4a W 2400 0 45 2399.84 2345, oz~ N36. lU9,20 N I0 35 57 W 0,070 -47.73 !07.80 ,~ 9 55 41 W O.5OO -45.98 1.0.8..79 ..... N ....... 9 56__I0 .... W ............ 0,_~40 -4D.,8_4___ 109.85 N 9 7 56 W 0,090 -45,47 iLL CALCULATIONS PERFORMED BY I B M Et. ECTRO/hiC COMPUTER DEPTH ANGLE DE P'rt-~ SEA DIREC ~i~TANCE ANG t~{ ..... .~E_G_ZA~O F T .... 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EAS U B.ED_LQE,PZ.~_~ND_O_I,HER__D,A_TA__.EQR .... Et/ER,Y_ EV..EN_I O 0.._F_EE_T__QF__5_LJ.B__SE_A,_D EP_.T. H ,. ........ LLEASURED ...... _.LSR_~C~L_~UB ....... M.D_.T_VD V_ER_TI_CAL D. EP_T.H.: ...... - D. EP.....T.N ..... 5.EA_DiFFEREN.~__CORRE_C_T_Z.O.N T_O_T. AL___COORD_I.N AZ~F.~---~ ........... .8..A,2._9 7 !.5..4_. ....... 7.100 ...... 127_5 ............... 35 856.5 ....................... _7.2.5.4_, .............. 7200 ........... !.3.1.1 ............................................ ~_6 870Z _ .8_9.8.0 .............. 9.26 2 ' _ _9 A02 735~,, ............ .7.3.0.0._ 1_3_68 37 7~+5A, ......... 7~00 ........ _7.5 ~A_,_ 75 00 :7Z5.~..,. ........ .77.00 785, ~_. 79 5 ~ · 7_?..,0,0 .....~5,.~_? ' ~ ~ .......... g 822_ ............... 1.0093. 10~25 _ ._L0JL~J .. ........... 1050_7____ ~._1_02~.3 .............. 1098o _ = , .87 ::8_?..=..~ ..... O0 ........ 1853 21 8~5~.__t..8,.0.0.__._._I_8.7_9. k5 89.5_~_, 8~00 ...... 1906 __27 .905A. ....... 90~.0~ ....................... 1935 ..... 2_9 !_g.5..5_,_7_:I._$ .... 4...7_8 0.,.6 9 .... E_ ............ 1 Z95.,_ O r~ ...... S .._~d35 0_, ~ 7_ E 13 ~3_,5_3.._5 z. Lg_'g. 2~._l..~___g . . . 80_.~4_. ...... S000 ....... 1.6.3.0. 8.1_5..~_, ..... 8 !00 ..... !6.68 38 83.5..4_, ........... 63 00 ...... 1.7_39 3 4 l 035 · 0_9__5 .......... ~_~ 5.0.,..Q3._g ............... __ 8 45.4_. .... 8400 ....... 1.771 VERTICAL SECTION SCALE i"= IOOO'~: ..... ATLANTIC RICHFIELD COMPANY, i-- RADIUS OF CURVATURE METHOD GYROSCOPIC SURVEY ; ._ _ I , ..... : ' ' 'i' .... ~ ' , ................................................ ~ ............ : ...................................................... : ......................................................... H O. R I Z O.N..'FA 1,.... V I E W.ii~., _2 ..... i · ' ' ' '.i ' SCALE 1':5OO' ' ........................., ' ATLANTIC RICHFIELD COMPANY'"'";,, ..... ~'~ ' ! : DRILL 'SITE 9-2 .... ..................................... · ......... "": ............. ~ ...... ~'-'"- ...... i'""'~-'-"'..-.";7""'il."J ................... ~' ................................. : ............' ............................. :'"RADIUS OF 'CURVATURE' METHOD .................................. · ': ..... ! ;-i-17 ! ' : ' ' ..... GYROSCOPIC SURVEY ,. · ~ ............... . - - : .... ; - ' ! ' ' i '. .... ................. , ............. . ........................ ,, .................. ALL DEPTHS..,.SHOWNL__i' .............................. 7600 ........... , ................................................................. _ 8000 8400 8800 9200 TVD = 9,2.1 6 ....... :-TMD =11,199 ATLANTIC RICHFIELD COMPANY DS 9-2 (31-12-10-15) API 50-029-20198; ADL 28327; Permit No. 76-16 DRILLING HISTORY Spud at 1:30 PM 2-16-76. Drilled 17-1/2" hole to 2750'. Ran 13-3/8" 72# MN-80 Buttress casing with shoe at 2726~. Cemented with 4350 sacks Arcticset Cement. Landed 13-3/8" casing, displaced mud and water from 13-3/8" x 20" annulus with diesel. Packed off 13-3/8" casing, NU and test BOPE. RIH with 12-1/4" BHA, drilled FC, cement, shoe and formation to 2825'. Pressure tested to equivalent .65 gradient. Directionally drilled 12-1/4" hole to 11,199'. Ran DIL/BHC/GR and FDC/CNL logs, POH. Ran 9-5/8" 47# MN-80 and S00-95 casing with shoe at 11,153' and FC at 11,072'. Cemented with 1050 sacks Class G cement. RIH with RTTS and shifting tool. Cemented through lower FO at 2617' with 115 sacks Arctic set, closed and pressure tested lower FO. Pulled up and opened upper FO at 2406', placed 9.5 ppg Arctic Pack in 9-5/8" x 13-3/8" annulus. Less than 1% water at end of job. Closed FO and pressure tested with 3000 psi okay. RIH with 8-1/2" bit and 9-5/8" casing scraper to 11,072'. POH. Ran GR/CBL and Gyro survey. POH. RIH and changed mud to water and water to diesel. Ran 5-1/2" 17# MN-80 8rd LT&C A-B modified completion assembly with shear sub at 10,585'. Baker SAB packer at 10,424'<i SSBV nipple at 2184' ND BOPE, NU and test xmas tree. Ran dummy valve and test BV control lines to 5000 psi. Dropped ball and set packer. Pressure test annulus with 2000 psi, okay. Pressure test tubing with 2860 psi, okay. Ran dummy gun to 11,072'. Released rig at 2400 hours 3-20-76. STATE of ALASKA DEPARTMENT OF NATURAL RESOURCES '"'D.i, vision of Oil and Gas ~a/' O. K. Gi 1 breth, Jr.,~f~L~~ TO: Director neer/~l~ Thru- Hoyle H. Hal~ilton Chief Petroleum Engi Ben LeNorman Petrol eum Inspector DATE : .March 24., ln~C SUBJECT: February 2~, 1976 - Departed my hom, e at 6:00 PM for a 6:30 showup for a 7:15 PM departure via ~.,,~i~n Flight #43 to Deadhorse. ~ Arrived at Deadhorse at 9'00 PM and hitchhiked a ride on a Parson's bus to Arco base. At Arco base we met with Gil Meyer, alternate to Bill Congdon, to try to deten, ine which of the two tests would begin first, t!e advised Rowan Rig #35 was ahead in nipplin9 up so we radioed the rig for transportation a~.~d arrived at Drill .Site Temperature-40°F, no wind, ice fog .... Drilling foreman for Arco was Jack Hurray and toolpusher for Rowan was Red Adams. Many lines were frozen and the stack had not been picked up yet. February .2.6.,._197~- At lO:O0 AM we called Jack Morrow, Arco drilling foreman at Drill Site #6 to determine .what progress Parker Rig #141 was making in ni?plin.q up. They were about to do a top job and at this point in time it appeared two tests might coincide. I advised Jack Morrow that if this did occur I would ~ive preference to Rowan Rig #35 since the equipment had not been previously tested. I had personally tested BOPE on Parker Rig #141 on two previous occasions, t,?hile nippling up, I toured the location at Drill Site ,~3 and found it well organized, the reserve pit well built, steel welded fuel tanks were not bermed, the rig in 'good repair and the well sign in place. However, we noticed no N2 backup at the accumulator add Red Adar,~,s'advised the rig has never had t,hi~ system since its arrival on the slope in 1969, $,~e discussed this with Jack Murray who advised the system would be installed as. soon as possible. February 27, 1976 - Drill Site #6 called at 5-00 PM and advised they would begin 1! . ~e's'{s a'{aPproxi'mately 6-00 PM. .~e arrived at Parker Riq #141 at 6-15 PM and the tests began at 7-20 PM. The new drilling foreman was Ueldon Arbsland and the toolpusher, B~ll Selby. ,~ Pipe rams and eight valves and thirty flanges in the choke manifold tested to 5000 PSIG. The manual adjustable choke was .free moving and the S~,.!ACO choke was actuated.. One wing valve and check valve on the kill line and both win,q, valves on the choke line tested to 50(}0 PSIG. The inside valve on the kill line'would not test and will have to be :repaired or replaced. While removing drill pipe to.test the blind rams, we toured the location which was well organized, reserve pit well built, steel welded fuel tanks not benned, the rig in good repair and the well sign not received 'From Anchorage. O. K. Gilbreth, Jr. -2- March 24-, 1976 The accumulator was tested to 2750 PSIG. N2 bottles tested to llO0, 150~0, 1600 and 1400PSIG. ~le recommended bottles #1, ~,2, and ~4 be replaced. Ram.,, were actuated~by both primary and remoted controls. Blind rams tested to 5000 PSIG and hydril tested to 3000 PSIG. Al~ this point they could not find the test adapter sub for testing the kelly cock and decided to fabricate a new one. February 28, 1976_- At a little past midnight the new adapter sub was completed 6~ut the kei'ly was frozen in the rathole. This was finally overcome and tests resumed at 1:25 AM. Kelly cock and lower kelly valve tested to 5000 PSIG. Both dart type and ball type floor valves were on the floor. Tests were completed at 2:00 AM. A field inspection report was completed, the original given to ~t!eldon Arbsland, a copy mailed, to Benny Loudermilk and a copy attached to this report, l~Ie were driven back to Drill Site #3, arriving there at 2:20 AM. The new drilling foremaLf at Drill Site #3 was Buck Rice. Tests began at 11:25 AM, but there was an immediate flange leak and the hydril would not test. The accumulator was tested to 2800 PSIG and rams were actuated by both the primary and remote controls. While awaiting repairs ~ve drove to Drill Site #9, Rowan Rig #34 to see if they had installed the N2 backup as recon'mended back in January. They had done a neat job complete with gauge and bleedoff valve. Buck Rice observed the hookup and will copy it for Rig #35 as these sister rigs are almost identical in construction. While at Rig #34 we tested the N2 bottles, each of which tested in excess of 2000 PSIG. Tests resumed at 3:00 PM and we tested both the upper and lower pipe rams to 5000 PSIG. Both wing valves on the choke line and the wing valve and check valve on the kill line tested to 5000 PSIG. It was definitely decided at this time to change the packing element in the hydril. Drill pipe was removed and blind rams tested to 5000 PSIG. hie decided to isolate the choke manifold from the stack with a wing valve and continue tests. However, one valve refused to test and it was so located that until it was repaired or replaced no other valves in the choke manifold could be tested. February.. 29, 1976 - By lO:O0 AM many delays had occurred. The hydril packing element was replaced, but one of .the roughnecks fell some thirty feet into the cellar and was rushed to the hospital. Fortunately, his injuries were minor. One of the wing valves on the choke line which previously tested okay would not close and had to be repaired. Tests resumed at 3:00 PM with the lower kelly valve testing to 5000 PSIG. However, the kelly cock would not test and the kelly was set back in the rathole for steaming. O. K. Gilbreth, Jr. -2- Hatch 23, 1976 Tests resumed at 6:45 PM and thirteen valves and forty-two flanges in the choke manifold tested to 5000 PSIG. The manual adjustable choke was free moving and the SWACO superchoke was tested to 5000 PSIG. At this point in ti~ a roughneck dropped a 1/2" clevis pin into the stack. An attempt to make up drill pipe into the test plug failed when it was found a piece of rubber about the size of a man's shoe from the old hydril element had dropped precisely into the box up on the test plug~ sub. The stack ~,~as drained and the lower pipe rams preventer opened to retrieve the piece of rubber. Drill pipe was then made up. into the test plug and it was then raised until the clevis pin coul,d be retrieved by hand. The preventer was then nippled up and retested to 5000 PSIG. At ll'30 PM the hydril was tested to 3000 PSIG and the repaired valve on the choke line tested to 5000 PSIG. Kelly cock was tested to 5000 PSIG and tests con- cluded at 12:00 midnight. Both 'dart type and ball type valves were on the floor. A field inspection report was prepared, the original given to Buck Rice, a copy mailed to Benny Loudermild and a copy attached to this report. March'l, 1976- I departed Deadhorse at 4-50 PM.via Wien flight #20 and arrived Anchorage at 6:30 PH and at my home at 7-00 PM. In summary, I witnessed BOPE tests at Arco DS 3-1 and DS 6-6. Attachments AtlantiCRichfieldCompany North AmC~ ,_ ~oducing Divisior~ North A~a ~)~ ct Post Office E~ox 360 Anchorage, A~aska 99510 Tg]ephone 907 277 5(~37 March 4, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Pemit No. 76-16 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer Enclosure CRK/BDR/j 1 F~ No. P--4 REV. 5-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'Fi'EE SUBMIT IN DUPLICATE -~. APl NLFMERICAL CODE 50-029-20198 6 LEASE DESIGN'A'I'ION AND SEHIAL NO. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ADL 28327 1. 7.IF INDIA]~', ALOTTEE OR TRIBE NAME OIL [~ GAS ~ WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT,F.~'tIVl OR LEASE NAME ATLANTIC RICHFIELD COMPANY Prudhoe Bay 3. ADi)RESS OF OPERATOR 9. WELL NO P.O. BOX 360, Anchorage, Alaska 99510 DS 9-2 (31-12-10-15) 4. LOCATION OF WEI.~ 697' FEL & 170' FSL Sec 2, T10N-R15E, UM 10. FIELD A_ND POOL, OH WILDCAT Pructhoe Ba¥-Sadlerochit Pool 11. SEC., T.. R., IH.. ~BOTTOM HOLE OBJ-F, CrrVE) Sec 12, T10N-R15E 12. PERMIT NO. 76-16 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CL'-~iENTING JOBS INCLUDING DEPTH SET AND VOL~ USED. PEH.FOlqJkTIONS. TESTS A/XrD I~ESULTS. FISHING JOB~. JU1VK IN HOLE A-ND SIDE-/q{ACKED HOLE A_ND ANY OTHER SIGNIFICANT CItANGF_~ IN HOLIil CONDITIONS, Report on operations for the month of February. Spud @ 1:30 PM 2-16-76. Drilled 17-1/2" hole to 2750'. Ran 13-3/8" 72# MN-80 Buttress casing w/shoe @ 2726'. Cemented w/4350 sx Arcticset cmt. Landed casing, displaced mud and water from 13-3/8" X 20" annulus w/diesel. Packed off 13-3/8" csg, Nil and test BOPE. RIHw/12-1/4" BHA, drilled FC, cement, shoe and formation to 2825'. Pressure tested to equivalent .65 psi/ft. Directionally drilling 12-1/4" hole @ 7583' on March 1, 1976. NOTE--Report on this form is required for each calendar month{ regardless I~lhe stotul'of operations, and must be filed Jn duplicate with th e oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. February 4, 197~ Re: Prudhoe Bay DS 9-2 (31-12-10-.15) Atlantic Richfield Conq~an,y State Pe~it No. 76-16 C. R. Know!es District Drilling Engineer Atlantic Richfield Company P. O. Box ~0 Anchora~, Alaska 995t0 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 12, Township lON, Range 15E, UM. Well samples, core chips and a mud log are required. A directional survey is not requi red. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ing or migration of anadromous fish. Operations in these areas are. subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code), Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- merit of' Fish and Game.. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations prOl~lgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, as amended. Prior to c~ncing operations you may be contacted by a ~presentative of ~ Department of Environmental Conservation. Pursuant to ~ ~.40, Local Hire Under State Leases, the Alaska Department of Labor is ~ing notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours~after the. well is spuddea. We would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equi~nt before surface casing shoe is drilled. C. R. ~mowles 2- February 4, 1976 In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Very-~ truly yours, //1 i ,?7 ! ? / ? } Thos. R. Marshall, Jr. Secretary Alaska Oil and Gas Conservation Committee Enclosure CC: Department of Fish and Game, Habitat Section w/o encl. ~partment of Environmental Conservation w/o encl. Deparbr~nt of Labor, Supervisor, Labor Law Compliance Division w/ encl. AtlantidRichfieldCompany North Amerim-~,Producing Division North Alaska ~rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 29, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE' DS 9-2 Dear Mr. Gilbreth: Enclosed herewith is our Application for Permit to drill DS 9-2, a $100.00 filing fee, and the required survey plat. We are enclosing two extra copies of the survey plat that can be added to your DS 9-1 file. For your information, as well as for the State Department of Labor, the surface and target location are on Lease ADL 28327. The effective date for this lease is October 1, 1965, with a termination date of March 27, 1984. Very truly yours, C. R. Knowles District Drilling Engineer CRK:jha Enclosures Form 10-401 REV. la. TYPE OF WORK SUBMIT IN TRIr TE (Other i.n,s~uc Ih STATE OF ALASKA ? [::ii~ tl~:!)~(:~ ~-' OIL AND GAS CONSERVATION CO~M4~TEE.. PERMIT TO DRILL OR DEEPEN DRILL [] b. TYPE OF WELL OIL GAS SINGLE WELL ['~ ,,rEEL ['-] OTItER ZONE 2. NAME OF OPERATOR Atlantic Richfield Company DEEPEN L_J .~.,,,,*':-.,Ic', ..... ~- ': MULTIPLE I-"! ZON~ L_! 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL A, ~urfa~e 697 ' ~L & 170' NSL Sec 2, TiON, RiSE, UM atpro~dp:od, zo.e 1320' SNL, 1320' WEL Sec 12, T10N, RISE, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 6-1/2 miles northeast of Deadhorse APl # 50-029-20198 6. LEASE I)ESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLO'H'EF. OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 9-2 (31-12-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Poo] 11. SEC., T., R., M., (BOTTOM ItOLE OBJECTIVE) Sec 12, T10N, RISE 12. 14. BOND INFORMATION: n~EStatewide Surety and/or No. Federal Insurance Co. #8011-38-40 1S. DISTANCE FROM PROPOSED * } 16. No. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 1320' 2560 .~ . (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, ! OR APPLIED FOR, FT. 2640 101S0' 21. ELEVATIONS (Show whether DF.RT. CR, etc.) 21' Pad Elevation 23. PROPOSED CASING AND CEMENTING PROGRAM Amount $100' 000 17. NO,ACRES ASSIGNED TO THIS WELL · . 320 20. ROTARY OR CABLE TOOLS Rotary. ,~. 22. APPROX. DATE WORK WILL START February 14, 1976 SIZE OF HOLE SIZE OF CASING W%IGHT PER FOOT GRADE SETTING DEPTH Quantity of cement '32" 20" 94# H-40 100-+ Circ to surface approx. 500 sx 17-1/2" 13-3/8" 72#~,~v,~<~ b~N-80 2700+ Circ to surface approx. 5500 sx 12-1/4" 9-5/8" 47# b~N-80 10150_+ _+2500' cmt column on 1st stage _+1. ~ S00-95 300' cmt column on 2nd stage +125 ... 1'500 sx The Atlantic Richfield Company proposes' to directionally drill this well to 10150' MD_+, 9558 TVD_+ to produce the Sadlerochit zone. Logs will be run across selected intervals. A 20-3/4", 2000 psi Hydril will be used on the 20" conductor. A 13-5/8", 5000 psi Hydril and 13-3/8" 5000 psi Pipe and blind ranis will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# N-80 tubing, packer, ~nd ~ ~ ' -- n~e~sar~ provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. The well will not be perforated at this time. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certi~Foregoing,j~I' .... nd Correct (This space for State office use) [SAMPLES AND CORE CttlPS REQUIRED [] YES [~ NO DIRECTIONAL SURVEY REQUIRED ~¥ES [] NO MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY: OTttER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20198 PERMIT NO. 76-1 6 APPROVAL DATE February 4, 1976 T~TL~': Chairman D^TE,February 4, !976 ~See Instruction On Reverse Side AS BUILT WELL No. l LAT. 70'14'34.121" LONG. i48 14 28.254 WELL No. 2 LAT. 70° 14' 35.2T~" LONG. 14.8o14~2a.969'' Y 5 941 501.83 X 717 747.0'1 Y 5 94.1 618.22 717 719.06 SECTION 2 697' 673 ' - ~' SEC. I Ld CERTIFIC;ATE OF SURVEYOR i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASK~A AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY 5UPER~ ¥151ON, AND ALL Di/~ENSIONS AND OTHER DETAILS ARE CORRECT. .^TE · EXISTING WELL OR CONDUCTOR PIPE- ARCO No' " ,, HVL No. 32-DS"9"L76 ~; ATLANTIC RICHFIELD CO. ....... AS BUILT" , DRILL SITE' No.9 WELLS No, 1 LOCATED IN' PROTRACTED SECTION 2~T10N,R15E,U-M. PREPARED BY HEWITT V. LOUNSBUR¥ & ASSOC. 723 W. 6tl~ AVE., ANCHORAGE, ALASKA ~, , ,,,, , u, ~. ..,. , ,, ,i , i, , , -DATE 1/27/76. SCALIE 1" = 30~)' CHKD. BY GD FIELD BK LOOSELEAF i ~ ...... . ~ . ,J CHECK LIST FOR NEW WELL PERMITS Company /~/ ~.0 Yes No Remarks 1. Is the permit fee attached ..................... ,~ Lease & Wel 1 No. ~ ~. /~,~ / 2. Is well to be located in a defined pool .............. ~ 3. Is a registered survey plat attached ................. ~( 4. Is well located proper distance from property line ........ 5. Is well located proPer distance from other wells ........ · . , ~4/¢~ .... 6. Is sufficient undedicated acreage available in this pool ...... .~. 7. Is well to be deviated ...................... ~,,,~[,.. 8. Is operator the only affected party ................ ~e~e] .... 9. Can permit be approved before ten-day wait ............ /~ 10. Does operator have a bond in force ................. ~i Il. Is a conservation order needed ................... 12. Is administrative approval needed ................ 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16 Will cement cover all known productive horizons ......... 17. Will surface casing protect fresh water zones ........... 18 Will all casin~ ~ive adequate safety in collapse tension & burst · ~. ~ 19. Does BOPE have sufficient pressure rating ............. Additional Requirements' Approval Recommended· Geology Engi neeri ng' TR~ ~ HWK h/--f,¢ idOKG ~.~ HHH JAL LCS ..... >' JCM Revised 1/15/75 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No Special'effort has been made to chronologically organize this category of information. ,o 500292019800 Caliper Specialists Since 1953 KINLEY CORPORATION 5815 Royalton, Houston, Texas 77081-2993 U.S.A. Phone (71 3) 664-4501 Telefax (71 3) 664-1037 SERVICE AVAILABLE WORLDWIDE WITH ALL KINLEY WIRELINE TOOLS Calipers · Tubing Perforators · Sand Line Cutters · Power Jars · Measuring Line Cutters KINLEY SURVEY INTERPRETATION Common Abbreviations L.U. ,- Low~ Upset U.U. ' UpI~' Ups~ u.B. ,, upper Body m.B. ~ middle Body LB. ~ lower Body Corr. ~ Corro~on Dev. - Oepo~e~ ~catd. ,, ~tt~ TABULATION SHF, ET: IOINTS: are numbered from the top down. Numbering starts with the first full joint below the Christmas tree. PUP IOINTS: are designated by decimal numbers. For example, joint 32.1 represents the first pup joint below joint no. 32. SPECIAL TOOLS & NIPPLES: are designated bY letters. For example, "B" is the second special tool or nipple from the top of the well. GAS LIFT MANDRELS: are numbered down from the top, as shown: GLM (1), GLM (2), etc. TABULATION SYMBOLS We use a circle as the basic tabulation symbol. The Kinley Caliper records the simultaneous action of all fifteen or thirty feelers. Our survey, therefore, has either 15 or 30 lines. These lines provide a view around the circumference of the inner surface of the pipe. A complete circle on the tabulation sheet indicates that at least 14 of 15 feelers, or 28 of 30 feelers found tubing wall reductions at the same depth in the well. This would be described as a ring. The number of feelers that indicate tubing wall reductions at the same depth is also noted on the tabulation sheet. For a 15-Feeler Caliper ["~ 3 to 5 E~] 6 to9 F"] 10 to 13 O 14to 15 For a 30-Feeler Caliper CD ,o ,, CD ,o ,9 CD ,o CD ,o MEASUREMENT SYMBOLS [~] A PIT- A number alone represents the depth of penetration, expressed in hundredths of an inch, of the deepest pit. In this example 0.08". A groove around the pipe, found by 14 of 15 feelers or 28 of 30 feelers. The number inside the circle represents the maximum depth of the ring, expressed in hundredths of an inch. A PARTIAL RING - A groove around the pipe, found by 3 to 13 of 15 feelers or 6 to 27 of 30 feelers. The number inside the partial drcle represents the maximum depth of the ring, expressed in hundredths of an inch. MINOR DAMAGE - Indicates a "minor" amount of damage that is not severe enough to warrant measurement. F-] No COMMENT - Indicates no damage was found in that joint. Arco (Alaska), Inc. Prudhoe Bay, AK Drill Site #9-02 August 8, 1994 Survey No. 24111 T-30 Chart No. X1633 1st: 09-08-90 #20336 T15 This is the first survey of this well to be made with the Kinley 30- Feeler Microscopic Caliper. The condition of the internal surface of the ~ 1/2" 17# 13CR-80 tubing in the well, from 2,985' to 10,100'(WLM), is covered in this report. A comparison between this survey and the previous report issued on this well indicates a change in tubing during the period between surveys. The condition of the tubing surveyed and analyzed appears good with respect to corrosive damage. As there are no penetrations of any consequence recorded in the survey, the usual cross-sectional drawing and Pit Depth Rank Chart are not included in the report. The condition of the pup joints above and below the GLM's appears good with respect to corrosive damage. Photocopies of some of these assemblies are included in the report. CALIPER TECHNICIAN Steve Adcock SURVEY ANALYST Oscar Martinez om Distribution: ARCO (ALASKA), INC., ATTENTION: Records Processor, Room #AT0-1529, P. O. Box 10-3240, Anchorage, AK 99510-3240 (7R) ARCO (ALASKA), INC., ATTENTION: Mr. Jason Weaver, Room #ATO- 1788, P. O. Box 10-3240, Anchorage, AK 99510-3240 (1R) Chart received: Report mailed: 08-15-94 08-26-94 KINLEY CALIPER TALLY SHEET (Composite) DRILL SITE #09-02 Survey # 24111 August 8, 1994 5 1/2" 17# 13CR-80 Body: 0.304 Upset: 0.304 Penetrations Over 85% (Possible Hole) # of Jts Penetrations 41 - 85% (Poor) Penetrations 21 - 40% (Fair) Penetrations 11 - 20% (Good) Penetrations 1 - 10% (Very Good) No Penetrations Recorded 160 TOTAL JOINTS SURVEYED: 160 ( Includes 1 Pup Joints ) KINLEY CORROSION PROFILE DRILL SITE #09-02 PRUDNOE BA Y, AK August 8, 1994 SURVEY # 24111 5 1/2" 17# 13CR-80 CORROSIVE DA MA GE FREQUENCY DISTRIBUTIONS MAXIMUM PENETRATION NUMBER OF JOINTS % WALL LOSS CONFIGURATION NUMBER OF JOINTS ... DESCRIPTION BODY PENETRATIONS G£M GLM (2) GLM (3) GLM (4) GLM (5) GLM GLM (7) GLM (8) G£M (9) GLM (10) GLM (11) EOS in Jr. #169 ~ 10, 100' (W£Mi % WALL LOSS 20 40 60 80 ~ 12 t'8 24 PIT DEPTH (1/100 inch) 3O 1o0 KINLEY CALIPER JOINT TABULATION SHEET JOINT NO 5 1/2" 17# 13CR-80 Body: 0.304 Upset: 0.304 Chart # X1633 Feeler Ratio I · I MAXIMUM MAXIMUM UPSET/MAKEUP BODY PENETRATION PENETRATION DRILL SITE #09-02 PRUDHOE BAY, AK Storey # 24111 August 8, 1994 Run # 1 COMMENTS Lower Pup Joint 1st full length Joint DAMAGE PROFILE 0 (% WALL) 1( -BODY I -UPSET JOINT NO KINLEY CALIPER JOINT TABULATION SHEET 5 1/2" 17# 13CR-80 Body: 0.304 Upset: 0.304 Chad # X1633 Feeler Ratio I · 1 DRILL SITE #09-02 PRUDHOE BAY, AK Survey # 24111 August 8, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY PENETRATION PENETRATION COMMENTS DAMAGE PROFILE 0 (% WALL) 1( -BODY I -UPSET KINLEY CALIPER JOINT TABULATION SHEET JOINT NO 5 1/2" 17# 13CR-80 Body: 0.304 Upset: 0.304 Chart # X1633 Feeler Ratio I · I MAXIMUM MAXIMUM UPSET/MAKEUP BODY PENETRATION PENETRATION COMMENTS DRILL SITE #09-02 PRUDHOE BAY, AK Survey # 24111 August 8, 1994 Run # 1 DA MAG E PROFILE 0 (% WALL) -BODY I -UPSET JOINT NO 1151 1152 1~53 I 154 1~55 1156 1157 1158 1159 KINLEY CALIPER JOINT TABULATION SHEET ,5 1/2" 17# 13CR-80 Body: 0.304 Upset: 0.304 Chad # X1633 Feeler Ratio I · 1 DRILL SITE #09-02 PRUDHOE BAY, AK Survey # 24111 August 8, 1994 Run # 1 MAXIMUM UPSET/MAKEUP PENETRATION % INCHES MAXIMUM BODY PENETRATION % INCHES COMMENTS GLM (10) DA M AG E PROFILE ,, (% WALL) '~ GLM (11); Survey ends in Jt. #159 @ 10,100' (WLM) BODY ! - UPSET · o. · · .. ....: . ,. . .o' ,:.. ·. · .;....' : · ':: .... ':.. " .. · .z.·. . ~., ...~ '~, ~ ~. : . ...... ~° . . . . ' .. ..o ~.o .j,...~' -'.. .... o.'. *.... '. ~. '.. .. * :~. . . ,'. · · ,. . : · · o .. ,: · :. . ~. .. ..- . · .. .. ., .; ~ . . .'... , ~.: *~ .- *. . ~. _ · . .. · . · . 'ii: . . . .. :*-- , .-;., .' [ ..~ . . .. .. . .. ~ · . . ..o · . ; . .. o. .- I Company LIBRARY T.~PE CURVE SPECIFICATIONS ARCO Alaska, !nc. Well D.S. 9-2 ECC~ 2081 Field County, State (Abbrev.) Prudho e Bay _.~ _.~ ~,%%B~ North Slope, Alas.~,%~00~ ' Date ~%B\~'' '~'~ DELIVERY DATE . Scandard Curve , . Logs Used .11/.18/84 9/lo/77 Scale ~ CCL : ' ' Files' i-3 Casing Collar Loca:or [ SSN LSN , GR CNAV Compensated Neutron t' 60 - 0 Short Space i. t 5O - 550~ Long Space 0 - 200 Gamma Ray- 0 - 100, 100 - 200 File 4 Average CN 60 - 0 '* REEL HEADER 'EEL NAME : ;ATE : ,RIGIN : FSYS iERVICE NAME: B!TL!S EEL CONTINUATION NUMBER: 01 REVIOUS REEL NAME : "OMMENTS: DRESSER ATLAS LIS CUSTOMER TaPE --- CRE~TED BY SDS oROG~aM R 2.0 ENGTH: 132 BYTES * TAPE HEADER aPE NAME : ATE : RiGIN : FSYS ERViCE NAM=: PASS 1 aPE CONTINUATION NUMBER: 01 ;REVIOUS TAPE NANE : ]OMMENTS: ~ENGTH: 132 BYTES * FILE HEADER # I ** 'iLE NAME: PASS 1,O01 'ERVICE NAM=: .'ERSiON # : 1 .'ATE: 85/11/20 :AX RECORD LENGTH: 102~ BYTES ~iLE TYPE: LO ~REVIOUS FILE NAME: , ~* !NFCRMATICN RECORDS ** MNEM CONTENTS APIN : 5002920198 CN : ARCC aLASKa, iNC. WN : D,S, ~-2 FN : PP, U[:HOE BAY COUN : NORTh SLOPE STAT : ALASKA LOC : 150.00 FORMAT ** UNITS ENTRY BLOCKS 'YPE ENTRY CESCRZPTiON 9 11 0 I DEPTHS DECREASE 6C.0 FRAME SPACING · lIN FRAME SPACING UNITS 31 MAXIMUM FRAMES /R :CORD TERMINATOR -0,500 LEVEL SPACING ']ATUN SP~CIFIC~Ti0N BLOCKS -URVE "'ME REPR CODm_ S~Z=~ ~ SAMPLE UNTTS~ i I i i ii i I i CCL 68 4 I DIM ** ij TEN 68 4 I LBF ' SPD 68 4 I F/MN FIWCN 68 4 1 VER ** FORMAT ** TYPE SEF~ MAX F-IL ENTRY BLOCKS ENTRY DESCRIPTION 4 -1 DEPTHS Dr-CREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 31 MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 L r-VE L ',SPACING DATUM SPECIFICATION BLOCKS CURVE REPR ,NAME CODE SIZE SAMPLE UNITS MJLSN 68 4 I CPS SSN 68 4 I CPS GR 68 4 I API CCL 68 4 1 DIM WTEN 68 4 1 LBF SmD 68 4 1 F/MN C'N 68 4 I % S, DATA ** DEPTH 11031.CC0 FT' 3362.256C M LSN 24.997 SSN TEN 228.727 SPD DEPTH 11000.CC0 FT LSN 25.067 TEN 386.540 -- 4 8 9 11 o DEPTH 10900.CC0 FT LSN 48.126 T=N~ -6 . 127 CuRiDEPTM 10800.C. C0 NAMtLSN 56.633 ---t TEN -0.655 128.g89 16.998 3352.807C M r. SSN 110.116 SPD 14.976 t - 3322.327C M SSN 173.531 SPD 13.664 FT 329'1.847C M SSN 198.864 SDD 15.479 LSN! SSN Dm GR I_- CCL LS TEN TE SPDI CN DE ** LS TE PTM 10700.CC0 FT N 83.685 N 4.6~4 326t.367C M SSN 227.424 SPD 12.357 PTH I 0631 . 5CC FT N 64.938 N -5.875 3240.488C M SSN 224.445 SPD 12.779 9R GR CN GR GR GR CN GR CN 34.0C8 49.159 ~1.8~4 49.7~C 2C.6~7 118 41.62C 35.694 85.974 25.274 124.473 34.861 CCL CCL CCL CCL CCL CCL -5.900 -~'. O00 -4 · -5.000 -_ -4.000 -5.000 S'TA RTiNG DEPTH E N'DI NG DEPTH =11 031. 000 FT =105:31.500 FT ** FILE TRAILER ** FILE NAME: PASS 1.001 SERVICE NAME: VERSION # : 1 DATE: MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FILE 3362.2560 3240.4880 ,3 ** FILE HEADER # 2 ** FILE NAME: PASS 2.002 SERVICE NAME: VERSION ~ : 1 DATE: 85/11/20 MAX RECORD LENGTH: 1024 FILE TYPE: LO PREVIOUS FILE NAME: ** INFORMATION RECORDS ** MNEM CONTENTS lliI m APIN : 5002920198 CN : ARCO ALASKA, WN : C.S. 9-2 FN : PRUDHOE BAY COUN : NORT~ SLOPE STAT : ALASKA LOC : 150.00 iNC. ** ~ORMAT ** BYTES UNITS TYPE 8 9 11 '0 D&T CUR NAM L SN SSN GR COL TEN SPD CN ENTRY ~LOCKS ENTRY CESCRIPTION 1 BEPTHS DECREASE 6C.0 FRANE SPACING .lIN FRAME SPACING UNITS 31 ~X!MUM FRaMES/RECORD TmR~INATCR -0,500 LEVEL SPACING UM SPECIFICATION BLOCKS VE E REPR CODE SIZE SAMPLE UNITS 68 4 I CPS 68 4 1 CPS- 68 4 I API 68 4 I DIM 68 4 I LBF 6~ 4 1 F/MN 68 4 I % ** FORMAT ** -~ EN'TR Y BLOCKS TYPE ENTRY DESCRIPTION 4 I DEPTHS DECREASE 8 6C.0 FRAME SPACING 9 ..lIN FRAME SPACING UNITS 11 31 MAXIMUM FRAMES/RECORD 0 TERFINATOR -0,500 LEVEL SPACING DATUM SPECIFICATION BLOCKS 'URVE REPR NAME CODE SIZE SAMPLE ~NITS ~SN 68 4 1 CPS SSN 68 4 1 CPS SR 68 4 I ~PI CCL 68 4 I DIM TEN 68 4 1 LBF SPD 68 4 I F/MN CN 68 4 I % ** DATA ** gEPTH 11019.000 FT 3358.595C M LSN 20.998 SSN I C9,989 TEN -54,=.94 SPD 1 .COO GR CN DEPTH 11COO.CCO FT 3352.8070 M LSN 24,395 SSN 1C9.57B TEN 436,&77 SPO 15,074 GR CN DEPTH 10900.0C0 FT 3322.3270 M LSN 45,940 SSN 170.~12 TEN 11 .859 SPD 1~.$10 OR CN OEPTH 10800.000 r-T 3291.847C M LSN 59.914 SSN 203,288 TEN 12,93~ SmO 16,514 t ' DEPTH 10700.0C0 FT 3261.3670 M GR CN LSN 70.549 SSN 216.431 TEN -11 .880 SPD 17,329 CN DEPTH 10635.5C0 FT 3241,707C M LSN 34,493 SSN 158.726 TEN -4,$66 SPD 14,817 GR CN STARTING DEPTH :11019.000 r-T ENDING D:PT-H =10635.500 FT 3~58,5980 M 3241,7C70 M 36,624 6~,344 37,524 51,48C 23,7C9 3~,815 38.723 33,924 27.2CS 129,415 53,3~C CCL CCL CCL CCL CCL CCL -5.000 -5.000 -~.oeo -5.000 -'.uO0 ** FILE TRAILER ** FiLE NAME: P$SS 2,002 SERVICE NAME: VERSION # : 1 DATE: 85/11/ F'I'L E TypE: NEXT FILE NA~E: ** FILr- HEADER # 3 ** FILE NAME: P~SS 3.003 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 MAX RECORD LENGTM: FiLE TYPE: LC PREVIOUS FILE N~ME: 1024 ** INFORMATION RECORDS ** BYTES MNEM CONT:NTS APIN : 50C2920198 CN : ARCO ALASKA, WN : D.S. 9-2 FN : PRUDHCE BAY COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 ** FORMAT ** I NC. UNITS ENTRY BLOCKS TYPE ENTRY ~ 1 8 60.0 9 .lIN 11 31 0 -0.500 DATUM SPECiF DESCRIPTION D=P'THS D~~ . ~ _~R:ASE · mRAM~. SD~CIN~. -~ FRAME SP~CZNG UNITS MAXIMUM SR~MES/~ECORD T:R~INATOR LEVEL SPACING IC~TICN BLOCKS CURVE REPR NAM: CODE SIZE SAMPLE bNITS LSN 68 4 1 CoS SSN 68 4 1 CPS GR 68 4 I ~PI COL 68 4 I DIM TEN 68 4 I L:F~ SPD 68 ¢ I :/MN CN 68 4 1 ** FORMAT ** TYPE 8 9 11 0 ENTRY · ENTRY 1 60 .o .lIN 31 mN_ ~.LOCKS C:SCRiPTION DEPTHS DECREES: FRANE SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERk, INATOR t "" V ,u t ]~TUM ~PEC!FICATION BLOCKS ]URVE REPR W&ME CODE SIZE SAMPLE UNITS _SN 68 4 I CPS ]SN 68 4 I CPS DR 68 4 I ~PI iCL 68 4 I ~IM TEN 68 4 I LBF SPD 68 4 I F/MN 3N. 68 4 I % ** DATA ** ]EPTH 11020.000 FT 3358.903C M _SN 27.997 SSN 113.989 TEN -57.944 SPD O.CO0 GR CN 3EPTH 11000.C. C0 FT 3352.807C M LSN 24.713 SSN 111.528 TEN 365.191 SPD 11.932 GR CN gEPTH 10900.C00 FT 3322.327~ M LSN 46.469 SSN 168.516 TEN 7.330 SPD 12.692 GR CN DEPTH 10800.C00 FT 3291.8476 M LSN 47.148 SSN 166.832 TEN 11.984 SPD 13.042 GR CN SEPTH 10700.000 r-.T 3261.3570 M LSN 77.0~9 SSN TEN -1.082 SPD 220.650 13.154 GR CN DEPTH 10636.500 FT 3242.0120 M LSN 3Z.864 SSN TEN 4.585 SPD STARTING DEPTH =1102C.000 =T ENDING DEPTH :10636.500 FT 158.581 GR 12.0~7 CN t , 3~55.¢03~ 3242.0120 ** FILE TRAILER FILE NAME: PASS SERVICE NAME: VERSION # : 1 D~TE: 85/11/ MAXIMUM LENGTh: FILE TYPE: LO NEXT FIL~ NAME: 3.003 1024 ** T~PE TRAILER ** TAPE NAME: SERVICE NAME: PASS 3 DATE. ORIGIN O: DATA: FSYS ~AD: r~TTNII~TT~N # : 01 3~.624 44.173 42.024 51.846 25.522 37.43C 34.173 36.103 ~ 210 2~ .877 135.517 CCL CCL CCL CCL CCL CCL -5.000 -5.000 · -5.000 -5.000 -5 COMMENTS: ~* REEL TRAILER *~ REEL NAME: SERVICE NAME: BITLIS DATE : ...... ORIGIN OF DATA: FSYS REEL CONTINUATION # : 01 NEXT R:EL NA~E: COMMENTS: DRESSER ATLAS LIS CUSTOMER TAPE --- CREATED BY SDS FROGRAM R 2.0 REEL HEADER - 1 TAPE HEADER - 1 rILE HEADER - 3 INFORMATION - 3 :ORMAT - 6 SATA - 76 TABLE DUMP - 3 FILE TRAILER - 3 TAPE TRAILER - 1 REEL TRAILER - I TOTAL RECORDS: '98 * ALASKA COMPUTING CENTER * ****************************** * * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 9-2 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API AFUMBER : 50-029-20198-00 REFERENCE NO : 97154 RECEIVEU AUG 1 5 1997 Alaska Oit & Gas Cons. C~mmission Anchorage * ALASKA COMPUTING CENTER . ............................ ....... SCHLUMBERGER ....... * ............................ COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 9-2 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20198-00 REFERENCE NO : 97154 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/08/ 7 ORIGIN : FLIC REEL NAME : 97154 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 9-2, PRUDHOE BAY, 50-029-20198-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/08/ 7 ORIGIN : FLIC TAPE NAME : 97154 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 9-2, PRUDHOE BAY, 50-029-20198-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 9-2 API NUMBER: 500292019800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7-AUG-97 JOB NUMBER: 97154 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: DOUG CISMOSK SURFACE LOCATION SECTION: 2 TOWNSHIP: 1 ON RANGE: 15E FNL: FSL: 170 FEL: 697 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 54. O0 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 7. 000 11097.0 29. O0 2ND STRING 7. 000 2985.0 26. O0 3RD STRING 5. 500 10151.0 17. O0 PRODUCTION STRING 4. 500 10278. 0 12. 60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH 88888.0 88887.0 10834.5 10833.5 10814.5 10815.0 10807.5 10807.5 10805.0 10804.5 10800.5 10800.5 10794.5 10795.5 10785.5 10785.5 10772.0 10771.0 10735.5 10734.0 10711.5 10712.0 10690.0 10690.5 10684.0 10686.0 10680.5 10681.0 10678.0 10679.0 10635.0 10636.0 10602.0 10603.5 10562.5 10562.5 10559.0 10559.0 10536.5 10536.0 10503.0 10502.0 100.0 99.0 $ SIGM ....... 88887 0 10833 5 10815 0 10807 5 10804 5 10800 5 10795 5 10785 5 10771 0 10734 0 10712 0 10690 5 10686 0 10681.0 10679.0 10636.0 10603.5 10562.5 10559.0 10536.0 10502.0 99.0 REFIARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA ACQUIRED ON D.S. 9-2. DUE TO SCALE BUILDUP ON CASING IT WAS DIFFICULT TO CORRELATE BASELINE PASS #1 CASED HOLE GAM~A RAY TO THE BASE GAMMA RAY, INSTEAD BASELINE PASS #1 SIGMA WAS CORRELATED TO THE BASE GAF~A RAY FOR DEPTH MATCHING. BASELINE PASS #1 CASED HOLE GAMSL% RAY WAS CARRIED WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10853.0 10484.0 TDTP 10868.0 10484.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. THIS FILE CONTAINS CASED HOLE TDTP BASELINE PASS #1 DATA. THIS DATA HAS BEEN CLIPPED FOR INVALID DATA READINGS AND IS DEPTH MATCHED TO THE BASE GAFk4A RAY PROVIDED BY ARCO. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: TYPE REPR CODE VALUE 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100713 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 100713 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI TDTP PU-S 100713 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 100713 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 100713 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 100713 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 100713 O0 000 O0 0 1 1 1 4 68 0000000000 LCO1 TDTP 100713 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 100713 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 100713 O0 000 O0 0 i 1 1 4 68 0000000000 TCAN TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 100713 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 100713 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 100713 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 100713 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 100713 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11149.500 SIGM. TDTP -999.250 CPHI.TDTP -999.250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP LCO1. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR. BCS DEPT. 10450. 000 SIGM. TDTP -999. 250 CPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 82.332 -999.250 -999.250 -999.250 -999.250 -999.250 182.734 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 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: O. 5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10853.0 10484.0 TDTP 10868.0 10484.0 $ 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 88887.0 88888.0 10862.5 10862.5 10853.5 10853.0 10842.0 10841.0 10835.5 10835.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 10834.0 10833.0 10829.5 10831.0 10827.0 10827.5 10820.0 10821.0 10814.0 10815.0 10808.5 10809.0 10804.0 10804.5 10802.0 10802.5 10799.5 10800.5 10798.5 10799.0 10790.0 10791.0 10786.5 10787.5 10785.0 10785.5 10777.0 10777.0 10771.0 10770.5 10771.5 10764.5 10764.0 10762.0 10761.5 10753.0 10752.5 10751.0 10751.0 10747.5 10747.0 10747.5 10728.0 10727.5 10725.0 10725.0 10717.0 10717.5 10710.0 10711.0 10708.0 10708.5 10701.0 10701.5 10697.0 10698.0 10695.5 10696.5 10688.0 10690.0 10684.5 10687.0 10680.5 10682.0 10678.0 10679.5 10673.0 10674.5 10640.5 10642.0 10629.5 10631.0 10620.0 10621.5 10601.0 10603.5 10599.5 10601.5 10586.0 10588.0 10580.5 10583.0 10579.0 10579.0 10573.5 10574.5 10572.0 10572.5 10561.0 10562.0 10555.5 10556.5 10543.5 10543.5 10536.5 10536.5 10528.5 10528.0 10527.5 10527.5 10513.0 10511.5 10505.0 10505.0 10501.5 10501.0 10495.5 10496.5 10492.5 10494.0 10487.5 10487.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 100.0 $ 99.5 100.0 RE~RKS: THIS FILE CONTAINS CASED HOLE TDTP BASELINE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH BASELINE PASS #2 TO GRCH BASELINE PASS #1, AND SIGM BASELINE PASS #2 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 $ 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100713 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 100713 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI TDTP PU-S 100713 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 100713 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 100713 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 100713 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 100713 O0 000 O0 0 2 1 1 4 68 0000000000 LCO1 TDTP 100713 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 100713 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FBAC TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 100713 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 100713 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 100713 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 100713 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10868. 000 SIGM. TDTP 20. 430 CPHI. TDTP 52. 895 SBMF. TDTP SBHN. TDTP 49. 271 SIGC. TDTP O. 906 SIBH. TDTP 49. 271 TRAT. TDTP LCO1. TDTP 3. 064 SDSI. TDTP O. 470 BACK. TDTP 127. 250 FBAC. TDTP TCAN. TDTP 42251 . 055 TCAF. TDTP 13128. 951 TCND. TDTP 21615. 836 TCFD. TDTP TSCN. TDTP 5272. 337 TSCF. TDTP 1720. 606 INND. TDTP 1738. 005 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1520. 000 CCL. TDTP O. 000 36.554 2.188 145.125 5634.999 323.521 DEPT. 10483 . 500 SIGM. TDTP -999 . 250 CPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 LCO1.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 72. 750 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10853.0 10478.0 TDTP 10868.0 10478.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10857.5 10847.0 10843.0 10841.0 10838.5 10837.0 10836.5 10835.0 10832.5 10821.5 10819.5 10813.5 10804.0 10801.5 10799.5 10797.5 10789.5 10786.0 10784.5 10776.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.0 88888.0 10841.0 10840.0 10838.5 10835.5 10822.5 10802.5 10799.0 10791.5 10787.5 10785.5 10777.5 10857.5 10847.0 10843.5 10837.0 10833.0 10820.5 10815.0 10804.5 10801.0 10785.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 10 10776.0 10771.0 10770.5 10766.5 10761 5 10757 5 10752 5 10750 0 10747 0 10745 5 10742.0 10737.0 10734.0 10727.0 10723.5 10715.5 10709.5 10701.0 10694.5 10686.5 10680.0 10676.5 10672.5 10672.0 10646.0 10642.5 10630.5 10628.5 10628.0 10619.0 10615.5 10600.5 10599.0 10582.0 10560.0 10553.5 10547.5 10542.0 10541.5 10539 0 10535 5 10522 0 10515 0 10513 5 10507 0 10504 5 105OO. 5 10489.5 10489.0 100.0 $ REMARKS: 10771.0 10766.5 10762.0 10757.5 10752.5 10747.0 10742.0 10737.0 10728.0 10717.5 10711.5 10703.0 10696.5 10689.0 10674.5 10645.0 10633.5 10630.5 10621.5 10601.5 10583.0 10555.0 10549.5 10543.5 10515.5 10507.5 10501.0 10489.0 100.0 10776.5 10771.5 10751.5 10745.0 10734.5 10724.0 10682.0 10679.0 10675.0 10647.5 10631.5 10620.0 10604.0 10561.5 10542.0 10540.0 10536.5 10523.0 10511.0 10505.0 10487.5 98.0 THIS FILE CONTAINS CASED HOLE TDTP BASELINE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH BASELINE PASS #3 TO GRCH BASELINE PASS 1, AND SIGM BASELINE LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 11 PASS #3 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100713 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 100713 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI TDTP PU-S 100713 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 100713 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 100713 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 100713 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 100713 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 100713 O0 000 O0 0 3 1 1 4 68 0000000000 LCO1 TDTP 100713 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100713 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 100713 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI-dI. SS MOD l~IVlBSAMP ELEIVI CODE (HEX) TSCF TDTP CPS 100713 INND TDTP CPS 100713 INFD TDTP CPS 100713 GRCH TDTP GAPI 100713 TENS TDTP LB 100713 CCL TDTP V 100713 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. 10868. 000 SIGM. TDTP 37.192 CPHI. TDTP 61. 602 SBHF. TDTP SBHN. TDTP 52.396 SIGC. TDTP O. 000 SIBH. TDTP 53. 506 TRAT. TDTP LCO1. TDTP 2. 856 SDSI. TDTP 1. 021 BACK. TDTP 159. 068 FBAC. TDTP TCAN. TDTP 44003. 383 TCAF. TDTP 14281.264 TCND. TDTP 21289. 742 TCFD. TDTP TSCN. TDTP 5124.624 TSCF. TDTP 1794.564 INND. TDTP 1815.010 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1670. 000 CCL. TDTP O. 000 DEPT. 10476. 000 SIGM. TDTP 36. 740 CPHI. TDTP 83. 068 SBHF. TDTP SBHN. TDTP 52.417 SIGC. TDTP O. 000 SIBH. TDTP 53. 540 TRAT. TDTP LCO1. TDTP 4. 870 SDSI. TDTP 1.271 BACK. TDTP 125. 553 FBAC. TDTP TCAN. TDTP 17513. 375 TCAF. TDTP 3657. 057 TCND. TDTP 15631. 723 TCFD. TDTP TSCN. TDTP 1992.128 TSCF. TDTP 409. 054 INND. TDTP 1634. 737 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1615. 000 CCL. TDTP O. 000 45. 869 2. 071 115. 828 5780. 828 295. 845 46.582 2.581 27.390 3261.868 279.542 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 13 FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O . 5000 FILE SUF~VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10853.0 10452.0 TDTP 10868.0 10452.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10862.0 10842.0 10837.5 10836.0 10827.5 10821.0 10815.0 10804.5 10802.5 10800.5 10799.0 10795.5 10790.0 10787.0 10785.5 10781.0 10777.5 10777.0 10771.5 10768.0 10767.5 10764.0 10753.5 10751.0 10745.5 10743.0 10738.0 10735.0 10728.0 10722.5 10717.0 10696.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.0 88888.5 10862.5 10841.0 10837.0 10835.5 10827.5 10821.5 10815.5 10815.0 10804.5 10802.5 10800.5 10799.0 10797.0 10791.0 10787.5 10785.5 10781.0 10777.0 10777.0 10771.0 10767.0 10766.5 10763.0 10752.5 10751.0 10744.5 10745.0 10742.0 10737.0 10734.5 10727.5 10722.5 10717.5 10698.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 14 10695.5 10696.5 10690.5 10691.5 10687.5 10689.0 10677.5 10679.0 10657.0 10658.0 10644.0 10645.0 10640.0 10641.5 10620.0 10621.5 10601.0 10603.5 10599.5 10601.5 10592.5 10594.5 10575.5 10577.0 10566.0 10565.0 10564.5 10565.0 10561.5 10562.0 10549.5 10550.0 10540.0 10540.0 10539.5 10540.0 10536.0 10536.0 10534.0 10534.0 10533.0 10533.0 10527.5 10527.5 10524.0 10523.5 10515.5 10515.0 10511.5 10511.0 10507.5 10507.5 10501.5 10501.0 10498.5 10498.5 10490.5 10489.5 10489.5 10489.0 100.0 99.5 99.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH BORAX PASS #1 TO GRCH BASELINE PASS #1, AND SIGM BORAX PASS #1 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 15 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100713 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 100713 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI TDTP PU-S 100713 O0 000 O0 0 4 1 I 4 68 0000000000 SBHF TDTP CU 100713 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 100713 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 100713 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 100713 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 TDTP 100713 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 100713 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 100713 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 100713 O0 000 O0 0 4 i 1 4 68 0000000000 GRCH TDTP GAPI 100713 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 100713 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 100713 O0 000 O0 0 4 1 i 4 68 0000000000 ** DATA ** DEPT. 10868.500 SIGM. TDTP 16. 602 CPHI. TDTP 41. 197 SBHF. TDTP SBHN. TDTP 95. 834 SIGC. TDTP O. 000 SIBH. TDTP 123. 018 TRAT. TDTP LCO1. TDTP 2. 538 SDSI. TDTP O. 436 BACK. TDTP 190. 670 FBAC. TDTP TCAN. TDTP 10662.100 TCAF. TDTP 4200. 744 TCND. TDTP 9456. 453 TCFD. TDTP TSCN. TDTP 2207. 895 TSCF. TDTP 869. 885 INND. TDTP 1862. 891 INFD. TDTP 82.938 1.879 135.047 2788.116 280.371 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 16 GRCH. TDTP -999.250 TENS. TDTP 1665. 000 CCL. TDTP DEPT. 10451. 000 SIGM. TDTP 46. 263 CPHI. TDTP SBHN. TDTP 96. 943 SIGC. TDTP O. 000 SIBH. TDTP LCO1 . TDTP 3. 343 SDSI. TDTP 1 . 905 BACK. TDTP TCAN. TDTP 6681 . 711 TCAF. TDTP 1876. 337 TCND. TDTP TSCN. TDTP 320. 551 TSCF. TDTP 95. 891 INND. TDTP GRCH. TDTP -999.250 TENS. TDTP 1710. 000 CCL. TDTP 0.000 46.416 SBHF. TDTP 124. 794 TRAT. TDTP 154. 718 FBAC. TDTP 6509. 911 TCFD. TDTP 1632. 873 INFD. TDTP O. 000 79.575 1.458 26.324 1478.553 249.182 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI1MBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10853.0 10478.0 TDTP 10868.0 10478.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 17 BASELINE DEPTH 88888.0 10856.0 10841.5 10835 0 10830 0 10828 0 10819 0 10813 5 10807 5 10803 0 10801 5 10789 0 10785 5 10784 0 10776.0 10770 5 10770 0 10763 5 10761 0 10757 5 10752 0 10750 0 10747 5 10746.5 10744.5 10742.0 10740.0 10737.0 10736.5 10728.0 10726.5 10723.5 10715 5 10713 0 10707 0 10703 5 10695 5 10694 0 10679 5 10676.5 10673 0 10671 5 10670 0 10642 5 10638 5 10631 0 10608 0 10604 0 10600 0 10598 5 10595 0 10581 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.0 88889.5 10841.5 10835.5 10829.0 10820.5 10802.5 10791.0 10787.5 10771.0 10764.0 10758.0 10752.5 10747.0 10742.5 10737.0 10727.5 10717.5 10709.0 10696.5 10675.0 10672.5 10645.0 10642.0 10633.0 10607.0 10601.5 10598.0 10857.5 10842.0 10830.5 10815.0 10809.5 10804.5 10785.5 10777.5 10771.0 10761.5 10751.5 10748.0 10745.0 10740.5 10737.0 10730.0 10724.0 10716.0 10706.5 10698.5 10681.5 10679.0 10674.5 10609.5 10603.5 10585.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 18 10580.0 10581.0 10576.0 10580.0 10571.0 10572.5 10560.0 10562.0 10555.0 10556.5 10549.0 10550.5 10535.0 10536.0 10526.0 10527.0 10510.5 10511.5 10506.5 10507.5 10504.0 10504.5 10500.5 10501.0 100.0 100.5 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH BORAX PASS #2 TO GRCH BASELINE PASS #1, AND SIGM BORAX PASS #2 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 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 7-AUG-1997 15:31 PAGE: 19 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100713 SIGM TDTP CU 100713 CPHI TDTP PU-S 100713 SBHF TDTP CU 100713 SBHN TDTP CU 100713 SIGC TDTP CU 100713 SIBH TDTP CU 100713 TRAT TDTP 100713 LCO1 TDTP 100713 SDSI TDTP CU 100713 BACK TDTP CPS 100713 FBAC TDTP CPS 100713 TCAN TDTP CPS 100713 TCAF TDTP CPS 100713 TCND TDTP CPS 100713 TCFD TDTP CPS 100713 TSCN TDTP CPS 100713 TSCF TDTP CPS 100713 INND TDTP CPS 100713 INFD TDTP CPS 100713 GRCH TDTP GAPI 100713 TENS TDTP LB 100713 CCL TDTP V 100713 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10869.500 SIGM. TDTP 18. 725 CPHI. TDTP 49.564 SBHF. TDTP SBHN. TDTP 97. 075 SIGC. TDTP O . 000 SIBH. TDTP 125. 005 TRAT. TDTP LCO1. TDTP 2. 841 SDSI. TDTP O. 543 BACK. TDTP 192. 826 FBAC. TDTP TCAN. TDTP 9880. 883 TCAF. TDTP 3478. 486 TCND. TDTP 8881. 049 TCFD. TDTP TSCN. TDTP 1763. 648 TSCF. TDTP 620. 878 IN-ND. TDTP 1782. 575 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1540. 000 CCL. TDTP O. 000 DEPT. 10478.500 SIGM. TDTP 41.181 CPHI.TDTP 56.378 SBHF. TDTP SBHN. TDTP 97. 733 SIGC. TDTP O. 332 SIBH. TDTP 126. 057 TRAT. TDTP LCO1. TDTP 3. 493 SDSI. TDTP 1. 993 BACK. TDTP 150. 546 FBAC. TDTP TCAN. TDTP 4938. 447 TCAF. TDTP 1331. 844 TCND. TDTP 6205. 482 TCFD. TDTP TSCN. TDTP 356.182 TSCF. TDTP 101.962 INND. TDTP 1645.347 INFD. TDTP GRCH. TDTP 72.438 TENS. TDTP 1695. 000 CCL. TDTP 2.398 84.913 1.987 137.955 2421.955 281.139 88.104 1.651 28.790 1381.035 250.180 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 2O **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP $ REMARKS: THE ARITHMETIC AVERAGE OF PASS 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 3 73 84 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 21 TYPE REPR CODE VALUE 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 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 100713 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PNAV CU 100713 O0 000 O0 0 6 1 1 4 68 0000000000 CPHI PNAV PU-S 100713 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PNAV CU 100713 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPNAV CU 100713 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PNAV CU 100713 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PNAV CU 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PNAV 100713 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PNAV CU 100713 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TCNDPNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 INND PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PNAV CPS 100713 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 PNAV 100713 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 100713 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10867.000 SIGM. PNAV 17.342 CPHI.PNAV 47.483 SBHF. PNAV 44.364 SBHN. PNAV 51.422 SIGC. PNAV 0.624 SIBH. PNAV 52.175 TRAT. PNAV 2.132 SDSI.PNAV 0.351 BACK. TDTP 46.901 FBAC. TDTP 84.154 TCAN. PNAV 33391.844 TCAF. PNAV 11002.086 TCND.PNAV 21735.508 TCFD.PNAV 5817.348 TSCN. PNAV 5272.271 TSCF. PNAV 1784.369 INND.PNAV 1828.373 INFD.PNAV 312.532 LCO1.PNAV 2.966 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 22 DEPT. 10483. 000 SIGM. PNAV -999.250 CPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 76.300 FBAC. TDTP 14.002 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 LCO1.PNAV -999.250 GRCH. TDTP 61. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SUM~3~Y VENDOR TOOL CODE START DEPTH TDTP 10868.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 10484.0 25-MAR-97 CP44.2 1331 25-MAR-97 10868.0 10868.0 10452.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 23 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY $ 10868.0 1800.0 NO TOOL NUMBER ........... TND- PC- 3 9 5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11097.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (?T) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/SEAWATER & BOR NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 RE~RKS: TIED IN TO SWS BHC DATED 3/10/76. PURPOSE OF THIS LOG WAS TO LOOK FOR A CHANNEL BEHIND PIPE CONFIRM THAT SQUEEZE PERFSARE HOLDING. THERE ARE TWO STRINGS OF CASING IN THE LOGGING INTERVAL WH ADVERSELY AFFECTS TPHI READING. THERE IS AN UP CHANNEL FROM THE UPPERMOST PERFORATED INTER SQUEEZE PERF APPEAR TO BE HOLDING. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP BASELINE PASS #1. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 24 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100713 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS1 CU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS1 PU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS1 CU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS1 CU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS1 CU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS1 CU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS1 100713 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PS1 100713 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS1 CU 100713 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PSi CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS1 CPS 100713 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS1 CPS 100713 O0 000 O0 0 7 I 1 4 68 0000000000 TENS PS1 LB 100713 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUMB IgIIMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GR PS1 GAPI 100713 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS1 V 100713 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10875.000 SIGM. PS1 16.483 TPHI.PS1 0.000 SBHF. PS1 SBHN. PS1 60.600 SIGC. PS1 0.000 SIBH. PSl 63.344 TRAT. PS1 LCO1.PS1 1093.271 SDSI.PSl 0.564 BACK. PSI 7.361 FBAC. PS1 TCAN. PS1 5447.686 TCAF. PS1 0.000 TCND.PS1 -999.250 TCFD.PS1 TSCN. PS1 1093.271 TSCF. PS1 0.000 I1TND.PS1 306.697 INFD. PS1 TENS. PSi 1485.000 GR.PS1 329.750 CCL.PS1 0.000 DEPT. 10483.500 SIGM. PS1 36.422 TPHI.PS1 76.368 SBHF. PS1 SBHN. PS1 54.197 SIGC. PS1 0.000 SIBH. PS1 56.389 TRAT. PS1 LCO1.PS1 4.426 SDSI.PS1 1.104 BACK. PSi 76.641 FBAC. PS1 TCAN. PS1 18892.129 TCAF. PS1 4309.829 TClTD.PS1 16145.219 TCFD. PS1 TSCN. PS1 2064.160 TSCF. PS1 466.410 Iig~iD.PS1 1736.880 INFD. PS1 TENS.PSi 1655.000 GR.PS1 65.000 CCL.PS1 0.000 101.069 0.000 2.629 -999.250 -0.089 48.200 2. 362 14.358 3572. 837 286. 054 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 26 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUM~Nh~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 10868.0 10484.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 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): 25-MAR-97 CP44.2 1331 25-MAR-97 10868.0 10868.0 10452.0 10868.0 1800.0 NO TOOL NUMBER ........... TND-PC-395 11097.0 CRUDE/SEAWATER & BOR THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 27 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO SWS BHC DATED 3/10/76. PURPOSE OF THIS LOG WAS TO LOOK FOR A CHANNEL BEHIND PIPE CONFIRM THAT SQUEEZE PERFS ARE HOLDING. THERE ARE TWO STRINGS OF CASING IN THE LOGGING INTERVAL WH ADVERSELY AFFECTS TPHI READING. THERE IS AN UP CHANNEL FROM THE UPPERMOST PERFORATED INTER SQUEEZE PERF APPEAR TO BE HOLDING. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP BASELINE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100713 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS2 CU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS2 PU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS2 CU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 28 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) SBHNPS2 CU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS2 CU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS2 CU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS2 100713 O0 000 O0 0 8 1 1 4 68 0000000000 LCO1 PS2 100713 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS2 CU 100713 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS2 CPS 100713 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS2 LB 100713 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS2 GAPI 100713 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS2 V 100713 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10875.500 SIGM. PS2 36.422 TPHI.PS2 76.368 SBHF. PS2 SBHN. PS2 54.197 SIGC. PS2 0.000 SIBH. PS2 56.389 TRAT. PS2 LCO1.PS2 4.426 SDSI.PS2 1.104 BACK. PS2 76.641 FBAC. PS2 TCAN. PS2 18892.129 TCAF.PS2 4309.829 TCND.PS2 16145.219 TCFD. PS2 TSCN. PS2 2064.160 TSCF. PS2 466.410 INND.PS2 1736.880 INFD. PS2 TENS. PS2 1085.000 GR.PS2 459.250 CCL.PS2 0.000 48.200 2.362 14.358 3572.837 286.054 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 29 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/ 7 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: 3 DEPTH INCREMENT: O . 5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10868.0 10478.0 TDTP LOG HEADER DATA DATE LOGGED: 25-MAR-97 SOFTWARE VERSION: CP44.2 TIME LOGGER ON BOTTOM: 1331 25-MAR-97 TD DRILLER (FT) : 10868.0 TD LOGGER (FT) : 10868.0 TOP LOG INTERVAL (FT) : 10452.0 BOTTOM LOG INTERVAL (FT) : 10868.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : TOOL NUMBER ........... TND-PC-395 11097.0 CRUDE/SEAWATER & BOR LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 3O WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO SWS BHC DATED 3/10/76. PURPOSE OF THIS LOG WAS TO LOOK FOR A CHANNEL BEHIND PIPE CONFIRM THAT SQUEEZE PERFS ARE HOLDING. THERE ARE TWO STRINGS OF CASING IN THE LOGGING INTERVAL WH ADVERSELY AFFECTS TPHI READING. THERE IS AN UP CHANNEL FROM THE UPPERMOST PERFORATED INTER SQUEEZE PERF APPEAR TO BE HOLDING. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP BASELINE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 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 7-AUG-1997 15:31 PAGE: 31 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 9 1 1 4 68 0000000000 DEPT FT 100713 SIGM PS3 CU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS3 PU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS3 CU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPS3 CU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS3 CU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS3 CU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS3 100713 O0 000 O0 0 9 1 1 4 68 0000000000 LCO1 PS3 100713 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS3 CU 100713 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 INNDPS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS3 CPS 100713 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS3 LB 100713 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS3 GAPI 100713 O0 000 O0 0 9 1 i 4 68 0000000000 CCL PS3 V 100713 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10874.500 SIGM. PS3 37.442 TPHI.PS3 71.368 SBHF. PS3 SBHN. PS3 50.895 SIGC. PS3 0.000 SIBH.PS3 51.105 TRAT. PS3 LCO1.PS3 4.355 SDSI.PS3 1.187 BACK. PS3 109.025 FBAC. PS3 TCAN. PS3 17941.945 TCAF. PS3 4134.349 TCND.PS3 16289.990 TCFD.PS3 TSCN. PS3 2042.188 TSCF. PS3 468.898 INND.PS3 1695.820 INFD.PS3 TENS.PS3 1265.000 GR.PS3 438.500 CCL.PS3 0.000 DEPT. 10476.500 SIGM. PS3 36.246 TPHI.PS3 74.554 SBHF. PS3 SBHN. PS3 50.434 SIGC. PS3 0.000 SIBH. PS3 50.434 TRAT. PS3 LCO1.PS3 4.370 SDSI.PS3 1.183 BACK. PS3 127.227 FBAC. PS3 TCAN. PS3 18011.195 TCAF. PS3 4062.279 TCND. PS3 16035.559 TCFD.PS3 TSCN. PS3 2062.769 TSCF. PS3 472.004 INND.PS3 1598.798 INFD.PS3 TENS.PS3 1635.000 GR.PS3 88.875 CCL.PS3 0.000 43.309 2.315 21.048 3546.508 271.755 45.694 2.406 26.916 3470.348 266.286 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 32 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 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: 4 DEPTH INCREMENT: O. 5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10868.0 10452.0 TDTP $ LOG HEADER DATA DATE LOGGED: 25-MAR-97 SOFTWARE VERSION: CP44.2 TIME LOGGER ON BOTTOM: 1331 25-MAR-97 TD DRILLER (FT) : 10868.0 TD LOGGER (FT) : 10868.0 TOP LOG INTERVAL (FT) : 10452.0 BOTTOM LOG INTERVAL (FT) : 10868.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 33 TDTP THERMAL DECAY TND-PC-395 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11097.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/SEAWATER & BOR NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO SWS BHC DATED 3/10/76. PURPOSE OF THIS LOG WAS TO LOOK FOR A CHANNEL BEHIND PIPE CONFIRM THAT SQUEEZE PERFS ARE HOLDING. THERE ARE TWO STRINGS OF CASING IN THE LOGGING INTERVAL WH ADVERSELY AFFECTS TPHI READING. THERE IS AN UP CHANNEL FROM THE UPPERMOST PERFORATED INTER SQUEEZE PERF APPEAR TO BE HOLDING. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP BORAX PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 34 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 100713 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM BX1 CU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI BX1 PU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF BXl CU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNBX1 CU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC BX1 CU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH BXl CU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT BX1 100713 O0 000 O0 0 10 1 1 4 68 0000000000 LCO1 BX1 100713 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI BX1 CU 100713 O0 000 O0 0 10 1 1 4 68 0000000000 BACK BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TCANBX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TCNDBX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 INNDBX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 INFD BX1 CPS 100713 O0 000 O0 0 10 1 1 4 68 0000000000 TENS BX1 LB 100713 O0 000 O0 0 10 1 1 4 68 0000000000 GR BX1 GAPI 100713 O0 000 O0 0 10 1 1 4 68 0000000000 CCL BX1 V 100713 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 35 ** DATA ** DEPT. 10876.500 SIGM. BX1 SBHN. BX1 88.088 SIGC.BX1 LCO1.BX1 1o727 SDSI.BX1 TCAN. BX1 6052°036 TCAF. BX1 TSCN. BX1 1210.428 TSCF.BX1 TENS.BX1 1190.000 GR.BX1 DEPT. 10446.500 SIGM. BX1 SBHN. BX1 97.345 SIGC.BX1 LCO1.BX1 10.663 SDSI.BX1 TCAN. BX1 5807.354 TCAF. BX1 TSCN. BX1 211.106 TSCF. BX1 TENS.BX1 1690.000 GR.BX1 17.862 TPHI.BX1 0.000 SIBH. BXl 0.791 BACK. BX1 3504.940 TCND.BXl 701.000 INND.BX1 485.250 CCL.BX1 49.243 TPHI.BX1 0.000 SIBH. BX1 4.184 BACK. BX1 1260.006 TCND.BX1 19.797 INND.BX1 682.500 CCL.BX1 15 105 232 8593 1693 0 68. 125. 315. 6076. 1709. O. 918 176 361 641 383 000 021 436 677 473 305 000 SBHF. BX1 TRAT. BX1 FBAC. BX1 TCFD.BX1 INFD.BX1 SBHF. BX1 TRAT. BX1 FBAC. BX1 TCFD.BX1 INFD.BX1 78.692 1.239 303.242 2704.749 268.527 82.172 1.849 278.579 822.561 250.243 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 11 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 SD?4~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 10868.0 10478.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 36 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): 25-MAR-97 CP44.2 1331 25-MAR-97 10868.0 10868.0 10452.0 10868.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... TDTP THERMAL DECAY $ TOOL lVIJMBER ........... TND- PC- 3 9 5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11097.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/SEAWATER & BOR NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO SWS BHC DATED 3/10/76. PURPOSE OF THIS LOG WAS TO LOOK FOR A CHANNEL BEHIND PIPE CONFIRM THAT SQUEEZE PERFSARE HOLDING. LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 37 THERE ARE TWO STRINGS OF CASING IN THE LOGGING INTERVAL WH ADVERSELY AFFECTS TPHI READING. THERE IS AN UP CHANNEL FROM THE UPPERMOST PERFORATED INTER SQUEEZE PERF APPEAR TO BE HOLDING. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP 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 92 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100713 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX2 CU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX2 PU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF BX2 CU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNBX2 CU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC BX2 CU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH BX2 CU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX2 100713 O0 000 O0 0 11 1 i 4 68 0000000000 LCO1 EX2 100713 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI BX2 CU 100713 O0 000 O0 0 11 1 1 4 68 0000000000 BACK BX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TCANBX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 38 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 11 1 1 4 68 0000000000 TCAF EX2 CPS 100713 TCNDBX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD BX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN BX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF BX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 INNDBX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 INFD BX2 CPS 100713 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX2 LB 100713 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX2 GAPI 100713 O0 000 O0 0 11 1 1 4 68 0000000000 CCL BX2 V 100713 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 10876.000 SIGM. BX2 49.243 TPHI.BX2 68.021 SBHF. BX2 SBHN. BX2 97.345 SIGC. BX2 0.000 SIBH. BX2 125.436 TRAT. BX2 LCO1.BX2 10.663 SDSI.BX2 4.184 BACK. BX2 315.677 FBAC.BX2 TCAN. BX2 5807.354 TCAF. BX2 1260.006 TCND.BX2 6076.473 TCFD.BX2 TSCN. BX2 211.106 TSCF. BX2 19.797 INND.BX2 1709.305 INFD.BX2 TENS.BX2 1025.000 GR.BX2 462.500 CCL.BX2 0.000 DEPT. 10477.000 SIGM. BX2 43.071 TPHI.BX2 SBHN. BX2 93.106 SIGC.BX2 0.359 SIBH.BX2 LCO1.BX2 3.408 SDSI.BX2 1.841 BACK.BX2 TCAN. BX2 4801.215 TCAF. BX2 1353.275 TCND.BX2 TSCN. BX2 350.808 TSCF. BX2 102.926 INND.BX2 TENS.BX2 1700.000 GR.BX2 80.688 CCL.BX2 51 088 118 654 150 701 6432 313 1747 828 0 000 SBHF. BX2 TRAT. BX2 FBAC. BX2 TCFD.BX2 INFD.BX2 82.172 1. 849 278.579 822. 561 250.243 83. 206 1. 546 28. 790 1442.272 248.378 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1997 15:31 PAGE: 39 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/08/ 7 ORIGIN : FLIC TAPE NAME : 97154 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 9-2, PRUDHOE BAY, 50-029-20198-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/08/ 7 ORIGIN : FLIC REEL NAME : 97154 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA INC, D.S. 9-2, PRUDHOE BAY, 50-029-20198-00 11 II ilii 111,1 11 II 1,1 11 11 11 I,). ii 1111,11, 111111 666666 666666 66 66 66 66666666 66666666 66 66 66 66 66 66 66 66 666666 666666 000000 000000 O0 / O0 00 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 00 0000 00 O0 O0 O0 O0 000000 000000 0000 00 000000 O0 O0 O0 O0 00 0000 O0 0000 O0 OO 00 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 0000 O 0 000000 7777777777 77777777'77 77 77 77 77 77 77 77 7:7 77 17 77 77 333333 3.33:333 33 33 33 33 33 33 33 33 33 ~ 333 33 333333 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 00 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 6~6666 666666 66 66 66 66666666 66666666 66 ~6 bb 66 666666 606666 66 66 66 66 7777777777 7777777777 77 77 ~77 7'7 77 77 ? 7 77 77 ? 7 '? 7 222222 222222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 U O D D D D U b D P U O D D tt O D D fi U D D U U D D UUBiJU DDDD *,5TgRT, USE~. PCAV [10707,bO362J dub i,~Ut~ITtiR SwS KblOL34 JUL,,. 79. *STAR'f* *&FAR'l* U;S~;~4 PCAt~ [107()7,60j62J 5HIP 5L(l. 1557 SBiP 8L~. 1557 [.)ATb 01-.~A¥-80 17:13:10 17:13:10 iiii, Ii iiiiii II ii I1 ii II I1 II Ii Ii, IiIlii IIIIIi Y~ ~Y ~Y 00000r) 00000o 333333 000000 000000 333.~3 ~ O0 O0 O0 O0 33 00 O0 00 O0 33 00 00O0 O0 0000 33 0 0 00 0 0 0 0 0 0 0 0 3 .~ 00 00 00 00 00 00 .:1 0 0 00 0 O 0 0 0 0 0 0 3 ~ 0000 O0 0000 O0 0000 O0 0000 O0 O0 O0 O0 O0 33 33 000000 000000 ~33i5~3 0000o0 000000 3:'~3 t.33 USE;R PCAb [10707,~0362J dOB ;SftlP SE; 5WS KL, lOE34 JOb-19. *STA,PT* OS~a:VEglf~.O0J<05'/>. [10707.6Q~ .J621 CREATED PRINTED: 01. MA~-80 17:1:4{ Sw I TCH~.;S: /~ Ib~]: F[JRI' /CUPIES: 1 /SPACING: I /I~iMi [': 107 1557 [)AI'E; O1-MAY-80 0.1-MAY-80 17:02:36 1'1:13:10 SC,Hi,0HbE,RGER COMPUTING CENTE~ 0707 , 60362 1112 B~TE8 : P. C. A. t.. CONT1NL]ATION NUI~BER: Ol REEL NAME: [,,IS FOR[v~AT CUSTOMEP TAPE [)ATE: 80/ 51 I TAPE; 'rAPE NAt~IE: 00362 SE]AV ICE N A~,~: kDIT TAP,E CONTINUATION NUtv~BE~R: 01 PREVIOU~ TAPE NAME;: C (~ ~ t~4 E N 'I' S: DATL,.: 801 51 1 HEADER LE;NGTi~i: 62 ByTE,S F ILK t'.~AHE: hDIT .001 ~'IAXI. NUD PHYSICAL ~E.:CUHD EENGrH: 1024 PREVIUU5 FlLk THF. ~iPST NPHI IS 'it-~E, DIGIT1ZLD CURVE FRLI~ A¢~ [)PEIq HOLE; LOG RUN [JN lO-N~AP-76, A[RCLJ OIL ~, GAS C[). O.S. 9-2 PRUDHOE bA}t 1ON N. Si,OPE ALASF. A 490 0 REP CODE DAT'Otq SPECI,F~C~'i~ION BLOCKS UNITS APl, AP1 APl APl FILL~ SIZE EXP PROC SAtq REP i')EPT SHIFI' 1~' ~I> 0 0 0 0 0 4 0 0 1 68 0 0 PU 42 68 3 0 0 4 0 0 1 68 0 0 G A P I, 4:2 ,i] 1 32 0 0 4 0 0 I 68 0 0 P lJ 4 2 6 8 3 0 0 4 0 0 1 6 8 0 0 C/C 42 42 I 0 0 4 0 0 1 b8 0 0 CPS q2 3~ 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 q 0 0 1 ~8 0 0 GAPI /42 31 32 0 0 4 0 0 1 68 0 0 P U q 2 6 8 3 0 0 4 0 0 I 6 8 0 0 C/C 42 42 I 0 0 4 0 0 I bS 0 0 CPS 4!2 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 b8 0 0 111 11100,000 I 1000. 000 10900.000 10800,000 10700.000 10600.000 10500.000 1 0445. 000 MNEP40~ lC NP?tl NCNL NRAT i~ C N b N p H 1 aP}t I N C r',, L Ni~AT NPHI. NCNb NFAT N P H 1 NCNb NRAT NPHI NC aL NRAT NC Nb NPH I NCNb NEA'I' 7.117 3.502 30. 938 117 . 117 .3. 502 28. 563 114.114 3.502 29.750 280.566 3.094 30.594 271.128 3.094 24.2@1 32 ~. 0 ~ 7 2.428 42.969 211.068 4.290 36.406 253.539 -999.250 -999.250 -999.250 -999.250 J~,N ES[iN lC GR NCNb ~CNb N C N L G}~ ~'CNL NCNL GR fCNL, FCNL NCNL GR FCNL NCNb ~CNL NCNB ~'C N L G~ NCNb 3 1 2 1 -9 -9 -9 -9 A L U E 21.900 32.604 24.367 21.900 32.604 24.367 400 894 24:3 v 20.400 94.5.~80 81. 424 21.400 84.942 71~.273 19.700 30.416 23.466 82.400 52.338 05.062 34.700 80.652 99.250 99.250 99.250 99.250 MNLMONIC NPHI ~CNb NPHI ~'CN~ NPHI GR ~ICNb NPH I GR I~CNb N P H 1 GR NPH 1 ~'CNb NPHI GA ~ CNb NPHI GR ~"'CNb NPHI GR VAbUg 29.880 48.100 64.779 29.880 48.100 64. 779 31.020 48.100 64.7'79 27.660 1'7.100 93.522 26.700 21.800 83.226 16.940 1.8.500 135.135 45.900 174.800 51.909 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC NRA'I NPHI. NRAT NPHI N R A 1~ NPHI N RAT NPH I NPHI N R A T NPHI NRAT .NPHi NRAt NPHI N R A I' N P H i 'VALUE: 3.530 36.440 3.530 36. 440 3.220 36. 440 3.056 27.940 3.010 27.080 2.31o 11.960 4.200 48.44:0 2.308 -99925.000 -999.250 -999.250 NUM.B..ER OF RECORDS: 69 LENGTH [JF RECORDS: i014 B~;TEi8 L ~'5; N G'I' t;.i O F L, A S T 1~. E C fl] F~ D: 6130 B Y T E S ~' i L E; T F:~ A I L E R I'APE, TP.A I LI~,iR 1,024 DATE: 80/ 5/ i SSSSSSS$ HH f-ii~ S S S S S S S S i~ i i. i-t ~i SS HH ~-~2 88 H~ HH 88 HH HH 88 HH HH IIIIlI 1IIIII II II ii I1 II II i1 II Ii II iiiiii iiiii. I PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP *STAP_Ti USkh PCAL [10701,60~62} JOb SHIP S~;~. ~557 DA'rE O1-MAX-80 Mi}[:]ITi)~ S~S KL10E34 JUL-'/9. *START* QULUL S'~I1CHES: /~Ib~.;:~"U~T /COPiES:I /SPACING: ! /LiNIT:I07 17:13:10 SnIP TO : ~SHIPPING I~SI~',UCTIE}NS 1 S ,S LJ E D 1 - ,~} A ¥ - 8 0 1 6: 1. 8 VEN~FDP, A~ C/1LiIF[]~i~iiA 91~003 PCCC B ~ GHB PCCC
